[Title 40 CFR ]
[Code of Federal Regulations (annual edition) - July 1, 1999 Edition]
[From the U.S. Government Printing Office]


          40



          Protection of Environment



[[Page i]]

          PART 60

                         Revised as of July 1, 1999

          CONTAINING
          A CODIFICATION OF DOCUMENTS
          OF GENERAL APPLICABILITY
          AND FUTURE EFFECT

          AS OF JULY 1, 1999
          With Ancillaries
          Published by
          the Office of the Federal Register
          National Archives and Records
          Administration

          as a Special Edition of
          the Federal Register



[[Page ii]]






                     U.S. GOVERNMENT PRINTING OFFICE
                            WASHINGTON : 1999



               For sale by U.S. Government Printing Office
 Superintendent of Documents, Mail Stop: SSOP, Washington, DC 20402-9328



[[Page iii]]




                            Table of Contents



                                                                    Page
  Explanation.................................................       v

  Title 40:

          Chapter I--Environmental Protection Agency..........       3

  Finding Aids:

      Material Incorporated by Reference......................    1193

      Table of CFR Titles and Chapters........................    1199

      Alphabetical List of Agencies Appearing in the CFR......    1217

      List of CFR Sections Affected...........................    1228



[[Page iv]]





                     ----------------------------

                     Cite this Code:  CFR
                     To cite the regulations in 
                       this volume use title, 
                       part and section number. 
                       Thus,  40 CFR 60.1 refers 
                       to title 40, part 60, 
                       section 1.

                     ----------------------------

[[Page v]]



                               EXPLANATION

    The Code of Federal Regulations is a codification of the general and 
permanent rules published in the Federal Register by the Executive 
departments and agencies of the Federal Government. The Code is divided 
into 50 titles which represent broad areas subject to Federal 
regulation. Each title is divided into chapters which usually bear the 
name of the issuing agency. Each chapter is further subdivided into 
parts covering specific regulatory areas.
    Each volume of the Code is revised at least once each calendar year 
and issued on a quarterly basis approximately as follows:

Title 1 through Title 16.................................as of January 1
Title 17 through Title 27..................................as of April 1
Title 28 through Title 41...................................as of July 1
Title 42 through Title 50................................as of October 1

    The appropriate revision date is printed on the cover of each 
volume.

LEGAL STATUS

    The contents of the Federal Register are required to be judicially 
noticed (44 U.S.C. 1507). The Code of Federal Regulations is prima facie 
evidence of the text of the original documents (44 U.S.C. 1510).

HOW TO USE THE CODE OF FEDERAL REGULATIONS

    The Code of Federal Regulations is kept up to date by the individual 
issues of the Federal Register. These two publications must be used 
together to determine the latest version of any given rule.
    To determine whether a Code volume has been amended since its 
revision date (in this case, July 1, 1999), consult the ``List of CFR 
Sections Affected (LSA),'' which is issued monthly, and the ``Cumulative 
List of Parts Affected,'' which appears in the Reader Aids section of 
the daily Federal Register. These two lists will identify the Federal 
Register page number of the latest amendment of any given rule.

EFFECTIVE AND EXPIRATION DATES

    Each volume of the Code contains amendments published in the Federal 
Register since the last revision of that volume of the Code. Source 
citations for the regulations are referred to by volume number and page 
number of the Federal Register and date of publication. Publication 
dates and effective dates are usually not the same and care must be 
exercised by the user in determining the actual effective date. In 
instances where the effective date is beyond the cut-off date for the 
Code a note has been inserted to reflect the future effective date. In 
those instances where a regulation published in the Federal Register 
states a date certain for expiration, an appropriate note will be 
inserted following the text.

OMB CONTROL NUMBERS

    The Paperwork Reduction Act of 1980 (Pub. L. 96-511) requires 
Federal agencies to display an OMB control number with their information 
collection request.

[[Page vi]]

Many agencies have begun publishing numerous OMB control numbers as 
amendments to existing regulations in the CFR. These OMB numbers are 
placed as close as possible to the applicable recordkeeping or reporting 
requirements.

OBSOLETE PROVISIONS

    Provisions that become obsolete before the revision date stated on 
the cover of each volume are not carried. Code users may find the text 
of provisions in effect on a given date in the past by using the 
appropriate numerical list of sections affected. For the period before 
January 1, 1986, consult either the List of CFR Sections Affected, 1949-
1963, 1964-1972, or 1973-1985, published in seven separate volumes. For 
the period beginning January 1, 1986, a ``List of CFR Sections 
Affected'' is published at the end of each CFR volume.

INCORPORATION BY REFERENCE

    What is incorporation by reference? Incorporation by reference was 
established by statute and allows Federal agencies to meet the 
requirement to publish regulations in the Federal Register by referring 
to materials already published elsewhere. For an incorporation to be 
valid, the Director of the Federal Register must approve it. The legal 
effect of incorporation by reference is that the material is treated as 
if it were published in full in the Federal Register (5 U.S.C. 552(a)). 
This material, like any other properly issued regulation, has the force 
of law.
    What is a proper incorporation by reference? The Director of the 
Federal Register will approve an incorporation by reference only when 
the requirements of 1 CFR part 51 are met. Some of the elements on which 
approval is based are:
    (a) The incorporation will substantially reduce the volume of 
material published in the Federal Register.
    (b) The matter incorporated is in fact available to the extent 
necessary to afford fairness and uniformity in the administrative 
process.
    (c) The incorporating document is drafted and submitted for 
publication in accordance with 1 CFR part 51.
    Properly approved incorporations by reference in this volume are 
listed in the Finding Aids at the end of this volume.
    What if the material incorporated by reference cannot be found? If 
you have any problem locating or obtaining a copy of material listed in 
the Finding Aids of this volume as an approved incorporation by 
reference, please contact the agency that issued the regulation 
containing that incorporation. If, after contacting the agency, you find 
the material is not available, please notify the Director of the Federal 
Register, National Archives and Records Administration, Washington DC 
20408, or call (202) 523-4534.

CFR INDEXES AND TABULAR GUIDES

    A subject index to the Code of Federal Regulations is contained in a 
separate volume, revised annually as of January 1, entitled CFR Index 
and Finding Aids. This volume contains the Parallel Table of Statutory 
Authorities and Agency Rules (Table I). A list of CFR titles, chapters, 
and parts and an alphabetical list of agencies publishing in the CFR are 
also included in this volume.
    An index to the text of ``Title 3--The President'' is carried within 
that volume.
    The Federal Register Index is issued monthly in cumulative form. 
This index is based on a consolidation of the ``Contents'' entries in 
the daily Federal Register.
    A List of CFR Sections Affected (LSA) is published monthly, keyed to 
the revision dates of the 50 CFR titles.

[[Page vii]]


REPUBLICATION OF MATERIAL

    There are no restrictions on the republication of material appearing 
in the Code of Federal Regulations.

INQUIRIES

    For a legal interpretation or explanation of any regulation in this 
volume, contact the issuing agency. The issuing agency's name appears at 
the top of odd-numbered pages.
    For inquiries concerning CFR reference assistance, call 202-523-5227 
or write to the Director, Office of the Federal Register, National 
Archives and Records Administration, Washington, DC 20408.

SALES

    The Government Printing Office (GPO) processes all sales and 
distribution of the CFR. For payment by credit card, call 202-512-1800, 
M-F, 8 a.m. to 4 p.m. e.s.t. or fax your order to 202-512-2233, 24 hours 
a day. For payment by check, write to the Superintendent of Documents, 
Attn: New Orders, P.O. Box 371954, Pittsburgh, PA 15250-7954. For GPO 
Customer Service call 202-512-1803.

ELECTRONIC SERVICES

    The full text of the Code of Federal Regulations, The United States 
Government Manual, the Federal Register, Public Laws, Weekly Compilation 
of Presidential Documents and the Privacy Act Compilation are available 
in electronic format at www.access.gpo.gov/nara (``GPO Access''). For 
more information, contact Electronic Information Dissemination Services, 
U.S. Government Printing Office. Phone 202-512-1530, or 888-293-6498 
(toll-free). E-mail, [email protected].
    The Office of the Federal Register also offers a free service on the 
National Archives and Records Administration's (NARA) World Wide Web 
site for public law numbers, Federal Register finding aids, and related 
information. Connect to NARA's web site at www.nara.gov/fedreg. The NARA 
site also contains links to GPO Access.

                              Raymond A. Mosley,
                                    Director,
                          Office of the Federal Register.

July 1, 1999.



[[Page ix]]



                               THIS TITLE

    Title 40--Protection of Environment is composed of twenty-four 
volumes. The parts in these volumes are arranged in the following order: 
parts 1-49, parts 50-51, part 52 (52.01-52.1018), part 52 (52.1019-End), 
parts 53-59, part 60, parts 61-62, part 63 (63.1-63.1199), part 63 
(63.1200-End), parts 64-71, parts 72-80, parts 81-85, part 86, parts 87-
135, parts 136-149, parts 150-189, parts 190-259, parts 260-265, parts 
266-299, parts 300-399, parts 400-424, parts 425-699, parts 700-789, and 
part 790 to End. The contents of these volumes represent all current 
regulations codified under this title of the CFR as of July 1, 1999.

    Chapter I--Environmental Protection Agency appears in all twenty-
four volumes. A Pesticide Tolerance Commodity/Chemical Index appears in 
parts 150-189. A Toxic Substances Chemical--CAS Number Index appears in 
parts 700-789 and part 790 to End. Redesignation Tables appear in the 
volumes containing parts 50-51, parts 150-189, and parts 700-789. 
Regulations issued by the Council on Environmental Quality appear in the 
volume containing part 790 to End. The OMB control numbers for title 40 
appear in Sec. 9.1 of this chapter.

    For this volume, Linda L. Jones was Chief Editor. The Code of 
Federal Regulations publication program is under the direction of 
Frances D. McDonald, assisted by Alomha S. Morris.

[[Page x]]





[[Page 1]]



                   TITLE 40--PROTECTION OF ENVIRONMENT




                      (This book contains part 60)

  --------------------------------------------------------------------
                                                                    Part

Chapter I--Environmental Protection Agency (Continued)......          60

[[Page 3]]



               CHAPTER I--ENVIRONMENTAL PROTECTION AGENCY




  --------------------------------------------------------------------

                 SUBCHAPTER C--AIR PROGRAMS (CONTINUED)
Part                                                                Page
60              Standards of performance for new stationary 
                    sources.................................           5



  Editorial Note: Subchapter C--Air programs is contained in volumes 40 
CFR parts 50-51, part 52 (52.01-52.1018), part 52 (52.1019-End), 53-59, 
part 60, parts 61-62, part 63 (63.1-63.1199), part 63 (63.1200-End), 
parts 64-71, parts 72-80, parts 81-85, part 86, and parts 87-135.

[[Page 5]]



                 SUBCHAPTER C--AIR PROGRAMS (CONTINUED)





PART 60--STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--Table of Contents




                      Subpart A--General Provisions

Sec.
60.1  Applicability.
60.2  Definitions.
60.3  Units and abbreviations.
60.4  Address.
60.5  Determination of construction or modification.
60.6  Review of plans.
60.7  Notification and record keeping.
60.8  Performance tests.
60.9  Availability of information.
60.10  State authority.
60.11  Compliance with standards and maintenance requirements.
60.12  Circumvention.
60.13  Monitoring requirements.
60.14  Modification.
60.15  Reconstruction.
60.16  Priority list.
60.17  Incorporations by reference.
60.18  General control device requirements.
60.19  General notification and reporting requirements.

    Subpart B--Adoption and Submittal of State Plans for Designated 
                               Facilities

60.20  Applicability.
60.21  Definitions.
60.22  Publication of guideline documents, emission guidelines, and 
          final compliance times.
60.23  Adoption and submittal of State plans; public hearings.
60.24  Emission standards and compliance schedules.
60.25  Emission inventories, source surveillance, reports.
60.26  Legal authority.
60.27  Actions by the Administrator.
60.28  Plan revisions by the State.
60.29  Plan revisions by the Administrator.

           Subpart C--Emission Guidelines and Compliance Times

60.30  Scope.
60.31  Definitions.

Subpart Ca  [Reserved]

    Subpart Cb--Emissions Guidelines and Compliance Times for Large 
 Municipal Waste Combustors That Are Constructed on or Before September 
                                20, 1994

60.30b  Scope.
60.31b  Definitions.
60.32b  Designated facilities.
60.33b  Emission guidelines for municipal waste combustor metals, acid 
          gases, organics, and nitrogen oxides.
60.34b  Emission guidelines for municipal waste combustor operating 
          practices.
60.35b  Emission guidelines for municipal waste combustor operator 
          training and certification.
60.36b  Emission guidelines for municipal waste combustor fugitive ash 
          emissions.
60.37b  Emission guidelines for air curtain incinerators.
60.38b  Compliance and performance testing.
60.39b  Reporting and recordkeeping guidelines and compliance schedules.

Subpart Cc--Emission Guidelines and Compliance Times for Municipal Solid 
                             Waste Landfills

60.30c  Scope.
60.31c  Definitions.
60.32c  Designated facilities.
60.33c  Emission guidelines for municipal solid waste landfill 
          emissions.
60.34c  Test methods and procedures.
60.35c  Reporting and recordkeeping guidelines.
60.36c  Compliance times.

Subpart Cd--Emissions Guidelines and Compliance Times for Sulfuric Acid 
                            Production Units

60.30d  Designated facilities.
60.31d  Emissions guidelines.
60.32d  Compliance times.

[[Page 6]]

   Subpart Ce--Emission Guidelines and Compliance Times for Hospital/
                  Medical/Infectious Waste Incinerators

60.30e  Scope.
60.31e  Definitions.
60.32e  Designated facilities.
60.33e  Emission guidelines.
60.34e  Operator training and qualification guidelines.
60.35e  Waste management guidelines.
60.36e  Inspection guidelines.
60.37e  Compliance, performance testing, and monitoring guidelines.
60.38e  Reporting and recordkeeping guidelines.
60.39e  Compliance times.

  Table 1 to Subpart Ce--Emission Limits for Small, Medium, and Large 
                                  HMIWI

 Table 2 to Subpart Ce--Emission Limits for Small HMIWI which meet the 
                      criteria under Sec. 60.33e(b)

    Subpart D--Standards of Performance for Fossil-Fuel-Fired Steam 
  Generators for Which Construction is Commenced After August 17, 1971

60.40  Applicability and designation of affected facility.
60.41  Definitions.
60.42  Standard for particulate matter.
60.43  Standard for sulfur dioxide.
60.44  Standard for nitrogen oxides.
60.45  Emission and fuel monitoring.
60.46  Test methods and procedures.

    Subpart Da--Standards of Performance for Electric Utility Steam 
Generating Units for Which Construction is Commenced After September 18, 
                                  1978

60.40a  Applicability and designation of affected facility.
60.41a  Definitions.
60.42a  Standard for particulate matter.
60.43a  Standard for sulfur dioxide.
60.44a  Standard for nitrogen oxides.
60.45a  Commercial demonstration permit.
60.46a  Compliance provisions.
60.47a  Emission monitoring.
60.48a  Compliance determination procedures and methods.
60.49a  Reporting requirements.

     Subpart Db--Standards of Performance for Industrial-Commercial-
                  Institutional Steam Generating Units

60.40b  Applicability and delegation of authority.
60.41b  Definitions.
60.42b  Standard for sulfur dioxide.
60.43b  Standard for particulate matter.
60.44b  Standard for nitrogen oxides.
60.45b  Compliance and performance test methods and procedures for 
          sulfur dioxide.
60.46b  Compliance and performance test methods and procedures for 
          particulate matter and nitrogen oxides.
60.47b  Emission monitoring for sulfur dioxide.
60.48b  Emission monitoring for particulate matter and nitrogen oxides.
60.49b  Reporting and recordkeeping requirements.

  Subpart Dc--Standards of Performance for Small Industrial-Commercial-
                  Institutional Steam Generating Units

60.40c  Applicability and delegation of authority.
60.41c  Definitions.
60.42c  Standard for sulfur dioxide.
60.43c  Standard for particulate matter.
60.44c  Compliance and performance test methods and procedures for 
          sulfur dioxide.
60.45c  Compliance and performance test methods and procedures for 
          particulate matter.
60.46c  Emission monitoring for sulfur dioxide.
60.47c  Emission monitoring for particulate matter.
60.48c  Reporting and recordkeeping requirements.

          Subpart E--Standards of Performance for Incinerators

60.50  Applicability and designation of affected facility.
60.51  Definitions.
60.52  Standard for particulate matter.
60.53  Monitoring of operations.
60.54  Test methods and procedures.

Subpart Ea--Standards of Performance for Municipal Waste Combustors for 
Which Construction is Commenced After December 20, 1989 and on or Before 
                           September 20, 1994

60.50a  Applicability and delegation of authority.
60.51a  Definitions.
60.52a  Standard for municipal waste combustor metals.
60.53a  Standard for municipal waste combustor organics.
60.54a  Standard for municipal waste combustor acid gases.
60.55a  Standard for nitrogen oxides.
60.56a  Standard for municipal waste combustor operating practices.
60.57a  [Reserved]
60.58a  Compliance and performance testing.
60.59a  Reporting and recordkeeping requirements.

[[Page 7]]

     Subpart Eb--Standards of Performance for Large Municipal Waste 
Combustors for Which Construction is Commenced After September 20, 1994 
or for Which Modification or Reconstruction is Commenced After June 19, 
                                  1996

60.50b  Applicability and delegation of authority.
60.51b  Definitions.
60.52b  Standards for municipal waste combustor metals, acid gases, 
          organics, and nitrogen oxides.
60.53b  Standards for municipal waste combustor operating practices.
60.54b  Standards for municipal waste combustor operator training and 
          certification.
60.55b  Standards for municipal waste combustor fugitive ash emissions.
60.56b  Standards for air curtain incinerators.
60.57b  Siting requirements.
60.58b  Compliance and performance testing.
60.59b  Reporting and recordkeeping requirements.

  Subpart Ec--Standards of Performance for Hospital/Medical/Infectious 
 Waste Incinerators for Which Construction is Commenced After June 20, 
                                  1996

60.50c  Applicability and delegation of authority.
60.51c  Definitions.
60.52c  Emission limits.
60.53c  Operator training and qualification requirements.
60.54c  Siting requirements.
60.55c  Waste management plan.
60.56c  Compliance and performance testing.
60.57c  Monitoring requirements.
60.58c  Reporting and recordkeeping requirements.

  Table 1 to Subpart Ec--Emission Limits for Small, Medium, and Large 
                                  HMIWI

            Table 2 to Subpart Ec--Toxic Equivalency Factors

Table 3 to Subpart Ec--Operating Parameters to be Monitored and Minimum 
                  Measurement and Recording Frequencies

     Subpart F--Standards of Performance for Portland Cement Plants

60.60  Applicability and designation of affected facility.
60.61  Definitions.
60.62  Standard for particulate matter.
60.63  Monitoring of operations.
60.64  Test methods and procedures.
60.65  Recordkeeping and reporting requirements.
60.66  Delegation of authority.

       Subpart G--Standards of Performance for Nitric Acid Plants

60.70  Applicability and designation of affected facility.
60.71  Definitions.
60.72  Standard for nitrogen oxides.
60.73  Emission monitoring.
60.74  Test methods and procedures.

      Subpart H--Standards of Performance for Sulfuric Acid Plants

60.80  Applicability and designation of affected facility.
60.81  Definitions.
60.82  Standard for sulfur dioxide.
60.83  Standard for acid mist.
60.84  Emission monitoring.
60.85  Test methods and procedures.

   Subpart I--Standards of Performance for Hot Mix Asphalt Facilities

60.90  Applicability and designation of affected facility.
60.91  Definitions.
60.92  Standard for particulate matter.
60.93  Test methods and procedures.

      Subpart J--Standards of Performance for Petroleum Refineries

60.100  Applicability, designation of affected facility, and 
          reconstruction.
60.101  Definitions.
60.102  Standard for particulate matter.
60.103  Standard for carbon monoxide.
60.104  Standards for sulfur oxides.
60.105  Monitoring of emissions and operations.
60.106  Test methods and procedures.
60.107  Reporting and recordkeeping requirements.
60.108  Performance test and compliance provisions.
60.109  Delegation of authority.

 Subpart K--Standards of Performance for Storage Vessels for Petroleum 
    Liquids for Which Construction, Reconstruction, or Modification 
        Commenced After June 11, 1973, and Prior to May 19, 1978

60.110  Applicability and designation of affected facility.
60.111  Definitions.
60.112  Standard for volatile organic compounds (VOC).
60.113  Monitoring of operations.

[[Page 8]]

 Subpart Ka--Standards of Performance for Storage Vessels for Petroleum 
    Liquids for Which Construction, Reconstruction, or Modification 
        Commenced After May 18, 1978, and Prior to July 23, 1984

60.110a  Applicability and designation of affected facility.
60.111a  Definitions.
60.112a  Standard for volatile organic compounds (VOC).
60.113a  Testing and procedures.
60.114a  Alternative means of emission limitation.
60.115a  Monitoring of operations.

Subpart Kb--Standards of Performance for Volatile Organic Liquid Storage 
     Vessels (Including Petroleum Liquid Storage Vessels) for Which 
 Construction, Reconstruction, or Modification Commenced After July 23, 
                                  1984

60.110b  Applicability and designation of affected facility.
60.111b  Definitions.
60.112b  Standard for volatile organic compounds (VOC).
60.113b  Testing and procedures.
60.114b  Alternative means of emission limitation.
60.115b  Reporting and recordkeeping requirements.
60.116b  Monitoring of operations.
60.117b  Delegation of authority.

     Subpart L--Standards of Performance for Secondary Lead Smelters

60.120  Applicability and designation of affected facility.
60.121  Definitions.
60.122  Standard for particulate matter.
60.123  Test methods and procedures.

   Subpart M--Standards of Performance for Secondary Brass and Bronze 
                            Production Plants

60.130  Applicability and designation of affected facility.
60.131  Definitions.
60.132  Standard for particulate matter.
60.133  Test methods and procedures.

  Subpart N--Standards of Performance for Primary Emissions from Basic 
Oxygen Process Furnances for Which Construction is Commenced After June 
                                11, 1973

60.140  Applicability and designation of affected facility.
60.141  Definitions.
60.142  Standard for particulate matter.
60.143  Monitoring of operations.
60.144  Test methods and procedures.

Subpart Na--Standards of Performance for Secondary Emissions from Basic 
    Oxygen Process Steelmaking Facilities for Which Construction is 
                    Commenced After January 20, 1983

60.140a  Applicability and designation of affected facilities.
60.141a  Definitions.
60.142a  Standards for particulate matter.
60.143a  Monitoring of operations.
60.144a  Test methods and procedures.
60.145a  Compliance provisions.

     Subpart O--Standards of Performance for Sewage Treatment Plants

60.150  Applicability and designation of affected facility.
60.151  Definitions.
60.152  Standard for particulate matter.
60.153  Monitoring of operations.
60.154  Test methods and procedures.
60.155  Reporting.
60.156  Delegation of authority.

     Subpart P--Standards of Performance for Primary Copper Smelters

60.160  Applicability and designation of affected facility.
60.161  Definitions.
60.162  Standard for particulate matter.
60.163  Standard for sulfur dioxide.
60.164  Standard for visible emissions.
60.165  Monitoring of operations.
60.166  Test methods and procedures.

      Subpart Q--Standards of Performance for Primary Zinc Smelters

60.170  Applicability and designation of affected facility.
60.171  Definitions.
60.172  Standard for particulate matter.
60.173  Standard for sulfur dioxide.
60.174  Standard for visible emissions.
60.175  Monitoring of operations.
60.176  Test methods and procedures.

      Subpart R--Standards of Performance for Primary Lead Smelters

60.180  Applicability and designation of affected facility.
60.181  Definitions.
60.182  Standard for particulate matter.
60.183  Standard for sulfur dioxide.
60.184  Standard for visible emissions.
60.185  Monitoring of operations.
60.186  Test methods and procedures.

   Subpart S--Standards of Performance for Primary Aluminum Reduction 
                                 Plants

60.190  Applicability and designation of affected facility.

[[Page 9]]

60.191  Definitions.
60.192  Standard for fluorides.
60.193  Standard for visible emissions.
60.194  Monitoring of operations.
60.195  Test methods and procedures.

    Subpart T--Standards of Performance for the Phosphate Fertilizer 
              Industry: Wet-Process Phosphoric Acid Plants

60.200  Applicability and designation of affected facility.
60.201  Definitions.
60.202  Standard for fluorides.
60.203  Monitoring of operations.
60.204  Test methods and procedures.

    Subpart U--Standards of Performance for the Phosphate Fertilizer 
                  Industry: Superphosphoric Acid Plants

60.210  Applicability and designation of affected facility.
60.211  Definitions.
60.212  Standard for fluorides.
60.213  Monitoring of operations.
60.214  Test methods and procedures.

    Subpart V--Standards of Performance for the Phosphate Fertilizer 
                  Industry: Diammonium Phosphate Plants

60.220  Applicability and designation of affected facility.
60.221  Definitions.
60.222  Standard for fluorides.
60.223  Monitoring of operations.
60.224  Test methods and procedures.

    Subpart W--Standards of Performance for the Phosphate Fertilizer 
                 Industry: Triple Superphosphate Plants

60.230  Applicability and designation of affected facility.
60.231  Definitions.
60.232  Standard for fluorides.
60.233  Monitoring of operations.
60.234  Test methods and procedures.

    Subpart X--Standards of Performance for the Phosphate Fertilizer 
       Industry: Granular Triple Superphosphate Storage Facilities

60.240  Applicability and designation of affected facility.
60.241  Definitions.
60.242  Standard for fluorides.
60.243  Monitoring of operations.
60.244  Test methods and procedures.

     Subpart Y--Standards of Performance for Coal Preparation Plants

60.250  Applicability and designation of affected facility.
60.251  Definitions.
60.252  Standards for particulate matter.
60.253  Monitoring of operations.
60.254  Test methods and procedures.

Subpart Z--Standards of Performance for Ferroalloy Production Facilities

60.260  Applicability and designation of affected facility.
60.261  Definitions.
60.262  Standard for particulate matter.
60.263  Standard for carbon monoxide.
60.264  Emission monitoring.
60.265  Monitoring of operations.
60.266  Test methods and procedures.

  Subpart AA--Standards of Performance for Steel Plants: Electric Arc 
Furnaces Constructed After October 21, 1974 and On or Before August 17, 
                                  1983

60.270  Applicability and designation of affected facility.
60.271  Definitions.
60.272  Standard for particulate matter.
60.273  Emission monitoring.
60.274  Monitoring of operations.
60.275  Test methods and procedures.
60.276  Recordkeeping and reporting requirements.

  Subpart AAa--Standards of Performance for Steel Plants: Electric Arc 
  Furnaces and Argon-Oxygen Decarburization Vessels Constructed After 
                             August 7, 1983

60.270a  Applicability and designation of affected facility.
60.271a  Definitions.
60.272a  Standard for particulate matter.
60.273a  Emission monitoring.
60.274a  Monitoring of operations.
60.275a  Test methods and procedures.
60.276a  Recordkeeping and reporting requirements.

        Subpart BB--Standards of Performance for Kraft Pulp Mills

60.280  Applicability and designation of affected facility.
60.281  Definitions.
60.282  Standard for particulate matter.
60.283  Standard for total reduced sulfur (TRS).
60.284  Monitoring of emissions and operations.
60.285  Test methods and procedures.

   Subpart CC--Standards of Performance for Glass Manufacturing Plants

60.290  Applicability and designation of affected facility.
60.291  Definitions.
60.292  Standards for particulate matter.

[[Page 10]]

60.293  Standards for particulate matter from glass melting furnace with 
          modified-processes.
60.294--60.295  [Reserved]
60.296  Test methods and procedures.

        Subpart DD--Standards of Performance for Grain Elevators

60.300  Applicability and designation of affected facility.
60.301  Definitions.
60.302  Standard for particulate matter.
60.303  Test methods and procedures.
60.304  Modifications.

   Subpart EE--Standards of Performance for Surface Coating of Metal 
                                Furniture

60.310  Applicability and designation of affected facility.
60.311  Definitions and symbols.
60.312  Standard for volatile organic compounds (VOC).
60.313  Performance tests and compliance provisions.
60.314  Monitoring of emissions and operations.
60.315  Reporting and recordkeeping requirements.
60.316  Test methods and procedures.

Subpart FF  [Reserved]

    Subpart GG--Standards of Performance for Stationary Gas Turbines

60.330  Applicability and designation of affected facility.
60.331  Definitions.
60.332  Standard for nitrogen oxides.
60.333  Standard for sulfur dioxide.
60.334  Monitoring of operations.
60.335  Test methods and procedures.

   Subpart HH--Standards of Performance for Lime Manufacturing Plants

60.340  Applicability and designation of affected facility.
60.341  Definitions.
60.342  Standard for particulate matter.
60.343  Monitoring of emissions and operations.
60.344  Test methods and procedures.

Subpart KK--Standards of Performance for Lead-Acid Battery Manufacturing 
                                 Plants

60.370  Applicability and designation of affected facility.
60.371  Definitions.
60.372  Standards for lead.
60.373  Monitoring of emissions and operations.
60.374  Test methods and procedures.

  Subpart LL--Standards of Performance for Metallic Mineral Processing 
                                 Plants

60.380  Applicability and designation of affected facility.
60.381  Definitions.
60.382  Standard for particulate matter.
60.383  Reconstruction.
60.384  Monitoring of operations.
60.385  Recordkeeping and reporting requirements.
60.386  Test methods and procedures.

Subpart MM--Standards of Performance for Automobile and Light Duty Truck 
                       Surface Coating Operations

60.390  Applicability and designation of affected facility.
60.391  Definitions.
60.392  Standards for volatile organic compounds.
60.393  Performance test and compliance provisions.
60.394  Monitoring of emissions and operations.
60.395  Reporting and recordkeeping requirements.
60.396  Reference methods and procedures.
60.397  Modifications.
60.398  Innovative technology waivers.

     Subpart NN--Standards of Performance for Phosphate Rock Plants

60.400  Applicability and designation of affected facility.
60.401  Definitions.
60.402  Standard for particulate matter.
60.403  Monitoring of emissions and operations.
60.404  Test methods and procedures.

  Subpart PP--Standards of Performance for Ammonium Sulfate Manufacture

60.420  Applicability and designation of affected facility.
60.421  Definitions.
60.422  Standards for particulate matter.
60.423  Monitoring of operations.
60.424  Test methods and procedures.

  Subpart QQ--Standards of Performance for the Graphic Arts Industry: 
                    Publication Rotogravure Printing

60.430  Applicability and designation of affected facility.
60.431  Definitions and notations.
60.432  Standard for volatile organic compounds.
60.433  Performance test and compliance provisions.
60.434  Monitoring of operations and recordkeeping.
60.435  Test methods and procedures.

[[Page 11]]

  Subpart RR--Standards of Performance for Pressure Sensitive Tape and 
                    Label Surface Coating Operations

60.440  Applicability and designation of affected facility.
60.441  Definitions and symbols.
60.442  Standard for volatile organic compounds.
60.443  Compliance provisions.
60.444  Performance test procedures.
60.445  Monitoring of operations and recordkeeping.
60.446  Test methods and procedures.
60.447  Reporting requirements.

  Subpart SS--Standards of Performance for Industrial Surface Coating: 
                            Large Appliances

60.450  Applicability and designation of affected facility.
60.451  Definitions.
60.452  Standard for volatile organic compounds.
60.453  Performance test and compliance provisions.
60.454  Monitoring of emissions and operations.
60.455  Reporting and recordkeeping requirements.
60.456  Test methods and procedures.

   Subpart TT--Standards of Performance for Metal Coil Surface Coating

60.460  Applicability and designation of affected facility.
60.461  Definitions.
60.462  Standards for volatile organic compounds.
60.463  Performance test and compliance provisions.
60.464  Monitoring of emissions and operations.
60.465  Reporting and recordkeeping requirements.
60.466  Test methods and procedures.

Subpart UU--Standards of Performance for Asphalt Processing and Asphalt 
                           Roofing Manufacture

60.470  Applicability and designation of affected facilities.
60.471  Definitions.
60.472  Standards for particulate matter.
60.473  Monitoring of operations.
60.474  Test methods and procedures.

 Subpart VV--Standards of Performance for Equipment Leaks of VOC in the 
           Synthetic Organic Chemicals Manufacturing Industry

60.480  Applicability and designation of affected facility.
60.481  Definitions.
60.482-1  Standards: General.
60.482-2  Standards: Pumps in light liquid service.
60.482-3  Standards: Compressors.
60.482-4  Standards: Pressure relief devices in gas/vapor service.
60.482-5  Standards: Sampling connection systems.
60.482-6  Standards: Open-ended valves or lines.
60.482-7  Standards: Valves in gas/vapor service and in light liquid 
          service.
60.482-8  Standards: Pumps and valves in heavy liquid service, pressure 
          relief devices in light liquid or heavy liquid service, and 
          flanges and other connectors.
60.482-9  Standards: Delay of repair.
60.482-10  Standards: Closed vent systems and control devices.
60.483-1  Alternative standards for valves--allowable percentage of 
          valves leaking.
60.483-2  Alternative standards for valves--skip period leak detection 
          and repair.
60.484  Equivalence of means of emission limitation.
60.485  Test methods and procedures.
60.486  Recordkeeping requirements.
60.487  Reporting requirements.
60.488  Reconstruction.
60.489  List of chemicals produced by affected facilities.

   Subpart WW--Standards of Performance for the Beverage Can Surface 
                            Coating Industry

60.490  Applicability and designation of affected facility.
60.491  Definitions.
60.492  Standards for volatile organic compounds.
60.493  Performance test and compliance provisions.
60.494  Monitoring of emissions and operations.
60.495  Reporting and recordkeeping requirements.
60.496  Test methods and procedures.

    Subpart XX--Standards of Performance for Bulk Gasoline Terminals

60.500  Applicability and designation of affected facility.
60.501  Definitions.
60.502  Standards for Volatile Organic Compound (VOC) emissions from 
          bulk gasoline terminals.
60.503  Test methods and procedures.
60.504  [Reserved]
60.505  Reporting and recordkeeping.
60.506  Reconstruction.

[[Page 12]]

 Subpart AAA--Standards of Performance for New Residential Wood Heaters

60.530  Applicability and designation of affected facility.
60.531  Definitions.
60.532  Standards for particulate matter.
60.533  Compliance and certification.
60.534  Test methods and procedures.
60.535  Laboratory accreditation.
60.536  Permanent label, temporary label, and owner's manual.
60.537  Reporting and recordkeeping.
60.538  Prohibitions.
60.539  Hearing and appeal procedures.
60.539a  Delegation of authority.
60.539b  General provisions exclusions.

Subpart BBB--Standards of Performance for the Rubber Tire Manufacturing 
                                Industry

60.540  Applicability and designation of affected facilities.
60.541  Definitions.
60.542  Standards for volatile organic compounds.
60.542a  Alternate standard for volatile organic compounds.
60.543  Performance test and compliance provisions.
60.544  Monitoring of operations.
60.545  Recordkeeping requirements.
60.546  Reporting requirements.
60.547  Test methods and procedures.
60.548  Delegation of authority.

Subpart CCC  [Reserved]

  Subpart DDD--Standards of Performance for Volatile Organic Compound 
         (VOC) Emissions from the Polymer Manufacturing Industry

60.560  Applicability and designation of affected facilities.
60.561  Definitions.
60.562-1  Standards: Process emissions.
60.562-2  Standards: Equipment leaks of VOC.
60.563  Monitoring requirements.
60.564  Test methods and procedures.
60.565  Reporting and recordkeeping requirements.
60.566  Delegation of authority.

Subpart EEE  [Reserved]

 Subpart FFF--Standards of Performance for Flexible Vinyl and Urethane 
                          Coating and Printing

60.580  Applicability and designation of affected facility.
60.581  Definitions and symbols.
60.582  Standard for volatile organic compounds.
60.583  Test methods and procedures.
60.584  Monitoring of operations and recordkeeping requirements.
60.585  Reporting requirements.

  Subpart GGG--Standards of Performance for Equipment Leaks of VOC in 
                          Petroleum Refineries

60.590  Applicability and designation of affected facility.
60.591  Definitions.
60.592  Standards.
60.593  Exceptions.

  Subpart HHH--Standards of Performance for Synthetic Fiber Production 
                               Facilities

60.600  Applicability and designation of affected facility.
60.601  Definitions.
60.602  Standard for volatile organic compounds.
60.603  Performance test and compliance provisions.
60.604  Reporting requirements.

  Subpart III--Standards of Performance for Volatile Organic Compound 
   (VOC) Emissions From the Synthetic Organic Chemical Manufacturing 
              Industry (SOCMI) Air Oxidation Unit Processes

60.610  Applicability and designation of affected facility.
60.611  Definitions.
60.612  Standards.
60.613  Monitoring of emissions and operations.
60.614  Test methods and procedures.
60.615  Reporting and recordkeeping requirements.
60.616  Reconstruction.
60.617  Chemicals affected by subpart III.
60.618  Delegation of authority.

    Subpart JJJ--Standards of Performance for Petroleum Dry Cleaners

60.620  Applicability and designation of affected facility.
60.621  Definitions.
60.622  Standards for volatile organic compounds.
60.623  Equivalent equipment and procedures.
60.624  Test methods and procedures.
60.625  Recordkeeping requirements.

 Subpart KKK--Standards of Performance for Equipment Leaks of VOC From 
                  Onshore Natural Gas Processing Plants

60.630  Applicability and designation of affected facility.
60.631  Definitions.
60.632  Standards.
60.633  Exceptions.

[[Page 13]]

60.634  Alternative means of emission limitation.
60.635  Recordkeeping requirements.
60.636  Reporting requirements.

     Subpart LLL--Standards of Performance for Onshore Natural Gas 
                  Processing: SO2 Emissions

60.640  Applicability and designation of affected facilities.
60.641  Definitions.
60.642  Standards for sulfur dioxide.
60.643  Compliance provisions.
60.644  Test methods and procedures.
60.645  [Reserved]
60.646  Monitoring of emissions and operations.
60.647  Recordkeeping and reporting requirements.
60.648  Optional procedure for measuring hydrogen sulfide in acid gas--
          Tutwiler Procedure.

Subpart MMM  [Reserved]

  Subpart NNN--Standards of Performance for Volatile Organic Compound 
 (VOC) Emissions From Synthetic Organic Chemical Manufacturing Industry 
                     (SOCMI) Distillation Operations

60.660  Applicability and designation of affected facility.
60.661  Definitions.
60.662  Standards.
60.663  Monitoring of emissions and operations.
60.664  Test methods and procedures.
60.665  Reporting and recordkeeping requirements.
60.666  Reconstruction.
60.667  Chemicals affected by subpart NNN.
60.668  Delegation of authority.

Subpart OOO--Standards of Performance for Nonmetallic Mineral Processing 
                                 Plants

60.670  Applicability and designation of affected facility.
60.671  Definitions.
60.672  Standard for particulate matter.
60.673  Reconstruction.
60.674  Monitoring of operations.
60.675  Test methods and procedures.
60.676  Reporting and recordkeeping.

  Subpart PPP--Standard of Performance for Wool Fiberglass Insulation 
                          Manufacturing Plants

60.680  Applicability and designation of affected facility.
60.681  Definitions.
60.682  Standard for particulate matter.
60.683  Monitoring of operations.
60.684  Recordkeeping and reporting requirements.
60.685  Test methods and procedures.

 Subpart QQQ--Standards of Performance for VOC Emissions From Petroleum 
                       Refinery Wastewater Systems

60.690  Applicability and designation of affected facility.
60.691  Definitions.
60.692-1  Standards: General.
60.692-2  Standards: Individual drain systems.
60.692-3  Standards: Oil-water separators.
60.692-4  Standards: Aggregate facility.
60.692-5  Standards: Closed vent systems and control devices.
60.692-6  Standards: Delay of repair.
60.692-7  Standards: Delay of compliance.
60.693-1  Alternative standards for individual drain systems.
60.693-2  Alternative standards for oil-water separators.
60.694  Permission to use alternative means of emission limitation.
60.695  Monitoring of operations.
60.696  Performance test methods and procedures and compliance 
          provisions.
60.697  Recordkeeping requirements.
60.698  Reporting requirements.
60.699  Delegation of authority.

  Subpart RRR--Standards of Performance for Volatile Organic Compound 
Emissions from Synthetic Organic Chemical Manufacturing Industry (SOCMI) 
                            Reactor Processes

60.700  Applicability and designation of affected facility.
60.701  Definitions.
60.702  Standards.
60.703  Monitoring of emissions and operations.
60.704  Test methods and procedures.
60.705  Reporting and recordkeeping requirements.
60.706  Reconstruction.
60.707  Chemicals affected by subpart RRR.
60.708  Delegation of authority.

    Subpart SSS--Standards of Performance for Magnetic Tape Coating 
                               Facilities

60.710  Applicability and designation of affected facility.
60.711  Definitions, symbols, and cross-reference tables.
60.712  Standards for volatile organic compounds.
60.713  Compliance provisions.
60.714  Installation of monitoring devices and recordkeeping.
60.715  Test methods and procedures.
60.716  Permission to use alternative means of emission limitation.

[[Page 14]]

60.717  Reporting and monitoring requirements.
60.718  Delegation of authority.

 Subpart TTT--Standards of Performance for Industrial Surface Coating: 
         Surface Coating of Plastic Parts for Business Machines

60.720  Applicability and designation of affected facility.
60.721  Definitions.
60.722  Standards for volatile organic compounds.
60.723  Performance test and compliance provisions.
60.724  Reporting and recordkeeping requirements.
60.725  Test methods and procedures.
60.726  Delegation of authority.

   Subpart UUU--Standards of Performance for Calciners and Dryers in 
                           Mineral Industries

60.730  Applicability and designation of affected facility.
60.731  Definitions.
60.732  Standards for particulate matter.
60.733  Reconstruction.
60.734  Monitoring of emissions and operations.
60.735  Recordkeeping and reporting requirements.
60.736  Test methods and procedures.
60.737  Delegation of authority.

     Subpart VVV--Standards of Performance for Polymeric Coating of 
                    Supporting Substrates Facilities

60.740  Applicability and designation of affected facility.
60.741  Definitions, symbols, and cross-reference tables.
60.742  Standards for violatile organic compounds.
60.743  Compliance provisions.
60.744  Monitoring requirements.
60.745  Test methods and procedures.
60.746  Permission to use alternative means of emission limitation.
60.747  Reporting and recordkeeping requirements.
60.748  Delegation of authority.

    Subpart WWW--Standards of Performance for Municipal Solid Waste 
                                Landfills

60.750  Applicability, designation of affected facility, and delegation 
          of authority.
60.751  Definitions.
60.752  Standards for air emissions from municipal solid waste 
          landfills.
60.753  Operational standards for collection and control systems.
60.754  Test methods and procedures.
60.755  Compliance provisions.
60.756  Monitoring of operations.
60.757  Reporting requirements.
60.758  Recordkeeping requirements.
60.759  Specifications for active collection systems.

Appendix A to Part 60--Test Methods
Appendix B to Part 60--Performance Specifications
Appendix C to Part 60--Determination of Emission Rate Change
Appendix D to Part 60--Required Emission Inventory Information
Appendix E to Part 60  [Reserved]
Appendix F to Part 60--Quality Assurance Procedures
Appendix G to Part 60--Provisions for an Alternative Method of 
          Demonstrating Compliance With 40 CFR 60.43 for the Newton 
          Power Station of Central Illinois Public Service Company
Appendix H to Part 60  [Reserved]
Appendix I to Part 60--Removable Label and Owner's Manual

    Authority: 42 U.S.C. 7401-7601.

    Source: 36 FR 24877, Dec. 23, 1971, unless otherwise noted.



                      Subpart A--General Provisions



Sec. 60.1  Applicability.

    (a) Except as provided in subparts B and C, the provisions of this 
part apply to the owner or operator of any stationary source which 
contains an affected facility, the construction or modification of which 
is commenced after the date of publication in this part of any standard 
(or, if earlier, the date of publication of any proposed standard) 
applicable to that facility.
    (b) Any new or revised standard of performance promulgated pursuant 
to section 111(b) of the Act shall apply to the owner or operator of any 
stationary source which contains an affected facility, the construction 
or modification of which is commenced after the date of publication in 
this part of such new or revised standard (or, if earlier, the date of 
publication of any proposed standard) applicable to that facility.
    (c) In addition to complying with the provisions of this part, the 
owner or operator of an affected facility may be required to obtain an 
operating permit issued to stationary sources by an authorized State air 
pollution control agency or by the Administrator of the U.S. 
Environmental Protection Agency (EPA) pursuant to Title V of the Clean

[[Page 15]]

Air Act (Act) as amended November 15, 1990 (42 U.S.C. 7661). For more 
information about obtaining an operating permit see part 70 of this 
chapter.
    (d) Site-specific standard for Merck & Co., Inc.'s Stonewall Plant 
in Elkton, Virginia. (1) This paragraph applies only to the 
pharmaceutical manufacturing facility, commonly referred to as the 
Stonewall Plant, located at Route 340 South, in Elkton, Virginia 
(``site'').
    (2) Except for compliance with 40 CFR 60.49b(u), the site shall have 
the option of either complying directly with the requirements of this 
part, or reducing the site-wide emissions caps in accordance with the 
procedures set forth in a permit issued pursuant to 40 CFR 52.2454. If 
the site chooses the option of reducing the site-wide emissions caps in 
accordance with the procedures set forth in such permit, the 
requirements of such permit shall apply in lieu of the otherwise 
applicable requirements of this part.
    (3) Notwithstanding the provisions of paragraph (d)(2) of this 
section, for any provisions of this part except for Subpart Kb, the 
owner/operator of the site shall comply with the applicable provisions 
of this part if the Administrator determines that compliance with the 
provisions of this part is necessary for achieving the objectives of the 
regulation and the Administrator notifies the site in accordance with 
the provisions of the permit issued pursuant to 40 CFR 52.2454.

[40 FR 53346, Nov. 17, 1975, as amended at 55 FR 51382, Dec. 13, 1990; 
59 FR 12427, Mar. 16, 1994; 62 FR 52641, Oct. 8, 1997]



Sec. 60.2  Definitions.

    The terms used in this part are defined in the Act or in this 
section as follows:
    Act means the Clean Air Act (42 U.S.C. 7401 et seq.)
    Administrator means the Administrator of the Environmental 
Protection Agency or his authorized representative.
    Affected facility means, with reference to a stationary source, any 
apparatus to which a standard is applicable.
    Alternative method means any method of sampling and analyzing for an 
air pollutant which is not a reference or equivalent method but which 
has been demonstrated to the Administrator's satisfaction to, in 
specific cases, produce results adequate for his determination of 
compliance.
    Approved permit program means a State permit program approved by the 
Administrator as meeting the requirements of part 70 of this chapter or 
a Federal permit program established in this chapter pursuant to Title V 
of the Act (42 U.S.C. 7661).
    Capital expenditure means an expenditure for a physical or 
operational change to an existing facility which exceeds the product of 
the applicable ``annual asset guideline repair allowance percentage'' 
specified in the latest edition of Internal Revenue Service (IRS) 
Publication 534 and the existing facility's basis, as defined by section 
1012 of the Internal Revenue Code. However, the total expenditure for a 
physical or operational change to an existing facility must not be 
reduced by any ``excluded additions'' as defined in IRS Publication 534, 
as would be done for tax purposes.
    Clean coal technology demonstration project means a project using 
funds appropriated under the heading `Department of Energy-Clean Coal 
Technology', up to a total amount of $2,500,000,000 for commercial 
demonstrations of clean coal technology, or similar projects funded 
through appropriations for the Environmental Protection Agency.
    Commenced means, with respect to the definition of new source in 
section 111(a)(2) of the Act, that an owner or operator has undertaken a 
continuous program of construction or modification or that an owner or 
operator has entered into a contractual obligation to undertake and 
complete, within a reasonable time, a continuous program of construction 
or modification.
    Construction means fabrication, erection, or installation of an 
affected facility.
    Continuous monitoring system means the total equipment, required 
under the emission monitoring sections in applicable subparts, used to 
sample and condition (if applicable), to analyze, and to provide a 
permanent record of emissions or process parameters.
    Electric utility steam generating unit means any steam electric 
generating

[[Page 16]]

unit that is constructed for the purpose of supplying more than one-
third of its potential electric output capacity and more than 25 MW 
electrical output to any utility power distribution system for sale. Any 
steam supplied to a steam distribution system for the purpose of 
providing steam to a steam-electric generator that would produce 
electrical energy for sale is also considered in determining the 
electrical energy output capacity of the affected facility.
    Equivalent method means any method of sampling and analyzing for an 
air pollutant which has been demonstrated to the Administrator's 
satisfaction to have a consistent and quantitatively known relationship 
to the reference method, under specified conditions.
    Excess Emissions and Monitoring Systems Performance Report is a 
report that must be submitted periodically by a source in order to 
provide data on its compliance with stated emission limits and operating 
parameters, and on the performance of its monitoring systems.
    Existing facility means, with reference to a stationary source, any 
apparatus of the type for which a standard is promulgated in this part, 
and the construction or modification of which was commenced before the 
date of proposal of that standard; or any apparatus which could be 
altered in such a way as to be of that type.
    Isokinetic sampling means sampling in which the linear velocity of 
the gas entering the sampling nozzle is equal to that of the undisturbed 
gas stream at the sample point.
    Issuance of a part 70 permit will occur, if the State is the 
permitting authority, in accordance with the requirements of part 70 of 
this chapter and the applicable, approved State permit program. When the 
EPA is the permitting authority, issuance of a Title V permit occurs 
immediately after the EPA takes final action on the final permit.
    Malfunction means any sudden, infrequent, and not reasonably 
preventable failure of air pollution control equipment, process 
equipment, or a process to operate in a normal or usual manner. Failures 
that are caused in part by poor maintenance or careless operation are 
not malfunctions.
    Modification means any physical change in, or change in the method 
of operation of, an existing facility which increases the amount of any 
air pollutant (to which a standard applies) emitted into the atmosphere 
by that facility or which results in the emission of any air pollutant 
(to which a standard applies) into the atmosphere not previously 
emitted.
    Monitoring device means the total equipment, required under the 
monitoring of operations sections in applicable subparts, used to 
measure and record (if applicable) process parameters.
    Nitrogen oxides means all oxides of nitrogen except nitrous oxide, 
as measured by test methods set forth in this part.
    One-hour period means any 60-minute period commencing on the hour.
    Opacity means the degree to which emissions reduce the transmission 
of light and obscure the view of an object in the background.
    Owner or operator means any person who owns, leases, operates, 
controls, or supervises an affected facility or a stationary source of 
which an affected facility is a part.
    Part 70 permit means any permit issued, renewed, or revised pursuant 
to part 70 of this chapter.
    Particulate matter means any finely divided solid or liquid 
material, other than uncombined water, as measured by the reference 
methods specified under each applicable subpart, or an equivalent or 
alternative method.
    Permit program means a comprehensive State operating permit system 
established pursuant to title V of the Act (42 U.S.C. 7661) and 
regulations codified in part 70 of this chapter and applicable State 
regulations, or a comprehensive Federal operating permit system 
established pursuant to title V of the Act and regulations codified in 
this chapter.
    Permitting authority means:
    (1) The State air pollution control agency, local agency, other 
State agency, or other agency authorized by the Administrator to carry 
out a permit program under part 70 of this chapter; or

[[Page 17]]

    (2) The Administrator, in the case of EPA-implemented permit 
programs under title V of the Act (42 U.S.C. 7661).
    Proportional sampling means sampling at a rate that produces a 
constant ratio of sampling rate to stack gas flow rate.
    Reactivation of a very clean coal-fired electric utility steam 
generating unit means any physical change or change in the method of 
operation associated with the commencement of commercial operations by a 
coal-fired utility unit after a period of discontinued operation where 
the unit:
    (1) Has not been in operation for the two-year period prior to the 
enactment of the Clean Air Act Amendments of 1990, and the emissions 
from such unit continue to be carried in the permitting authority's 
emissions inventory at the time of enactment;
    (2) Was equipped prior to shut-down with a continuous system of 
emissions control that achieves a removal efficiency for sulfur dioxide 
of no less than 85 percent and a removal efficiency for particulates of 
no less than 98 percent;
    (3) Is equipped with low-NOx burners prior to the time of 
commencement of operations following reactivation; and
    (4) Is otherwise in compliance with the requirements of the Clean 
Air Act.
    Reference method means any method of sampling and analyzing for an 
air pollutant as specified in the applicable subpart.
    Repowering means replacement of an existing coal-fired boiler with 
one of the following clean coal technologies: atmospheric or pressurized 
fluidized bed combustion, integrated gasification combined cycle, 
magnetohydrodynamics, direct and indirect coal-fired turbines, 
integrated gasification fuel cells, or as determined by the 
Administrator, in consultation with the Secretary of Energy, a 
derivative of one or more of these technologies, and any other 
technology capable of controlling multiple combustion emissions 
simultaneously with improved boiler or generation efficiency and with 
significantly greater waste reduction relative to the performance of 
technology in widespread commercial use as of November 15, 1990. 
Repowering shall also include any oil and/or gas-fired unit which has 
been awarded clean coal technology demonstration funding as of January 
1, 1991, by the Department of Energy.
    Run means the net period of time during which an emission sample is 
collected. Unless otherwise specified, a run may be either intermittent 
or continuous within the limits of good engineering practice.
    Shutdown means the cessation of operation of an affected facility 
for any purpose.
    Six-minute period means any one of the 10 equal parts of a one-hour 
period.
    Standard means a standard of performance proposed or promulgated 
under this part.
    Standard conditions means a temperature of 293 K (68F) and a 
pressure of 101.3 kilopascals (29.92 in Hg).
    Startup means the setting in operation of an affected facility for 
any purpose.
    State means all non-Federal authorities, including local agencies, 
interstate associations, and State-wide programs, that have delegated 
authority to implement: (1) The provisions of this part; and/or (2) the 
permit program established under part 70 of this chapter. The term State 
shall have its conventional meaning where clear from the context.
    Stationary source means any building, structure, facility, or 
installation which emits or may emit any air pollutant.
    Title V permit means any permit issued, renewed, or revised pursuant 
to Federal or State regulations established to implement title V of the 
Act (42 U.S.C. 7661). A title V permit issued by a State permitting 
authority is called a part 70 permit in this part.
    Volatile Organic Compound means any organic compound which 
participates in atmospheric photochemical reactions; or which is 
measured by a reference method, an equivalent method, an alternative 
method, or which is determined by procedures specified under any 
subpart.

[44 FR 55173, Sept. 25, 1979, as amended at 45 FR 5617, Jan. 23, 1980; 
45 FR 85415, Dec. 24, 1980; 54 FR 6662, Feb. 14, 1989; 55 FR 51382, Dec. 
13, 1990; 57 FR 32338, July 21, 1992; 59 FR 12427, Mar. 16, 1994]

[[Page 18]]



Sec. 60.3  Units and abbreviations.

    Used in this part are abbreviations and symbols of units of measure. 
These are defined as follows:
    (a) System International (SI) units of measure:

A--ampere
g--gram
Hz--hertz
J--joule
K--degree Kelvin
kg--kilogram
m--meter
m 3--cubic meter
mg--milligram--10- 3 gram
mm--millimeter--10- 3 meter
Mg--megagram--10 6 gram
mol--mole
N--newton
ng--nanogram--10- 9 gram
nm--nanometer--10- 9 meter
Pa--pascal
s--second
V--volt
W--watt
--ohm
 g--microgram--10- 6 gram

    (b) Other units of measure:

Btu--British thermal unit
  deg.C--degree Celsius (centigrade)
cal--calorie
cfm--cubic feet per minute
cu ft--cubic feet
dcf--dry cubic feet
dcm--dry cubic meter
dscf--dry cubic feet at standard conditions
dscm--dry cubic meter at standard conditions
eq--equivalent
  deg.F--degree Fahrenheit
ft--feet
gal--gallon
gr--grain
g-eq--gram equivalent
hr--hour
in--inch
k--1,000
l--liter
lpm--liter per minute
lb--pound
meq--milliequivalent
min--minute
ml--milliliter
mol. wt.--molecular weight
ppb--parts per billion
ppm--parts per million
psia--pounds per square inch absolute
psig--pounds per square inch gage
 deg.R--degree Rankine
scf--cubic feet at standard conditions
scfh--cubic feet per hour at standard conditions
scm--cubic meter at standard conditions
sec--second
sq ft--square feet
std--at standard conditions

    (c) Chemical nomenclature:

CdS--cadmium sulfide
CO--carbon monoxide
CO2--carbon dioxide
HCl--hydrochloric acid
Hg--mercury
H2O--water
H2S--hydrogen sulfide
H2SO4--sulfuric acid
N2--nitrogen
NO--nitric oxide
NO2--nitrogen dioxide
NOx--nitrogen oxides
O2--oxygen
SO2--sulfur dioxide
SO3--sulfur trioxide
SOx--sulfur oxides

    (d) Miscellaneous:

A.S.T.M.--American Society for Testing and Materials

[42 FR 37000, July 19, 1977; 42 FR 38178, July 27, 1977]



Sec. 60.4  Address.

    (a) All requests, reports, applications, submittals, and other 
communications to the Administrator pursuant to this part shall be 
submitted in duplicate to the appropriate Regional Office of the U.S. 
Environmental Protection Agency to the attention of the Director of the 
Division indicated in the following list of EPA Regional Offices.

Region I (Connecticut, Maine, Massachusetts, New Hampshire, Rhode 
Island, Vermont), Director, Air Management Division, U.S. Environmental 
Protection Agency, John F. Kennedy Federal Building, Boston, MA 02203.
Region II (New Jersey, New York, Puerto Rico, Virgin Islands), Director, 
Air and Waste Management Division, U.S. Environmental Protection Agency, 
Federal Office Building, 26 Federal Plaza (Foley Square), New York, NY 
10278.
Region III (Delaware, District of Columbia, Maryland, Pennsylvania, 
Virginia, West Virginia), Director, Air and Waste Management Division, 
U.S. Environmental Protection Agency, Curtis Building, Sixth and Walnut 
Streets, Philadelphia, PA 19106.
Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North 
Carolina, South Carolina, Tennessee), Director, Air and Waste Management 
Division, U.S. Environmental Protection Agency, 345 Courtland Street, 
NE., Atlanta, GA 30365.
Region V (Illinois, Indiana, Michigan, Minnesota, Ohio, Wisconsin), 
Director, Air and

[[Page 19]]

Radiation Division, U.S. Environmental Protection Agency, 77 West 
Jackson Boulevard, Chicago, IL 60604-3590.
Region VI (Arkansas, Louisiana, New Mexico, Oklahoma, Texas); Director; 
Air, Pesticides, and Toxics Division; U.S. Environmental Protection 
Agency, 1445 Ross Avenue, Dallas, TX 75202.
Region VII (Iowa, Kansas, Missouri, Nebraska), Director, Air and Toxics 
Division, U.S. Environmental Protection Agency, 726 Minnesota Avenue, 
Kansas City, KS 66101.
Region VIII (Colorado, Montana, North Dakota, South Dakota, Utah, 
Wyoming), Director, Air and Waste Management Division, U.S. 
Environmental Protection Agency, 1860 Lincoln Street, Denver, CO 80295.
Region IX (American Samoa, Arizona, California, Guam, Hawaii, Nevada), 
Director, Air and Waste Management Division, U.S. Environmental 
Protection Agency, 215 Fremont Street, San Francisco, CA 94105.
Region X (Alaska, Oregon, Idaho, Washington), Director, Air and Waste 
Management Division, U.S. Environmental Protection Agency, 1200 Sixth 
Avenue, Seattle, WA 98101.

    (b) Section 111(c) directs the Administrator to delegate to each 
State, when appropriate, the authority to implement and enforce 
standards of performance for new stationary sources located in such 
State. All information required to be submitted to EPA under paragraph 
(a) of this section, must also be submitted to the appropriate State 
Agency of any State to which this authority has been delegated 
(provided, that each specific delegation may except sources from a 
certain Federal or State reporting requirement). The appropriate mailing 
address for those States whose delegation request has been approved is 
as follows:

    (A) [Reserved]
    (B) State of Alabama, Air Pollution Control Division, Air Pollution 
Control Commission, 645 S. McDonough Street, Montgomery, AL 36104.
    (C) State of Alaska, Department of Environmental Conservation, Pouch 
O, Juneau, AK 99811.
    (D) Arizona:
Arizona Department of Health Services, 1740 West Adams Street, Phoenix, 
AZ 85007.
Maricopa County Department of Health Services, Bureau of Air Pollution 
Control, 1825 East Roosevelt Street, Phoenix, AZ 85006.
Pima County Health Department, Air Quality Control District, 151 West 
Congress, Tucson, AZ 85701.
Pima County Air Pollution Control District, 151 West Congress Street, 
Tucson, AZ 85701.

(1) The following table lists the specific source and pollutant 
categories that have been delegated to the air pollution control 
agencies in Arizona. A star (*) is used to indicate each category that 
has been delegated.

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[GRAPHIC] [TIFF OMITTED] TC01JN92.001

    (E) State of Arkansas: Chief, Division of Air Pollution Control, 
Arkansas Department of Pollution Control and Ecology, 8001 National 
Drive, P.O. Box 9583, Little Rock, AR 72209.
    (F) California:
Amador County Air Pollution Control District, P.O. Box 430, 810 Court 
Street, Jackson, CA 95642
Bay Area Air Pollution Control District, 939 Ellis Street, San 
Francisco, CA 94109.
Butte County Air Pollution Control District, P.O. Box 1229, 316 Nelson 
Avenue, Oroville, CA 95965
Calaveras County Air Pollution Control District, Government Center, El 
Dorado Road, San Andreas, CA 95249
Colusa County Air Pollution Control District, 751 Fremont Street, 
Colusa, CA 95952
El Dorado Air Pollution Control District, 330 Fair Lane, Placerville, CA 
95667
Fresno County Air Pollution Control District, 1221 Fulton Mall, Fresno, 
CA 93721
Glenn County Air Pollution Control District, P.O. Box 351, 720 North 
Colusa Street, Willows, CA 95988
Great Basin Unified Air Pollution Control District, 157 Short Street, 
Suite 6, Bishop, CA 93514
Imperial County Air Pollution Control District, County Services 
Building, 939 West Main Street, El Centro, CA 92243
Kern County Air Pollution Control District, 1601 H Street, Suite 250, 
Bakersfield, CA 93301
Kings County Air Pollution Control District, 330 Campus Drive, Hanford, 
CA 93230
Lake County Air Pollution Control District, 255 North Forbes Street, 
Lakeport, CA 95453
Lassen County Air Pollution Control District, 175 Russell Avenue, 
Susanville, CA 96130
Madera County Air Pollution Control District, 135 W. Yosemite Avenue, 
Madera, CA 93637.
Mariposa County Air Pollution Control District, Box 5, Mariposa, CA 
95338
Mendocino County Air Pollution Control District, County Courthouse, 
Ukiah, CA 95482.
Merced County Air Pollution Control District, P.O. Box 471, 240 East 
15th Street, Merced, CA 95340
Modoc County Air Pollution Control District, 202 West 4th Street, 
Alturas, CA 96101
Monterey Bay Unified Air Pollution Control, 1164 Monroe Street, Suite 
10, Salinas, CA 93906
Nevada County Air Pollution Control District, H.E.W. Complex, Nevada 
City, CA 95959
North Coast Unified Air Quality Management District, 5630 South 
Broadway, Eureka, CA 95501
Northern Sonoma County Air Pollution Control District, 134 ``A'' Avenue, 
Auburn, CA 95448
Placer County Air Pollution Control District, 11491 ``B'' Avenue, 
Auburn, CA 95603
Plumas County Air Pollution Control District, P.O. Box 480, Quincy, CA 
95971
Sacramento County Air Pollution Control District, 3701 Branch Center 
Road, Sacramento, CA 95827.

[[Page 22]]

San Bernardino County Air Pollution Control District, 15579-8th, 
Victorville, CA 92392
San Diego County Air Pollution Control District, 9150 Chesapeake Drive, 
San Diego, CA 92123.
San Joaquin County Air Pollution Control District, 1601 E. Hazelton 
Street (P.O. Box 2009) Stockton, CA 95201.
San Luis Obispo County Air Pollution Control District, P.O. Box 637, San 
Luis Obispo, CA 93406
Santa Barbara County Air Pollution Control District, 315 Camino del 
Rimedio, Santa Barbara, CA 93110
Shasta County Air Pollution Control District, 2650 Hospital Lane, 
Redding, CA 96001
Sierra County Air Pollution Control District, P.O. Box 286, Downieville, 
CA 95936
Siskiyou County Air Pollution Control District, 525 South Foothill 
Drive, Yreka, CA 96097
South Coast Air Quality Management District, 9150 Flair Drive, El Monte, 
CA 91731
Stanislaus County Air Pollution Control District, 1030 Scenic Drive, 
Modesto, CA 95350
Sutter County Air Pollution Control District, Sutter County Office 
Building, 142 Garden Highway, Yuba City, CA 95991
Tehama County Air Pollution Control District, P.O. Box 38, 1760 Walnut 
Street, Red Bluff, CA 96080
Tulare County Air Pollution Control District, County Civic Center, 
Visalia, CA 93277
Tuolumne County Air Pollution Control District, 9 North Washington 
Street, Sonora, CA 95370
Ventura County Air Pollution Control District, 800 South Victoria 
Avenue, Ventura, CA 93009
Yolo-Solano Air Pollution Control District, P.O. Box 1006, 323 First 
Street, 5, Woodland, CA 95695

(1) The following table lists the specific source and pollutant 
categories that have been delegated to the air pollution control 
agencies in California. A star (*) is used to indicate each category 
that has been delegated.

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[[Page 24]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.003

    (G) State of Colorado, Department of Health, Air Pollution Control 
Division, 4210 East 11th Avenue, Denver, CO 80220.

    Editorial Note: For a table listing Region VIII's NSPS delegation 
status, see paragraph (c) of this section.
    (H) State of Connecticut, Bureau of Air Management, Department of 
Environmental Protection, State Office Building, 165 Capitol Avenue, 
Hartford, CT 06106.
    (I) State of Delaware, Delaware Department of Natural Resources and 
Environmental Control, 89 Kings Highway, P.O. Box 1401, Dover, DE 19901
    (J) District of Columbia, Department of Consumer and Regulatory 
Affairs, 5000 Overlook Avenue SW., Washington DC 20032.
    (K) Bureau of Air Quality Management, Department of Environmental 
Regulation, Twin Towers Office Building, 2600 Blair Stone Road, 
Tallahassee, FL 32301.
    (L) State of Georgia, Environmental Protection Division, Department 
of Natural Resources, 270 Washington Street, SW., Atlanta, GA 30334.
    (M) Hawaii Department of Health, 1250 Punchbowl Street, Honolulu, HI 
96813

[[Page 25]]

Hawaii Department of Health (mailing address), Post Office Box 3378, 
Honolulu, HI 96801
    (N) State of Idaho, Department of Health and Welfare, Statehouse, 
Boise, ID 83701.
    (O) State of Illinois, Bureau of Air, Division of Air Pollution 
Control, Illinois Environmental Protection Agency, 2200 Churchill Road, 
Springfield, IL 62794-9276.
    (P) State of Indiana, Indiana Department of Environmental 
Management, 100 North Senate Avenue, P.O. Box 6015, Indianapolis, 
Indiana 46206-6015.
    (Q) State of Iowa: Iowa Department of Natural Resources, 
Environmental Protection Division, Henry A. Wallace Building, 900 East 
Grand, Des Moines, IO 50319.
    (R) State of Kansas: Kansas Department of Health and Environment, 
Bureau of Air Quality and Radiation Control, Forbes Field, Topeka, KS 
66620.
    (S) Division of Air Pollution Control, Department for Natural 
Resources and Environmental Protection, U.S. 127, Frankfort, KY 40601.
    (T) State of Louisiana: Program Administrator, Air Quality Division, 
Louisiana Department of Environmental Quality, P.O. Box 44096, Baton 
Rouge, LA 70804.
    (U) State of Maine, Bureau of Air Quality Control, Department of 
Environmental Protection, State House, Station No. 17, Augusta, ME 
04333.
    (V) State of Maryland: Bureau of Air Quality and Noise Control, 
Maryland State Department of Health and Mental Hygiene, 201 West Preston 
Street, Baltimore, MD 21201.
    (W) Commonwealth of Massachusetts, Division of Air Quality Control, 
Department of Environmental Protection, One Winter Street, 7th floor, 
Boston, MA 02108.
    (X) State of Michigan, Air Quality Division, Michigan Department of 
Environmental Quality, P.O. Box 30260, Lansing, Michigan 48909.
    (Y) Minnesota Pollution Control Agency, Division of Air Quality, 520 
Lafayette Road, St. Paul, MN 55155.
    (Z) Bureau of Pollution Control, Department of Natural Resources, 
P.O. Box 10385, Jackson, MS 39209.
    (AA) State of Missouri: Missouri Department of Natural Resources, 
Division of Environmental Quality, P.O. Box 176, Jefferson City, MO 
65102.
    (BB) State of Montana, Department of Health and Environmental 
Services, Air Quality Bureau, Cogswell Building, Helena, MT 59601.

    Editorial Note: For a table listing Region VIII's NSPS delegation 
status, see paragraph (c) of this section.
    (CC) State of Nebraska, Nebraska Department of Environmental 
Control, P.O. Box 94877, State House Station, Lincoln, NE 68509.
Lincoln-Lancaster County Health Department, Division of Environmental 
Health, 2200 St. Marys Avenue, Lincoln, NE 68502

    (DD) Nevada:
Nevada Department of Conservation and Natural Resources, Division of 
Environmental Protection, 201 South Fall Street, Carson City, NV 89710.
Clark County County District Health Department, Air Pollution Control 
Division, 625 Shadow Lane, Las Vegas, NV 89106.
Washoe County District Health Department, Division of Environmental 
Protection, 10 Kirman Avenue, Reno, NV 89502.

(1) The following table lists the specific source and pollutant 
categories that have been delegated to the air pollution control 
agencies in Nevada. A star (*) is used to indicate each category that 
has been delegated.

[[Page 26]]

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[[Page 27]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.005

    (EE) State of New Hampshire, Air Resources Division, Department of 
Environmental Services, 64 North Main Street, Caller Box 2033, Concord, 
NH 03302-2033.
    (FF) State of New Jersey: New Jersey Department of Environmental 
Protection, Division of Environmental Quality, Enforcement Element, John 
Fitch Plaza, CN-027, Trenton, NJ 08625.
    (1) The following table lists the specific source and pollutant 
categories that have been delegated to the states in Region II. The (X) 
symbol is used to indicate each category that has been delegated.

----------------------------------------------------------------------------------------------------------------
                                                                           State
                        Subpart          -----------------------------------------------------------------------
                                             New Jersey         New York         Puerto Rico     Virgin Islands
----------------------------------------------------------------------------------------------------------------
D             Fossil-Fuel Fired Steam     X...............  X...............  X...............  X
               Generators for Which
               Construction Commenced
               After August 17, 1971
               (Steam Generators and
               Lignite Fired Steam
               Generators).
Da            Electric Utility Steam      X...............                    X...............
               Generating Units for
               Which Construction
               Commenced After September
               18, 1978.
Db            Industrial-Commercial-      X...............  X...............  X...............  X
               Institutional Steam
               Generating Units.
E             Incinerators..............  X...............  X...............  X...............  X
F             Portland Cement Plants....  X...............  X...............  X...............  X
G             Nitric Acid Plants........  X...............  X...............  X...............  X
H             Sulfuric Acid Plants......  X...............  X...............  X...............  X
I             Asphalt Concrete Plants...  X...............  X...............  X...............  X
J             Petroleum Refineries--(All  X...............  X...............  X...............  X
               Categories).
K             Storage Vessels for         X...............  X...............  X...............  X
               Petroleum Liquids
               Constructed After June
               11, 1973, and prior to
               May 19, 1978.
Ka            Storage Vessels for         X...............  X...............  X...............
               Petroleum Liquids
               Constructed After May 18,
               1978.
L             Secondary Lead Smelters...  X...............  X...............  X...............  X
M             Secondary Brass and Bronze  X...............  X...............  X...............  X
               Ingot Production Plants.
N             Iron and Steel Plants.....  X...............  X...............  X...............  X
O             Sewage Treatment Plants...  X...............  X...............  X...............  X
P             Primary Copper Smelters...  X...............  X...............  X...............  X
Q             Primary Zinc Smelters.....  X...............  X...............  X...............  X
R             Primary Lead Smelters.....  X...............  X...............  X...............  X

[[Page 28]]

 
S             Primary Aluminum Reduction  X...............  X...............  X...............  X
               Plants.
T             Phosphate Fertilizer        X...............  X...............  X...............  X
               Industry: Wet Process
               Phosphoric Acid Plants.
U             Phosphate Fertilizer        X...............  X...............  X...............  X
               Industry: Superphosphoric
               Acid Plants.
V             Phosphate Fertilizer        X...............  X...............  X...............  X
               Industry: Diammonium
               Phosphate Plants.
W             Phosphate Fertilizer        X...............  X...............  X...............  X
               Industry: Triple
               Superphosphate Plants.
X             Phosphate Fertilizer        X...............  X...............  X...............  X
               Industry: Granular Triple
               Superphosphate.
Y             Coal Preparation Plants...  X...............  X...............  X...............  X
Z             Ferroally Production        X...............  X...............  X...............  X
               Facilities.
AA            Steel Plants: Electric Arc  X...............  X...............  X...............  X
               Furnaces.
AAa           Electric Arc Furnaces and   X...............  X...............  X...............  ................
               Argon-Oxygen
               Decarburization Vessels
               in Steel Plants.
BB            Kraft Pulp Mills..........  X...............  X...............  X...............  ................
CC            Glass Manufacturing Plants  X...............  X...............  X...............  ................
DD            Grain Elevators...........  X...............  X...............  X...............  ................
EE            Surface Coating of Metal    X...............  X...............  X...............  ................
               Furniture.
GG            Stationary Gas Turbines...  X...............  X...............  X...............  ................
HH            Lime Plants...............  X...............  X...............  X...............  ................
KK            Lead Acid Battery           X...............  X...............                    ................
               Manufacturing Plants.
LL            Metallic Mineral            X...............  X...............  X...............  ................
               Processing Plants.
MM            Automobile and Light-Duty   X...............  X...............    ..............  ................
               Truck Surface Coating
               Operations.
NN            Phosphate Rock Plants.....  X...............  X...............
PP            Ammonium Sulfate            X...............  X...............
               Manufacturing Plants.
QQ            Graphic Art Industry        X...............  X...............  X...............  X
               Publication Rotogravure
               Printing.
RR            Pressure Sensitive Tape     X...............  X...............  X...............  ................
               and Label Surface Coating
               Operations.
SS            Industrial Surface          X...............  X...............  X...............  ................
               Coating: Large Appliances.
TT            Metal Coil Surface Coating  X...............  X...............  X...............  ................
UU            Asphalt Processing and      X...............  X...............  X...............  ................
               Asphalt Roofing
               Manufacture.
VV            Equipment Leaks of          X...............                    X...............  ................
               Volatile Organic
               Compounds in Synthetic
               Organic Chemical
               Manufacturing Industry.
WW            Beverage Can Surface        X...............  X...............  X...............  ................
               Coating Industry.
XX            Bulk Gasoline Terminals...  X...............  X...............  X...............  ................
FFF           Flexible Vinyl and          X...............  X...............  X...............  ................
               Urethane Coating and
               Printing.
GGG           Equipment Leaks of VOC in   X...............                    X...............
               Petroleum Refineries.
HHH           Synthetic Fiber Production  X...............                    X...............
               Facilities.
JJJ           Petroleum Dry Clearners...  X...............  X...............  X...............  ................
KKK           Equipment Leaks of VOC
               from Onshore Natural Gas
               Processing Plants.
LLL           Onshore Natural Gas                           X...............
               Processing Plants; SO2
               Emissions.
OOO           Nonmetallic Mineral                           X...............  X...............  ................
               Processing Plants.
PPP           Wool Fiberglass Insulation                    X...............  X...............  ................
               Manufacturing Plants.
----------------------------------------------------------------------------------------------------------------

    (GG) State of New Mexico: Director, New Mexico Environmental 
Improvement Division, Health and Environment Department, 1190 St. 
Francis Drive, Santa Fe, NM 87503.
    (i) The City of Albuquerque and Bernalillo County: Director, The 
Albuquerque Environmental Health Department, The City of Albuquerque, 
P.O. Box 1293, Albuquerque, NM 87103.
    (HH) New York: New York State Department of Environmental 
Conservation, 50 Wolf Road Albany, New York 12233, attention: Division 
of Air Resources.
    (II) North Carolina Environmental Management Commission, Department 
of Natural and Economic Resources, Division of Environmental Management, 
P.O. Box 27687, Raleigh, NC 27611. Attention: Air Quality Section.
    (JJ) State of North Dakota, State Department of Health and 
Consolidated Laboratories, Division of Environmental Engineering, State 
Capitol, Bismarck, ND 58505.

    Editorial Note: For a table listing Region VIII's NSPS delegation 
status, see paragraph (c) of this section.
    (KK) State of Ohio:
    (i) Medina, Summit and Portage Counties; Director, Akron Regional 
Air Quality Management District, 177 South Broadway, Akron, OH 44308.
    (ii) Stark County: Air Pollution Control Division, 420 Market Avenue 
North, Canton, Ohio 44702-3335.
    (iii) Butler, Clermont, Hamilton, and Warren Counties: Air Program 
Manager, Hamilton County Department of Environmental Services, 1632 
Central Parkway, Cincinnati, Ohio 45210.
    (iv) Cuyahoga County: Commissioner, Department of Public Health & 
Welfare, Division of Air Pollution Control, 1925 Saint Clair, Cleveland, 
Ohio 44114.
    (v) Belmont, Carroll, Columbiana, Harrison, Jefferson, and Monroe 
Counties: Director, North Ohio Valley Air Authority

[[Page 29]]

(NOVAA), 814 Adams Street, Steubenville, OH 43952.
    (vi) Clark, Darke, Greene, Miami, Montgomery, and Preble Counties: 
Director, Regional Air Pollution Control Agency (RAPCA) 451 West Third 
Street, Dayton, Ohio 45402.
    (vii) Lucas County and the City of Rossford (in Wood County): 
Director, Toledo Environmental Services Agency, 26 Main Street, Toledo, 
OH 43605.
    (viii) Adams, Brown, Lawrence, and Scioto Counties; Engineer-
Director, Air Division, Portsmouth City Health Department, 740 Second 
Street, Portsmouth, OH 45662.
    (ix) Allen, Ashland, Auglaize, Crawford, Defiance, Erie, Fulton, 
Hancock, Hardin, Henry, Huron, Marion, Mercer, Ottawa, Paulding, Putnam, 
Richland, Sandusky, Seneca, Van Wert, Williams, Wood (except City of 
Rossford), and Wyandot Counties: Ohio Environmental Protection Agency, 
Northwest District Office, Air Pollution Control, 347 Dunbridge Rd., 
Bowling Green, Ohio 43402.
    (x) Ashtabula, Holmes, Lorain, and Wayne Counties: Ohio 
Environmental Protection Agency, Northeast District Office, Air 
Pollution Unit, 2110 East Aurora Road, Twinsburg, OH 44087.
    (xi) Athens, Coshocton, Gallia, Guernsey, Hocking, Jackson, Meigs, 
Morgan, Muskingum, Noble, Perry, Pike, Ross, Tuscarawas, Vinton, and 
Washington Counties: Ohio Environmental Protection Agency, Southeast 
District Office, Air Pollution Unit, 2195 Front Street, Logan, OH 43138.
    (xii) Champaign, Clinton, Highland, Logan, and Shelby Counties: Ohio 
Environmental Protection Agency, Southwest District Office, Air 
Pollution Unit, 401 East Fifth Street, Dayton, Ohio 45402-2911.
    (xiii) Delaware, Fairfield, Fayette, Franklin, Knox, Licking, 
Madison, Morrow, Pickaway, and Union Counties: Ohio Environmental 
Protection Agency, Central District Office, Air Pollution Control, 3232 
Alum Creek Drive, Columbus, Ohio, 43207-3417.
    (xiv) Geauga and Lake Counties: Lake County General Health District, 
Air Pollution Control, 105 Main Street, Painesville, OH 44077.
    (xv) Mahoning and Trumbull Counties: Mahoning-Trumbull Air Pollution 
Control Agency, 9 West Front Street, Youngstown, OH 44503.

    (LL) State of Oklahoma, Oklahoma State Department of Health, Air 
Quality Service, P.O. Box 53551, Oklahoma City, OK 73152.
    (i) Oklahoma City and County: Director, Oklahoma City-County Health 
Department, 921 Northeast 23rd Street, Oklahoma City, OK 73105.
    (ii) Tulsa County: Tulsa City-County Health Department, 4616 East 
Fifteenth Street, Tulsa, OK 74112.
    (MM) State of Oregon, Department of Environmental Quality, Yeon 
Building, 522 S.W. Fifth, Portland, OR 97204.
    (i)--(viii) [Reserved]
    (ix) Lane Regional Air Pollution Authority, 225 North Fifth, Suite 
501, Springfield, OR 97477.
    (NN) (a) City of Philadelphia: Philadelphia Department of Public 
Health, Air Management Services, 500 S. Broad Street, Philadelphia, PA 
19146.
    (b) Commonwealth of Pennsylvania: Department of Environmental 
Resources, Post Office Box 2063, Harrisburg, PA 17120.
    (c) Allegheny County: Allegheny County Health Department, Bureau of 
Air Pollution Control, 301 Thirty-ninth Street, Pittsburgh, PA 15201.
    (OO) State of Rhode Island, Division of Air and Hazardous Materials, 
Department of Environmental Management, 291 Promenade Street, 
Providence, RI 02908.
    (PP) State of South Carolina, Office of Environmental Quality 
Control, Department of Health and Environmental Control, 2600 Bull 
Street, Columbia, SC 29201.
    (QQ) State of South Dakota, Department of Water and Natural 
Resources, Office of Air Quality and Solid Waste, Joe Foss Building, 523 
East Capitol, Pierre, SD 57501-3181.

    Editorial Note: For a table listing Region VIII's NSPS delegation 
status, see paragragh (c) of this section.
    (RR) Division of Air Pollution Control, Tennessee Department of 
Public Health, 256 Capitol Hill Building, Nashville, TN 37219.

Knox County Department of Air Pollution, City/County Building, Room 
L222, 400 Main Avenue, Knoxville, TN 37902.
Air Pollution Control Bureau, Metropolitan Health Department, 311 23rd 
Avenue North, Nashville, TN 37203.
    (SS) State of Texas, Texas Air Control Board, 6330 Highway 290 East, 
Austin, TX 78723.
    (TT) State of Utah, Department of Health, Bureau of Air Quality, 288 
North 1460 West, P.O. Box 16690, Salt Lake City, UT 84113--0690.

    Editorial Note: For a table listing Region VIII's NSPS delegation 
status, see paragraph (c) of this section.
    (UU) State of Vermont, Air Pollution Control Division, Agency of 
Natural Resources, Building 3 South, 103 South Main Street, Waterbury, 
VT 05676.
    (VV) Commonwealth of Virginia, Virginia State Air Pollution Control 
Board, Room 1106, Ninth Street Office Building, Richmond, VA 23219.
    (WW)(i) Washington: Washington Department of Ecology, Post Office 
Box 47600, Olympia, WA 98504.
    (ii) Benton-Franklin Counties Clean Air Authority (BFCCAA), 650 
George Washington Way, Richland, WA 99352.

[[Page 30]]

    (iii) Northwest Air Pollution Authority (NWAPA), 302 Pine Street, 
#207, Mt. Vernon, WA 98273-3852.
    (iv) Olympic Air Pollution Control Authority (OAPCA), 909 Sleater-
Kinney Rd. SE - Suite 1, Lacey, WA 98503.
    (v) Puget Sound Air Pollution Control Authority (PSAPCA), 110 Union 
Street, Suite 500, Seattle, WA 98101.
    (vi) Southwest Air Pollution Control Authority (SWAPCA), 1308 N.E. 
134th Street, Suite D, Vancouver, WA 98685-2747.
    (vii) Spokane County Air Pollution Control Authority (SCAPCA), West 
1101 College Avenue, Health Building, Room 403, Spokane, WA 99201.
    (viii) [Reserved]
    (ix) The following is a table indicating the delegation status of 
the New Source Performance Standards for the State of Washington.

[[Page 31]]



                                      Delegation of Authority--New Source Performance Standards State of Washington
--------------------------------------------------------------------------------------------------------------------------------------------------------
           Subpart                      Description               WDOE 1      BFCCAA 2     NWAPCA 3     OAPCA 4      PSAPCA 5     SWAPCA 6     SCAPCA 7
--------------------------------------------------------------------------------------------------------------------------------------------------------
A...........................  General Provisions.............     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
D...........................  Fossil-Fuel-Fired Steam             01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Generators.
Da..........................  Electric Utility Steam              01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Generating Units.
Db..........................  Industrial-Commercial-              01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Institutional Steam Generating
                               Units.
Dc..........................  Small Industrial-Commercial-        01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Institutional Steam Generating
                               Units.
E...........................  Incinerators...................     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
Ea..........................  Municipal Waste Combustion.....     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
F...........................  Portland Cement Plants.........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
G...........................  Nitric Acid Plants.............     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
H...........................  Sulfuric Acid Plants...........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
I...........................  Asphalt Concrete Plants........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
J...........................  Petroleum Refineries...........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
K...........................  Petroleum Liquid Storage            01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Vessels 6/11/73-5/19/78.
Ka..........................  Petroleum Liquid Storage            01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Vessels After 5/18/78-7/23/84.
Kb..........................  Volatile Organic Liquid Storage     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Vessels After 7/23/84.
L...........................  Secondary Lead Smelters........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
M...........................  Brass & Bronze Ingot Production     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Plants.
N...........................  Iron & Steel Plants: BOPF           01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Particulate.
Na..........................  Iron & Steel Plants: BOPF, Hot      01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Metal & Skimming Stations.
O...........................  Sewage Treatment Plants........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
P...........................  Primary Copper Smelters........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
Q...........................  Primary Zinc Smelters..........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
R...........................  Primary Lead Smelters..........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
S...........................  Primary Aluminum Reduction          01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Plants.
T...........................  Wet Process Phosphoric Acid         01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Plants.
U...........................  Superphosphoric Acid Plants....     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
V...........................  Diammonium Phosphate Plants....     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
W...........................  Triple Superphosphate Plants...     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
X...........................  Granular Triple Superphosphate      01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Storage Facilities.
Y...........................  Coal Preparation Plants........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
Z...........................  Ferroalloy Production               01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Facilities.
AA..........................  Steel Plant Electric Arc            01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Furnaces 10/21/74-8/17/83.
AAa.........................  Steel Plant Electric Arc            01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Furnaces & Argon-Oxygen
                               Decarburization Vessels after
                               8/7/83.
BB..........................  Kraft Pulp Mills...............     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
CC..........................  Glass Manufacturing Plants.....     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
DD..........................  Grain Elevators................     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
EE..........................  Surface Coating of Metal            01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Furniture.
GG..........................  Stationary Gas Turbines........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
HH..........................  Lime Manufacturing Plants......     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
KK..........................  Lead-Acid Battery Manufacturing     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Plant.
LL..........................  Metallic Mineral Processing         01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Plants.
MM..........................  Automobile & Light Duty Truck       01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Surface Coating Operations.
NN..........................  Phosphate Rock Plants..........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
PP..........................  Ammonium Sulfate Manufacture...     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
QQ..........................  Graphic Arts Industry:              01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Publication Rotogravure
                               Printing.

[[Page 32]]

 
RR..........................  Pressure Sensitive Tape & Label     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Surface Coating Operations.
SS..........................  Industrial Surface Coating:         01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Large Appliances.
TT..........................  Metal Coil Surface Coating.....     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
UU..........................  Asphalt Processing & Asphalt        01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Roofing Manufacturer.
VV..........................  SOCMI Equipment Leaks (VOC)....     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
WW..........................  Beverage Can Surface Coating        01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Operations.
XX..........................  Bulk Gasoline Terminals........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
AAA.........................  Residential Wood Heaters.......     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
BBB.........................  Rubber Tire Manufacturing......     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
DDD.........................  Polymer Manufacturing Industry      01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               (VOC).
FFF.........................  Flexible Vinyl and Urethane         01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Coating and Printing.
GGG.........................  Equipment Leaks of VOC in           01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Petroleum Refineries.
HHH.........................  Synthetic Fiber Production          01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Facilities.
III.........................  VOC Emissions from SOCMI Air        01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Oxidation Unit Processes.
JJJ.........................  Petroleum Dry Cleaners.........     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
KKK.........................  VOC Emissions from Onshore          01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Natural Gas Production.
LLL.........................  Onshore Natural Gas Production      01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               (SO2).
NNN.........................  VOC Emissions from SOCMI            01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Distillation Facilities.
OOO.........................  Nonmetallic Mineral Processing      01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Plants.
PPP.........................  Wool Fiberglass Insulation          01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Manufacturing Plants.
QQQ.........................  VOC Emissions from Petroleum        01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Refinery Wastewater Systems.
SSS.........................  Magnetic Tape Coating               01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Facilities.
TTT.........................  Surface Coating of Plastic          01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Parts for Business Machines.
UUU.........................  Calciners & Dryers In Mineral       01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93
                               Industries.
VVV.........................  Polymeric Coating of Support        01/01/93     01/01/93     01/01/93     01/01/93     01/01/93     01/01/93    01/01/93
                               Substrates Facilities.
--------------------------------------------------------------------------------------------------------------------------------------------------------
1 WDOE--State of Washington Department of Ecology.
2 BFCCAA--Benton Franklin Counties Clean Air Authority.
3 NWAPCA--Northwest Air Pollution Control Authority.
4 OAPCA--Olympic Air Pollution Control Authority.
5 PSAPCA--Puget Sound Air Pollution Control Agency.
6 SWAPCA--Southwest Air Pollution Control Authority.
7 SCAPCA--Spokane County Air Pollution Control Authority.


[[Page 33]]

    (XX) State of West Virginia: Air Pollution Control Commission, 1558 
Washington Street East, Charleston, WV 25311.
    (YY) Wisconsin--Wisconsin Department of Natural Resources, P.O. Box 
7921, Madison, WI 53707.
    (ZZ) State of Wyoming, Department of Environmental Quality, Air 
Quality Division, Herschler Building, 122 West 25th Street, Cheyenne, WY 
82002.

    Editorial Note: For a table listing Region VIII's NSPS delegation 
status, see paragraph (c) of this section.
    (AAA) Territory of Guam: Guam Environmental Protection Agency, Post 
Office Box 2999, Agana, Guam 96910.
    (1) The following table lists the specific source and pollutant 
categories that have been delegated to the air pollution control agency 
in Guam. A star (*) is used to indicate each category that has been 
delegated.

[[Page 34]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.006


[[Page 35]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.007

    (BBB) Commonwealth of Puerto Rico: Commonwealth of Puerto Rico 
Environmental Quality Board, P.O. Box 11488, Santurce, PR 00910,  
Attention: Air Quality Area Director (see table under 
Sec. 60.4(b)(FF)(1)).
    (CCC) U.S. Virgin Islands: U.S. Virgin Islands Department of 
Conservation and Cultural Affairs, P.O. Box 578, Charlotte Amalie, St. 
Thomas, VI 00801.
    (c) The following is a table indicating the delegation status of New 
Source Performance Standards for Region VIII.

                              Delegation Status of New Source Performance Standards
                                            [(NSPS) for Region VIII]
----------------------------------------------------------------------------------------------------------------
                    Subpart                         CO       MT\1\        ND       SD\1\      UT\1\        WY
----------------------------------------------------------------------------------------------------------------
A--General Provisions.........................        (*)        (*)        (*)        (*)        (*)        (*)
D--Fossil Fuel Fired Steam Generators.........        (*)        (*)        (*)        (*)        (*)        (*)
Da--Electric Utility Steam Generators.........        (*)        (*)        (*)        (*)        (*)        (*)
Db--Industrial-Commercial--Institutional Steam        (*)        (*)        (*)        (*)        (*)        (*)
 Generators...................................
Dc--Industrial-Commercial--Institutional Steam        (*)        (*)        (*)        (*)        (*)
 Generators...................................
E--Incinerators...............................        (*)        (*)        (*)        (*)        (*)        (*)
Ea--Municipal Waste Combustors................        (*)        (*)        (*)        (*)        (*)        (*)
F--Portland Cement Plants.....................        (*)        (*)        (*)        (*)        (*)        (*)
G--Nitric Acid Plants.........................        (*)        (*)        (*)                   (*)        (*)
H--Sulfuric Acid Plants.......................        (*)        (*)        (*)                   (*)        (*)
I--Asphalt Concrete Plants....................        (*)        (*)        (*)        (*)        (*)        (*)
J--Petroleum Refineries.......................        (*)        (*)        (*)                   (*)        (*)
K--Petroleum Storage Vessels (after 6/11/73 &         (*)        (*)        (*)        (*)        (*)        (*)
 prior to.....................................
  5/19/78)....................................
Ka--Petroleum Storage Vessels (after 5/18/78 &        (*)        (*)        (*)        (*)        (*)        (*)
 prior to.....................................
  7/23/84)....................................
Kb--Petroleum Storage Vessels (after 7/23/84).        (*)        (*)        (*)        (*)        (*)        (*)
L--Secondary Lead Smelters....................        (*)        (*)        (*)                   (*)        (*)
M--Secondary Brass & Bronze Production Plants.        (*)        (*)        (*)                   (*)        (*)
N--Primary Emissions from Basic Oxygen Process        (*)        (*)        (*)                   (*)        (*)
 Furnaces (after 6/11/73).....................
Na--Secondary Emissions from Basic Oxygen             (*)        (*)        (*)                   (*)        (*)
 Process Furnaces (after 1/20/83).............
O--Sewage Treatment Plants....................        (*)        (*)        (*)        (*)        (*)        (*)
P--Primary Copper Smelters....................        (*)        (*)        (*)                   (*)        (*)

[[Page 36]]

 
Q--Primary Zinc Smelters......................        (*)        (*)        (*)                   (*)        (*)
R--Primary Lead Smelters......................        (*)        (*)        (*)                   (*)        (*)
S--Primary Aluminum Reduction Plants..........        (*)        (*)        (*)                   (*)        (*)
T--Phosphate Fertilizer Industry: Wet Process         (*)        (*)        (*)                   (*)        (*)
 Phosphoric Plants............................
U--Phosphate Fertilizer Industry:                     (*)        (*)        (*)                   (*)        (*)
 Superphosphoric Acid Plants..................
V--Phosphate Fertilizer Industry: Diammonium          (*)        (*)        (*)                   (*)        (*)
 Phosphate Plants.............................
W--Phosphate Fertilizer Industry: Triple              (*)        (*)        (*)                   (*)        (*)
 Superphosphate Plants........................
X--Phosphate Fertilizer Industry: Granular            (*)        (*)        (*)                   (*)        (*)
 Triple Superphosphate Storage Facilities.....
Y--Coal Preparation Plants....................        (*)        (*)        (*)        (*)        (*)        (*)
Z--Ferroalloy Production Facilities...........        (*)        (*)        (*)                   (*)        (*)
AA--Steel Plants: Electric Arc Furnaces (10/21/       (*)        (*)        (*)                   (*)        (*)
 74-8/17/83)..................................
AAa--Steel Plants: Electric Arc Furnaces and          (*)        (*)        (*)                   (*)        (*)
 Argon-Oxygen Decarburization Vessels (after 8/
 7/83)........................................
BB--Kraft Pulp Mills..........................        (*)        (*)        (*)                   (*)        (*)
CC--Glass Manufacturing Plants................        (*)        (*)        (*)                   (*)        (*)
DD--Grain Elevator............................        (*)        (*)        (*)        (*)        (*)        (*)
EE--Surface Coating of Metal Furniture........        (*)        (*)        (*)                   (*)        (*)
GG--Stationary Gas Turbines...................        (*)        (*)        (*)        (*)        (*)        (*)
HH--Lime Manufacturing Plants.................        (*)        (*)        (*)        (*)        (*)        (*)
KK--Lead-Acid Battery Manufacturing Plants....        (*)        (*)        (*)                   (*)        (*)
LL--Metallic Mineral Processing Plants........        (*)        (*)        (*)        (*)        (*)        (*)
MM--Automobile & Light Duty Truck Surface             (*)        (*)        (*)                   (*)        (*)
 Coating Operations...........................
NN--Phosphate Rock Plants.....................        (*)        (*)        (*)                   (*)        (*)
PP--Ammonium Sulfate Manufacturing............        (*)        (*)        (*)                   (*)        (*)
QQ--Graphic Arts Industry: Publication                (*)        (*)        (*)        (*)        (*)        (*)
 Rotogravure Printing.........................
RR--Pressure Sensitive Tape & Label Surface           (*)        (*)        (*)        (*)        (*)        (*)
 Coating......................................
SS--Industrial Surface Coating: Large                 (*)        (*)        (*)                   (*)        (*)
 Applications.................................
TT--Metal Coil Surface Coating................        (*)        (*)        (*)                   (*)        (*)
UU--Asphalt Processing & Asphalt Roofing              (*)        (*)        (*)                   (*)        (*)
 Manufacture..................................
VV--Synthetic Organic Chemicals Manufacturing:        (*)        (*)        (*)        (*)        (*)        (*)
 Equipment Leaks of VOC.......................
WW--Beverage Can Surface Coating Industry.....        (*)        (*)        (*)                   (*)        (*)
XX--Bulk Gasoline Terminals...................        (*)        (*)        (*)        (*)        (*)        (*)
AAA--Residential Wood Heaters.................        (*)        (*)        (*)        (*)        (*)        (*)
BBB--Rubber Tires.............................        (*)        (*)        (*)                   (*)        (*)
DDD--VOC Emissions from Polymer Manufacturing         (*)        (*)        (*)                   (*)        (*)
 Industry.....................................
FFF--Flexible Vinyl & Urethane Coating &              (*)        (*)        (*)                   (*)        (*)
 Printing.....................................
GGG--Equipment Leaks of VOC in Petroleum              (*)        (*)        (*)                   (*)        (*)
 Refineries...................................
HHH--Synthetic Fiber Production...............        (*)        (*)        (*)                   (*)        (*)
III--VOC Emissions from the Synthetic Organic                    (*)        (*)                   (*)        (*)
 Chemical Manufacturing Industry Air Oxidation
 Unit Processes...............................
JJJ--Petroleum Dry Cleaners...................        (*)        (*)        (*)        (*)        (*)        (*)
KKK--Equipment Leaks of VOC from Onshore              (*)        (*)        (*)                   (*)        (*)
 Natural Gas Processing Plants................
LLL--Onshore Natural Gas Processing: SO2              (*)        (*)        (*)                   (*)        (*)
 Emissions....................................
NNN--VOC Emissions from the Synthetic Organic         (*)        (*)        (*)        (*)        (*)        (*)
 Chemical Manufacturing Industry Distillation
 Operations...................................
OOO--Nonmetallic Mineral Processing Plants....        (*)        (*)        (*)        (*)        (*)        (*)
PPP--Wool Fiberglass Insulation Manufacturing         (*)        (*)        (*)                   (*)        (*)
 Plants.......................................
QQQ--VOC Emissions from Petroleum Refinery            (*)        (*)        (*)                   (*)        (*)
 Wastewater Systems...........................
RRR--VOC Emissions from Synthetic Organic             (*)                   (*)                   (*)
 Chemical Manufacturing Industry (SOCMI)
 Reactor Processes............................
SSS--Magnetic Tape Industry...................        (*)        (*)        (*)        (*)        (*)        (*)

[[Page 37]]

 
TTT--Plastic Parts for Business Machine               (*)        (*)        (*)                   (*)        (*)
 Coatings.....................................
UUU--Calciners and Dryers in Mineral                  (*)                   (*)                   (*)
 Industries...................................
VVV--Polymeric Coating of Supporting                  (*)        (*)        (*)                   (*)        (*)
 Substrates...................................
WWW--Municipal Solid Waste Landfills..........                              (*)                   (*)
----------------------------------------------------------------------------------------------------------------
(*) Indicates approval of state regulation.
\1\ Indicates approval of New Source Performance Standards as part of the State Implementation Plan (SIP).


[40 FR 18169, Apr. 25, 1975]

    Editorial Note: For Federal Register citations affecting Sec. 60.4 
see the List of CFR Sections Affected appearing in the Finding Aids 
section of this volume.



Sec. 60.5  Determination of construction or modification.

    (a) When requested to do so by an owner or operator, the 
Administrator will make a determination of whether action taken or 
intended to be taken by such owner or operator constitutes construction 
(including reconstruction) or modification or the commencement thereof 
within the meaning of this part.
    (b) The Administrator will respond to any request for a 
determination under paragraph (a) of this section within 30 days of 
receipt of such request.

[40 FR 58418, Dec. 16, 1975]



Sec. 60.6  Review of plans.

    (a) When requested to do so by an owner or operator, the 
Administrator will review plans for construction or modification for the 
purpose of providing technical advice to the owner or operator.
    (b)(1) A separate request shall be submitted for each construction 
or modification project.
    (2) Each request shall identify the location of such project, and be 
accompanied by technical information describing the proposed nature, 
size, design, and method of operation of each affected facility involved 
in such project, including information on any equipment to be used for 
measurement or control of emissions.
    (c) Neither a request for plans review nor advice furnished by the 
Administrator in response to such request shall (1) relieve an owner or 
operator of legal responsibility for compliance with any provision of 
this part or of any applicable State or local requirement, or (2) 
prevent the Administrator from implementing or enforcing any provision 
of this part or taking any other action authorized by the Act.

[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974]



Sec. 60.7  Notification and record keeping.

    (a) Any owner or operator subject to the provisions of this part 
shall furnish the Administrator written notification or, if acceptable 
to both the Administrator and the owner or operator of a source, 
electronic notification, as follows:
    (1) A notification of the date construction (or reconstruction as 
defined under Sec. 60.15) of an affected facility is commenced 
postmarked no later than 30 days after such date. This requirement shall 
not apply in the case of mass-produced facilities which are purchased in 
completed form.
    (2) [Reserved]
    (3) A notification of the actual date of initial startup of an 
affected facility postmarked within 15 days after such date.
    (4) A notification of any physical or operational change to an 
existing facility which may increase the emission rate of any air 
pollutant to which a standard applies, unless that change is 
specifically exempted under an applicable subpart or in Sec. 60.14(e). 
This notice shall be postmarked 60 days or as soon as practicable before 
the change is commenced and shall include information describing the 
precise nature of the change, present and proposed emission control 
systems, productive capacity of the facility before and after the 
change, and the expected completion

[[Page 38]]

date of the change. The Administrator may request additional relevant 
information subsequent to this notice.
    (5) A notification of the date upon which demonstration of the 
continuous monitoring system performance commences in accordance with 
Sec. 60.13(c). Notification shall be postmarked not less than 30 days 
prior to such date.
    (6) A notification of the anticipated date for conducting the 
opacity observations required by Sec. 60.11(e)(1) of this part. The 
notification shall also include, if appropriate, a request for the 
Administrator to provide a visible emissions reader during a performance 
test. The notification shall be postmarked not less than 30 days prior 
to such date.
    (7) A notification that continuous opacity monitoring system data 
results will be used to determine compliance with the applicable opacity 
standard during a performance test required by Sec. 60.8 in lieu of 
Method 9 observation data as allowed by Sec. 60.11(e)(5) of this part. 
This notification shall be postmarked not less than 30 days prior to the 
date of the performance test.
    (b) Any owner or operator subject to the provisions of this part 
shall maintain records of the occurrence and duration of any startup, 
shutdown, or malfunction in the operation of an affected facility; any 
malfunction of the air pollution control equipment; or any periods 
during which a continuous monitoring system or monitoring device is 
inoperative.
    (c) Each owner or operator required to install a continuous 
monitoring device shall submit excess emissions and monitoring systems 
performance report (excess emissions are defined in applicable subparts) 
and-or summary report form (see paragraph (d) of this section) to the 
Administrator semiannually, except when: more frequent reporting is 
specifically required by an applicable subpart; or the Administrator, on 
a case-by-case basis, determines that more frequent reporting is 
necessary to accurately assess the compliance status of the source. All 
reports shall be postmarked by the 30th day following the end of each 
six-month period. Written reports of excess emissions shall include the 
following information:
    (1) The magnitude of excess emissions computed in accordance with 
Sec. 60.13(h), any conversion factor(s) used, and the date and time of 
commencement and completion of each time period of excess emissions. The 
process operating time during the reporting period.
    (2) Specific identification of each period of excess emissions that 
occurs during startups, shutdowns, and malfunctions of the affected 
facility. The nature and cause of any malfunction (if known), the 
corrective action taken or preventative measures adopted.
    (3) The date and time identifying each period during which the 
continuous monitoring system was inoperative except for zero and span 
checks and the nature of the system repairs or adjustments.
    (4) When no excess emissions have occurred or the continuous 
monitoring system(s) have not been inoperative, repaired, or adjusted, 
such information shall be stated in the report.
    (d) The summary report form shall contain the information and be in 
the format shown in figure 1 unless otherwise specified by the 
Administrator. One summary report form shall be submitted for each 
pollutant monitored at each affected facility.
    (1) If the total duration of excess emissions for the reporting 
period is less than 1 percent of the total operating time for the 
reporting period and CMS downtime for the reporting period is less than 
5 percent of the total operating time for the reporting period, only the 
summary report form shall be submitted and the excess emission report 
described in Sec. 60.7(c) need not be submitted unless requested by the 
Administrator.
    (2) If the total duration of excess emissions for the reporting 
period is 1 percent or greater of the total operating time for the 
reporting period or the total CMS downtime for the reporting period is 5 
percent or greater of the total operating time for the reporting period, 
the summary report form and the excess emission report described in 
Sec. 60.7(c) shall both be submitted.

[[Page 39]]

   Figure 1--Summary Report--Gaseous and Opacity Excess Emission and 
                      Monitoring System Performance

Pollutant (Circle One--SO2/NOX/TRS/H2S/
          CO/Opacity)
Reporting period dates: From __________ to __________
Company:
Emission Limitation_____________________________________________________
Address:
Monitor Manufacturer and Model No.______________________________________
Date of Latest CMS Certification or Audit_______________________________
Process Unit(s) Description:
Total source operating time in reporting period \1\_____________________

------------------------------------------------------------------------
                                            CMS performance
  Emission data summary \1\                   summary \1\
------------------------------------------------------------------------
1. Duration of excess                    1. CMS downtime in
 emissions in reporting                   reporting period due
 period due to:                           to:
  a. Startup/shutdown........  ........    a. Monitor           ........
                                          equipment
                                          malfunctions.
  b. Control equipment         ........    b. Non-Monitor       ........
   problems.                              equipment
                                          malfunctions.
  c. Process problems........  ........    c. Quality           ........
                                          assurance
                                          calibration.
  d. Other known causes......  ........    d. Other known       ........
                                          causes.
  e. Unknown causes..........  ........    e. Unknown causes..  ........
2. Total duration of excess    ........  2. Total CMS Downtime  ........
 emission.
3. Total duration of excess       % \2\  3. [Total CMS             % \2\
 emissions  x  (100) [Total               Downtime]  x  (100)
 source operating time].                  [Total source
                                          operating time].
------------------------------------------------------------------------
\1\ For opacity, record all times in minutes. For gases, record all
  times in hours.
\2\ For the reporting period: If the total duration of excess emissions
  is 1 percent or greater of the total operating time or the total CMS
  downtime is 5 percent or greater of the total operating time, both the
  summary report form and the excess emission report described in Sec.
  60.7(c) shall be submitted.

    On a separate page, describe any changes since last quarter in CMS, 
process or controls. I certify that the information contained in this 
report is true, accurate, and complete.

_______________________________________________________________________
Name

_______________________________________________________________________
Signature

_______________________________________________________________________
Title

_______________________________________________________________________
Date

    (e)(1) Notwithstanding the frequency of reporting requirements 
specified in paragraph (c) of this section, an owner or operator who is 
required by an applicable subpart to submit excess emissions and 
monitoring systems performance reports (and summary reports) on a 
quarterly (or more frequent) basis may reduce the frequency of reporting 
for that standard to semiannual if the following conditions are met:
    (i) For 1 full year (e.g., 4 quarterly or 12 monthly reporting 
periods) the affected facility's excess emissions and monitoring systems 
reports submitted to comply with a standard under this part continually 
demonstrate that the facility is in compliance with the applicable 
standard;
    (ii) The owner or operator continues to comply with all 
recordkeeping and monitoring requirements specified in this subpart and 
the applicable standard; and
    (iii) The Administrator does not object to a reduced frequency of 
reporting for the affected facility, as provided in paragraph (e)(2) of 
this section.
    (2) The frequency of reporting of excess emissions and monitoring 
systems performance (and summary) reports may be reduced only after the 
owner or operator notifies the Administrator in writing of his or her 
intention to make such a change and the Administrator does not object to 
the intended change. In deciding whether to approve a reduced frequency 
of reporting, the Administrator may review information concerning the 
source's entire previous performance history during the required 
recordkeeping period prior to the intended change, including performance 
test results, monitoring data, and evaluations of an owner or operator's 
conformance with operation and maintenance requirements. Such 
information may be used by the Administrator to make a judgment about 
the source's potential for noncompliance in the future. If the 
Administrator disapproves the owner or operator's request to reduce the 
frequency of reporting, the Administrator will notify the owner or 
operator in writing within 45 days after receiving notice of the owner 
or operator's intention. The notification from the Administrator to the 
owner or operator will specify the grounds on which the disapproval is

[[Page 40]]

based. In the absence of a notice of disapproval within 45 days, 
approval is automatically granted.
    (3) As soon as monitoring data indicate that the affected facility 
is not in compliance with any emission limitation or operating parameter 
specified in the applicable standard, the frequency of reporting shall 
revert to the frequency specified in the applicable standard, and the 
owner or operator shall submit an excess emissions and monitoring 
systems performance report (and summary report, if required) at the next 
appropriate reporting period following the noncomplying event. After 
demonstrating compliance with the applicable standard for another full 
year, the owner or operator may again request approval from the 
Administrator to reduce the frequency of reporting for that standard as 
provided for in paragraphs (e)(1) and (e)(2) of this section.
    (f) Any owner or operator subject to the provisions of this part 
shall maintain a file of all measurements, including continuous 
monitoring system, monitoring device, and performance testing 
measurements; all continuous monitoring system performance evaluations; 
all continuous monitoring system or monitoring device calibration 
checks; adjustments and maintenance performed on these systems or 
devices; and all other information required by this part recorded in a 
permanent form suitable for inspection. The file shall be retained for 
at least two years following the date of such measurements, maintenance, 
reports, and records, except as follows:
    (1) This paragraph applies to owners or operators required to 
install a continuous emissions monitoring system (CEMS) where the CEMS 
installed is automated, and where the calculated data averages do not 
exclude periods of CEMS breakdown or malfunction. An automated CEMS 
records and reduces the measured data to the form of the pollutant 
emission standard through the use of a computerized data acquisition 
system. In lieu of maintaining a file of all CEMS subhourly measurements 
as required under paragraph (f) of this section, the owner or operator 
shall retain the most recent consecutive three averaging periods of 
subhourly measurements and a file that contains a hard copy of the data 
acquisition system algorithm used to reduce the measured data into the 
reportable form of the standard.
    (2) This paragraph applies to owners or operators required to 
install a CEMS where the measured data is manually reduced to obtain the 
reportable form of the standard, and where the calculated data averages 
do not exclude periods of CEMS breakdown or malfunction. In lieu of 
maintaining a file of all CEMS subhourly measurements as required under 
paragraph (f) of this section, the owner or operator shall retain all 
subhourly measurements for the most recent reporting period. The 
subhourly measurements shall be retained for 120 days from the date of 
the most recent summary or excess emission report submitted to the 
Administrator.
    (3) The Administrator or delegated authority, upon notification to 
the source, may require the owner or operator to maintain all 
measurements as required by paragraph (f) of this section, if the 
Administrator or the delegated authority determines these records are 
required to more accurately assess the compliance status of the affected 
source.
    (g) If notification substantially similar to that in paragraph (a) 
of this section is required by any other State or local agency, sending 
the Administrator a copy of that notification will satisfy the 
requirements of paragraph (a) of this section.
    (h) Individual subparts of this part may include specific provisions 
which clarify or make inapplicable the provisions set forth in this 
section.

[36 FR 24877, Dec. 28, 1971, as amended at 40 FR 46254, Oct. 6, 1975; 40 
FR 58418, Dec. 16, 1975; 45 FR 5617, Jan. 23, 1980; 48 FR 48335, Oct. 
18, 1983; 50 FR 53113, Dec. 27, 1985; 52 FR 9781, Mar. 26, 1987; 55 FR 
51382, Dec. 13, 1990; 59 FR 12428, Mar. 16, 1994; 59 FR 47265, Sep. 15, 
1994; 64 FR 7463, Feb. 12, 1999]



Sec. 60.8  Performance tests.

    (a) Within 60 days after achieving the maximum production rate at 
which the affected facility will be operated, but not later than 180 
days after initial startup of such facility and at such other times as 
may be required by the

[[Page 41]]

Administrator under section 114 of the Act, the owner or operator of 
such facility shall conduct performance test(s) and furnish the 
Administrator a written report of the results of such performance 
test(s).
    (b) Performance tests shall be conducted and data reduced in 
accordance with the test methods and procedures contained in each 
applicable subpart unless the Administrator (1) specifies or approves, 
in specific cases, the use of a reference method with minor changes in 
methodology, (2) approves the use of an equivalent method, (3) approves 
the use of an alternative method the results of which he has determined 
to be adequate for indicating whether a specific source is in 
compliance, (4) waives the requirement for performance tests because the 
owner or operator of a source has demonstrated by other means to the 
Administrator's satisfaction that the affected facility is in compliance 
with the standard, or (5) approves shorter sampling times and smaller 
sample volumes when necessitated by process variables or other factors. 
Nothing in this paragraph shall be construed to abrogate the 
Administrator's authority to require testing under section 114 of the 
Act.
    (c) Performance tests shall be conducted under such conditions as 
the Administrator shall specify to the plant operator based on 
representative performance of the affected facility. The owner or 
operator shall make available to the Administrator such records as may 
be necessary to determine the conditions of the performance tests. 
Operations during periods of startup, shutdown, and malfunction shall 
not constitute representative conditions for the purpose of a 
performance test nor shall emissions in excess of the level of the 
applicable emission limit during periods of startup, shutdown, and 
malfunction be considered a violation of the applicable emission limit 
unless otherwise specified in the applicable standard.
    (d) The owner or operator of an affected facility shall provide the 
Administrator at least 30 days prior notice of any performance test, 
except as specified under other subparts, to afford the Administrator 
the opportunity to have an observer present. If after 30 days notice for 
an initially scheduled performance test, there is a delay (due to 
operational problems, etc.) in conducting the scheduled performance 
test, the owner or operator of an affected facility shall notify the 
Administrator (or delegated State or local agency) as soon as possible 
of any delay in the original test date, either by providing at least 7 
days prior notice of the rescheduled date of the performance test, or by 
arranging a rescheduled date with the Administrator (or delegated State 
or local agency) by mutual agreement.
    (e) The owner or operator of an affected facility shall provide, or 
cause to be provided, performance testing facilities as follows:
    (1) Sampling ports adequate for test methods applicable to such 
facility. This includes (i) constructing the air pollution control 
system such that volumetric flow rates and pollutant emission rates can 
be accurately determined by applicable test methods and procedures and 
(ii) providing a stack or duct free of cyclonic flow during performance 
tests, as demonstrated by applicable test methods and procedures.
    (2) Safe sampling platform(s).
    (3) Safe access to sampling platform(s).
    (4) Utilities for sampling and testing equipment.
    (f) Unless otherwise specified in the applicable subpart, each 
performance test shall consist of three separate runs using the 
applicable test method. Each run shall be conducted for the time and 
under the conditions specified in the applicable standard. For the 
purpose of determining compliance with an applicable standard, the 
arithmetic means of results of the three runs shall apply. In the event 
that a sample is accidentally lost or conditions occur in which one of 
the three runs must be discontinued because of forced shutdown, failure 
of an irreplaceable portion of the sample train, extreme meteorological 
conditions, or other circumstances, beyond the owner or operator's 
control, compliance may, upon the Administrator's approval, be 
determined using the

[[Page 42]]

arithmetic mean of the results of the two other runs.

[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974; 42 
FR 57126, Nov. 1, 1977; 44 FR 33612, June 11, 1979; 54 FR 6662, Feb. 14, 
1989; 54 FR 21344, May 17, 1989; 64 FR 7463, Feb. 12, 1999]



Sec. 60.9  Availability of information.

    The availability to the public of information provided to, or 
otherwise obtained by, the Administrator under this part shall be 
governed by part 2 of this chapter. (Information submitted voluntarily 
to the Administrator for the purposes of Secs. 60.5 and 60.6 is governed 
by Secs. 2.201 through 2.213 of this chapter and not by Sec. 2.301 of 
this chapter.)



Sec. 60.10  State authority.

    The provisions of this part shall not be construed in any manner to 
preclude any State or political subdivision thereof from:
    (a) Adopting and enforcing any emission standard or limitation 
applicable to an affected facility, provided that such emission standard 
or limitation is not less stringent than the standard applicable to such 
facility.
    (b) Requiring the owner or operator of an affected facility to 
obtain permits, licenses, or approvals prior to initiating construction, 
modification, or operation of such facility.



Sec. 60.11  Compliance with standards and maintenance requirements.

    (a) Compliance with standards in this part, other than opacity 
standards, shall be determined in accordance with performance tests 
established by Sec. 60.8, unless otherwise specified in the applicable 
standard.
    (b) Compliance with opacity standards in this part shall be 
determined by conducting observations in accordance with Reference 
Method 9 in appendix A of this part, any alternative method that is 
approved by the Administrator, or as provided in paragraph (e)(5) of 
this section. For purposes of determining initial compliance, the 
minimum total time of observations shall be 3 hours (30 6-minute 
averages) for the performance test or other set of observations (meaning 
those fugitive-type emission sources subject only to an opacity 
standard).
    (c) The opacity standards set forth in this part shall apply at all 
times except during periods of startup, shutdown, malfunction, and as 
otherwise provided in the applicable standard.
    (d) At all times, including periods of startup, shutdown, and 
malfunction, owners and operators shall, to the extent practicable, 
maintain and operate any affected facility including associated air 
pollution control equipment in a manner consistent with good air 
pollution control practice for minimizing emissions. Determination of 
whether acceptable operating and maintenance procedures are being used 
will be based on information available to the Administrator which may 
include, but is not limited to, monitoring results, opacity 
observations, review of operating and maintenance procedures, and 
inspection of the source.
    (e)(1) For the purpose of demonstrating initial compliance, opacity 
observations shall be conducted concurrently with the initial 
performance test required in Sec. 60.8 unless one of the following 
conditions apply. If no performance test under Sec. 60.8 is required, 
then opacity observations shall be conducted within 60 days after 
achieving the maximum production rate at which the affected facility 
will be operated but no later than 180 days after initial startup of the 
facility. If visibility or other conditions prevent the opacity 
observations from being conducted concurrently with the initial 
performance test required under Sec. 60.8, the source owner or operator 
shall reschedule the opacity observations as soon after the initial 
performance test as possible, but not later than 30 days thereafter, and 
shall advise the Administrator of the rescheduled date. In these cases, 
the 30-day prior notification to the Administrator required in 
Sec. 60.7(a)(6) shall be waived. The rescheduled opacity observations 
shall be conducted (to the extent possible) under the same operating 
conditions that existed during the initial performance test conducted 
under Sec. 60.8. The visible emissions observer shall determine whether 
visibility or other conditions prevent the opacity observations from

[[Page 43]]

being made concurrently with the initial performance test in accordance 
with procedures contained in Reference Method 9 of appendix B of this 
part. Opacity readings of portions of plumes which contain condensed, 
uncombined water vapor shall not be used for purposes of determing 
compliance with opacity standards. The owner or operator of an affected 
facility shall make available, upon request by the Administrator, such 
records as may be necessary to determine the conditions under which the 
visual observations were made and shall provide evidence indicating 
proof of current visible observer emission certification. Except as 
provided in paragraph (e)(5) of this section, the results of continuous 
monitoring by transmissometer which indicate that the opacity at the 
time visual observations were made was not in excess of the standard are 
probative but not conclusive evidence of the actual opacity of an 
emission, provided that the source shall meet the burden of proving that 
the instrument used meets (at the time of the alleged violation) 
Performance Specification 1 in appendix B of this part, has been 
properly maintained and (at the time of the alleged violation) that the 
resulting data have not been altered in any way.
    (2) Except as provided in paragraph (e)(3) of this section, the 
owner or operator of an affected facility to which an opacity standard 
in this part applies shall conduct opacity observations in accordance 
with paragraph (b) of this section, shall record the opacity of 
emissions, and shall report to the Administrator the opacity results 
along with the results of the initial performance test required under 
Sec. 60.8. The inability of an owner or operator to secure a visible 
emissions observer shall not be considered a reason for not conducting 
the opacity observations concurrent with the initial performance test.
    (3) The owner or operator of an affected facility to which an 
opacity standard in this part applies may request the Administrator to 
determine and to record the opacity of emissions from the affected 
facility during the initial performance test and at such times as may be 
required. The owner or operator of the affected facility shall report 
the opacity results. Any request to the Administrator to determine and 
to record the opacity of emissions from an affected facility shall be 
included in the notification required in Sec. 60.7(a)(6). If, for some 
reason, the Administrator cannot determine and record the opacity of 
emissions from the affected facility during the performance test, then 
the provisions of paragraph (e)(1) of this section shall apply.
    (4) An owner or operator of an affected facility using a continuous 
opacity monitor (transmissometer) shall record the monitoring data 
produced during the initial performance test required by Sec. 60.8 and 
shall furnish the Administrator a written report of the monitoring 
results along with Method 9 and Sec. 60.8 performance test results.
    (5) An owner or operator of an affected facility subject to an 
opacity standard may submit, for compliance purposes, continuous opacity 
monitoring system (COMS) data results produced during any performance 
test required under Sec. 60.8 in lieu of Method 9 observation data. If 
an owner or operator elects to submit COMS data for compliance with the 
opacity standard, he shall notify the Administrator of that decision, in 
writing, at least 30 days before any performance test required under 
Sec. 60.8 is conducted. Once the owner or operator of an affected 
facility has notified the Administrator to that effect, the COMS data 
results will be used to determine opacity compliance during subsequent 
tests required under Sec. 60.8 until the owner or operator notifies the 
Administrator, in writing, to the contrary. For the purpose of 
determining compliance with the opacity standard during a performance 
test required under Sec. 60.8 using COMS data, the minimum total time of 
COMS data collection shall be averages of all 6-minute continuous 
periods within the duration of the mass emission performance test. 
Results of the COMS opacity determinations shall be submitted along with 
the results of the performance test required under Sec. 60.8. The owner 
or operator of an affected facility using a COMS for compliance purposes 
is responsible for demonstrating that the COMS meets the requirements 
specified in Sec. 60.13(c) of this part, that

[[Page 44]]

the COMS has been properly maintained and operated, and that the 
resulting data have not been altered in any way. If COMS data results 
are submitted for compliance with the opacity standard for a period of 
time during which Method 9 data indicates noncompliance, the Method 9 
data will be used to determine opacity compliance.
    (6) Upon receipt from an owner or operator of the written reports of 
the results of the performance tests required by Sec. 60.8, the opacity 
observation results and observer certification required by 
Sec. 60.11(e)(1), and the COMS results, if applicable, the Administrator 
will make a finding concerning compliance with opacity and other 
applicable standards. If COMS data results are used to comply with an 
opacity standard, only those results are required to be submitted along 
with the performance test results required by Sec. 60.8. If the 
Administrator finds that an affected facility is in compliance with all 
applicable standards for which performance tests are conducted in 
accordance with Sec. 60.8 of this part but during the time such 
performance tests are being conducted fails to meet any applicable 
opacity standard, he shall notify the owner or operator and advise him 
that he may petition the Administrator within 10 days of receipt of 
notification to make appropriate adjustment to the opacity standard for 
the affected facility.
    (7) The Administrator will grant such a petition upon a 
demonstration by the owner or operator that the affected facility and 
associated air pollution control equipment was operated and maintained 
in a manner to minimize the opacity of emissions during the performance 
tests; that the performance tests were performed under the conditions 
established by the Administrator; and that the affected facility and 
associated air pollution control equipment were incapable of being 
adjusted or operated to meet the applicable opacity standard.
    (8) The Administrator will establish an opacity standard for the 
affected facility meeting the above requirements at a level at which the 
source will be able, as indicated by the performance and opacity tests, 
to meet the opacity standard at all times during which the source is 
meeting the mass or concentration emission standard. The Administrator 
will promulgate the new opacity standard in the Federal Register.
    (f) Special provisions set forth under an applicable subpart shall 
supersede any conflicting provisions in paragraphs (a) through (e) of 
this section.
    (g) For the purpose of submitting compliance certifications or 
establishing whether or not a person has violated or is in violation of 
any standard in this part, nothing in this part shall preclude the use, 
including the exclusive use, of any credible evidence or information, 
relevant to whether a source would have been in compliance with 
applicable requirements if the appropriate performance or compliance 
test or procedure had been performed.

[38 FR 28565, Oct. 15, 1973, as amended at 39 FR 39873, Nov. 12, 1974; 
43 FR 8800, Mar. 3, 1978; 45 FR 23379, Apr. 4, 1980; 48 FR 48335, Oct. 
18, 1983; 50 FR 53113, Dec. 27, 1985; 51 FR 1790, Jan. 15, 1986; 52 FR 
9781, Mar. 26, 1987; 62 FR 8328, Feb. 24, 1997]



Sec. 60.12  Circumvention.

    No owner or operator subject to the provisions of this part shall 
build, erect, install, or use any article, machine, equipment or 
process, the use of which conceals an emission which would otherwise 
constitute a violation of an applicable standard. Such concealment 
includes, but is not limited to, the use of gaseous diluents to achieve 
compliance with an opacity standard or with a standard which is based on 
the concentration of a pollutant in the gases discharged to the 
atmosphere.

[39 FR 9314, Mar. 8, 1974]



Sec. 60.13  Monitoring requirements.

    (a) For the purposes of this section, all continuous monitoring 
systems required under applicable subparts shall be subject to the 
provisions of this section upon promulgation of performance 
specifications for continuous monitoring systems under appendix B to 
this part and, if the continuous monitoring system is used to 
demonstrate compliance with emission limits on a continuous basis, 
appendix F to this part, unless otherwise specified in an

[[Page 45]]

applicable subpart or by the Administrator. Appendix F is applicable 
December 4, 1987.
    (b) All continuous monitoring systems and monitoring devices shall 
be installed and operational prior to conducting performance tests under 
Sec. 60.8. Verification of operational status shall, as a minimum, 
include completion of the manufacturer's written requirements or 
recommendations for installation, operation, and calibration of the 
device.
    (c) If the owner or operator of an affected facility elects to 
submit continous opacity monitoring system (COMS) data for compliance 
with the opacity standard as provided under Sec. 60.11(e)(5), he shall 
conduct a performance evaluation of the COMS as specified in Performance 
Specification 1, appendix B, of this part before the performance test 
required under Sec. 60.8 is conducted. Otherwise, the owner or operator 
of an affected facility shall conduct a performance evaluation of the 
COMS or continuous emission monitoring system (CEMS) during any 
performance test required under Sec. 60.8 or within 30 days thereafter 
in accordance with the applicable performance specification in appendix 
B of this part, The owner or operator of an affected facility shall 
conduct COMS or CEMS performance evaluations at such other times as may 
be required by the Administrator under section 114 of the Act.
    (1) The owner or operator of an affected facility using a COMS to 
determine opacity compliance during any performance test required under 
Sec. 60.8 and as described in Sec. 60.11(e)(5) shall furnish the 
Administrator two or, upon request, more copies of a written report of 
the results of the COMS performance evaluation described in paragraph 
(c) of this section at least 10 days before the performance test 
required under Sec. 60.8 is conducted.
    (2) Except as provided in paragraph (c)(1) of this section, the 
owner or operator of an affected facility shall furnish the 
Administrator within 60 days of completion two or, upon request, more 
copies of a written report of the results of the performance evaluation.
    (d)(1) Owners and operators of all continuous emission monitoring 
systems installed in accordance with the provisions of this part shall 
check the zero (or low-level value between 0 and 20 percent of span 
value) and span (50 to 100 percent of span value) calibration drifts at 
least once daily in accordance with a written procedure. The zero and 
span shall, as a minimum, be adjusted whenever the 24-hour zero drift or 
24-hour span drift exceeds two times the limits of the applicable 
performance specifications in appendix B. The system must allow the 
amount of excess zero and span drift measured at the 24-hour interval 
checks to be recorded and quantified, whenever specified. For continuous 
monitoring systems measuring opacity of emissions, the optical surfaces 
exposed to the effluent gases shall be cleaned prior to performing the 
zero and span drift adjustments except that for systems using automatic 
zero adjustments. The optical surfaces shall be cleaned when the 
cumulative automatic zero compensation exceeds 4 percent opacity.
    (2) Unless otherwise approved by the Administrator, the following 
procedures shall be followed for continuous monitoring systems measuring 
opacity of emissions. Minimum procedures shall include a method for 
producing a simulated zero opacity condition and an upscale (span) 
opacity condition using a certified neutral density filter or other 
related technique to produce a known obscuration of the light beam. Such 
procedures shall provide a system check of the analyzer internal optical 
surfaces and all electronic circuitry including the lamp and 
photodetector assembly.
    (e) Except for system breakdowns, repairs, calibration checks, and 
zero and span adjustments required under paragraph (d) of this section, 
all continuous monitoring systems shall be in continuous operation and 
shall meet minimum frequency of operation requirements as follows:
    (1) All continuous monitoring systems referenced by paragraph (c) of 
this section for measuring opacity of emissions shall complete a minimum 
of one cycle of sampling and analyzing for each successive 10-second 
period and one cycle of data recording for each successive 6-minute 
period.

[[Page 46]]

    (2) All continuous monitoring systems referenced by paragraph (c) of 
this section for measuring emissions, except opacity, shall complete a 
minimum of one cycle of operation (sampling, analyzing, and data 
recording) for each successive 15-minute period.
    (f) All continuous monitoring systems or monitoring devices shall be 
installed such that representative measurements of emissions or process 
parameters from the affected facility are obtained. Additional 
procedures for location of continuous monitoring systems contained in 
the applicable Performance Specifications of appendix B of this part 
shall be used.
    (g) When the effluents from a single affected facility or two or 
more affected facilities subject to the same emission standards are 
combined before being released to the atmosphere, the owner or operator 
may install applicable continuous monitoring systems on each effluent or 
on the combined effluent. When the affected facilities are not subject 
to the same emission standards, separate continuous monitoring systems 
shall be installed on each effluent. When the effluent from one affected 
facility is released to the atmosphere through more than one point, the 
owner or operator shall install an applicable continuous monitoring 
system on each separate effluent unless the installation of fewer 
systems is approved by the Administrator. When more than one continuous 
monitoring system is used to measure the emissions from one affected 
facility (e.g., multiple breechings, multiple outlets), the owner or 
operator shall report the results as required from each continuous 
monitoring system.
    (h) Owners or operators of all continuous monitoring systems for 
measurement of opacity shall reduce all data to 6-minute averages and 
for continuous monitoring systems other than opacity to 1-hour averages 
for time periods as defined in Sec. 60.2. Six-minute opacity averages 
shall be calculated from 36 or more data points equally spaced over each 
6-minute period. For continuous monitoring systems other than opacity, 
1-hour averages shall be computed from four or more data points equally 
spaced over each 1-hour period. Data recorded during periods of 
continuous system breakdown, repair, calibration checks, and zero and 
span adjustments shall not be included in the data averages computed 
under this paragraph. For owners and operators complying with the 
requirements in Sec. 60.7(f) (1) or (2), data averages must include any 
data recorded during periods of monitor breakdown or malfunction. An 
arithmetic or integrated average of all data may be used. The data may 
be recorded in reduced or nonreduced form (e.g., ppm pollutant and 
percent O2 or ng/J of pollutant). All excess emissions shall 
be converted into units of the standard using the applicable conversion 
procedures specified in subparts. After conversion into units of the 
standard, the data may be rounded to the same number of significant 
digits as used in the applicable subparts to specify the emission limit 
(e.g., rounded to the nearest 1 percent opacity).
    (i) After receipt and consideration of written application, the 
Administrator may approve alternatives to any monitoring procedures or 
requirements of this part including, but not limited to the following:
    (1) Alternative monitoring requirements when installation of a 
continuous monitoring system or monitoring device specified by this part 
would not provide accurate measurements due to liquid water or other 
interferences caused by substances with the effluent gases.
    (2) Alternative monitoring requirements when the affected facility 
is infrequently operated.
    (3) Alternative monitoring requirements to accommodate continuous 
monitoring systems that require additional measurements to correct for 
stack moisture conditions.
    (4) Alternative locations for installing continuous monitoring 
systems or monitoring devices when the owner or operator can demonstrate 
that installation at alternate locations will enable accurate and 
representative measurements.
    (5) Alternative methods of converting pollutant concentration 
measurements to units of the standards.
    (6) Alternative procedures for performing daily checks of zero and 
span drift that do not involve use of span gases or test cells.

[[Page 47]]

    (7) Alternatives to the A.S.T.M. test methods or sampling procedures 
specified by any subpart.
    (8) Alternative continuous monitoring systems that do not meet the 
design or performance requirements in Performance Specification 1, 
appendix B, but adequately demonstrate a definite and consistent 
relationship between its measurements and the measurements of opacity by 
a system complying with the requirements in Performance Specification 1. 
The Administrator may require that such demonstration be performed for 
each affected facility.
    (9) Alternative monitoring requirements when the effluent from a 
single affected facility or the combined effluent from two or more 
affected facilities are released to the atmosphere through more than one 
point.
    (j) An alternative to the relative accuracy test specified in 
Performance Specification 2 of appendix B may be requested as follows:
    (1) An alternative to the reference method tests for determining 
relative accuracy is available for sources with emission rates 
demonstrated to be less than 50 percent of the applicable standard. A 
source owner or operator may petition the Administrator to waive the 
relative accuracy test in section 7 of Performance Specification 2 and 
substitute the procedures in section 10 if the results of a performance 
test conducted according to the requirements in Sec. 60.8 of this 
subpart or other tests performed following the criteria in Sec. 60.8 
demonstrate that the emission rate of the pollutant of interest in the 
units of the applicable standard is less than 50 percent of the 
applicable standard. For sources subject to standards expressed as 
control efficiency levels, a source owner or operator may petition the 
Administrator to waive the relative accuracy test and substitute the 
procedures in section 10 of Performance Specification 2 if the control 
device exhaust emission rate is less than 50 percent of the level needed 
to meet the control efficiency requirement. The alternative procedures 
do not apply if the continuous emission monitoring system is used to 
determine compliance continuously with the applicable standard. The 
petition to waive the relative accuracy test shall include a detailed 
description of the procedures to be applied. Included shall be location 
and procedure for conducting the alternative, the concentration or 
response levels of the alternative RA materials, and the other equipment 
checks included in the alternative procedure. The Administrator will 
review the petition for completeness and applicability. The 
determination to grant a waiver will depend on the intended use of the 
CEMS data (e.g., data collection purposes other than NSPS) and may 
require specifications more stringent than in Performance Specification 
2 (e.g., the applicable emission limit is more stringent than NSPS).
    (2) The waiver of a CEMS relative accuracy test will be reviewed and 
may be rescinded at such time following successful completion of the 
alternative RA procedure that the CEMS data indicate the source 
emissions approaching the level of the applicable standard. The 
criterion for reviewing the waiver is the collection of CEMS data 
showing that emissions have exceeded 70 percent of the applicable 
standard for seven, consecutive, averaging periods as specified by the 
applicable regulation(s). For sources subject to standards expressed as 
control efficiency levels, the criterion for reviewing the waiver is the 
collection of CEMS data showing that exhaust emissions have exceeded 70 
percent of the level needed to meet the control efficiency requirement 
for seven, consecutive, averaging periods as specified by the applicable 
regulation(s) [e.g., Sec. 60.45(g) (2) and (3), Sec. 60.73(e), and 
Sec. 60.84(e)]. It is the responsibility of the source operator to 
maintain records and determine the level of emissions relative to the 
criterion on the waiver of relative accuracy testing. If this criterion 
is exceeded, the owner or operator must notify the Administrator within 
10 days of such occurrence and include a description of the nature and 
cause of the increasing emissions. The Administrator will review the 
notification and may rescind the waiver and require the owner or 
operator to conduct a relative accuracy test of the

[[Page 48]]

CEMS as specified in section 7 of Performance Specification 2.

[40 FR 46255, Oct. 6, 1975; 40 FR 59205, Dec. 22, 1975, as amended at 41 
FR 35185, Aug. 20, 1976; 48 FR 13326, Mar. 30, 1983; 48 FR 23610, May 
25, 1983; 48 FR 32986, July 20, 1983; 52 FR 9782, Mar. 26, 1987; 52 FR 
17555, May 11, 1987; 52 FR 21007, June 4, 1987; 64 FR 7463, Feb. 12, 
1999]



Sec. 60.14  Modification.

    (a) Except as provided under paragraphs (e) and (f) of this section, 
any physical or operational change to an existing facility which results 
in an increase in the emission rate to the atmosphere of any pollutant 
to which a standard applies shall be considered a modification within 
the meaning of section 111 of the Act. Upon modification, an existing 
facility shall become an affected facility for each pollutant to which a 
standard applies and for which there is an increase in the emission rate 
to the atmosphere.
    (b) Emission rate shall be expressed as kg/hr of any pollutant 
discharged into the atmosphere for which a standard is applicable. The 
Administrator shall use the following to determine emission rate:
    (1) Emission factors as specified in the latest issue of 
``Compilation of Air Pollutant Emission Factors,'' EPA Publication No. 
AP-42, or other emission factors determined by the Administrator to be 
superior to AP-42 emission factors, in cases where utilization of 
emission factors demonstrate that the emission level resulting from the 
physical or operational change will either clearly increase or clearly 
not increase.
    (2) Material balances, continuous monitor data, or manual emission 
tests in cases where utilization of emission factors as referenced in 
paragraph (b)(1) of this section does not demonstrate to the 
Administrator's satisfaction whether the emission level resulting from 
the physical or operational change will either clearly increase or 
clearly not increase, or where an owner or operator demonstrates to the 
Administrator's satisfaction that there are reasonable grounds to 
dispute the result obtained by the Administrator utilizing emission 
factors as referenced in paragraph (b)(1) of this section. When the 
emission rate is based on results from manual emission tests or 
continuous monitoring systems, the procedures specified in appendix C of 
this part shall be used to determine whether an increase in emission 
rate has occurred. Tests shall be conducted under such conditions as the 
Administrator shall specify to the owner or operator based on 
representative performance of the facility. At least three valid test 
runs must be conducted before and at least three after the physical or 
operational change. All operating parameters which may affect emissions 
must be held constant to the maximum feasible degree for all test runs.
    (c) The addition of an affected facility to a stationary source as 
an expansion to that source or as a replacement for an existing facility 
shall not by itself bring within the applicability of this part any 
other facility within that source.
    (d) [Reserved]
    (e) The following shall not, by themselves, be considered 
modifications under this part:
    (1) Maintenance, repair, and replacement which the Administrator 
determines to be routine for a source category, subject to the 
provisions of paragraph (c) of this section and Sec. 60.15.
    (2) An increase in production rate of an existing facility, if that 
increase can be accomplished without a capital expenditure on that 
facility.
    (3) An increase in the hours of operation.
    (4) Use of an alternative fuel or raw material if, prior to the date 
any standard under this part becomes applicable to that source type, as 
provided by Sec. 60.1, the existing facility was designed to accommodate 
that alternative use. A facility shall be considered to be designed to 
accommodate an alternative fuel or raw material if that use could be 
accomplished under the facility's construction specifications as amended 
prior to the change. Conversion to coal required for energy 
considerations, as specified in section 111(a)(8) of the Act, shall not 
be considered a modification.
    (5) The addition or use of any system or device whose primary 
function is the reduction of air pollutants, except

[[Page 49]]

when an emission control system is removed or is replaced by a system 
which the Administrator determines to be less environmentally 
beneficial.
    (6) The relocation or change in ownership of an existing facility.
    (f) Special provisions set forth under an applicable subpart of this 
part shall supersede any conflicting provisions of this section.
    (g) Within 180 days of the completion of any physical or operational 
change subject to the control measures specified in paragraph (a) of 
this section, compliance with all applicable standards must be achieved.
    (h) No physical change, or change in the method of operation, at an 
existing electric utility steam generating unit shall be treated as a 
modification for the purposes of this section provided that such change 
does not increase the maximum hourly emissions of any pollutant 
regulated under this section above the maximum hourly emissions 
achievable at that unit during the 5 years prior to the change.
    (i) Repowering projects that are awarded funding from the Department 
of Energy as permanent clean coal technology demonstration projects (or 
similar projects funded by EPA) are exempt from the requirements of this 
section provided that such change does not increase the maximum hourly 
emissions of any pollutant regulated under this section above the 
maximum hourly emissions achievable at that unit during the five years 
prior to the change.
    (j)(1) Repowering projects that qualify for an extension under 
section 409(b) of the Clean Air Act are exempt from the requirements of 
this section, provided that such change does not increase the actual 
hourly emissions of any pollutant regulated under this section above the 
actual hourly emissions achievable at that unit during the 5 years prior 
to the change.
    (2) This exemption shall not apply to any new unit that:
    (i) Is designated as a replacement for an existing unit;
    (ii) Qualifies under section 409(b) of the Clean Air Act for an 
extension of an emission limitation compliance date under section 405 of 
the Clean Air Act; and
    (iii) Is located at a different site than the existing unit.
    (k) The installation, operation, cessation, or removal of a 
temporary clean coal technology demonstration project is exempt from the 
requirements of this section. A temporary clean coal control technology 
demonstration project, for the purposes of this section is a clean coal 
technology demonstration project that is operated for a period of 5 
years or less, and which complies with the State implementation plan for 
the State in which the project is located and other requirements 
necessary to attain and maintain the national ambient air quality 
standards during the project and after it is terminated.
    (l) The reactivation of a very clean coal-fired electric utility 
steam generating unit is exempt from the requirements of this section.

[40 FR 58419, Dec. 16, 1975, amended at 43 FR 34347, Aug. 3, 1978; 45 FR 
5617, Jan. 23, 1980; 57 FR 32339, July 21, 1992]



Sec. 60.15  Reconstruction.

    (a) An existing facility, upon reconstruction, becomes an affected 
facility, irrespective of any change in emission rate.
    (b) ``Reconstruction'' means the replacement of components of an 
existing facility to such an extent that:
    (1) The fixed capital cost of the new components exceeds 50 percent 
of the fixed capital cost that would be required to construct a 
comparable entirely new facility, and
    (2) It is technologically and economically feasible to meet the 
applicable standards set forth in this part.
    (c) ``Fixed capital cost'' means the capital needed to provide all 
the depreciable components.
    (d) If an owner or operator of an existing facility proposes to 
replace components, and the fixed capital cost of the new components 
exceeds 50 percent of the fixed capital cost that would be required to 
construct a comparable entirely new facility, he shall notify the 
Administrator of the proposed replacements. The notice must be 
postmarked 60 days (or as soon as practicable) before construction of 
the replacements is commenced and must include the following 
information:

[[Page 50]]

    (1) Name and address of the owner or operator.
    (2) The location of the existing facility.
    (3) A brief description of the existing facility and the components 
which are to be replaced.
    (4) A description of the existing air pollution control equipment 
and the proposed air pollution control equipment.
    (5) An estimate of the fixed capital cost of the replacements and of 
constructing a comparable entirely new facility.
    (6) The estimated life of the existing facility after the 
replacements.
    (7) A discussion of any economic or technical limitations the 
facility may have in complying with the applicable standards of 
performance after the proposed replacements.
    (e) The Administrator will determine, within 30 days of the receipt 
of the notice required by paragraph (d) of this section and any 
additional information he may reasonably require, whether the proposed 
replacement constitutes reconstruction.
    (f) The Administrator's determination under paragraph (e) shall be 
based on:
    (1) The fixed capital cost of the replacements in comparison to the 
fixed capital cost that would be required to construct a comparable 
entirely new facility;
    (2) The estimated life of the facility after the replacements 
compared to the life of a comparable entirely new facility;
    (3) The extent to which the components being replaced cause or 
contribute to the emissions from the facility; and
    (4) Any economic or technical limitations on compliance with 
applicable standards of performance which are inherent in the proposed 
replacements.
    (g) Individual subparts of this part may include specific provisions 
which refine and delimit the concept of reconstruction set forth in this 
section.

[40 FR 58420, Dec. 16, 1975]



Sec. 60.16  Priority list.

                   Prioritized Major Source Categories
------------------------------------------------------------------------
      Priority Number \1\                    Source Category
------------------------------------------------------------------------
1.                              Synthetic Organic Chemical Manufacturing
                                 Industry (SOCMI) and Volatile Organic
                                 Liquid Storage Vessels and Handling
                                 Equipment
                                (a) SOCMI unit processes
                                (b) Volatile organic liquid (VOL)
                                 storage vessels and handling equipment
                                (c) SOCMI fugitive sources
                                (d) SOCMI secondary sources
2.                              Industrial Surface Coating: Cans
3.                              Petroleum Refineries: Fugitive Sources
4.                              Industrial Surface Coating: Paper
5.                              Dry Cleaning
                                (a) Perchloroethylene
                                (b) Petroleum solvent
6.                              Graphic Arts
7.                              Polymers and Resins: Acrylic Resins
8.                              Mineral Wool (Deleted)
9.                              Stationary Internal Combustion Engines
10.                             Industrial Surface Coating: Fabric
11.                             Industrial-Commercial-Institutional
                                 Steam Generating Units.
12.                             Incineration: Non-Municipal (Deleted)
13.                             Non-Metallic Mineral Processing
14.                             Metallic Mineral Processing
15.                             Secondary Copper (Deleted)
16.                             Phosphate Rock Preparation
17.                             Foundries: Steel and Gray Iron
18.                             Polymers and Resins: Polyethylene
19.                             Charcoal Production
20.                             Synthetic Rubber
                                (a) Tire manufacture
                                (b) SBR production
21.                             Vegetable Oil
22.                             Industrial Surface Coating: Metal Coil
23.                             Petroleum Transportation and Marketing
24.                             By-Product Coke Ovens
25.                             Synthetic Fibers
26.                             Plywood Manufacture
27.                             Industrial Surface Coating: Automobiles
28.                             Industrial Surface Coating: Large
                                 Appliances
29.                             Crude Oil and Natural Gas Production
30.                             Secondary Aluminum
31.                             Potash (Deleted)
32.                             Lightweight Aggregate Industry: Clay,
                                 Shale, and Slate \2\
33.                             Glass
34.                             Gypsum
35.                             Sodium Carbonate
36.                             Secondary Zinc (Deleted)
37.                             Polymers and Resins: Phenolic
38.                             Polymers and Resins: Urea-Melamine
39.                             Ammonia (Deleted)
40.                             Polymers and Resins: Polystyrene
41.                             Polymers and Resins: ABS-SAN Resins
42.                             Fiberglass
43.                             Polymers and Resins: Polypropylene
44.                             Textile Processing
45.                             Asphalt Processing and Asphalt Roofing
                                 Manufacture
46.                             Brick and Related Clay Products
47.                             Ceramic Clay Manufacturing (Deleted)
48.                             Ammonium Nitrate Fertilizer
49.                             Castable Refractories (Deleted)
50.                             Borax and Boric Acid (Deleted)
51.                             Polymers and Resins: Polyester Resins
52.                             Ammonium Sulfate

[[Page 51]]

 
53.                             Starch
54.                             Perlite
55.                             Phosphoric Acid: Thermal Process
                                 (Deleted)
56.                             Uranium Refining
57.                             Animal Feed Defluorination (Deleted)
58.                             Urea (for fertilizer and polymers)
59.                             Detergent (Deleted)
 
                         Other Source Categories
 
Lead acid battery manufacture \3\
Organic solvent cleaning \3\
Industrial surface coating: metal furniture \3\
Stationary gas turbines \4\
Municipal solid waste landfills \4\
------------------------------------------------------------------------
\1\ Low numbers have highest priority, e.g., No. 1 is high priority, No.
  59 is low priority.
\2\ Formerly titled ``Sintering: Clay and Fly Ash''.
\3\ Minor source category, but included on list since an NSPS is being
  developed for that source category.
\4\ Not prioritized, since an NSPS for this major source category has
  already been promulgated.


[47 FR 951, Jan. 8, 1982, as amended at 47 FR 31876, July 23, 1982; 51 
FR 42796, Nov. 25, 1986; 52 FR 11428, Apr. 8, 1987; 61 FR 9919, Mar. 12, 
1996]



Sec. 60.17  Incorporations by reference.

    The materials listed below are incorporated by reference in the 
corresponding sections noted. These incorporations by reference were 
approved by the Director of the Federal Register on the date listed. 
These materials are incorporated as they exist on the date of the 
approval, and a notice of any change in these materials will be 
published in the Federal Register. The materials are available for 
purchase at the corresponding address noted below, and all are available 
for inspection at the Office of the Federal Register, 800 North Capitol 
Street, NW., suite 700, Washington, DC and at the Library (MD-35), U.S. 
EPA, Research Triangle Park, NC.
    (a) The following materials are available for purchase from at least 
one of the following addresses: American Society for Testing and 
Materials (ASTM), 1916 Race Street, Philadelphia, Pennsylvania 19103; or 
the University Microfilms International, 300 North Zeeb Road, Ann Arbor, 
MI 48106.

    (1) ASTM D388-77, Standard Specification for Classification of Coals 
by Rank, incorporation by reference (IBR) approved for Secs. 60.41(f); 
60.45(f)(4)(i), (ii), (vi); 60.41a; 60.41b; 60.41c; 60.25(b), (c).
    (2) ASTM D3178-73, Standard Test Methods for Carbon and Hydrogen in 
the Analysis Sample of Coal and Coke, IBR approved January 27, 1983 for 
Sec. 60.45(f)(5)(i).
    (3) ASTM D3176-74, Standard Method for Ultimate Analysis of Coal and 
Coke, IBR approved January 27, 1983, for Sec. 60.45(f)(5)(i); appendix A 
to part 60, Method 19.
    (4) ASTM D1137-53 (Reapproved 1975), Standard Method for Analysis of 
Natural Gases and Related Types of Gaseous Mixtures by the Mass 
Spectrometer, IBR approved January 27, 1983 for Sec. 60.45(f)(5)(i).
    (5) ASTM D1945-64 (Reapproved 1976), Standard Method for Analysis of 
Natural Gas by Gas Chromatography, IBR approved January 27, 1983 for 
Sec. 60.45(f)(5)(i).
    (6) ASTM D1946-77, Standard Method for Analysis of Reformed Gas by 
Gas Chromatography, IBR approved for Secs. 60.45(f)(5)(i), 
60.18(c)(3)(i), 60.18(f), 60.614(d)(2)(ii), 60.614(d)(4), 
60.664(d)(2)(ii), 60.664(d)(4), 60.564(f), 60.704(d)(2)(ii) and 
60.704(d)(4).
    (7) ASTM D2015-77, Standard Test Method for Gross Calorific Value of 
Solid Fuel by the Adiabatic Bomb Calorimeter, IBR approved January 27, 
1983 for Sec. 60.45(f)(5)(ii); Sec. 60.46(g); appendix A to part 60, 
Method 19.
    (8) ASTM D1826-77, Standard Test Method for Calorific Value of Gases 
in Natural Gas Range by Continuous Recording Calorimeter, IBR approved 
January 27, 1983, for Secs. 60.45(f)(5)(ii); 60.46(g); 60.296(f); 
appendix A to part 60, Method 19.
    (9) ASTM D240-76, Standard Test Method for Heat of Combustion of 
Liquid Hydrocarbon Fuels by Bomb Calorimeter, IBR approved January 27, 
1983, for Sec. 60.46(g); 60.296(f); appendix A to part 60, Method 19.
    (10) ASTM D396-78, Standard Specification for Fuel Oils, IBR 
approved for Secs. 60.40b; 60.41b; 60.41c; 60.111(b); 60.111a(b).
    (11) ASTM D2880-78, Standard Specification for Gas Turbine Fuel 
Oils, IBR approved January 27, 1983 for Secs. 60.111(b), 60.111a(b), 
60.335(b)(2).
    (12) ASTM D975-78, Standard Specification for Diesel Fuel Oils, IBR 
approved January 27, 1983 for Secs. 60.111(b), 60.111a(b).
    (13) ASTM D323-82, Test Method for Vapor Pressure of Petroleum 
Products (Reid Method), IBR approved April 8, 1987 for Secs. 60.111(1), 
60.111a(g), 60.111b(g), and 60.116b(f)(2)(ii).
    (14) ASTM A99-76, Standard Specification for Ferromanganese, IBR 
approved January 27, 1983 for Sec. 60.261.
    (15) ASTM A483-64 (Reapproved 1974), Standard Specification for 
Silicomanganese, IBR approved January 27, 1983 for Sec. 60.261.
    (16) ASTM A101-73, Standard Specification for Ferrochromium, IBR 
approved January 27, 1983 for Sec. 60.261.
    (17) ASTM A100-69 (Reapproved 1974), Standard Specification for 
Ferrosilicon, IBR approved January 27, 1983 for Sec. 60.261.

[[Page 52]]

    (18) ASTM A482-76, Standard Specification for Ferrochromesilicon, 
IBR approved January 27, 1983 for Sec. 60.261.
    (19) ASTM A495-76, Standard Specification for Calcium-Silicon and 
Calcium Manganese-Silicon, IBR approved January 27, 1983 for 
Sec. 60.261.
    (20) ASTM D 1072-80, Standard Method for Total Sulfur in Fuel Gases, 
IBR approved July 31, 1984 for Sec. 60.335(b)(2).
    (21) ASTM D2986-71 (Reapproved 1978), Standard Method for Evaluation 
of Air, Assay Media by the Monodisperse DOP (Dioctyl Phthalate) Smoke 
Test, IBR approved January 27, 1983 for appendix A to part 60, Method 5, 
par. 3.1.1; Method 12, par. 4.1.1; Method 17, par. 3.1.1.
    (22) ASTM D 1193-77, Standard Specification for Reagent Water, for 
appendix A to part 60, Method 6, par. 3.1.1; Method 7, par. 3.2.2; 
Method 7C, par. 3.1.1; Method 7D, par. 3.1.1; Method 8, par. 3.1.3; 
Method 12, par. 4.1.3; Method 25D, par. 3.2.2.4; Method 26A, par. 3.1.1; 
Method 29, pars. 4.2.2., 4.4.2., and 4.5.6.; Method 14A, par. 7.1.
    (23) [Reserved]
    (24) ASTM D2234-76, Standard Methods for Collection of a Gross 
Sample of Coal, IBR approved January 27, 1983, for appendix A to part 
60, Method 19.
    (25) ASTM D3173-73, Standard Test Method for Moisture in the 
Analysis Sample of Coal and Coke, IBR approved January 27, 1983, for 
appendix A to part 60, Method 19.
    (26) ASTM D3177-75, Standard Test Methods for Total Sulfur in the 
Analysis Sample of Coal and Coke, IBR approved January 27, 1983, for 
appendix A to part 60, Method 19.
    (27) ASTM D2013-72, Standard Method of Preparing Coal Samples for 
Analysis, IBR approved January 27, 1983, for appendix A to part 60, 
Method 19.
    (28) ASTM D270-65 (Reapproved 1975), Standard Method of Sampling 
Petroleum and Petroleum Products, IBR approved January 27, 1983, for 
appendix A to part 60, Method 19.
    (29) ASTM D737-85, Standard Test Method for Air Permeability of 
Textile Fabrics, IBR approved January 27, 1983 for Sec. 61.23(a).
    (30) ASTM D1475-60 (Reapproved 1980), Standard Test Method for 
Density of Paint, Varnish, Lacquer, and Related Products, IBR approved 
January 27, 1983 for Sec. 60.435(d)(1), appendix A to part 60, Method 
24, par. 2.1, and Method 24A, par. 2.2.
    (31) ASTM D2369-81, Standard Test Method for Volatile Content of 
Coatings, IBR approved January 27, 1983 for appendix A to part 60, 
Method 24.
    (32) ASTM D3792-79, Standard Method for Water Content of Water-
Reducible Paints by Direct Injection Into a Gas Chromatograph, IBR 
approved January 27, 1983 for appendix A to part 60, Method 24, par. 
2.3.
    (33) ASTM D4017-81, Standard Test Method for Water in Paints and 
Paint Materials by the Karl Fischer Titration Method, IBR approved 
January 27, 1983 for appendix A to part 60, Method 24, par. 2.4.
    (34) ASTM E169-63 (Reapproved 1977), General Techniques of 
Ultraviolet Quantitative Analysis, IBR approved for Sec. 60.485(d), 
Sec. 60.593(b), and Sec. 60.632(f).
    (35) ASTM E168-67 (Reapproved 1977), General Techniques of Infrared 
Quantitative Analysis, IBR approved for Sec. 60.485(d), Sec. 60.593(b), 
and Sec. 60.632(f).
    (36) ASTM E260-73, General Gas Chromatography Procedures, IBR 
approved for Sec. 60.485(d), Sec. 60.593(b), and Sec. 60.632(f).
    (37) ASTM D2879-83, Test Method for Vapor Pressure--Temperature 
Relationship and Initial Decomposition Temperature of Liquids by 
Isoteniscope, IBR approved April 8, 1987 for Secs. 60.485(e), 
60.111b(f)(3), 60.116b(e)(3)(ii), and 60.116b(f)(2)(i).
    (38) ASTM D2382-76, Heat of Combustion of Hydrocarbon Fuels by Bomb 
Calorimeter [High-Precision Method], IBR approved for Secs. 60.18(f), 
60.485(g), 60.614(d)(4), 60.664(d)(4), and 60.564(f), and 60.704(d)(4).
    (39) ASTM D2504-67 (Reapproved 1977), Noncondensable Gases in 
C3 and Lighter Hydrocarbon Products by Gas Chromatography, 
IBR approved for Sec. 60.485(g).
    (40) ASTM D86-78, Distillation of Petroleum Products, IBR approved 
for Sec. 60.593(d), Sec. 60.633(h), and Sec. 60.562-2(d).
    (41) [Reserved]
    (42) ASTM D 3031-81, Standard Test Method for Total Sulfur in 
Natural Gas by Hydrogenation, IBR approved July 31, 1984 for 
Sec. 60.335(b)(2).
    (43) ASTM D 4084-82, Standard Method for Analysis of Hydrogen 
Sulfide in Gaseous Fuels (Lead Acetate Reaction Rate Method), IBR 
approved July 31, 1984 for Sec. 60.335(b)(2).
    (44) ASTM D 3246-81, Standard Method for Sulfur in Petroleum Gas by 
Oxidative Microcoulometry, IBR approved July 31, 1984 for 
Sec. 60.335(b)(2).
    (45) ASTM D2584-68, Standard Test Method for Ignition Loss of Cured 
Reinforced Resins, IBR approved February 25, 1985 for Sec. 60.685(e).
    (46) ASTM D3431-80, Standard Test Method for Trace Nitrogen in 
Liquid Petroleum Hydrocarbons (Microcoulometric Method), IBR approved 
November 25, 1986, for appendix A to part 60, Method 19.
    (47) ASTM D129-64 (reapproved 1978), Standard Test Method for Sulfur 
in Petroleum Products (General Bomb Method), IBR approved for appendix A 
to part 60, Method 19.
    (48) ASTM D1552-83, Standard Test Method for Sulfur in Petroleum 
Products (High Temperature Method), IBR approved for appendix A to part 
60, Method 19.
    (49) ASTM D1835-86, Standard Specification for Liquefied Petroleum 
(LP) Gases, to be approved for Sec. 60.41b.

[[Page 53]]

    (50) ASTM D1835-86, Standard Specification for Liquefied Petroleum 
(LP) Gases, IBR approved for Secs. 60.41b; 60.41c.
    (51) ASTM D4057-81, Standard Practice for Manual Sampling of 
Petroleum and Petroleum Products, IBR approved for appendix A to part 
60, Method 19.
    (52) ASTM D4239-85, Standard Test Methods for Sulfur in the Analysis 
Sample of Coal and Coke Using High Temperature Tube Furnace Combustion 
Methods, IBR approved for appendix A to part 60, Method 19.
    (53) ASTM D2016-74 (Reapproved 1983), Standard Test Methods for 
Moisture Content of Wood * * * for appendix A, Method 28.
    (54) ASTM D4442-84, Standard Test Methods for Direct Moisture 
Content Measurement in Wood and Wood-base Materials * * * for appendix 
A, Method 28.
    (55)  [Reserved]
    (56) ASTM D129-64 (Reapproved 1978), Standard Test Method for Sulfur 
in Petroleum Products (General Bomb Method), IBR approved August 17, 
1989, for Sec. 60.106(j)(2).
    (57) ASTM D1552-83, Standard Test Method for Sulfur in Petroleum 
Products (High-Temperature Method), IBR approved August 17, 1989, for 
Sec. 60.106(j)(2).
    (58) ASTM D2622-87, Standard Test Method for Sulfur in Petroleum 
Products by X-Ray Spectrometry, IBR approved August 17, 1989, for 
Sec. 60.106(j)(2).
    (59) ASTM D1266-87, Standard Test Method for Sulfur in Petroleum 
Products (Lamp Method), IBR approved August 17, 1989, for 
Sec. 60.106(j)(2).
    (60) ASTM D2908-74, Standard Practice for Measuring Volatile Organic 
Matter in Water by Aqueous-Injection Gas Chromatography, IBR approved 
for Sec. 60.564(j).
    (61) ASTM D3370-76, Standard Practices for Sampling Water, IBR 
approved for Sec. 60.564(j).
    (62) ASTM D4457-85 Test Method for Determination of Dichloromethane 
and 1,1,1-Trichloroethane in Paints and Coatings by Direct Injection 
into a Gas Chromatograph, IBR approved for appendix A, Method 24.
    (63) ASTM D 5403-93 Standard Test Methods for Volatile Content of 
Radiation Curable Materials. IBR approved September 11, 1995 for Method 
24 of Appendix A.

    (b) The following material is available for purchase from the 
Association of Official Analytical Chemists, 1111 North 19th Street, 
Suite 210, Arlington, VA 22209.

    (1) AOAC Method 9, Official Methods of Analysis of the Association 
of Official Analytical Chemists, 11th edition, 1970, pp. 11-12, IBR 
approved January 27, 1983 for Secs. 60.204(d)(2), 60.214(d)(2), 
60.224(d)(2), 60.234(d)(2).

    (c) The following material is available for purchase from the 
American Petroleum Institute, 1220 L Street NW., Washington, DC 20005.

    (1) API Publication 2517, Evaporation Loss from External Floating 
Roof Tanks, Second Edition, February 1980, IBR approved January 27, 
1983, for Secs. 60.111(i), 60.111a(f), 60.111a(f)(1) and 
60.116b(e)(2)(i).

    (d) The following material is available for purchase from the 
Technical Association of the Pulp and Paper Industry (TAPPI), Dunwoody 
Park, Atlanta, GA 30341.

    (1) TAPPI Method T624 os-68, IBR approved January 27, 1983 for 
Sec. 60.285(d)(4).

    (e) The following material is available for purchase from the Water 
Pollution Control Federation (WPCF), 2626 Pennsylvania Avenue NW., 
Washington, DC 20037.

    (1) Method 209A, Total Residue Dried at 103-105  deg. C, in Standard 
Methods for the Examination of Water and Wastewater, 15th Edition, 1980, 
IBR approved February 25, 1985 for Sec. 60.683(b).

    (f) The following material is available for purchase from the 
following address: Underwriter's Laboratories, Inc. (UL), 333 Pfingsten 
Road, Northbrook, IL 60062.

    (1) UL 103, Sixth Edition revised as of September 3, 1986, Standard 
for Chimneys, Factory-built, Residential Type and Building Heating 
Appliance.

    (g) The following material is available for purchase from the 
following address: West Coast Lumber Inspection Bureau, 6980 SW. Barnes 
Road, Portland, OR 97223.

    (1) West Coast Lumber Standard Grading Rules No. 16, pages 5-21 and 
90 and 91, September 3, 1970, revised 1984.

    (h) The following material is available for purchase from the 
American Society of Mechanical Engineers (ASME), 345 East 47th Street, 
New York, NY 10017.

    (1) ASME QRO-1-1994, Standard for the Qualification and 
Certification of Resource Recovery Facility Operators, IBR approved for 
Secs. 60.56a, 60.54b(a), and 60.54b(b).
    (2) ASME PTC 4.1-1964 (Reaffirmed 1991), Power Test Codes: Test Code 
for Steam Generating Units (with 1968 and 1969 Addenda), IBR approved 
for Secs. 60.46b, 60.58a(h)(6)(ii), and 60.58b(i)(6)(ii).
    (3) ASME Interim Supplement 19.5 on Instruments and Apparatus: 
Application, Part

[[Page 54]]

II of Fluid Meters, 6th Edition (1971), IBR approved for 
Secs. 60.58a(h)(6)(ii) and 60.58b(i)(6)(ii).

    (i) Test Methods for Evaluating Solid Waste, Physical/Chemical 
Methods,'' EPA Publication SW-846 Third Edition (November 1986), as 
amended by Updates I (July, 1992), II (September 1994), IIA (August, 
1993), and IIB (January, 1995). Test Method are incorporated by 
reference for appendix A to part 60, Method 29, pars. 2.2.1; 2.3.1; 2.5; 
3.3.12.1; 3.3.12.2; 3.3.13; 3.3.14; 5.4.3; 6.2; 6.3; 7.2.1; 7.2.3; and 
Table 29-2. The Third Edition of SW-846 and Updates I, II, IIA, and IIB 
(document number 955-001-00000-1) are available from the Superintendent 
of Documents, U.S. Government Printing Office, Washington, DC 20402, 
(202) 512-1800. Copies may be obtained from the Library of the U.S. 
Environmental Protection Agency, 401 M Street, SW., Washington, DC 
20460.
    (j) Standard Methods for the Examination of Water and Wastewater, 
16th edition, 1985. Method 303F Determination of Mercury by the Cold 
Vapor Technique. This document may be obtained from the American Public 
Health Association, 1015 18th Street, NW., Washington, DC 20036, and is 
incorporated by reference for Method 29, pars 5.4.3; 6.3; and 7.2.3 of 
appendix A to part 60.
    (k) This material is available for purchase from the American 
Hospital Association (AHA) Service, Inc., Post Office Box 92683, 
Chicago, Illinois 60675-2683. You may inspect a copy at EPA's Air and 
Radiation Docket and Information Center (Docket A-91-61, Item IV-J-124), 
Room M-1500, 401 M Street SW., Washington, DC.

    (1) An Ounce of Prevention: Waste Reduction Strategies for Health 
Care Facilities. American Society for Health Care Environmental Services 
of the American Hospital Association. Chicago, Illinois. 1993. AHA 
Catalog No. 057007. ISBN 0-87258-673-5. IBR approved for Sec. 60.35e and 
Sec. 60.55c.

    (l) This material is available for purchase from the National 
Technical Information Services, 5285 Port Royal Road, Springfield, 
Virginia 22161. You may inspect a copy at EPA's Air and Radiation Docket 
and Information Center (Docket A-91-61, Item IV-J-125), Room M-1500, 401 
M Street SW., Washington, DC.

    (1) OMB Bulletin No. 93-17: Revised Statistical Definitions for 
Metropolitan Areas. Office of Management and Budget, June 30, 1993. NTIS 
No. PB 93-192-664. IBR approved for Sec. 60.31e.


[48 FR 3735, Jan. 27, 1983]

    Editorial Note: For Federal Register citations affecting Sec. 60.17, 
see the List of CFR Sections Affected in the Finding Aids section of 
this volume.



Sec. 60.18  General control device requirements.

    (a) Introduction. This section contains requirements for control 
devices used to comply with applicable subparts of parts 60 and 61. The 
requirements are placed here for administrative convenience and only 
apply to facilities covered by subparts referring to this section.
    (b) Flares. Paragraphs (c) through (f) apply to flares.
    (c)(1) Flares shall be designed for and operated with no visible 
emissions as determined by the methods specified in paragraph (f), 
except for periods not to exceed a total of 5 minutes during any 2 
consecutive hours.
    (2) Flares shall be operated with a flame present at all times, as 
determined by the methods specified in paragraph (f).
    (3) An owner/operator has the choice of adhering to either the heat 
content specifications in paragraph (c)(3)(ii) of this section and the 
maximum tip velocity specifications in paragraph (c)(4) of this section, 
or adhering to the requirements in paragraph (c)(3)(i) of this section.
    (i)(A) Flares shall be used that have a diameter of 3 inches or 
greater, are nonassisted, have a hydrogen content of 8.0 percent (by 
volume), or greater, and are designed for and operated with an exit 
velocity less than 37.2 m/sec (122 ft/sec) and less than the velocity, 
Vmax, as determined by the following equation:

Vmax=(XH2-K1)* K2

Where:
Vmax=Maximum permitted velocity, m/sec.
K1=Constant, 6.0 volume-percent hydrogen.
K2=Constant, 3.9(m/sec)/volume-percent hydrogen.

[[Page 55]]

XH2=The volume-percent of hydrogen, on a wet basis, as 
calculated by using the American Society for Testing and Materials 
(ASTM) Method D1946-77. (Incorporated by reference as specified in 
Sec. 60.17).

    (B) The actual exit velocity of a flare shall be determined by the 
method specified in paragraph (f)(4) of this section.
    (ii) Flares shall be used only with the net heating value of the gas 
being combusted being 11.2 MJ/scm (300 Btu/scf) or greater if the flare 
is steam-assisted or air-assisted; or with the net heating value of the 
gas being combusted being 7.45 MJ/scm (200 Btu/scf) or greater if the 
flare is nonassisted. The net heating value of the gas being combusted 
shall be determined by the methods specified in paragraph (f)(3) of this 
section.
    (4)(i) Steam-assisted and nonassisted flares shall be designed for 
and operated with an exit velocity, as determined by the methods 
specified in paragraph (f)(4) of this section, less than 18.3 m/sec (60 
ft/sec), except as provided in paragraphs (c)(4) (ii) and (iii) of this 
section.
    (ii) Steam-assisted and nonassisted flares designed for and operated 
with an exit velocity, as determined by the methods specified in 
paragraph (f)(4), equal to or greater than 18.3 m/sec (60 ft/sec) but 
less than 122 m/sec (400 ft/sec) are allowed if the net heating value of 
the gas being combusted is greater than 37.3 MJ/scm (1,000 Btu/scf).
    (iii) Steam-assisted and nonassisted flares designed for and 
operated with an exit velocity, as determined by the methods specified 
in paragraph (f)(4), less than the velocity, Vmax, as 
determined by the method specified in paragraph (f)(5), and less than 
122 m/sec (400 ft/sec) are allowed.
    (5) Air-assisted flares shall be designed and operated with an exit 
velocity less than the velocity, Vmax, as determined by the 
method specified in paragraph (f)(6).
    (6) Flares used to comply with this section shall be steam-assisted, 
air-assisted, or nonassisted.
    (d) Owners or operators of flares used to comply with the provisions 
of this subpart shall monitor these control devices to ensure that they 
are operated and maintained in conformance with their designs. 
Applicable subparts will provide provisions stating how owners or 
operators of flares shall monitor these control devices.
    (e) Flares used to comply with provisions of this subpart shall be 
operated at all times when emissions may be vented to them.
    (f)(1) Reference Method 22 shall be used to determine the compliance 
of flares with the visible emission provisions of this subpart. The 
observation period is 2 hours and shall be used according to Method 22.
    (2) The presence of a flare pilot flame shall be monitored using a 
thermocouple or any other equivalent device to detect the presence of a 
flame.
    (3) The net heating value of the gas being combusted in a flare 
shall be calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.008

where:

HT=Net heating value of the sample, MJ/scm; where the net 
          enthalpy per mole of offgas is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to one mole is 20  deg.C;
          [GRAPHIC] [TIFF OMITTED] TC01JN92.009
          

[[Page 56]]


Ci=Concentration of sample component i in ppm on a wet basis, 
          as measured for organics by Reference Method 18 and measured 
          for hydrogen and carbon monoxide by ASTM D1946-77 
          (Incorporated by reference as specified in Sec. 60.17); and
Hi=Net heat of combustion of sample component i, kcal/g mole 
          at 25  deg.C and 760 mm Hg. The heats of combustion may be 
          determined using ASTM D2382-76 (incorporated by reference as 
          specified in Sec. 60.17) if published values are not available 
          or cannot be calculated.

    (4) The actual exit velocity of a flare shall be determined by 
dividing the volumetric flowrate (in units of standard temperature and 
pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as 
appropriate; by the unobstructed (free) cross sectional area of the 
flare tip.
    (5) The maximum permitted velocity, Vmax, for flares 
complying with paragraph (c)(4)(iii) shall be determined by the 
following equation.
Log10 (Vmax)=(HT+28.8)/31.7

Vmax=Maximum permitted velocity, M/sec
28.8=Constant
31.7=Constant
HT=The net heating value as determined in paragraph (f)(3).

    (6) The maximum permitted velocity, Vmax, for air-
assisted flares shall be determined by the following equation.
Vmax=8.706+0.7084 (HT)

Vmax=Maximum permitted velocity, m/sec
8.706=Constant
0.7084=Constant
HT=The net heating value as determined in paragraph (f)(3).

[51 FR 2701, Jan. 21, 1986, as amended at 63 FR 24444, May 4, 1998]



Sec. 60.19  General notification and reporting requirements.

    (a) For the purposes of this part, time periods specified in days 
shall be measured in calendar days, even if the word ``calendar'' is 
absent, unless otherwise specified in an applicable requirement.
    (b) For the purposes of this part, if an explicit postmark deadline 
is not specified in an applicable requirement for the submittal of a 
notification, application, report, or other written communication to the 
Administrator, the owner or operator shall postmark the submittal on or 
before the number of days specified in the applicable requirement. For 
example, if a notification must be submitted 15 days before a particular 
event is scheduled to take place, the notification shall be postmarked 
on or before 15 days preceding the event; likewise, if a notification 
must be submitted 15 days after a particular event takes place, the 
notification shall be delivered or postmarked on or before 15 days 
following the end of the event. The use of reliable non-Government mail 
carriers that provide indications of verifiable delivery of information 
required to be submitted to the Administrator, similar to the postmark 
provided by the U.S. Postal Service, or alternative means of delivery, 
including the use of electronic media, agreed to by the permitting 
authority, is acceptable.
    (c) Notwithstanding time periods or postmark deadlines specified in 
this part for the submittal of information to the Administrator by an 
owner or operator, or the review of such information by the 
Administrator, such time periods or deadlines may be changed by mutual 
agreement between the owner or operator and the Administrator. 
Procedures governing the implementation of this provision are specified 
in paragraph (f) of this section.
    (d) If an owner or operator of an affected facility in a State with 
delegated authority is required to submit periodic reports under this 
part to the State, and if the State has an established timeline for the 
submission of periodic reports that is consistent with the reporting 
frequency(ies) specified for such facility under this part, the owner or 
operator may change the dates by which periodic reports under this part 
shall be submitted (without changing the frequency of reporting) to be 
consistent with the State's schedule by mutual agreement between the 
owner or operator and the State. The allowance in the previous sentence 
applies in each State beginning 1 year after the affected facility is 
required to be in compliance with the applicable subpart in this part. 
Procedures governing the implementation of this provision are specified 
in paragraph (f) of this section.
    (e) If an owner or operator supervises one or more stationary 
sources affected

[[Page 57]]

by standards set under this part and standards set under part 61, part 
63, or both such parts of this chapter, he/she may arrange by mutual 
agreement between the owner or operator and the Administrator (or the 
State with an approved permit program) a common schedule on which 
periodic reports required by each applicable standard shall be submitted 
throughout the year. The allowance in the previous sentence applies in 
each State beginning 1 year after the stationary source is required to 
be in compliance with the applicable subpart in this part, or 1 year 
after the stationary source is required to be in compliance with the 
applicable 40 CFR part 61 or part 63 of this chapter standard, whichever 
is latest. Procedures governing the implementation of this provision are 
specified in paragraph (f) of this section.
    (f)(1)(i) Until an adjustment of a time period or postmark deadline 
has been approved by the Administrator under paragraphs (f)(2) and 
(f)(3) of this section, the owner or operator of an affected facility 
remains strictly subject to the requirements of this part.
    (ii) An owner or operator shall request the adjustment provided for 
in paragraphs (f)(2) and (f)(3) of this section each time he or she 
wishes to change an applicable time period or postmark deadline 
specified in this part.
    (2) Notwithstanding time periods or postmark deadlines specified in 
this part for the submittal of information to the Administrator by an 
owner or operator, or the review of such information by the 
Administrator, such time periods or deadlines may be changed by mutual 
agreement between the owner or operator and the Administrator. An owner 
or operator who wishes to request a change in a time period or postmark 
deadline for a particular requirement shall request the adjustment in 
writing as soon as practicable before the subject activity is required 
to take place. The owner or operator shall include in the request 
whatever information he or she considers useful to convince the 
Administrator that an adjustment is warranted.
    (3) If, in the Administrator's judgment, an owner or operator's 
request for an adjustment to a particular time period or postmark 
deadline is warranted, the Administrator will approve the adjustment. 
The Administrator will notify the owner or operator in writing of 
approval or disapproval of the request for an adjustment within 15 
calendar days of receiving sufficient information to evaluate the 
request.
    (4) If the Administrator is unable to meet a specified deadline, he 
or she will notify the owner or operator of any significant delay and 
inform the owner or operator of the amended schedule.

[59 FR 12428, Mar. 16, 1994, as amended at 64 FR 7463, Feb. 12, 1998]



    Subpart B--Adoption and Submittal of State Plans for Designated 
                               Facilities

    Source: 40 FR 53346, Nov. 17, 1975, unless otherwise noted.



Sec. 60.20  Applicability.

    The provisions of this subpart apply to States upon publication of a 
final guideline document under Sec. 60.22(a).



Sec. 60.21  Definitions.

    Terms used but not defined in this subpart shall have the meaning 
given them in the Act and in subpart A:
    (a) Designated pollutant means any air pollutant, emissions of which 
are subject to a standard of performance for new stationary sources but 
for which air quality criteria have not been issued, and which is not 
included on a list published under section 108(a) or section 
112(b)(1)(A) of the Act.
    (b) Designated facility means any existing facility (see 
Sec. 60.2(aa)) which emits a designated pollutant and which would be 
subject to a standard of performance for that pollutant if the existing 
facility were an affected facility (see Sec. 60.2(e)).
    (c) Plan means a plan under section 111(d) of the Act which 
establishes emission standards for designated pollutants from designated 
facilities and provides for the implementation and enforcement of such 
emission standards.
    (d) Applicable plan means the plan, or most recent revision thereof, 
which has

[[Page 58]]

been approved under Sec. 60.27(b) or promulgated under Sec. 60.27(d).
    (e) Emission guideline means a guideline set forth in subpart C of 
this part, or in a final guideline document published under 
Sec. 60.22(a), which reflects the degree of emission reduction 
achievable through the application of the best system of emission 
reduction which (taking into account the cost of such reduction) the 
Administrator has determined has been adequately demonstrated for 
designated facilities.
    (f) Emission standard means a legally enforceable regulation setting 
forth an allowable rate of emissions into the atmosphere, or prescribing 
equipment specifications for control of air pollution emissions.
    (g) Compliance schedule means a legally enforceable schedule 
specifying a date or dates by which a source or category of sources must 
comply with specific emission standards contained in a plan or with any 
increments of progress to achieve such compliance.
    (h) Increments of progress means steps to achieve compliance which 
must be taken by an owner or operator of a designated facility, 
including:
    (1) Submittal of a final control plan for the designated facility to 
the appropriate air pollution control agency;
    (2) Awarding of contracts for emission control systems or for 
process modifications, or issuance of orders for the purchase of 
component parts to accomplish emission control or process modification;
    (3) Initiation of on-site construction or installation of emission 
control equipment or process change;
    (4) Completion of on-site construction or installation of emission 
control equipment or process change; and
    (5) Final compliance.
    (i) Region means an air quality control region designated under 
section 107 of the Act and described in part 81 of this chapter.
    (j) Local agency means any local governmental agency.



Sec. 60.22  Publication of guideline documents, emission guidelines, and final compliance times.

    (a) Concurrently upon or after proposal of standards of performance 
for the control of a designated pollutant from affected facilities, the 
Administrator will publish a draft guideline document containing 
information pertinent to control of the designated pollutant form 
designated facilities. Notice of the availability of the draft guideline 
document will be published in the Federal Register and public comments 
on its contents will be invited. After consideration of public comments 
and upon or after promulgation of standards of performance for control 
of a designated pollutant from affected facilities, a final guideline 
document will be published and notice of its availability will be 
published in the Federal Register.
    (b) Guideline documents published under this section will provide 
information for the development of State plans, such as:
    (1) Information concerning known or suspected endangerment of public 
health or welfare caused, or contributed to, by the designated 
pollutant.
    (2) A description of systems of emission reduction which, in the 
judgment of the Administrator, have been adequately demonstrated.
    (3) Information on the degree of emission reduction which is 
achievable with each system, together with information on the costs and 
environmental effects of applying each system to designated facilities.
    (4) Incremental periods of time normally expected to be necessary 
for the design, installation, and startup of identified control systems.
    (5) An emission guideline that reflects the application of the best 
system of emission reduction (considering the cost of such reduction) 
that has been adequately demonstrated for designated facilities, and the 
time within which compliance with emission standards of equivalent 
stringency can be achieved. The Administrator will specify different 
emission guidelines or compliance times or both for different sizes, 
types, and classes of designated facilities when costs of control, 
physical limitations, geographical location, or similar factors make 
subcategorization appropriate. (6) Such other available information as 
the Administrator determines may contribute to the formulation of State 
plans.

[[Page 59]]

    (c) Except as provided in paragraph (d)(1) of this section, the 
emission guidelines and compliance times referred to in paragraph (b)(5) 
of this section will be proposed for comment upon publication of the 
draft guideline document, and after consideration of comments will be 
promulgated in subpart C of this part with such modifications as may be 
appropriate.
    (d)(1) If the Administrator determines that a designated pollutant 
may cause or contribute to endangerment of public welfare, but that 
adverse effects on public health have not been demonstrated, he will 
include the determination in the draft guideline document and in the 
Federal Register notice of its availability. Except as provided in 
paragraph (d)(2) of this section, paragraph (c) of this section shall be 
inapplicable in such cases.
    (2) If the Administrator determines at any time on the basis of new 
information that a prior determination under paragraph (d)(1) of this 
section is incorrect or no longer correct, he will publish notice of the 
determination in the Federal Register, revise the guideline document as 
necessary under paragraph (a) of this section, and propose and 
promulgate emission guidelines and compliance times under paragraph (c) 
of this section.

[40 FR 53346, Nov. 17, 1975, as amended at 54 FR 52189, Dec. 20, 1989]



Sec. 60.23  Adoption and submittal of State plans; public hearings.

    (a)(1) Unless otherwise specified in the applicable subpart, within 
9 months after notice of the availability of a final guideline document 
is published under Sec. 60.22(a), each State shall adopt and submit to 
the Administrator, in accordance with Sec. 60.4 of subpart A of this 
part, a plan for the control of the designated pollutant to which the 
guideline document applies.
    (2) Within nine months after notice of the availability of a final 
revised guideline document is published as provided in Sec. 60.22(d)(2), 
each State shall adopt and submit to the Administrator any plan revision 
necessary to meet the requirements of this subpart.
    (b) If no designated facility is located within a State, the State 
shall submit a letter of certification to that effect to the 
Administrator within the time specified in paragraph (a) of this 
section. Such certification shall exempt the State from the requirements 
of this subpart for that designated pollutant.
    (c)(1) Except as provided in paragraphs (c)(2) and (c)(3) of this 
section, the State shall, prior to the adoption of any plan or revision 
thereof, conduct one or more public hearings within the State on such 
plan or plan revision.
    (2) No hearing shall be required for any change to an increment of 
progress in an approved compliance schedule unless the change is likely 
to cause the facility to be unable to comply with the final compliance 
date in the schedule.
    (3) No hearing shall be required on an emission standard in effect 
prior to the effective date of this subpart if it was adopted after a 
public hearing and is at least as stringent as the corresponding 
emission guideline specified in the applicable guideline document 
published under Sec. 60.22(a).
    (d) Any hearing required by paragraph (c) of this section shall be 
held only after reasonable notice. Notice shall be given at least 30 
days prior to the date of such hearing and shall include:
    (1) Notification to the public by prominently advertising the date, 
time, and place of such hearing in each region affected;
    (2) Availability, at the time of public announcement, of each 
proposed plan or revision thereof for public inspection in at least one 
location in each region to which it will apply;
    (3) Notification to the Administrator;
    (4) Notification to each local air pollution control agency in each 
region to which the plan or revision will apply; and
    (5) In the case of an interstate region, notification to any other 
State included in the region.
    (e) The State shall prepare and retain, for a minimum of 2 years, a 
record of each hearing for inspection by any interested party. The 
record shall contain, as a minimum, a list of witnesses together with 
the text of each presentation.
    (f) The State shall submit with the plan or revision:

[[Page 60]]

    (1) Certification that each hearing required by paragraph (c) of 
this section was held in accordance with the notice required by 
paragraph (d) of this section; and
    (2) A list of witnesses and their organizational affiliations, if 
any, appearing at the hearing and a brief written summary of each 
presentation or written submission.
    (g) Upon written application by a State agency (through the 
appropriate Regional Office), the Administrator may approve State 
procedures designed to insure public participation in the matters for 
which hearings are required and public notification of the opportunity 
to participate if, in the judgment of the Administrator, the procedures, 
although different from the requirements of this subpart, in fact 
provide for adequate notice to and participation of the public. The 
Administrator may impose such conditions on his approval as he deems 
necessary. Procedures approved under this section shall be deemed to 
satisfy the requirements of this subpart regarding procedures for public 
hearings.

[40 FR 53346, Nov. 17, 1975, as amended at 60 FR 65414, Dec. 19, 1995]



Sec. 60.24  Emission standards and compliance schedules.

    (a) Each plan shall include emission standards and compliance 
schedules.
    (b)(1) Emission standards shall prescribe allowable rates of 
emissions except when it is clearly impracticable. Such cases will be 
identified in the guideline documents issued under Sec. 60.22. Where 
emission standards prescribing equipment specifications are established, 
the plan shall, to the degree possible, set forth the emission 
reductions achievable by implementation of such specifications, and may 
permit compliance by the use of equipment determined by the State to be 
equivalent to that prescribed.
    (2) Test methods and procedures for determining compliance with the 
emission standards shall be specified in the plan. Methods other than 
those specified in appendix A to this part may be specified in the plan 
if shown to be equivalent or alternative methods as defined in Sec. 60.2 
(t) and (u).
    (3) Emission standards shall apply to all designated facilities 
within the State. A plan may contain emission standards adopted by local 
jurisdictions provided that the standards are enforceable by the State.
    (c) Except as provided in paragraph (f) of this section, where the 
Administrator has determined that a designated pollutant may cause or 
contribute to endangerment of public health, emission standards shall be 
no less stringent than the corresponding emission guideline(s) specified 
in subpart C of this part, and final compliance shall be required as 
expeditiously as practicable but no later than the compliance times 
specified in subpart C of this part.
    (d) Where the Administrator has determined that a designated 
pollutant may cause or contribute to endangerment of public welfare but 
that adverse effects on public health have not been demonstrated, States 
may balance the emission guidelines, compliance times, and other 
information provided in the applicable guideline document against other 
factors of public concern in establishing emission standards, compliance 
schedules, and variances. Appropriate consideration shall be given to 
the factors specified in Sec. 60.22(b) and to information presented at 
the public hearing(s) conducted under Sec. 60.23(c).
    (e)(1) Any compliance schedule extending more than 12 months from 
the date required for submittal of the plan shall include legally 
enforceable increments of progress to achieve compliance for each 
designated facility or category of facilities. Increments of progress 
shall include, where practicable, each increment of progress specified 
in Sec. 60.21(h) and shall include such additional increments of 
progress as may be necessary to permit close and effective supervision 
of progress toward final compliance.
    (2) A plan may provide that compliance schedules for individual 
sources or categories of sources will be formulated after plan 
submittal. Any such schedule shall be the subject of a public hearing 
held according to Sec. 60.23 and shall be submitted to the Administrator 
within 60 days after the date of adoption of the schedule but in no case

[[Page 61]]

later than the date prescribed for submittal of the first semiannual 
report required by Sec. 60.25(e).
    (f) Unless otherwise specified in the applicable subpart on a case-
by-case basis for particular designated facilities or classes of 
facilities, States may provide for the application of less stringent 
emissions standards or longer compliance schedules than those otherwise 
required by paragraph (c) of this section, provided that the State 
demonstrates with respect to each such facility (or class of 
facilities):
    (1) Unreasonable cost of control resulting from plant age, location, 
or basic process design;
    (2) Physical impossibility of installing necessary control 
equipment; or
    (3) Other factors specific to the facility (or class of facilities) 
that make application of a less stringent standard or final compliance 
time significantly more reasonable.
    (g) Nothing in this subpart shall be construed to preclude any State 
or political subdivision thereof from adopting or enforcing (1) emission 
standards more stringent than emission guidelines specified in subpart C 
of this part or in applicable guideline documents or (2) compliance 
schedules requiring final compliance at earlier times than those 
specified in subpart C or in applicable guideline documents.

[40 FR 53346, Nov. 17, 1975, as amended at 60 FR 65414, Dec. 19, 1995]



Sec. 60.25  Emission inventories, source surveillance, reports.

    (a) Each plan shall include an inventory of all designated 
facilities, including emission data for the designated pollutants and 
information related to emissions as specified in appendix D to this 
part. Such data shall be summarized in the plan, and emission rates of 
designated pollutants from designated facilities shall be correlated 
with applicable emission standards. As used in this subpart, 
``correlated'' means presented in such a manner as to show the 
relationship between measured or estimated amounts of emissions and the 
amounts of such emissions allowable under applicable emission standards.
    (b) Each plan shall provide for monitoring the status of compliance 
with applicable emission standards. Each plan shall, as a minimum, 
provide for:
    (1) Legally enforceable procedures for requiring owners or operators 
of designated facilities to maintain records and periodically report to 
the State information on the nature and amount of emissions from such 
facilities, and/or such other information as may be necessary to enable 
the State to determine whether such facilities are in compliance with 
applicable portions of the plan.
    (2) Periodic inspection and, when applicable, testing of designated 
facilities.
    (c) Each plan shall provide that information obtained by the State 
under paragraph (b) of this section shall be correlated with applicable 
emission standards (see Sec. 60.25(a)) and made available to the general 
public.
    (d) The provisions referred to in paragraphs (b) and (c) of this 
section shall be specifically identified. Copies of such provisions 
shall be submitted with the plan unless:
    (1) They have been approved as portions of a preceding plan 
submitted under this subpart or as portions of an implementation plan 
submitted under section 110 of the Act, and
    (2) The State demonstrates:
    (i) That the provisions are applicable to the designated 
pollutant(s) for which the plan is submitted, and
    (ii) That the requirements of Sec. 60.26 are met.
    (e) The State shall submit reports on progress in plan enforcement 
to the Administrator on an annual (calendar year) basis, commencing with 
the first full report period after approval of a plan or after 
promulgation of a plan by the Administrator. Information required under 
this paragraph must be included in the annual report required by 
Sec. 51.321 of this chapter.
    (f) Each progress report shall include:
    (1) Enforcement actions initiated against designated facilities 
during the reporting period, under any emission standard or compliance 
schedule of the plan.
    (2) Identification of the achievement of any increment of progress 
required by the applicable plan during the reporting period.

[[Page 62]]

    (3) Identification of designated facilities that have ceased 
operation during the reporting period.
    (4) Submission of emission inventory data as described in paragraph 
(a) of this section for designated facilities that were not in operation 
at the time of plan development but began operation during the reporting 
period.
    (5) Submission of additional data as necessary to update the 
information submitted under paragraph (a) of this section or in previous 
progress reports.
    (6) Submission of copies of technical reports on all performance 
testing on designated facilities conducted under paragraph (b)(2) of 
this section, complete with concurrently recorded process data.

[40 FR 53346, Nov. 17, 1975, as amended at 44 FR 65071, Nov. 9, 1979]



Sec. 60.26  Legal authority.

    (a) Each plan shall show that the State has legal authority to carry 
out the plan, including authority to:
    (1) Adopt emission standards and compliance schedules applicable to 
designated facilities.
    (2) Enforce applicable laws, regulations, standards, and compliance 
schedules, and seek injunctive relief.
    (3) Obtain information necessary to determine whether designated 
facilities are in compliance with applicable laws, regulations, 
standards, and compliance schedules, including authority to require 
recordkeeping and to make inspections and conduct tests of designated 
facilities.
    (4) Require owners or operators of designated facilities to install, 
maintain, and use emission monitoring devices and to make periodic 
reports to the State on the nature and amounts of emissions from such 
facilities; also authority for the State to make such data available to 
the public as reported and as correlated with applicable emission 
standards.
    (b) The provisions of law or regulations which the State determines 
provide the authorities required by this section shall be specifically 
identified. Copies of such laws or regulations shall be submitted with 
the plan unless:
    (1) They have been approved as portions of a preceding plan 
submitted under this subpart or as portions of an implementation plan 
submitted under section 110 of the Act, and
    (2) The State demonstrates that the laws or regulations are 
applicable to the designated pollutant(s) for which the plan is 
submitted.
    (c) The plan shall show that the legal authorities specified in this 
section are available to the State at the time of submission of the 
plan. Legal authority adequate to meet the requirements of paragraphs 
(a)(3) and (4) of this section may be delegated to the State under 
section 114 of the Act.
    (d) A State governmental agency other than the State air pollution 
control agency may be assigned responsibility for carrying out a portion 
of a plan if the plan demonstrates to the Administrator's satisfaction 
that the State governmental agency has the legal authority necessary to 
carry out that portion of the plan.
    (e) The State may authorize a local agency to carry out a plan, or 
portion thereof, within the local agency's jurisdiction if the plan 
demonstrates to the Administrator's satisfaction that the local agency 
has the legal authority necessary to implement the plan or portion 
thereof, and that the authorization does not relieve the State of 
responsibility under the Act for carrying out the plan or portion 
thereof.



Sec. 60.27  Actions by the Administrator.

    (a) The Administrator may, whenever he determines necessary, extend 
the period for submission of any plan or plan revision or portion 
thereof.
    (b) After receipt of a plan or plan revision, the Administrator will 
propose the plan or revision for approval or disapproval. The 
Administrator will, within four months after the date required for 
submission of a plan or plan revision, approve or disapprove such plan 
or revision or each portion thereof.
    (c) The Administrator will, after consideration of any State hearing 
record, promptly prepare and publish proposed regulations setting forth 
a plan, or portion thereof, for a State if:
    (1) The State fails to submit a plan within the time prescribed;
    (2) The State fails to submit a plan revision required by 
Sec. 60.23(a)(2) within the time prescribed; or

[[Page 63]]

    (3) The Administrator disapproves the State plan or plan revision or 
any portion thereof, as unsatisfactory because the requirements of this 
subpart have not been met.
    (d) The Administrator will, within six months after the date 
required for submission of a plan or plan revision, promulgate the 
regulations proposed under paragraph (c) of this section with such 
modifications as may be appropriate unless, prior to such promulgation, 
the State has adopted and submitted a plan or plan revision which the 
Administrator determines to be approvable.
    (e)(1) Except as provided in paragraph (e)(2) of this section, 
regulations proposed and promulgated by the Administrator under this 
section will prescribe emission standards of the same stringency as the 
corresponding emission guideline(s) specified in the final guideline 
document published under Sec. 60.22(a) and will require final compliance 
with such standards as expeditiously as practicable but no later than 
the times specified in the guideline document.
    (2) Upon application by the owner or operator of a designated 
facility to which regulations proposed and promulgated under this 
section will apply, the Administrator may provide for the application of 
less stringent emission standards or longer compliance schedules than 
those otherwise required by this section in accordance with the criteria 
specified in Sec. 60.24(f).
    (f) If a State failed to hold a public hearing as required by 
Sec. 60.23(c), the Administrator will provide opportunity for a hearing 
within the State prior to promulgation of a plan under paragraph (d) of 
this section.



Sec. 60.28  Plan revisions by the State.

    (a) Plan revisions which have the effect of delaying compliance with 
applicable emission standards or increments of progress or of 
establishing less stringent emission standards shall be submitted to the 
Administrator within 60 days after adoption in accordance with the 
procedures and requirements applicable to development and submission of 
the original plan.
    (b) More stringent emission standards, or orders which have the 
effect of accelerating compliance, may be submitted to the Administrator 
as plan revisions in accordance with the procedures and requirements 
applicable to development and submission of the original plan.
    (c) A revision of a plan, or any portion thereof, shall not be 
considered part of an applicable plan until approved by the 
Administrator in accordance with this subpart.



Sec. 60.29  Plan revisions by the Administrator.

    After notice and opportunity for public hearing in each affected 
State, the Administrator may revise any provision of an applicable plan 
if:
    (a) The provision was promulgated by the Administrator, and
    (b) The plan, as revised, will be consistent with the Act and with 
the requirements of this subpart.



           Subpart C--Emission Guidelines and Compliance Times



Sec. 60.30  Scope.

    The following subparts contain emission guidelines and compliance 
times for the control of certain designated pollutants in accordance 
with section 111(d) and section 129 of the Clean Air Act and subpart B 
of this part.
    (a) Subpart Ca--[Reserved]
    (b) Subpart Cb--Municipal Waste Combustors.
    (c) Subpart Cc--Municipal Solid Waste Landfills.
    (d) Subpart Cd--Sulfuric Acid Production Plants.
    (e) Subpart Ce--Hospital/Medical/Infectious Waste Incinerators.

[62 FR 48379, Sept. 15, 1997]



Sec. 60.31  Definitions.

    Terms used but not defined in this subpart have the meaning given 
them in the Act and in subparts A and B of this part.

[42 FR 55797, Oct. 18, 1977]

[[Page 64]]

Subpart Ca  [Reserved]



    Subpart Cb--Emissions Guidelines and Compliance Times for Large 
 Municipal Waste Combustors That are Constructed on or Before September 
                                20, 1994

    Source: 60 FR 65415, Dec. 19, 1995, unless otherwise noted.



Sec. 60.30b  Scope.

    This subpart contains emission guidelines and compliance schedules 
for the control of certain designated pollutants from certain municipal 
waste combustors in accordance with section 111(d) and section 129 of 
the Clean Air Act and subpart B of this part. The provisions in these 
emission guidelines supersede the provisions of Sec. 60.24(f) of subpart 
B of this part.



Sec. 60.31b  Definitions.

    Terms used but not defined in this subpart have the meaning given 
them in the Clean Air Act and subparts A, B, and Eb of this part.
    Municipal waste combustor plant means one or more designated 
facilities (as defined in Sec. 60.32b) at the same location.

[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45119, 45125, Aug. 25, 
1997]



Sec. 60.32b  Designated facilities.

    (a) The designated facility to which these guidelines apply is each 
municipal waste combustor unit with a combustion capacity greater than 
250 tons per day of municipal solid waste for which construction was 
commenced on or before September 20, 1994.
    (b) Any municipal waste combustion unit that is capable of 
combusting more than 250 tons per day of municipal solid waste and is 
subject to a federally enforceable permit limiting the maximum amount of 
municipal solid waste that may be combusted in the unit to less than or 
equal to 11 tons per day is not subject to this subpart if the owner or 
operator:
    (1) Notifies the EPA Administrator of an exemption claim,
    (2) Provides a copy of the federally enforceable permit that limits 
the firing of municipal solid waste to less than 11 tons per day, and
    (3) Keeps records of the amount of municipal solid waste fired on a 
daily basis.
    (c) Physical or operational changes made to an existing municipal 
waste combustor unit primarily for the purpose of complying with 
emission guidelines under this subpart are not considered in determining 
whether the unit is a modified or reconstructed facility under subpart 
Ea or subpart Eb of this part.
    (d) A qualifying small power production facility, as defined in 
section 3(17)(C) of the Federal Power Act (16 U.S.C. 796(17)(C)), that 
burns homogeneous waste (such as automotive tires or used oil, but not 
including refuse-derived fuel) for the production of electric energy is 
not subject to this subpart if the owner or operator of the facility 
notifies the EPA Administrator of this exemption and provides data 
documenting that the facility qualifies for this exemption.
    (e) A qualifying cogeneration facility, as defined in section 
3(18)(B) of the Federal Power Act (16 U.S.C. 796(18)(B)), that burns 
homogeneous waste (such as automotive tires or used oil, but not 
including refuse-derived fuel) for the production of electric energy and 
steam or forms of useful energy (such as heat) that are used for 
industrial, commercial, heating, or cooling purposes, is not subject to 
this subpart if the owner or operator of the facility notifies the EPA 
Administrator of this exemption and provides data documenting that the 
facility qualifies for this exemption.
    (f) Any unit combusting a single-item waste stream of tires is not 
subject to this subpart if the owner or operator of the unit:
    (1) Notifies the EPA Administrator of an exemption claim, and
    (2) Provides data documenting that the unit qualifies for this 
exemption.
    (g) Any unit required to have a permit under section 3005 of the 
Solid Waste Disposal Act is not subject to this subpart.

[[Page 65]]

    (h) Any materials recovery facility (including primary or secondary 
smelters) that combusts waste for the primary purpose of recovering 
metals is not subject to this subpart.
    (i) Any cofired combustor, as defined under Sec. 60.51b of subpart 
Eb of this part, that meets the capacity specifications in paragraph (a) 
of this section is not subject to this subpart if the owner or operator 
of the cofired combustor:
    (1) Notifies the EPA Administrator of an exemption claim,
    (2) Provides a copy of the federally enforceable permit (specified 
in the definition of cofired combustor in this section), and
    (3) Keeps a record on a calendar quarter basis of the weight of 
municipal solid waste combusted at the cofired combustor and the weight 
of all other fuels combusted at the cofired combustor.
    (j) Air curtain incinerators, as defined under Sec. 60.51b of 
subpart Eb of this part, that meet the capacity specifications in 
paragraph (a) of this section, and that combust a fuel stream composed 
of 100 percent yard waste are exempt from all provisions of this subpart 
except the opacity standard under Sec. 60.37b, the testing procedures 
under Sec. 60.38b, and the reporting and recordkeeping provisions under 
Sec. 60.39b.
    (k) Air curtain incinerators that meet the capacity specifications 
in paragraph (a) of this section and that combust municipal solid waste 
other than yard waste are subject to all provisions of this subpart.
    (l) Pyrolysis/combustion units that are an integrated part of a 
plastics/rubber recycling unit (as defined in Sec. 60.51b) are not 
subject to this subpart if the owner or operator of the plastics/rubber 
recycling unit keeps records of the weight of plastics, rubber, and/or 
rubber tires processed on a calendar quarter basis; the weight of 
chemical plant feedstocks and petroleum refinery feedstocks produced and 
marketed on a calendar quarter basis; and the name and address of the 
purchaser of the feedstocks. The combustion of gasoline, diesel fuel, 
jet fuel, fuel oils, residual oil, refinery gas, petroleum coke, 
liquified petroleum gas, propane, or butane produced by chemical plants 
or petroleum refineries that use feedstocks produced by plastics/rubber 
recycling units are not subject to this subpart.
    (m) Cement kilns firing municipal solid waste are not subject to 
this subpart.

[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45119, 45125, Aug. 25, 
1997]



Sec. 60.33b  Emission guidelines for municipal waste combustor metals, acid gases, organics, and nitrogen oxides.

    (a) The emission limits for municipal waste combustor metals are 
specified in paragraphs (a)(1) through (a)(3) of this section.
    (1) For approval, a State plan shall include emission limits for 
particulate matter and opacity at least as protective as the emission 
limits for particulate matter and opacity specified in paragraphs 
(a)(1)(i) through (a)(1)(iii) of this section.
    (i) The emission limit for particulate matter contained in the gases 
discharged to the atmosphere from a designated facility is 27 milligrams 
per dry standard cubic meter, corrected to 7 percent oxygen.
    (ii) [Reserved]
    (iii) The emission limit for opacity exhibited by the gases 
discharged to the atmosphere from a designated facility is 10 percent 
(6-minute average).
    (2) For approval, a State plan shall include emission limits for 
cadmium and lead at least as protective as the emission limits for 
cadmium and lead specified in paragraphs (a)(2)(i) through (a)(2)(iv) of 
this section.
    (i) The emission limit for cadmium contained in the gases discharged 
to the atmosphere from a designated facility is 0.040 milligrams per dry 
standard cubic meter, corrected to 7 percent oxygen.
    (ii) [Reserved]
    (iii) The emission limit for lead contained in the gases discharged 
to the atmosphere from a designated facility is 0.49 milligrams per dry 
standard cubic meter, corrected to 7 percent oxygen.
    (iv) [Reserved]
    (3) For approval, a State plan shall include emission limits for 
mercury at least as protective as the emission limits specified in this 
paragraph. The

[[Page 66]]

emission limit for mercury contained in the gases discharged to the 
atmosphere from a designated facility is 0.080 milligrams per dry 
standard cubic meter or 15 percent of the potential mercury emission 
concentration (85-percent reduction by weight), corrected to 7 percent 
oxygen, whichever is less stringent.
    (4) For approval, a State plan shall be submitted by August 25, 1998 
and shall include an emission limit for lead at least as protective as 
the emission limit for lead specified in this paragraph. The emission 
limit for lead contained in the gases discharged to the atmosphere from 
a designated facility is 0.44 milligrams per dry standard cubic meter, 
corrected to 7 percent oxygen.
    (b) The emission limits for municipal waste combustor acid gases, 
expressed as sulfur dioxide and hydrogen chloride, are specified in 
paragraphs (b)(1) and (b)(2) of this section.
    (1) For approval, a State plan shall include emission limits for 
sulfur dioxide at least as protective as the emission limits for sulfur 
dioxide specified in paragraphs (b)(1)(i) and (b)(1)(ii) of this 
section.
    (i) The emission limit for sulfur dioxide contained in the gases 
discharged to the atmosphere from a designated facility is 31 parts per 
million by volume or 25 percent of the potential sulfur dioxide emission 
concentration (75-percent reduction by weight or volume), corrected to 7 
percent oxygen (dry basis), whichever is less stringent. Compliance with 
this emission limit is based on a 24-hour daily geometric mean.
    (ii) [Reserved]
    (2) For approval, a State plan shall include emission limits for 
hydrogen chloride at least as protective as the emission limits for 
hydrogen chloride specified in paragraphs (b)(2)(i) and (b)(2)(ii) of 
this section.
    (i) The emission limit for hydrogen chloride contained in the gases 
discharged to the atmosphere from a designated facility is 31 parts per 
million by volume or 5 percent of the potential hydrogen chloride 
emission concentration (95-percent reduction by weight or volume), 
corrected to 7 percent oxygen (dry basis), whichever is less stringent.
    (ii) [Reserved]
    (3) For approval, a State plan shall be submitted by August 25, 1998 
and shall include emission limits for sulfur dioxide and hydrogen 
chloride at least as protective as the emission limits specified in 
paragraphs (b)(3)(i) and (b)(3)(ii) of this section.
    (i) The emission limit for sulfur dioxide contained in the gases 
discharged to the atmosphere from a designated facility is 29 parts per 
million by volume or 25 percent of the potential sulfur dioxide emission 
concentration (75-percent reduction by weight or volume), corrected to 7 
percent oxygen (dry basis), whichever is less stringent. Compliance with 
this emission limit is based on a 24-hour daily geometric mean.
    (ii) The emission limit for hydrogen chloride contained in the gases 
discharged to the atmosphere from a designated facility is 29 parts per 
million by volume or 5 percent of the potential hydrogen chloride 
emission concentration (95-percent reduction by weight or volume), 
corrected to 7 percent oxygen (dry basis), whichever is less stringent.
    (c) The emission limits for municipal waste combustor organics, 
expressed as total mass dioxins/furans, are specified in paragraphs 
(c)(1) and (c)(2) of this section.
    (1) For approval, a State plan shall include an emission limit for 
dioxins/furans contained in the gases discharged to the atmosphere from 
a designated facility at least as protective as the emission limit for 
dioxins/furans specified in either paragraph (c)(1)(i) or (c)(1)(ii) of 
this section, as applicable.
    (i) The emission limit for designated facilities that employ an 
electrostatic precipitator-based emission control system is 60 nanograms 
per dry standard cubic meter (total mass), corrected to 7 percent 
oxygen.
    (ii) The emission limit for designated facilities that do not employ 
an electrostatic precipitator-based emission control system is 30 
nanograms per dry standard cubic meter (total mass), corrected to 7 
percent oxygen.
    (2) [Reserved]
    (d) For approval, a State plan shall include emission limits for 
nitrogen oxides at least as protective as the emission limits listed in 
table 1 of this

[[Page 67]]

subpart for designated facilities. Table 1 provides emission limits for 
the nitrogen oxides concentration level for each type of designated 
facility.

     Table 1--Nitrogen Oxides Guidelines for Designated Facilities
------------------------------------------------------------------------
                                                              Nitrogen
                                                               oxides
                                                              emission
           Municipal waste combustor technology             limit (parts
                                                             per million
                                                            by volume) a
------------------------------------------------------------------------
Mass burn waterwall.......................................          205
Mass burn rotary waterwall................................          250
Refuse-derived fuel combustor.............................          250
Fluidized bed combustor...................................          240
Mass burn refractory combustors...........................     no limit
------------------------------------------------------------------------
a Corrected to 7 percent oxygen, dry basis.

    (1) A State plan may allow nitrogen oxides emissions averaging as 
specified in paragraphs (d)(1)(i) through (d)(1)(v) of this section.
    (i) The owner or operator of a municipal waste combustor plant may 
elect to implement a nitrogen oxides emissions averaging plan for the 
designated facilities that are located at that plant and that are 
subject to subpart Cb, except as specified in paragraphs (d)(1)(i)(A) 
and (d)(1)(i)(B) of this section.
    (A) Municipal waste combustor units subject to subpart Ea or Eb 
cannot be included in the emissions averaging plan.
    (B) Mass burn refractory municipal waste combustor units and other 
municipal waste combustor technologies not listed in paragraph 
(d)(1)(iii) of this section may not be included in the emissions 
averaging plan.
    (ii) The designated facilities included in the nitrogen oxides 
emissions averaging plan must be identified in the initial compliance 
report specified in Sec. 60.59b(f) or in the annual report specified in 
Sec. 60.59b(g), as applicable, prior to implementing the averaging plan. 
The designated facilities being included in the averaging plan may be 
redesignated each calendar year. Partial year redesignation is allowable 
with State approval.
    (iii) To implement the emissions averaging plan, the average daily 
(24-hour) nitrogen oxides emission concentration level for gases 
discharged from the designated facilities being included in the 
emissions averaging plan must be no greater than the levels specified in 
table 2 of this subpart. Table 2 provides emission limits for the 
nitrogen oxides concentration level for each type of designated 
facility.

   Table 2--Nitrogen Oxides Limits For Existing Designated Facilities
 Included in an Emissions Averaging Plan at a Municpial Waste Combustor
                                 Planta
------------------------------------------------------------------------
                                                              Nitrogen
                                                               oxides
                                                              emission
           Municipal waste combustor technology             limit (parts
                                                             per million
                                                             by volume)b
------------------------------------------------------------------------
Mass burn waterwall.......................................          185
Mass burn rotary waterwall................................          220
Refuse-derived fuel combustor.............................          230
Fluidized bed combustor...................................          220
------------------------------------------------------------------------
a Mass burn refractory municipal waste combustors and other MWC
  technologies not listed above may not be included in an emissions
  averaging plan.
b Corrected to 7 percent oxygen, dry basis.

    (iv) Under the emissions averaging plan, the average daily nitrogen 
oxides emissions specified in paragraph (d)(1)(iii) of this section 
shall be calculated using equation (1). Designated facilities that are 
offline shall not be included in calculating the average daily nitrogen 
oxides emission level.
[GRAPHIC] [TIFF OMITTED] TR19DE95.000

where:

NOX 24-hr=24-hr daily average nitrogen oxides emission 
concentration level for the emissions averaging plan (parts per million 
by volume corrected to 7 percent oxygen).
NOX i-hr=24-hr daily average nitrogen oxides emission 
concentration level for designated facility i (parts per million by 
volume, corrected to 7 percent oxygen), calculated according to the 
procedures in Sec. 60.58b(h) of this subpart.
Si=maximum demonstrated municipal waste combustor unit load 
for designated facility i (pounds per hour steam or feedwater flow as 
determined in the most recent dioxin/furan performance test).

[[Page 68]]

h=total number of designated facilities being included in the daily 
emissions average.

    (v) For any day in which any designated facility included in the 
emissions averaging plan is offline, the owner or operator of the 
municipal waste combustor plant must demonstrate compliance according to 
either paragraph (d)(1)(v)(A) of this section or both paragraphs 
(d)(1)(v)(B) and (d)(1)(v)(C) of this section.
    (A) Compliance with the applicable limits specified in table 2 of 
this subpart shall be demonstrated using the averaging procedure 
specified in paragraph (d)(1)(iv) of this section for the designated 
facilities that are online.
    (B) For each of the designated facilities included in the emissions 
averaging plan, the nitrogen oxides emissions on a daily average basis 
shall be calculated and shall be equal to or less than the maximum daily 
nitrogen oxides emission level achieved by that designated facility on 
any of the days during which the emissions averaging plan was achieved 
with all designated facilities online during the most recent calendar 
quarter. The requirements of this paragraph do not apply during the 
first quarter of operation under the emissions averaging plan.
    (C) The average nitrogen oxides emissions (kilograms per day) 
calculated according to paragraph (d)(1)(v)(C)(2) of this section shall 
not exceed the average nitrogen oxides emissions (kilograms per day) 
calculated according to paragraph (d)(1)(v)(C)(1) of this section.
    (1) For all days during which the emissions averaging plan was 
implemented and achieved and during which all designated facilities were 
online, the average nitrogen oxides emissions shall be calculated. The 
average nitrogen oxides emissions (kilograms per day) shall be 
calculated on a calendar year basis according to paragraphs 
(d)(1)(v)(C)(1)(i) through (d)(1)(v)(C)(1)(iii) of this section.
    (i) For each designated facility included in the emissions averaging 
plan, the daily amount of nitrogen oxides emitted (kilograms per day) 
shall be calculated based on the hourly nitrogen oxides data required 
under Sec. 60.38b(a) and specified under Sec. 60.58b(h)(5) of subpart Eb 
of this part, the flue gas flow rate determined using table 19-1 of EPA 
Reference Method 19 or a State-approved method, and the hourly average 
steam or feedwater flow rate.
    (ii) The daily total nitrogen oxides emissions shall be calculated 
as the sum of the daily nitrogen oxides emissions from each designated 
facility calculated under paragraph (d)(1)(v)(C)(1)(i) of this section.
    (iii) The average nitrogen oxides emissions (kilograms per day) on a 
calendar year basis shall be calculated as the sum of all daily total 
nitrogen oxides emissions calculated under paragraph (d)(1)(v)(C)(1)(ii) 
of this section divided by the number of calendar days for which a daily 
total was calculated.
    (2) For all days during which one or more of the designated 
facilities under the emissions averaging plan was offline, the average 
nitrogen oxides emissions shall be calculated. The average nitrogen 
oxides emissions (kilograms per day) shall be calculated on a calendar 
year basis according to paragraphs (d)(1)(v)(C)(2)(i) through 
(d)(1)(v)(C)(2)(iii) of this section.
    (i) For each designated facility included in the emissions averaging 
plan, the daily amount of nitrogen oxides emitted (kilograms per day) 
shall be calculated based on the hourly nitrogen oxides data required 
under Sec. 60.38b(a) and specified under Sec. 60.58b(h)(5) of subpart Eb 
of this part, the flue gas flow rate determined using table 19-1 of EPA 
Reference Method 19 or a State-approved method, and the hourly average 
steam or feedwater flow rate.
    (ii) The daily total nitrogen oxides emissions shall be calculated 
as the sum of the daily nitrogen oxides emissions from each designated 
facility calculated under paragraph (d)(1)(v)(C)(2)(i) of this section.
    (iii) The average nitrogen oxides emissions (kilograms per day) on a 
calendar year basis shall be calculated as the sum of all daily total 
nitrogen oxides emissions calculated under paragraph (d)(1)(v)(C)(2)(ii) 
of this section divided by the number of calendar days for which a daily 
total was calculated.
    (2) A State plan may establish a program to allow owners or 
operators of municipal waste combustor plants to

[[Page 69]]

engage in trading of nitrogen oxides emission credits. A trading program 
must be approved by the Administrator before implementation.
    (3) For approval, a State plan shall be submitted by August 25, 1998 
and shall include emission limits for nitrogen oxides from fluidized bed 
combustors at least as protective as the emission limits listed in 
paragraphs (d)(3)(i) and (d)(3)(ii) of this section.
    (i) The emission limit for nitrogen oxides contained in the gases 
discharged to the atmosphere from a designated facility that is a 
fluidized bed combustor is 180 parts per million by volume, corrected to 
7 percent oxygen.
    (ii) If a State plan allows nitrogen oxides emissions averaging as 
specified in paragraphs (d)(1)(i) through (d)(1)(v) of this section, the 
emission limit for nitrogen oxides contained in the gases discharged to 
the atmosphere from a designated facility that is a fluidized bed 
combustor is 165 parts per million by volume, corrected to 7 percent 
oxygen.

[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45119, 45125, Aug. 25, 
1997]



Sec. 60.34b  Emission guidelines for municipal waste combustor operating practices.

    (a) For approval, a State plan shall include emission limits for 
carbon monoxide at least as protective as the emission limits for carbon 
monoxide listed in table 3 of this subpart. Table 3 provides emission 
limits for the carbon monoxide concentration level for each type of 
designated facility.

        Table 3.--Municipal Waste Combustor Operating Guidelines
------------------------------------------------------------------------
                                                   Carbon
                                                  monoxide
                                                 emissions
     Municipal waste combustor technology          level      Averaging
                                                 (parts per  time (hrs)b
                                                 million by
                                                  volume)a
------------------------------------------------------------------------
Mass burn waterwall...........................          100            4
Mass burn refractory..........................          100            4
Mass burn rotary refractory...................          100           24
Mass burn rotary waterwall....................          250           24
Modular starved air...........................           50            4
Modular excess air............................           50            4
Refuse-derived fuel stoker....................          200           24
Buddling fluidized bed combustor..............          100            4
Circulating fluidized bed combustor...........          100            4
Pulverized coal/refuse-derived fuel mixed fuel-         150            4
 fired combustor..............................
Spreader stoker coal/refuse-derived fuel mixed          200           24
 fuel-fired combustor.........................
------------------------------------------------------------------------
a Measured at the combustor outlet in conjunction with a measurement of
  oxygen concentration, corrected to 7 percent oxygen, dry basis.
  Calculated as an arithmetic average.
b Averaging times are 4-hour or 24-hour block averages.

    (b) For approval, a State plan shall include requirements for 
municipal waste combustor operating practices at least as protective as 
those requirements listed in Sec. 60.53b(b) and (c) of subpart Eb of 
this part.

[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45120, 45125, Aug. 25, 
1997]



Sec. 60.35b  Emission guidelines for municipal waste combustor operator training and certification.

    For approval, a State plan shall include requirements for designated 
facilities for municipal waste combustor operator training and 
certification at least as protective as those requirements listed in 
Sec. 60.54b of subpart Eb of this part. The State plan shall require 
compliance with these requirements according to the schedule specified 
in Sec. 60.39b(c)(4).

[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45120, Aug. 25, 1997]



Sec. 60.36b  Emission guidelines for municipal waste combustor fugitive ash emissions.

    For approval, a State plan shall include requirements for municipal 
waste combustor fugitive ash emissions at least as protective as those 
requirements listed in Sec. 60.55b of subpart Eb of this part.

[[Page 70]]



Sec. 60.37b  Emission guidelines for air curtain incinerators.

    For approval, a State plan shall include emission limits for opacity 
for air curtain incinerators at least as protective as those listed in 
Sec. 60.56b of subpart Eb of this part.



Sec. 60.38b  Compliance and performance testing.

    (a) For approval, a State plan shall include the performance testing 
methods listed in Sec. 60.58b of subpart Eb of this part, as applicable, 
except as provided for under Sec. 60.24(b)(2) of subpart B of this part 
and paragraphs (b) and (c) of this section.
    (b) For approval, a State plan shall include for designated 
facilities the alternative performance testing schedule for dioxins/
furans specified in Sec. 60.58b(g)(5)(iii) of subpart Eb of this part, 
as applicable, for those designated facilities that achieve a dioxin/
furan emission level less than or equal to 15 nanograms per dry standard 
cubic meter total mass, corrected to 7 percent oxygen.
    (c) [Reserved]

[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45120, Aug. 25, 1997]



Sec. 60.39b  Reporting and recordkeeping guidelines and compliance schedules.

    (a) For approval, a State plan shall include the reporting and 
recordkeeping provisions listed in Sec. 60.59b of subpart Eb of this 
part, as applicable, except for the siting requirements under 
Sec. 60.59b(a), (b)(5), and (d)(11) of subpart Eb of this part.
    (b) Not later than December 19, 1996, each State in which a 
designated facility is located shall submit to the EPA Administrator a 
plan to implement and enforce all provisions of this subpart except 
those specified under Sec. 60.33b (a)(4), (b)(3), and (d)(3). The 
compliance schedule specified in this paragraph is in accordance with 
section 129(b)(2) of the Act and supersedes the compliance schedule 
provided in Sec. 60.23(a)(1) of subpart B of this part.
    (c) For approval, a State plan shall include the compliance 
schedules specified in paragraphs (c)(1) through (c)(5) of this section.
    (1) A State plan shall allow designated facilities to comply with 
all requirements of a State plan (or close) within 1 year after approval 
of the State plan, except as provided by paragraph (c)(1)(i) and 
(c)(1)(ii) of this section.
    (i) A State plan that allows designated facilities more than 1 year 
but less than 3 years following the date of issuance of a revised 
construction or operation permit, if a permit modification is required, 
or more than 1 year but less than 3 years following approval of the 
State plan, if a permit modification is not required, shall include 
measurable and enforceable incremental steps of progress toward 
compliance. Suggested measurable and enforceable activities are 
specified in paragraphs (c)(1)(i)(A) through (c)(1)(i)(J) of this 
section.
    (A) Date for obtaining services of an architectural and engineering 
firm regarding the air pollution control device(s);
    (B) Date for obtaining design drawings of the air pollution control 
device(s);
    (C) Date for submittal of permit modifications, if necessary;
    (D) Date for submittal of the final control plan to the 
Administrator. [Sec. 60.21 (h)(1) of subpart B of this part.];
    (E) Date for ordering the air pollution control device(s);
    (F) Date for obtaining the major components of the air pollution 
control device(s);
    (G) Date for initiation of site preparation for installation of the 
air pollution control device(s);
    (H) Date for initiation of installation of the air pollution control 
device(s);
    (I) Date for initial startup of the air pollution control device(s); 
and
    (J) Date for initial performance test(s) of the air pollution 
control device(s).
    (ii) A State plan that allows designated facilities more than 1 year 
but up to 3 years after State plan approval to close shall require a 
closure agreement. The closure agreement must include the date of plant 
closure.
    (2) If the State plan requirements for a designated facility include 
a compliance schedule longer than 1 year after

[[Page 71]]

approval of the State plan in accordance with paragraph (c)(1)(i) or 
(c)(1)(ii) of this section, the State plan submittal (for approval) 
shall include performance test results for dioxin/furan emissions for 
each designated facility that has a compliance schedule longer than 1 
year following the approval of the State plan, and the performance test 
results shall have been conducted during or after 1990. The performance 
test shall be conducted according to the procedures in Sec. 60.38b.
    (3) [Reserved]
    (4) A State plan shall require compliance with the municipal waste 
combustor operator training and certification requirements under 
Sec. 60.35b according to the schedule specified in paragraphs (c)(4)(i) 
through (c)(4)(iii) of this section.
    (i) [Reserved]
    (ii) For designated facilities, the State plan shall require 
compliance with the municipal waste combustor operator training and 
certification requirements specified under Sec. 60.54b (a) through (c) 
of subpart Eb of this part by the date 6 months after the date of 
startup or 12 months after State plan approval, whichever is later.
    (iii) For designated facilities, the State plan shall require 
compliance with the requirements specified in Sec. 60.54b (d), (f), and 
(g) of subpart Eb of this part no later than 6 months after startup or 
12 months after State plan approval, whichever is later.
    (A) The requirement specified in Sec. 60.54b(d) of subpart Eb of 
this part does not apply to chief facility operators, shift supervisors, 
and control room operators who have obtained full certification from the 
American Society of Mechanical Engineers on or before the date of State 
plan approval.
    (B) The owner or operator of a designated facility may request that 
the EPA Administrator waive the requirement specified in Sec. 60.54b(d) 
of subpart Eb of this part for chief facility operators, shift 
supervisors, and control room operators who have obtained provisional 
certification from the American Society of Mechanical Engineers on or 
before the date of State plan approval.
    (C) The initial training requirements specified in Sec. 60.54b(f)(1) 
of subpart Eb of this part shall be completed no later than the date 
specified in paragraph (c)(4)(iii)(C)(1), (c)(4)(iii)(C)(2), or 
(c)(4)(iii)(C)(3), of this section whichever is later.
    (1) The date 6 months after the date of startup of the affected 
facility;
    (2) Twelve months after State plan approval; or
    (3) The date prior to the day when the person assumes 
responsibilities affecting municipal waste combustor unit operation.
    (5) A State plan shall require all designated facilities for which 
construction, modification, or reconstruction is commenced after June 
26, 1987 to comply with the emission limit for mercury specified in 
Sec. 60.33b(a)(3) and the emission limit for dioxins/furans specified in 
Sec. 60.33b(c)(1) within 1 year following issuance of a revised 
construction or operation permit, if a permit modification is required, 
or within 1 year following approval of the State plan, whichever is 
later.
    (d) In the event no plan for implementing the emission guidelines is 
approved by EPA, all designated facilities meeting the applicability 
requirements under Sec. 60.32b shall be in compliance with all of the 
guidelines, except those specified under Sec. 60.33b (a)(4), (b)(3), and 
(d)(3), no later than December 19, 2000.
    (e) Not later than August 25, 1998, each State in which a designated 
facility is operating shall submit to the EPA Administrator a plan to 
implement and enforce all provisions of this subpart specified in 
Sec. 60.33b (a)(4), (b)(3), and (d)(3).
    (f) In the event no plan for implementing the emission guidelines is 
approved by EPA, all designated facilities meeting the applicability 
requirements under Sec. 60.32b shall be in compliance with all of the 
guidelines, including those specified under Sec. 60.33b (a)(4), (b)(3), 
and (d)(3), no later than August 26, 2002.

[60 FR 65415, Dec. 19, 1995, as amended at 62 FR 45120, 45125, Aug. 25, 
1997]

[[Page 72]]



Subpart Cc--Emission Guidelines and Compliance Times for Municipal Solid 
                             Waste Landfills

    Source: 61 FR 9919, Mar. 12, 1996, unless otherwise noted.



Sec. 60.30c  Scope.

    This subpart contains emission guidelines and compliance times for 
the control of certain designated pollutants from certain designated 
municipal solid waste landfills in accordance with section 111(d) of the 
Act and subpart B.



Sec. 60.31c  Definitions.

    Terms used but not defined in this subpart have the meaning given 
them in the Act and in subparts A, B, and WWW of this part.
    Municipal solid waste landfill or MSW landfill means an entire 
disposal facility in a contiguous geographical space where household 
waste is placed in or on land. An MSW landfill may also receive other 
types of RCRA Subtitle D wastes such as commercial solid waste, 
nonhazardous sludge, conditionally exempt small quantity generator 
waste, and industrial solid waste. Portions of an MSW landfill may be 
separated by access roads. An MSW landfill may be publicly or privately 
owned. An MSW landfill may be a new MSW landfill, an existing MSW 
landfill or a lateral expansion.



Sec. 60.32c  Designated facilities.

    (a) The designated facility to which the guidelines apply is each 
existing MSW landfill for which construction, reconstruction or 
modification was commenced before May 30, 1991.
    (b) Physical or operational changes made to an existing MSW landfill 
solely to comply with an emission guideline are not considered a 
modification or reconstruction and would not subject an existing MSW 
landfill to the requirements of subpart WWW [see Sec. 60.750 of Subpart 
WWW].
    (c) For purposes of obtaining an operating permit under title V of 
the Act, the owner or operator of a MSW landfill subject to this subpart 
with a design capacity less than 2.5 million megagrams or 2.5 million 
cubic meters is not subject to the requirement to obtain an operating 
permit for the landfill under part 70 or 71 of this chapter, unless the 
landfill is otherwise subject to either part 70 or 71. For purposes of 
submitting a timely application for an operating permit under part 70 or 
71, the owner or operator of a MSW landfill subject to this subpart with 
a design capacity greater than or equal to 2.5 million megagrams and 2.5 
million cubic meters on the effective date of EPA approval of the 
State's program under section 111(d) of the Act, and not otherwise 
subject to either part 70 or 71, becomes subject to the requirements of 
Secs. 70.5(a)(1)(i) or 71.5(a)(1)(i) of this chapter 90 days after the 
effective date of such 111(d) program approval, even if the design 
capacity report is submitted earlier.
    (d) When a MSW landfill subject to this subpart is closed, the owner 
or operator is no longer subject to the requirement to maintain an 
operating permit under part 70 or 71 of this chapter for the landfill if 
the landfill is not otherwise subject to the requirements of either part 
70 or 71 and if either of the following conditions are met.
    (1) The landfill was never subject to the requirement for a control 
system under Sec. 60.33c(c) of this subpart; or
    (2) The owner or operator meets the conditions for control system 
removal specified in Sec. 60.752(b)(2)(v) of subpart WWW.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32750, June 16, 1998]



Sec. 60.33c  Emission guidelines for municipal solid waste landfill emissions.

    (a) For approval, a State plan shall include control of MSW landfill 
emissions at each MSW landfill meeting the following three conditions:
    (1) The landfill has accepted waste at any time since November 8, 
1987, or has additional design capacity available for future waste 
deposition;
    (2) The landfill has a design capacity greater than or equal to 2.5 
million megagrams and 2.5 million cubic meters. The landfill may 
calculate design capacity in either megagrams or cubic meters for 
comparison with the exemption values. Any density conversions

[[Page 73]]

shall be documented and submitted with the design capacity report; and
    (3) The landfill has a nonmethane organic compound emission rate of 
50 megagrams per year or more.
    (b) For approval, a State plan shall include the installation of a 
collection and control system meeting the conditions provided in 
Sec. 60.752(b)(2)(ii) of this part at each MSW landfill meeting the 
conditions in paragraph (a) of this section. The State plan shall 
include a process for State review and approval of the site-specific 
design plans for the gas collection and control system(s).
    (c) For approval, a State plan shall include provisions for the 
control of collected MSW landfill emissions through the use of control 
devices meeting the requirements of paragraph (c)(1), (2), or (3) of 
this section, except as provided in Sec. 60.24.
    (1) An open flare designed and operated in accordance with the 
parameters established in Sec. 60.18; or
    (2) A control system designed and operated to reduce NMOC by 98 
weight percent; or
    (3) An enclosed combustor designed and operated to reduce the outlet 
NMOC concentration to 20 parts per million as hexane by volume, dry 
basis at 3 percent oxygen, or less.
    (d) For approval, a State plan shall require each owner or operator 
of an MSW landfill having a design capacity less than 2.5 million 
megagrams by mass or 2.5 million cubic meters by volume to submit an 
initial design capacity report to the Administrator as provided in 
Sec. 60.757(a)(2) of subpart WWW by the date specified in Sec. 60.35c of 
this subpart. The landfill may calculate design capacity in either 
megagrams or cubic meters for comparison with the exemption values. Any 
density conversions shall be documented and submitted with the report. 
Submittal of the initial design capacity report shall fulfill the 
requirements of this subpart except as provided in paragraph (d)(1) and 
(d)(2) of this section.
    (1) The owner or operator shall submit an amended design capacity 
report as provided in Sec. 60.757(a)(3) of subpart WWW. [Guidance: Note 
that if the design capacity increase is the result of a modification, as 
defined in Sec. 60.751 of subpart WWW, that was commenced on or after 
May 30, 1991, the landfill will become subject to subpart WWW instead of 
this subpart. If the design capacity increase is the result of a change 
in operating practices, density, or some other change that is not a 
modification, the landfill remains subject to this subpart.]
    (2) When an increase in the maximum design capacity of a landfill 
with an initial design capacity less than 2.5 million megagrams or 2.5 
million cubic meters results in a revised maximum design capacity equal 
to or greater than 2.5 million megagrams and 2.5 million cubic meters, 
the owner or operator shall comply with paragraph (e) of this section.
    (e) For approval, a State plan shall require each owner or operator 
of an MSW landfill having a design capacity equal to or greater than 2.5 
million megagrams and 2.5 million cubic meters to either install a 
collection and control system as provided in paragraph (b) of this 
section and Sec. 60.752(b)(2) of subpart WWW or calculate an initial 
NMOC emission rate for the landfill using the procedures specified in 
Sec. 60.34c of this subpart and Sec. 60.754 of subpart WWW. The NMOC 
emission rate shall be recalculated annually, except as provided in 
Sec. 60.757(b)(1)(ii) of subpart WWW.
    (1) If the calculated NMOC emission rate is less than 50 megagrams 
per year, the owner or operator shall:
    (i) Submit an annual emission report, except as provided for in 
Sec. 60.757(b)(1)(ii); and
    (ii) Recalculate the NMOC emission rate annually using the 
procedures specified in Sec. 60.754(a)(1) of subpart WWW until such time 
as the calculated NMOC emission rate is equal to or greater than 50 
megagrams per year, or the landfill is closed.
    (2)(i) If the NMOC emission rate, upon initial calculation or annual 
recalculation required in paragraph (e)(1)(ii) of this section, is equal 
to or greater than 50 megagrams per year, the owner or operator shall 
install a collection and control system as provided in paragraph (b) of 
this section and Sec. 60.752(b)(2) of subpart WWW.
    (ii) If the landfill is permanently closed, a closure notification 
shall be

[[Page 74]]

submitted to the Administrator as provided in Sec. 60.35c of this 
subpart and Sec. 60.757(d) of subpart WWW.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32750, June 16, 1998; 64 
FR 9261, Feb. 24, 1999]



Sec. 60.34c  Test methods and procedures.

    For approval, a State plan shall include provisions for: the 
calculation of the landfill NMOC emission rate listed in Sec. 60.754, as 
applicable, to determine whether the landfill meets the condition in 
Sec. 60.33c(a)(3); the operational standards in Sec. 60.753; the 
compliance provisions in Sec. 60.755; and the monitoring provisions in 
Sec. 60.756.



Sec. 60.35c  Reporting and recordkeeping guidelines.

    For approval, a State plan shall include the recordkeeping and 
reporting provisions listed in Secs. 60.757 and 60.758, as applicable, 
except as provided under Sec. 60.24.
    (a) For existing MSW landfills subject to this subpart the initial 
design capacity report shall be submitted no later than 90 days after 
the effective date of EPA approval of the State's plan under section 
111(d) of the Act.
    (b) For existing MSW landfills covered by this subpart with a design 
capacity equal to or greater than 2.5 million megagrams and 2.5 million 
cubic meters, the initial NMOC emission rate report shall be submitted 
no later than 90 days after the effective date of EPA approval of the 
State's plan under section 111(d) of the Act.

[61 FR 9919, Mar. 12, 1996, as amended at 64 FR 9262, Feb. 24, 1999]



Sec. 60.36c  Compliance times.

    (a) Except as provided for under paragraph (b) of this section, 
planning, awarding of contracts, and installation of MSW landfill air 
emission collection and control equipment capable of meeting the 
emission guidelines established under Sec. 60.33c shall be accomplished 
within 30 months after the date the initial NMOC emission rate report 
shows NMOC emissions equal or exceed 50 megagrams per year.
    (b) For each existing MSW landfill meeting the conditions in 
Sec. 60.33c(a)(1) and Sec. 60.33c(a)(2) whose NMOC emission rate is less 
than 50 megagrams per year on the effective date of the State emission 
standard, installation of collection and control systems capable of 
meeting emission guidelines in Sec. 60.33c shall be accomplished within 
30 months of the date when the condition in Sec. 60.33c(a)(3) is met 
(i.e., the date of the first annual nonmethane organic compounds 
emission rate which equals or exceeds 50 megagrams per year).

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32750, June 16, 1998]



Subpart Cd--Emissions Guidelines and Compliance Times for Sulfuric Acid 
                            Production Units

    Source: 60 FR 65414, Dec. 19, 1995, unless otherwise noted.



Sec. 60.30d  Designated facilities.

    Sulfuric acid production units. The designated facility to which 
Secs. 60.31d and 60.32d apply is each existing ``sulfuric acid 
production unit'' as defined in Sec. 60.81(a) of subpart H of this pabt.



Sec. 60.31d  Emissions guidelines.

    Sulfuric acid production units. The emission guideline for 
designated facilities is 0.25 grams sulfuric acid mist (as measured by 
EPA Reference Method 8 of appendix A of this part) per kilogram (0.5 
pounds per ton) of sulfuric acid produced, the production being 
expressed as 100 percent sulfuric acid.



Sec. 60.32d  Compliance times.

    Sulfuric acid production units. Planning, awarding of contracts, and 
installation of equipment capable of attaining the level of the emission 
guideline established under Sec. 60.31d can be accomplished within 17 
months after the effective date of a State emission standard for 
sulfuric acid mist.



   Subpart Ce--Emission Guidelines and Compliance Times for Hospital/
                  Medical/Infectious Waste Incinerators

    Source: 62 FR 48379, Sept. 15, 1997, unless otherwise noted.

[[Page 75]]



Sec. 60.30e  Scope.

    This subpart contains emission guidelines and compliance times for 
the control of certain designated pollutants from hospital/medical/
infectious waste incinerator(s) (HMIWI) in accordance with sections 111 
and 129 of the Clean Air Act and subpart B of this part. The provisions 
in these emission guidelines supersede the provisions of Sec. 60.24(f) 
of subpart B of this part.



Sec. 60.31e  Definitions.

    Terms used but not defined in this subpart have the meaning given 
them in the Clean Air Act and in subparts A, B, and Ec of this part.
    Standard Metropolitan Statistical Area or SMSA means any areas 
listed in OMB Bulletin No. 93-17 entitled ``Revised Statistical 
Definitions for Metropolitan Areas'' dated June 30, 1993 (incorporated 
by reference, see Sec. 60.17).



Sec. 60.32e  Designated facilities.

    (a) Except as provided in paragraphs (b) through (h) of this 
section, the designated facility to which the guidelines apply is each 
individual HMIWI for which construction was commenced on or before June 
20, 1996.
    (b) A combustor is not subject to this subpart during periods when 
only pathological waste, low-level radioactive waste, and/or 
chemotherapeutic waste (all defined in Sec. 60.51c) is burned, provided 
the owner or operator of the combustor:
    (1) Notifies the Administrator of an exemption claim; and
    (2) Keeps records on a calendar quarter basis of the periods of time 
when only pathological waste, low-level radioactive waste, and/or 
chemotherapeutic waste is burned.
    (c) Any co-fired combustor (defined in Sec. 60.51c) is not subject 
to this subpart if the owner or operator of the co-fired combustor:
    (1) Notifies the Administrator of an exemption claim;
    (2) Provides an estimate of the relative weight of hospital waste, 
medical/infectious waste, and other fuels and/or wastes to be combusted; 
and
    (3) Keeps records on a calendar quarter basis of the weight of 
hospital waste and medical/infectious waste combusted, and the weight of 
all other fuels and wastes combusted at the co-fired combustor.
    (d) Any combustor required to have a permit under Section 3005 of 
the Solid Waste Disposal Act is not subject to this subpart.
    (e) Any combustor which meets the applicability requirements under 
subpart Cb, Ea, or Eb of this part (standards or guidelines for certain 
municipal waste combustors) is not subject to this subpart.
    (f) Any pyrolysis unit (defined in Sec. 60.51c) is not subject to 
this subpart.
    (g) Cement kilns firing hospital waste and/or medical/infectious 
waste are not subject to this subpart.
    (h) Physical or operational changes made to an existing HMIWI unit 
solely for the purpose of complying with emission guidelines under this 
subpart are not considered a modification and do not result in an 
existing HMIWI unit becoming subject to the provisions of subpart Ec 
(see Sec. 60.50c).
    (i) Beginning September 15, 2000, or on the effective date of an EPA 
approved operating permit program under Clean Air Act title V and the 
implementing regulations under 40 CFR part 70 in the State in which the 
unit is located, whichever date is later, designated facilities subject 
to this subpart shall operate pursuant to a permit issued under the EPA-
approved operating permit program.



Sec. 60.33e  Emission guidelines.

    (a) For approval, a State plan shall include the requirements for 
emission limits at least as protective as those requirements listed in 
Table 1 of this subpart, except as provided for in paragraph (b) of this 
section.
    (b) For approval, a State plan shall include the requirements for 
emission limits at least as protective as those requirements listed in 
Table 2 of this subpart for any small HMIWI which is located more than 
50 miles from the boundary of the nearest Standard Metropolitan 
Statistical Area (defined in Sec. 60.31e) and which burns less than 
2,000 pounds per week of hospital waste and medical/infectious waste. 
The 2,000 lb/week limitation does not apply during performance tests.
    (c) For approval, a State plan shall include the requirements for 
stack

[[Page 76]]

opacity at least as protective as Sec. 60.52c(b) of subpart Ec of this 
part.



Sec. 60.34e  Operator training and qualification guidelines.

    For approval, a State plan shall include the requirements for 
operator training and qualification at least as protective as those 
requirements listed in Sec. 60.53c of subpart Ec of this part. The State 
plan shall require compliance with these requirements according to the 
schedule specified in Sec. 60.39e(e).



Sec. 60.35e  Waste management guidelines.

    For approval, a State plan shall include the requirements for a 
waste management plan at least as protective as those requirements 
listed in Sec. 60.55c of subpart Ec of this part.



Sec. 60.36e  Inspection guidelines.

    (a) For approval, a State plan shall require that each small HMIWI 
subject to the emission limits under Sec. 60.33e(b) undergo an initial 
equipment inspection that is at least as protective as the following 
within 1 year following approval of the State plan:
    (1) At a minimum, an inspection shall include the following:
    (i) Inspect all burners, pilot assemblies, and pilot sensing devices 
for proper operation; clean pilot flame sensor, as necessary;
    (ii) Ensure proper adjustment of primary and secondary chamber 
combustion air, and adjust as necessary;
    (iii) Inspect hinges and door latches, and lubricate as necessary;
    (iv) Inspect dampers, fans, and blowers for proper operation;
    (v) Inspect HMIWI door and door gaskets for proper sealing;
    (vi) Inspect motors for proper operation;
    (vii) Inspect primary chamber refractory lining; clean and repair/
replace lining as necessary;
    (viii) Inspect incinerator shell for corrosion and/or hot spots;
    (ix) Inspect secondary/tertiary chamber and stack, clean as 
necessary;
    (x) Inspect mechanical loader, including limit switches, for proper 
operation, if applicable;
    (xi) Visually inspect waste bed (grates), and repair/seal, as 
appropriate;
    (xii) For the burn cycle that follows the inspection, document that 
the incinerator is operating properly and make any necessary 
adjustments;
    (xiii) Inspect air pollution control device(s) for proper operation, 
if applicable;
    (xiv) Inspect waste heat boiler systems to ensure proper operation, 
if applicable;
    (xv) Inspect bypass stack components;
    (xvi) Ensure proper calibration of thermocouples, sorbent feed 
systems and any other monitoring equipment; and
    (xvii) Generally observe that the equipment is maintained in good 
operating condition.
    (2) Within 10 operating days following an equipment inspection all 
necessary repairs shall be completed unless the owner or operator 
obtains written approval from the State agency establishing a date 
whereby all necessary repairs of the designated facility shall be 
completed.
    (b) For approval, a State plan shall require that each small HMIWI 
subject to the emission limits under Sec. 60.33e(b) undergo an equipment 
inspection annually (no more than 12 months following the previous 
annual equipment inspection), as outlined in paragraphs (a)(1) and 
(a)(2) of this section.



Sec. 60.37e  Compliance, performance testing, and monitoring guidelines.

    (a) Except as provided in paragraph (b) of this section, for 
approval, a State plan shall include the requirements for compliance and 
performance testing listed in Sec. 60.56c of subpart Ec of this part, 
excluding the fugitive emissions testing requirements under 
Sec. 60.56c(b)(12) and (c)(3).
    (b) For approval, a State plan shall require any small HMIWI subject 
to the emission limits under Sec. 60.33e(b) to meet the following 
compliance and performance testing requirements:
    (1) Conduct the performance testing requirements in Sec. 60.56c(a), 
(b)(1) through (b)(9), (b)(11) (Hg only), and (c)(1) of subpart Ec of 
this part. The 2,000 lb/week limitation under

[[Page 77]]

Sec. 60.33e(b) does not apply during performance tests.
    (2) Establish maximum charge rate and minimum secondary chamber 
temperature as site-specific operating parameters during the initial 
performance test to determine compliance with applicable emission 
limits.
    (3) Following the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8, whichever date 
comes first, ensure that the designated facility does not operate above 
the maximum charge rate or below the minimum secondary chamber 
temperature measured as 3-hour rolling averages (calculated each hour as 
the average of the previous 3 operating hours) at all times except 
during periods of startup, shutdown and malfunction. Operating parameter 
limits do not apply during performance tests. Operation above the 
maximum charge rate or below the minimum secondary chamber temperature 
shall constitute a violation of the established operating parameter(s).
    (4) Except as provided in paragraph (b)(5) of this section, 
operation of the designated facility above the maximum charge rate and 
below the minimum secondary chamber temperature (each measured on a 3-
hour rolling average) simultaneously shall constitute a violation of the 
PM, CO, and dioxin/furan emission limits.
    (5) The owner or operator of a designated facility may conduct a 
repeat performance test within 30 days of violation of applicable 
operating parameter(s) to demonstrate that the designated facility is 
not in violation of the applicable emission limit(s). Repeat performance 
tests conducted pursuant to this paragraph must be conducted using the 
identical operating parameters that indicated a violation under 
paragraph (b)(4) of this section.
    (c) For approval, a State plan shall include the requirements for 
monitoring listed in Sec. 60.57c of subpart Ec of this part, except as 
provided for under paragraph (d) of this section.
    (d) For approval, a State plan shall include requirements for any 
small HMIWI subject to the emission limits under Sec. 60.33e(b) to meet 
the following monitoring requirements:
    (1) Install, calibrate (to manufacturers' specifications), maintain, 
and operate a device for measuring and recording the temperature of the 
secondary chamber on a continuous basis, the output of which shall be 
recorded, at a minimum, once every minute throughout operation.
    (2) Install, calibrate (to manufacturers' specifications), maintain, 
and operate a device which automatically measures and records the date, 
time, and weight of each charge fed into the HMIWI.
    (3) The owner or operator of a designated facility shall obtain 
monitoring data at all times during HMIWI operation except during 
periods of monitoring equipment malfunction, calibration, or repair. At 
a minimum, valid monitoring data shall be obtained for 75 percent of the 
operating hours per day and for 90 percent of the operating hours per 
calendar quarter that the designated facility is combusting hospital 
waste and/or medical/infectious waste.



Sec. 60.38e  Reporting and recordkeeping guidelines.

    (a) For approval, a State plan shall include the reporting and 
recordkeeping requirements listed in Sec. 60.58c(b), (c), (d), (e), and 
(f) of subpart Ec of this part, excluding Sec. 60.58c(b)(2)(ii) 
(fugitive emissions) and (b)(7) (siting).
    (b) For approval, a State plan shall require the owner or operator 
of each small HMIWI subject to the emission limits under Sec. 60.33e(b) 
to:
    (1) Maintain records of the annual equipment inspections, any 
required maintenance, and any repairs not completed within 10 days of an 
inspection or the timeframe established by the State regulatory agency; 
and
    (2) Submit an annual report containing information recorded under 
paragraph (b)(1) of this section no later than 60 days following the 
year in which data were collected. Subsequent reports shall be sent no 
later than 12 calendar months following the previous report (once the 
unit is subject to permitting requirements under Title V of the Act, the 
owner or operator must submit these reports semiannually).

[[Page 78]]

The report shall be signed by the facilities manager.



Sec. 60.39e  Compliance times.

    (a) Not later than September 15, 1998, each State in which a 
designated facility is operating shall submit to the Administrator a 
plan to implement and enforce the emission guidelines.
    (b) Except as provided in paragraphs (c) and (d) of this section, 
State plans shall provide that designated facilities comply with all 
requirements of the State plan on or before the date 1 year after EPA 
approval of the State plan, regardless of whether a designated facility 
is identified in the State plan inventory required by Sec. 60.25(a) of 
subpart B of this part.
    (c) State plans that specify measurable and enforceable incremental 
steps of progress towards compliance for designated facilities planning 
to install the necessary air pollution control equipment may allow 
compliance on or before the date 3 years after EPA approval of the State 
plan (but not later than the September 16, 2002. Suggested measurable 
and enforceable activities to be included in State plans are:
    (1) Date for submitting a petition for site specific operating 
parameters under Sec. 60.56c(i) of subpart Ec of this part.
    (2) Date for obtaining services of an architectural and engineering 
firm regarding the air pollution control device(s);
    (3) Date for obtaining design drawings of the air pollution control 
device(s);
    (4) Date for ordering the air pollution control device(s);
    (5) Date for obtaining the major components of the air pollution 
control device(s);
    (6) Date for initiation of site preparation for installation of the 
air pollution control device(s);
    (7) Date for initiation of installation of the air pollution control 
device(s);
    (8) Date for initial startup of the air pollution control device(s); 
and
    (9) Date for initial compliance test(s) of the air pollution control 
device(s).
    (d) State plans that include provisions allowing designated 
facilities to petition the State for extensions beyond the compliance 
times required in paragraph (b) of this section shall:
    (1) Require that the designated facility requesting an extension 
submit the following information in time to allow the State adequate 
time to grant or deny the extension within 1 year after EPA approval of 
the State plan:
    (i) Documentation of the analyses undertaken to support the need for 
an extension, including an explanation of why up to 3 years after EPA 
approval of the State plan is sufficient time to comply with the State 
plan while 1 year after EPA approval of the State plan is not 
sufficient. The documentation shall also include an evaluation of the 
option to transport the waste offsite to a commercial medical waste 
treatment and disposal facility on a temporary or permanent basis; and
    (ii) Documentation of measurable and enforceable incremental steps 
of progress to be taken towards compliance with the emission guidelines.
    (2) Include procedures for granting or denying the extension; and
    (3) If an extension is granted, require compliance with the emission 
guidelines on or before the date 3 years after EPA approval of the State 
plan (but not later than September 16, 2002.
    (e) For approval, a State plan shall require compliance with 
Sec. 60.34e--Operator training and qualification guidelines and 
Sec. 60.36e--Inspection guidelines by the date 1 year after EPA approval 
of a State plan.
    (f) The Administrator shall develop, implement, and enforce a plan 
for existing HMIWI located in any State that has not submitted an 
approvable plan within date 2 years after September 15, 1997. Such plans 
shall ensure that each designated facility is in compliance with the 
provisions of this subpart no later than date 5 years after September 
15, 1997.

[[Page 79]]



                                        Table 1 to Subpart Ce--Emission Limits for Small, Medium, and Large HMIWI
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                                       Emission limits
                                                                   -------------------------------------------------------------------------------------
              Pollutant               Units (7 percent oxygen, dry                                       HMIWI size
                                                 basis)            -------------------------------------------------------------------------------------
                                                                             Small                   Medium                         Large
--------------------------------------------------------------------------------------------------------------------------------------------------------
Particulate matter..................  Milligrams per dry standard   115 (0.05).............  69 (0.03).............  34 (0.015).
                                       cubic meter (grains per dry
                                       standard cubic foot).
Carbon monoxide.....................  Parts per million by volume.  40.....................  40....................  40.
Dioxins/furans......................  Nanograms per dry standard    125 (55) or 2.3 (1.0)..  125 (55) or 2.3 (1.0).  125 (55) or 2.3 (1.0).
                                       cubic meter total dioxins/
                                       furans (grains per billion
                                       dry standard cubic feet) or
                                       nanograms per dry standard
                                       cubic meter TEQ (grains per
                                       billion dry standard cubic
                                       feet).
Hydrogen chloride...................  Parts per million by volume   100 or 93%.............  100 or 93%............  100 or 93%.
                                       or percent reduction.
Sulfur dioxide......................  Parts per million by volume.  55.....................  55....................  55.
Nitrogen oxides.....................  Parts per million by volume.  250....................  250...................  250.
Lead................................  Milligrams per dry standard   1.2 (0.52) or 70%......  1.2 (0.52) or 70%.....  1.2 (0.52) or 70%.
                                       cubic meter (grains per
                                       thousand dry standard cubic
                                       feet) or percent reduction.
Cadmium.............................  Milligrams per dry standard   0.16 (0.07) or 65%.....  0.16 (0.07) or 65%....
                                       cubic meter (grains per
                                       thousand dry standard cubic
                                       feet) or percent reduction.
Mercury.............................  Milligrams per dry standard   0.55 (0.24) or 85%.....  0.55 (0.24) or 85%....  0.55 (0.24) or 85%.
                                       cubic meter (grains per
                                       thousand dry standard cubic
                                       feet) or percent reduction.
--------------------------------------------------------------------------------------------------------------------------------------------------------


[[Page 80]]


 Table 2 to Subpart Ce--Emissions Limits for Small HMIWI Which Meet the
                     Criteria Under Sec.  60.33e(b)
------------------------------------------------------------------------
                                   Units (7 percent      HMIWI emission
           Pollutant              oxygen, dry basis)         limits
------------------------------------------------------------------------
Particulate matter............  Milligrams per dry     197 (0.086).
                                 standard cubic meter
                                 (grains per dry
                                 standard cubic foot).
Carbon monoxide...............  Parts per million by   40.
                                 volume.
Dioxins/furans................  nanograms per dry      800 (350) or 15
                                 standard cubic meter   (6.6).
                                 total dioxins/furans
                                 (grains per billion
                                 dry standard cubic
                                 feet) or nanograms
                                 per dry standard
                                 cubic meter TEQ
                                 (grains per billion
                                 dry standard cubic
                                 feet).
Hydrogen chloride.............  Parts per million by   3100.
                                 volume.
Sulfur dioxide................  Parts per million by   55.
                                 volume.
Nitrogen oxides...............  Parts per million by   250.
                                 volume.
Lead..........................  Milligrams per dry     10 (4.4).
                                 standard cubic meter
                                 (grains per thousand
                                 dry standard cubic
                                 feet).
Cadmium.......................  Milligrams per dry     4 (1.7).
                                 standard cubic meter
                                 (grains per thousand
                                 dry standard cubic
                                 feet).
Mercury.......................  Milligrams per dry     7.5 (3.3).
                                 standard cubic meter
                                 (grains per
                                 thousands dry
                                 standard cubic feet).
------------------------------------------------------------------------



    Subpart D--Standards of Performance for Fossil-Fuel-Fired Steam 
  Generators for Which Construction is Commenced After August 17, 1971



Sec. 60.40  Applicability and designation of affected facility.

    (a) The affected facilities to which the provisions of this subpart 
apply are:
    (1) Each fossil-fuel-fired steam generating unit of more than 73 
megawatts heat input rate (250 million Btu per hour).
    (2) Each fossil-fuel and wood-residue-fired steam generating unit 
capable of firing fossil fuel at a heat input rate of more than 73 
megawatts (250 million Btu per hour).
    (b) Any change to an existing fossil-fuel-fired steam generating 
unit to accommodate the use of combustible materials, other than fossil 
fuels as defined in this subpart, shall not bring that unit under the 
applicability of this subpart.
    (c) Except as provided in paragraph (d) of this section, any 
facility under paragraph (a) of this section that commenced construction 
or modification after August 17, 1971, is subject to the requirements of 
this subpart.
    (d) The requirements of Secs. 60.44 (a)(4), (a)(5), (b) and (d), and 
60.45(f)(4)(vi) are applicable to lignite-fired steam generating units 
that commenced construction or modification after December 22, 1976.
    (e) Any facility covered under subpart Da is not covered under this 
subpart.

[42 FR 37936, July 25, 1977, as amended at 43 FR 9278, Mar. 7, 1978; 44 
FR 33612, June 17, 1979]



Sec. 60.41  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act, and in subpart A of this part.
    (a) Fossil-fuel fired steam generating unit means a furnace or 
boiler used in the process of burning fossil fuel for the purpose of 
producing steam by heat transfer.
    (b) Fossil fuel means natural gas, petroleum, coal, and any form of 
solid, liquid, or gaseous fuel derived from such materials for the 
purpose of creating useful heat.
    (c) Coal refuse means waste-products of coal mining, cleaning, and 
coal preparation operations (e.g. culm, gob, etc.) containing coal, 
matrix material, clay, and other organic and inorganic material.
    (d) Fossil fuel and wood residue-fired steam generating unit means a 
furnace or boiler used in the process of burning fossil fuel and wood 
residue for the purpose of producing steam by heat transfer.
    (e) Wood residue means bark, sawdust, slabs, chips, shavings, mill 
trim, and other wood products derived from wood processing and forest 
management operations.

[[Page 81]]

    (f) Coal means all solid fuels classified as anthracite, bituminous, 
subbituminous, or lignite by the American Society and Testing and 
Materials, Designation D388-77 (incorporated by reference--see 
Sec. 60.17).

[39 FR 20791, June 14, 1974, as amended at 40 FR 2803, Jan. 16, 1975; 41 
FR 51398, Nov. 22, 1976; 43 FR 9278, Mar. 7, 1978; 48 FR 3736, Jan. 27, 
1983]



Sec. 60.42  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which:
    (1) Contain particulate matter in excess of 43 nanograms per joule 
heat input (0.10 lb per million Btu) derived from fossil fuel or fossil 
fuel and wood residue.
    (2) Exhibit greater than 20 percent opacity except for one six-
minute period per hour of not more than 27 percent opacity.
    (b)(1) On or after December 28, 1979, no owner or operator shall 
cause to be discharged into the atmosphere from the Southwestern Public 
Service Company's Harrington Station 1, in Amarillo, TX, any gases 
which exhibit greater than 35% opacity, except that a maximum or 42% 
opacity shall be permitted for not more than 6 minutes in any hour.
    (2) Interstate Power Company shall not cause to be discharged into 
the atmosphere from its Lansing Station Unit No. 4 in Lansing, IA, any 
gases which exhibit greater than 32% opacity, except that a maximum of 
39% opacity shall be permitted for not more than six minutes in any 
hour.

[39 FR 20792, June 14, 1974, as amended at 41 FR 51398, Nov. 22, 1976; 
42 FR 61537, Dec. 5, 1977; 44 FR 76787, Dec. 28, 1979; 45 FR 36077, May 
29, 1980; 45 FR 47146, July 14, 1980; 46 FR 57498, Nov. 24, 1981; 61 FR 
49976, Sept. 24, 1996]



Sec. 60.43  Standard for sulfur dioxide.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain sulfur 
dioxide in excess of:
    (1) 340 nanograms per joule heat input (0.80 lb per million Btu) 
derived from liquid fossil fuel or liquid fossil fuel and wood residue.
    (2) 520 nanograms per joule heat input (1.2 lb per million Btu) 
derived from solid fossil fuel or solid fossil fuel and wood residue, 
except as provided in paragraph (e) of this section.
    (b) When different fossil fuels are burned simultaneously in any 
combination, the applicable standard (in ng/J) shall be determined by 
proration using the following formula:
PSSO2=[y(340) +z(520)]/(y+z)
where:
    PSSO2 is the prorated standard for sulfur dioxide when 
burning different fuels simultaneously, in nanograms per joule heat 
input derived from all fossil fuels fired or from all fossil fuels and 
wood residue fired,
    y is the percentage of total heat input derived from liquid fossil 
fuel, and
    z is the percentage of total heat input derived from solid fossil 
fuel.

    (c) Compliance shall be based on the total heat input from all 
fossil fuels burned, including gaseous fuels.
    (d) [Reserved]
    (e) Units 1 and 2 (as defined in appendix G) at the Newton Power 
Station owned or operated by the Central Illinois Public Service Company 
will be in compliance with paragraph (a)(2) of this section if Unit 1 
and Unit 2 individually comply with paragraph (a)(2) of this section or 
if the combined emission rate from Units 1 and 2 does not exceed 470 
nanograms per joule (1.1 lb per million Btu) combined heat input to 
Units 1 and 2.

[39 FR 20792, June 14, 1974, as amended at 41 FR 51398, Nov. 22, 1976; 
52 FR 28954, Aug. 4, 1987]



Sec. 60.44  Standard for nitrogen oxides.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain nitrogen 
oxides, expressed as NO2 in excess of:

[[Page 82]]

    (1) 86 nanograms per joule heat input (0.20 lb per million Btu) 
derived from gaseous fossil fuel.
    (2) 129 nanograms per joule heat input (0.30 lb per million Btu) 
derived from liquid fossil fuel, liquid fossil fuel and wood residue, or 
gaseous fossil fuel and wood residue.
    (3) 300 nanograms per joule heat input (0.70 lb per million Btu) 
derived from solid fossil fuel or solid fossil fuel and wood residue 
(except lignite or a solid fossil fuel containing 25 percent, by weight, 
or more of coal refuse).
    (4) 260 nanograms per joule heat input (0.60 lb per million Btu) 
derived from lignite or lignite and wood residue (except as provided 
under paragraph (a)(5) of this section).
    (5) 340 nanograms per joule heat input (0.80 lb per million Btu) 
derived from lignite which is mined in North Dakota, South Dakota, or 
Montana and which is burned in a cyclone-fired unit.
    (b) Except as provided under paragraphs (c) and (d) of this section, 
when different fossil fuels are burned simultaneously in any 
combination, the applicable standard (in ng/J) is determined by 
proration using the following formula:
[GRAPHIC] [TIFF OMITTED] TC16NO91.000

where:
PSNOx=is the prorated standard for nitrogen oxides when 
          burning different fuels simultaneously, in nanograms per joule 
          heat input derived from all fossil fuels fired or from all 
          fossil fuels and wood residue fired;
w= is the percentage of total heat input derived from lignite;
x= is the percentage of total heat input derived from gaseous fossil 
          fuel;
y= is the percentage of total heat input derived from liquid fossil 
          fuel; and
z= is the percentage of total heat input derived from solid fossil fuel 
          (except lignite).

    (c) When a fossil fuel containing at least 25 percent, by weight, of 
coal refuse is burned in combination with gaseous, liquid, or other 
solid fossil fuel or wood residue, the standard for nitrogen oxides does 
not apply.
    (d) Cyclone-fired units which burn fuels containing at least 25 
percent of lignite that is mined in North Dakota, South Dakota, or 
Montana remain subject to paragraph (a)(5) of this section regardless of 
the types of fuel combusted in combination with that lignite.

[39 FR 20792, June 14, 1974, as amended at 41 FR 51398, Nov. 22, 1976; 
43 FR 9278, Mar. 7, 1978; 51 FR 42797, Nov. 25, 1986]



Sec. 60.45  Emission and fuel monitoring.

    (a) Each owner or operator shall install, calibrate, maintain, and 
operate continuous monitoring systems for measuring the opacity of 
emissions, sulfur dioxide emissions, nitrogen oxides emissions, and 
either oxygen or carbon dioxide except as provided in paragraph (b) of 
this section.
    (b) Certain of the continuous monitoring system requirements under 
paragraph (a) of this section do not apply to owners or operators under 
the following conditions:
    (1) For a fossil fuel-fired steam generator that burns only gaseous 
fossil fuel, continuous monitoring systems for measuring the opacity of 
emissions and sulfur dioxide emissions are not required.
    (2) For a fossil fuel-fired steam generator that does not use a flue 
gas desulfurization device, a continuous monitoring system for measuring 
sulfur dioxide emissions is not required if the owner or operator 
monitors sulfur dioxide emissions by fuel sampling and analysis under 
paragraph (d) of this section.
    (3) Notwithstanding Sec. 60.13(b), installation of a continuous 
monitoring system for nitrogen oxides may be delayed until after the 
initial performance tests under Sec. 60.8 have been conducted. If the 
owner or operator demonstrates during the performance test that 
emissions of nitrogen oxides are less than 70 percent of the applicable 
standards in Sec. 60.44, a continuous monitoring system for measuring 
nitrogen oxides emissions is not required. If the initial performance 
test results show that nitrogen oxide emissions are greater than 70 
percent of the applicable standard, the owner or operator shall install 
a continuous monitoring system for nitrogen oxides within one year after 
the date of the initial performance tests under Sec. 60.8 and comply 
with all other

[[Page 83]]

applicable monitoring requirements under this part.
    (4) If an owner or operator does not install any continuous 
monitoring systems for sulfur oxides and nitrogen oxides, as provided 
under paragraphs (b)(1) and (b)(3) or paragraphs (b)(2) and (b)(3) of 
this section a continuous monitoring system for measuring either oxygen 
or carbon dioxide is not required.
    (c) For performance evaluations under Sec. 60.13(c) and calibration 
checks under Sec. 60.13(d), the following procedures shall be used:
    (1) Methods 6, 7, and 3B, as applicable, shall be used for the 
performance evaluations of sulfur dioxide and nitrogen oxides continuous 
monitoring systems. Acceptable alternative methods for Methods 6, 7, and 
3B are given in Sec. 60.46(d).
    (2) Sulfur dioxide or nitric oxide, as applicable, shall be used for 
preparing calibration gas mixtures under Performance Specification 2 of 
appendix B to this part.
    (3) For affected facilities burning fossil fuel(s), the span value 
for a continuous monitoring system measuring the opacity of emissions 
shall be 80, 90, or 100 percent and for a continuous monitoring system 
measuring sulfur oxides or nitrogen oxides the span value shall be 
determined as follows:

                         [In parts per million]
------------------------------------------------------------------------
                                     Span value for     Span value for
            Fossil fuel              sulfur dioxide    nitrogen oxides
------------------------------------------------------------------------
Gas...............................           (\1\ )                  500
Liquid............................            1,000                  500
Solid.............................            1,500                 1000
Combinations......................    1,000y+1,500z      500(x+y)+1,000z
------------------------------------------------------------------------
\1\ Not applicable.

where:
x=the fraction of total heat input derived from gaseous fossil fuel, and
y=the fraction of total heat input derived from liquid fossil fuel, and
z=the fraction of total heat input derived from solid fossil fuel.

    (4) All span values computed under paragraph (c)(3) of this section 
for burning combinations of fossil fuels shall be rounded to the nearest 
500 ppm.
    (5) For a fossil fuel-fired steam generator that simultaneously 
burns fossil fuel and nonfossil fuel, the span value of all continuous 
monitoring systems shall be subject to the Administrator's approval.
    (d) [Reserved]
    (e) For any continuous monitoring system installed under paragraph 
(a) of this section, the following conversion procedures shall be used 
to convert the continuous monitoring data into units of the applicable 
standards (ng/J, lb/million Btu):
    (1) When a continuous monitoring system for measuring oxygen is 
selected, the measurement of the pollutant concentration and oxygen 
concentration shall each be on a consistent basis (wet or dry). 
Alternative procedures approved by the Administrator shall be used when 
measurements are on a wet basis. When measurements are on a dry basis, 
the following conversion procedure shall be used:
E=CF[20.9/(20.9--percent O2)]
where:

E, C, F, and %O2 are determined under paragraph (f) of this 
          section.

    (2) When a continuous monitoring system for measuring carbon dioxide 
is selected, the measurement of the pollutant concentration and carbon 
dioxide concentration shall each be on a consistent basis (wet or dry) 
and the following conversion procedure shall be used:
E=CFc [100/percent CO2]
where:

E, C, Fc and %CO2 are determined under paragraph 
          (f) of this section.

    (f) The values used in the equations under paragraphs (e) (1) and 
(2) of this section are derived as follows:
    (1) E=pollutant emissions, ng/J (lb/million Btu).
    (2) C=pollutant concentration, ng/dscm (lb/dscf), determined by 
multiplying the average concentration (ppm) for each one-hour period by 
4.15 x 10 4 M ng/dscm per ppm (2.59 x 10- 9 
M lb/dscf per ppm) where M=pollutant molecular weight, g/g-mole (lb/lb-
mole). M=64.07 for sulfur dioxide and 46.01 for nitrogen oxides.
    (3) %O2, %CO2=oxygen or carbon dioxide volume 
(expressed as percent), determined with equipment specified under 
paragraph (a) of this section.
    (4) F, Fc=a factor representing a ratio of the volume of 
dry flue gases generated to the calorific value of the fuel

[[Page 84]]

combusted (F), and a factor representing a ratio of the volume of carbon 
dioxide generated to the calorific value of the fuel combusted 
(Fc), respectively. Values of F and Fc are given 
as follows:
    (i) For anthracite coal as classified according to ASTM D388-77 
(incorporated by reference--see Sec. 60.17), 
F=2,723 x 10-\17\ dscm/J (10,140 dscf/million Btu and 
Fc=0.532 x 10 -\17\ scm CO2/J (1,980 
scf CO2/million Btu).
    (ii) For subbituminous and bituminous coal as classified according 
to ASTM D388-77 (incorporated by reference--see Sec. 60.17), 
F=2.637 x 10 -\7\ dscm/J (9,820 dscf/million Btu) and 
Fc=0.486 x 10-\7\ scm CO2/J (1,810 scf 
CO2/million Btu).
    (iii) For liquid fossil fuels including crude, residual, and 
distillate oils, F=2.476 x 10-7 dscm/J (9,220 dscf/million 
Btu) and Fc=0.384 x 10-7 scm CO2/J 
(1,430 scf CO2/million Btu).
    (iv) For gaseous fossil fuels, F=2.347 x 10- 7 
dscm/J (8,740 dscf/million Btu). For natural gas, propane, and butane 
fuels, Fc=0.279 x 10- 7 scm CO2/J 
(1,040 scf CO2/million Btu) for natural gas, 0.322 x 10- 
7 scm CO2/J (1,200 scf CO2/million Btu) for 
propane, and 0.338 x 10- 7 scm CO2/J (1,260 
scf CO2/million Btu) for butane.
    (v) For bark F=2.589 x 10-7 dscm/J (9,640 dscf/million 
Btu) and Fc=0.500 x 10-7 scm CO2/J 
(1,840 scf CO!2/ million Btu). For wood residue other than 
bark F=2.492 x 10-7 dscm/J (9,280 dscf/million Btu) and 
Fc=0.494 x 10-7 scm CO2/J (1,860 scf CO
!2/ million Btu).
    (vi) For lignite coal as classified according to ASTM D388-77 
(incorporated by reference--see Sec. 60.17), F=2.659 x 10-\7\ 
dscm/J (9,900 dscf/million Btu) and Fc=0.516 x 10 
-\7\ scm CO2/J (1,920 scf CO2/million 
Btu).
    (5) The owner or operator may use the following equation to 
determine an F factor (dscm/J or dscf/million Btu) on a dry basis (if it 
is desired to calculate F on a wet basis, consult the Administrator) or 
Fc factor (scm CO2/J, or scf CO2/
million Btu) on either basis in lieu of the F or Fc factors 
specified in paragraph (f)(4) of this section:
[GRAPHIC] [TIFF OMITTED] TC16NO91.001

    (i) H, C, S, N, and O are content by weight of hydrogen, carbon, 
sulfur, nitrogen, and oxygen (expressed as percent), respectively, as 
determined on the same basis as GCV by ultimate analysis of the fuel 
fired, using ASTM method D3178-74 or D3176 (solid fuels) or computed 
from results using ASTM method D1137-53(75), D1945-64(76), or D1946-77 
(gaseous fuels) as applicable. (These five methods are incorporated by 
reference--see Sec. 60.17.)
    (ii) GVC is the gross calorific value (kJ/kg, Btu/lb) of the fuel 
combusted determined by the ASTM test methods D2015-77 for solid fuels 
and D1826-77 for gaseous fuels as applicable. (These two methods are 
incorporated by reference--see Sec. 60.17.)

[[Page 85]]

    (iii) For affected facilities which fire both fossil fuels and 
nonfossil fuels, the F or Fc value shall be subject to the 
Administrator's approval.
    (6) For affected facilities firing combinations of fossil fuels or 
fossil fuels and wood residue, the F or Fc factors determined 
by paragraphs (f)(4) or (f)(5) of this section shall be prorated in 
accordance with the applicable formula as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.002

where:
Xi=the fraction of total heat input derived from each type of 
          fuel (e.g. natural gas, bituminous coal, wood residue, etc.)
Fi or (Fc)i=the applicable F or Fc 
          factor for each fuel type determined in accordance with 
          paragraphs (f)(4) and (f)(5) of this section.
n=the number of fuels being burned in combination.

    (g) Excess emission and monitoring system performance reports shall 
be submitted to the Administrator semiannually for each six-month period 
in the calendar year. All semiannual reports shall be postmarked by the 
30th day following the end of each six-month period. Each excess 
emission and MSP report shall include the information required in 
Sec. 60.7(c). Periods of excess emissions and monitoring systems (MS) 
downtime that shall be reported are defined as follows:
    (1) Opacity. Excess emissions are defined as any six-minute period 
during which the average opacity of emissions exceeds 20 percent 
opacity, except that one six-minute average per hour of up to 27 percent 
opacity need not be reported.
    (i) For sources subject to the opacity standard of Sec. 60.42(b)(1), 
excess emissions are defined as any six-minute period during which the 
average opacity of emissions exceeds 35 percent opacity, except that one 
six-minute average per hour of up to 42 percent opacity need not be 
reported.
    (ii) For sources subject to the opacity standard of 
Sec. 60.42(b)(2), excess emissions are defined as any six-minute period 
during which the average opacity of emissions exceeds 32 percent 
opacity, except that one six-minute average per hour of up to 39 percent 
opacity need not be reported.
    (2) Sulfur dioxide. Excess emissions for affected facilities are 
defined as:
    (i) Any three-hour period during which the average emissions 
(arithmetic average of three contiguous one-hour periods) of sulfur 
dioxide as measured by a continuous monitoring system exceed the 
applicable standard under Sec. 60.43.
    (3) Nitrogen oxides. Excess emissions for affected facilities using 
a continuous monitoring system for measuring nitrogen oxides are defined 
as any three-hour period during which the average emissions (arithmetic 
average of three contiguous one-hour periods) exceed the applicable 
standards under Sec. 60.44.

[40 FR 46256, Oct. 6, 1975]

    Editorial Note: For Federal Register citations affecting Sec. 60.45, 
see the List of CFR Sections Affected in the Finding Aids section of 
this volume.



Sec. 60.46  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b). 
Acceptable alternative methods and procedures are given in paragraph (d) 
of this section.
    (b) The owner or operator shall determine compliance with the 
particulate matter, SO2, and NOx standards in 
Secs. 60.42, 60.43, and 60.44 as follows:
    (1) The emission rate (E) of particulate matter, SO2, or 
NOx shall be computed for each run using the following 
equation:

E=C Fd (20.9)/(20.9-% 02)

E = emission rate of pollutant, ng/J (1b/million Btu).
C = concentration of pollutant, ng/dscm (1b/dscf).
%O2 = oxygen concentration, percent dry basis.
Fd = factor as determined from Method 19.

    (2) Method 5 shall be used to determine the particular matter 
concentration (C) at affected facilities without wet flue-gas-
desulfurization (FGD) systems and Method 5B shall be used to

[[Page 86]]

determine the particulate matter concentration (C) after FGD systems.
    (i) The sampling time and sample volume for each run shall be at 
least 60 minutes and 0.85 dscm (30 dscf). The probe and filter holder 
heating systems in the sampling train may be set to provide a gas 
temperature no greater than 16014  deg.C (32025 
deg.F).
    (ii) The emission rate correction factor, integrated or grab 
sampling and analysis procedure of Method 3B shall be used to determine 
the O2 concentration (%O2). The O2 
sample shall be obtained simultaneously with, and at the same traverse 
points as, the particulate sample. If the grab sampling procedure is 
used, the O2 concentration for the run shall be the 
arithmetic mean of all the individual O2 sample 
concentrations at each traverse point.
    (iii) If the particulate run has more than 12 traverse points, the 
O2 traverse points may be reduced to 12 provided that Method 
1 is used to locate the 12 O2 traverse points.
    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (4) Method 6 shall be used to determine the SO2 
concentration.
    (i) The sampling site shall be the same as that selected for the 
particulate sample. The sampling location in the duct shall be at the 
centroid of the cross section or at a point no closer to the walls than 
1 m (3.28 ft). The sampling time and sample volume for each sample run 
shall be at least 20 minutes and 0.020 dscm (0.71 dscf). Two samples 
shall be taken during a 1-hour period, with each sample taken within a 
30-minute interval.
    (ii) The emission rate correction factor, integrated sampling and 
analysis procedure of Method 3B shall be used to determine the 
O2 concentration (%O2). The O2 sample 
shall be taken simultaneously with, and at the same point as, the 
SO2 sample. The SO2 emission rate shall be 
computed for each pair of SO2 and O2 samples. The 
SO2 emission rate (E) for each run shall be the arithmetic 
mean of the results of the two pairs of samples.
    (5) Method 7 shall be used to determine the NOx 
concentration.
    (i) The sampling site and location shall be the same as for the 
SO2 sample. Each run shall consist of four grab samples, with 
each sample taken at about 15-minute intervals.
    (ii) For each NOx sample, the emission rate correction 
factor, grab sampling and analysis procedure of Method 3B shall be used 
to determine the O2 concentration (%O2). The 
sample shall be taken simultaneously with, and at the same point as, the 
NOx sample.
    (iii) The NOx emission rate shall be computed for each 
pair of NOx and O2 samples. The NOx 
emission rate (E) for each run shall be the arithmetic mean of the 
results of the four pairs of samples.
    (c) When combinations of fossil fuels or fossil fuel and wood 
residue are fired, the owner or operator (in order to compute the 
prorated standard as shown in Secs. 60.43(b) and 60.44(b)) shall 
determine the percentage (w, x, y, or z) of the total heat input derived 
from each type of fuel as follows:
    (1) The heat input rate of each fuel shall be determined by 
multiplying the gross calorific value of each fuel fired by the rate of 
each fuel burned.
    (2) ASTM Methods D 2015-77 (solid fuels), D 240-76 (liquid fuels), 
or D 1826-77 (gaseous fuels) (incorporated by reference--see Sec. 60.17) 
shall be used to determine the gross calorific values of the fuels. The 
method used to determine the calorific value of wood residue must be 
approved by the Administrator.
    (3) Suitable methods shall be used to determine the rate of each 
fuel burned during each test period, and a material balance over the 
steam generating system shall be used to confirm the rate.
    (d) The owner or operator may use the following as alternatives to 
the reference methods and procedures in this section or in other 
sections as specified:
    (1) The emission rate (E) of particulate matter, SO2 and 
NOx may be determined by using the Fc factor, 
provided that the following procedure is used:
    (i) The emission rate (E) shall be computed using the following 
equation:

E=C Fc (100/%CO2)

where:
E=emission rate of pollutant, ng/J (lb/million Btu).
C=concentration of pollutant, ng/dscm (lb/dscf).

[[Page 87]]

%CO2=carbon dioxide concentration, percent dry basis.
Fc=factor as determined in appropriate sections of Method 19.

    (ii) If and only if the average Fc factor in Method 19 is 
used to calculate E and either E is from 0.97 to 1.00 of the emission 
standard or the relative accuracy of a continuous emission monitoring 
system is from 17 to 20 percent, then three runs of Method 3B shall be 
used to determine the O2 and CO2 concentration 
according to the procedures in paragraph (b) (2)(ii), (4)(ii), or 
(5)(ii) of this section. Then if Fo (average of three runs), 
as calculated from the equation in Method 3B, is more than 3 
percent than the average Fo value, as determined from the 
average values of Fd and Fc in Method 19, i.e., 
Foa=0.209 (Fda/Fca), then the following 
procedure shall be followed:
    (A) When Fo is less than 0.97 Foa, then E 
shall be increased by that proportion under 0.97 Foa, e.g., 
if Fo is 0.95 Foa, E shall be increased by 2 
percent. This recalculated value shall be used to determine compliance 
with the emission standard.
    (B) When Fo is less than 0.97 Foa and when the 
average difference (d) between the continuous monitor minus the 
reference methods is negative, then E shall be increased by that 
proportion under 0.97 Foa, e.g., if Fo is 0.95 
Foa, E shall be increased by 2 percent. This recalculated 
value shall be used to determine compliance with the relative accuracy 
specification.
    (C) When Fo is greater than 1.03 Foa and when 
the average difference d is positive, then E shall be decreased by that 
proportion over 1.03 Foa, e.g., if Fo is 1.05 
Foa, E shall be decreased by 2 percent. This recalculated 
value shall be used to determine compliance with the relative accuracy 
specification.
    (2) For Method 5 or 5B, Method 17 may be used at facilities with or 
without wet FGD systems if the stack gas temperature at the sampling 
location does not exceed an average temperature of 160  deg.C (320 
deg.F). The procedures of sections 2.1 and 2.3 of Method 5B may be used 
with Method 17 only if it is used after wet FGD systems. Method 17 shall 
not be used after wet FGD systems if the effluent gas is saturated or 
laden with water droplets.
    (3) Particulate matter and SO2 may be determined 
simultaneously with the Method 5 train provided that the following 
changes are made:
    (i) The filter and impinger apparatus in sections 2.1.5 and 2.1.6 of 
Method 8 is used in place of the condenser (section 2.1.7) of Method 5.
    (ii) All applicable procedures in Method 8 for the determination of 
SO2 (including moisture) are used:
    (4) For Method 6, Method 6C may be used. Method 6A may also be used 
whenever Methods 6 and 3B data are specified to determine the 
SO2 emission rate, under the conditions in paragraph (d)(1) 
of this section.
    (5) For Method 7, Method 7A, 7C, 7D, or 7E may be used. If Method 
7C, 7D, or 7E is used, the sampling time for each run shall be at least 
1 hour and the integrated sampling approach shall be used to determine 
the O2 concentration (%O2) for the emission rate 
correction factor.
    (6) For Method 3, Method 3A or 3B may be used.
    (7) For Method 3B, Method 3A may be used.

[54 FR 6662, Feb. 14, 1989; 54 FR 21344, May 17, 1989, as amended at 55 
FR 5212, Feb. 14, 1990]



    Subpart Da--Standards of Performance for Electric Utility Steam 
Generating Units for Which Construction is Commenced After September 18, 
                                  1978

    Source: 44 FR 33613, June 11, 1979, unless otherwise noted.



Sec. 60.40a  Applicability and designation of affected facility.

    (a) The affected facility to which this subpart applies is each 
electric utility steam generating unit:
    (1) That is capable of combusting more than 73 megawatts (250 
million Btu/hour) heat input of fossil fuel (either alone or in 
combination with any other fuel); and
    (2) For which construction or modification is commenced after 
September 18, 1978.
    (b) Unless and until subpart GG of this part extends the 
applicability of

[[Page 88]]

subpart GG of this part to electric utility steam generators, this 
subpart applies to electric utility combined cycle gas turbines that are 
capable of combusting more than 73 megawatts (250 million Btu/hour) heat 
input of fossil fuel in the steam generator. Only emissions resulting 
from combustion of fuels in the steam generating unit are subject to 
this subpart. (The gas turbine emissions are subject to subpart GG of 
this part.)
    (c) Any change to an existing fossil-fuel-fired steam generating 
unit to accommodate the use of combustible materials, other than fossil 
fuels, shall not bring that unit under the applicability of this 
subpart.
    (d) Any change to an existing steam generating unit originally 
designed to fire gaseous or liquid fossil fuels, to accommodate the use 
of any other fuel (fossil or nonfossil) shall not bring that unit under 
the applicability of this subpart.

[44 FR 33613, June 11, 1979, as amended at 63 FR 49453, Sept. 16, 1998]



Sec. 60.41a  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    Steam generating unit means any furnace, boiler, or other device 
used for combusting fuel for the purpose of producing steam (including 
fossil-fuel-fired steam generators associated with combined cycle gas 
turbines; nuclear steam generators are not included).
    Electric utility steam generating unit means any steam electric 
generating unit that is constructed for the purpose of supplying more 
than one-third of its potential electric output capacity and more than 
25 MW electrical output to any utility power distribution system for 
sale. Any steam supplied to a steam distribution system for the purpose 
of providing steam to a steam-electric generator that would produce 
electrical energy for sale is also considered in determining the 
electrical energy output capacity of the affected facility.
    Fossil fuel means natural gas, petroleum, coal, and any form of 
solid, liquid, or gaseous fuel derived from such material for the 
purpose of creating useful heat.
    Subbituminous coal means coal that is classified as subbituminous A, 
B, or C according to the American Society of Testing and Materials 
(ASTM) Standard Specification for Classification of Coals by Rank D388-
77 (incorporated by reference--see Sec. 60.17).
    Lignite means coal that is classified as lignite A or B according to 
the American Society of Testing and Materials' (ASTM) Standard 
Specification for Classification of Coals by Rank D388-77 (incorporated 
by reference--see Sec. 60.17).
    Coal refuse means waste products of coal mining, physical coal 
cleaning, and coal preparation operations (e.g. culm, gob, etc.) 
containing coal, matrix material, clay, and other organic and inorganic 
material.
    Potential combustion concentration means the theoretical emissions 
(ng/J, lb/million Btu heat input) that would result from combustion of a 
fuel in an uncleaned state without emission control systems) and:
    (a) For particulate matter is:
    (1) 3,000 ng/J (7.0 lb/million Btu) heat input for solid fuel; and
    (2) 75 ng/J (0.17 lb/million Btu) heat input for liquid fuels.
    (b) For sulfur dioxide is determined under Sec. 60.48a(b).
    (c) For nitrogen oxides is:
    (1) 290 ng/J (0.67 lb/million Btu) heat input for gaseous fuels;
    (2) 310 ng/J (0.72 lb/million Btu) heat input for liquid fuels; and
    (3) 990 ng/J (2.30 lb/million Btu) heat input for solid fuels.
    Combined cycle gas turbine means a stationary turbine combustion 
system where heat from the turbine exhaust gases is recovered by a steam 
generating unit.
    Interconnected means that two or more electric generating units are 
electrically tied together by a network of power transmission lines, and 
other power transmission equipment.
    Electric utility company means the largest interconnected 
organization, business, or governmental entity that generates electric 
power for sale (e.g., a holding company with operating subsidiary 
companies).
    Principal company means the electric utility company or companies 
which own the affected facility.

[[Page 89]]

    Neighboring company means any one of those electric utility 
companies with one or more electric power interconnections to the 
principal company and which have geographically adjoining service areas.
    Net system capacity means the sum of the net electric generating 
capability (not necessarily equal to rated capacity) of all electric 
generating equipment owned by an electric utility company (including 
steam generating units, internal combustion engines, gas turbines, 
nuclear units, hydroelectric units, and all other electric generating 
equipment) plus firm contractual purchases that are interconnected to 
the affected facility that has the malfunctioning flue gas 
desulfurization system. The electric generating capability of equipment 
under multiple ownership is prorated based on ownership unless the 
proportional entitlement to electric output is otherwise established by 
contractual arrangement.
    System load means the entire electric demand of an electric utility 
company's service area interconnected with the affected facility that 
has the malfunctioning flue gas desulfurization system plus firm 
contractual sales to other electric utility companies. Sales to other 
electric utility companies (e.g., emergency power) not on a firm 
contractual basis may also be included in the system load when no 
available system capacity exists in the electric utility company to 
which the power is supplied for sale.
    System emergency reserves means an amount of electric generating 
capacity equivalent to the rated capacity of the single largest electric 
generating unit in the electric utility company (including steam 
generating units, internal combustion engines, gas turbines, nuclear 
units, hydroelectric units, and all other electric generating equipment) 
which is interconnected with the affected facility that has the 
malfunctioning flue gas desulfurization system. The electric generating 
capability of equipment under multiple ownership is prorated based on 
ownership unless the proportional entitlement to electric output is 
otherwise established by contractual arrangement.
    Available system capacity means the capacity determined by 
subtracting the system load and the system emergency reserves from the 
net system capacity.
    Spinning reserve means the sum of the unutilized net generating 
capability of all units of the electric utility company that are 
synchronized to the power distribution system and that are capable of 
immediately accepting additional load. The electric generating 
capability of equipment under multiple ownership is prorated based on 
ownership unless the proportional entitlement to electric output is 
otherwise established by contractual arrangement.
    Available purchase power means the lesser of the following:
    (a) The sum of available system capacity in all neighboring 
companies.
    (b) The sum of the rated capacities of the power interconnection 
devices between the principal company and all neighboring companies, 
minus the sum of the electric power load on these interconnections.
    (c) The rated capacity of the power transmission lines between the 
power interconnection devices and the electric generating units (the 
unit in the principal company that has the malfunctioning flue gas 
desulfurization system and the unit(s) in the neighboring company 
supplying replacement electrical power) less the electric power load on 
these transmission lines.
    Spare flue gas desulfurization system module means a separate system 
of sulfur dioxide emission control equipment capable of treating an 
amount of flue gas equal to the total amount of flue gas generated by an 
affected facility when operated at maximum capacity divided by the total 
number of nonspare flue gas desulfurization modules in the system.
    Emergency condition means that period of time when:
    (a) The electric generation output of an affected facility with a 
malfunctioning flue gas desulfurization system cannot be reduced or 
electrical output must be increased because:
    (1) All available system capacity in the principal company 
interconnected with the affected facility is being operated, and
    (2) All available purchase power interconnected with the affected 
facility is being obtained, or

[[Page 90]]

    (b) The electric generation demand is being shifted as quickly as 
possible from an affected facility with a malfunctioning flue gas 
desulfurization system to one or more electrical generating units held 
in reserve by the principal company or by a neighboring company, or
    (c) An affected facility with a malfunctioning flue gas 
desulfurization system becomes the only available unit to maintain a 
part or all of the principal company's system emergency reserves and the 
unit is operated in spinning reserve at the lowest practical electric 
generation load consistent with not causing significant physical damage 
to the unit. If the unit is operated at a higher load to meet load 
demand, an emergency condition would not exist unless the conditions 
under (a) of this definition apply.
    Electric utility combined cycle gas turbine means any combined cycle 
gas turbine used for electric generation that is constructed for the 
purpose of supplying more than one-third of its potential electric 
output capacity and more than 25 MW electrical output to any utility 
power distribution system for sale. Any steam distribution system that 
is constructed for the purpose of providing steam to a steam electric 
generator that would produce electrical power for sale is also 
considered in determining the electrical energy output capacity of the 
affected facility.
    Potential electrical output capacity is defined as 33 percent of the 
maximum design heat input capacity of the steam generating unit (e.g., a 
steam generating unit with a 100-MW (340 million Btu/hr) fossil-fuel 
heat input capacity would have a 33-MW potential electrical output 
capacity). For electric utility combined cycle gas turbines the 
potential electrical output capacity is determined on the basis of the 
fossil-fuel firing capacity of the steam generator exclusive of the heat 
input and electrical power contribution by the gas turbine.
    Anthracite means coal that is classified as anthracite according to 
the American Society of Testing and Materials' (ASTM) Standard 
Specification for Classification of Coals by Rank D388-77 (incorporated 
by reference--see Sec. 60.17).
    Solid-derived fuel means any solid, liquid, or gaseous fuel derived 
from solid fuel for the purpose of creating useful heat and includes, 
but is not limited to, solvent refined coal, liquified coal, and 
gasified coal.
    24-hour period means the period of time between 12:01 a.m. and 12:00 
midnight.
    Resource recovery unit means a facility that combusts more than 75 
percent non-fossil fuel on a quarterly (calendar) heat input basis.
    Noncontinental area means the State of Hawaii, the Virgin Islands, 
Guam, American Samoa, the Commonwealth of Puerto Rico, or the Northern 
Mariana Islands.
    Boiler operating day means a 24-hour period during which fossil fuel 
is combusted in a steam generating unit for the entire 24 hours.
    Gross output means the gross useful work performed by the steam 
generated. For units generating only electricity, the gross useful work 
performed is the gross electrical output from the turbine/generator set. 
For cogeneration units, the gross useful work performed is the gross 
electrical output plus one half the useful thermal output (i.e., steam 
delivered to an industrial process).

[44 FR 33613, June 11, 1979, as amended at 48 FR 3737, Jan. 27, 1983; 63 
FR 49453, Sept. 16, 1998]



Sec. 60.42a  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted under Sec. 60.8 is completed, no owner or operator subject 
to the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain 
particulate matter in excess of:
    (1) 13 ng/J (0.03 lb/million Btu) heat input derived from the 
combustion of solid, liquid, or gaseous fuel;
    (2) 1 percent of the potential combustion concentration (99 percent 
reduction) when combusting solid fuel; and
    (3) 30 percent of potential combustion concentration (70 percent 
reduction) when combusting liquid fuel.
    (b) On and after the date the particulate matter performance test 
required

[[Page 91]]

to be conducted under Sec. 60.8 is completed, no owner or operator 
subject to the provisions of this subpart shall cause to be discharged 
into the atmosphere from any affected facility any gases which exhibit 
greater than 20 percent opacity (6-minute average), except for one 6-
minute period per hour of not more than 27 percent opacity.



Sec. 60.43a  Standard for sulfur dioxide.

    (a) On and after the date on which the initial performance test 
required to be conducted under Sec. 60.8 is completed, no owner or 
operator subject to the provisions of this subpart shall cause to be 
discharged into the atmosphere from any affected facility which combusts 
solid fuel or solid-derived fuel, except as provided under paragraphs 
(c), (d), (f) or (h) of this section, any gases which contain sulfur 
dioxide in excess of:
    (1) 520 ng/J (1.20 lb/million Btu) heat input and 10 percent of the 
potential combustion concentration (90 percent reduction), or
    (2) 30 percent of the potential combustion concentration (70 percent 
reduction), when emissions are less than 260 ng/J (0.60 lb/million Btu) 
heat input.
    (b) On and after the date on which the initial performance test 
required to be conducted under Sec. 60.8 is completed, no owner or 
operator subject to the provisions of this subpart shall cause to be 
discharged into the atmosphere from any affected facility which combusts 
liquid or gaseous fuels (except for liquid or gaseous fuels derived from 
solid fuels and as provided under paragraphs (e) or (h) of this 
section), any gases which contain sulfur dioxide in excess of:
    (1) 340 ng/J (0.80 lb/million Btu) heat input and 10 percent of the 
potential combustion concentration (90 percent reduction), or
    (2) 100 percent of the potential combustion concentration (zero 
percent reduction) when emissions are less than 86 ng/J (0.20 lb/million 
Btu) heat input.
    (c) On and after the date on which the initial performance test 
required to be conducted under Sec. 60.8 is complete, no owner or 
operator subject to the provisions of this subpart shall cause to be 
discharged into the atmosphere from any affected facility which combusts 
solid solvent refined coal (SRC-I) any gases which contain sulfur 
dioxide in excess of 520 ng/J (1.20 lb/million Btu) heat input and 15 
percent of the potential combustion concentration (85 percent reduction) 
except as provided under paragraph (f) of this section; compliance with 
the emission limitation is determined on a 30-day rolling average basis 
and compliance with the percent reduction requirement is determined on a 
24-hour basis.
    (d) Sulfur dioxide emissions are limited to 520 ng/J (1.20 lb/
million Btu) heat input from any affected facility which:
    (1) Combusts 100 percent anthracite,
    (2) Is classified as a resource recovery facility, or
    (3) Is located in a noncontinental area and combusts solid fuel or 
solid-derived fuel.
    (e) Sulfur dioxide emissions are limited to 340 ng/J (0.80 lb/
million Btu) heat input from any affected facility which is located in a 
noncontinental area and combusts liquid or gaseous fuels (excluding 
solid-derived fuels).
    (f) The emission reduction requirements under this section do not 
apply to any affected facility that is operated under an SO2 
commercial demonstration permit issued by the Administrator in 
accordance with the provisions of Sec. 60.45a.
    (g) Compliance with the emission limitation and percent reduction 
requirements under this section are both determined on a 30-day rolling 
average basis except as provided under paragraph (c) of this section.
    (h) When different fuels are combusted simultaneously, the 
applicable standard is determined by proration using the following 
formula:
    (1) If emissions of sulfur dioxide to the atmosphere are greater 
than 260 ng/J (0.60 lb/million Btu) heat input

Es=(340x+520 y)/100 and
%Ps=10

    (2) If emissions of sulfur dioxide to the atmosphere are equal to or 
less than 260 ng/J (0.60 lb/million Btu) heat input:

Es=(340x+520 y)/100 and
%Ps=(10x+30 y)/100

where:


[[Page 92]]


Es is the prorated sulfur dioxide emission limit (ng/J heat 
          input),
%Ps is the percentage of potential sulfur dioxide emission 
          allowed.

x is the percentage of total heat input derived from the combustion of 
          liquid or gaseous fuels (excluding solid-derived fuels)
y is the percentage of total heat input derived from the combustion of 
          solid fuel (including solid-derived fuels)

[44 FR 33613, June 11, 1979, as amended at 54 FR 6663, Feb. 14, 1989; 54 
FR 21344, May 17, 1989]



Sec. 60.44a  Standard for nitrogen oxides.

    (a) On and after the date on which the initial performance test 
required to be conducted under Sec. 60.8 is completed, no owner or 
operator subject to the provisions of this subpart shall cause to be 
discharged into the atmosphere from any affected facility, except as 
provided under paragraphs (b) and (d) of this section, any gases which 
contain nitrogen oxides (expressed as NO2) in excess of the 
following emission limits, based on a 30-day rolling average:
    (1) NOx emission limits.

------------------------------------------------------------------------
                                                    Emission limit for
                                                        heat input
                                                 -----------------------
                    Fuel type                                    (lb/
                                                     ng/J       million
                                                                 Btu)
------------------------------------------------------------------------
Gaseous fuels:
  Coal-derived fuels............................         210        0.50
  All other fuels...............................          86        0.20
Liquid fuels:
  Coal-derived fuels............................         210        0.50
  Shale oil.....................................         210        0.50
  All other fuels...............................         130        0.30
Solid fuels:
  Coal-derived fuels............................         210        0.50
  Any fuel containing more than 25%, by weight,       (\1\ )      (\1\ )
   coal refuse..................................
  Any fuel containing more than 25%, by weight,          340        0.80
   lignite if the lignite is mined in North
   Dakota, South Dakota, or Montana, and is
   combusted in a slag tap furnace\2\...........
  Any fuel containing more than 25%, by weight,
   lignite not subject to the 340 ng/J heat
   input emission limit\2\......................
  Subbituminous coal............................         210        0.50
  Bituminous coal...............................         260        0.60
  Anthracite coal...............................         260        0.60
  All other fuels...............................         260        0.60
------------------------------------------------------------------------
\1\ Exempt from NOx standards and NOx monitoring     requirements.
\2\ Any fuel containing less than 25%, by weight, lignite is not
  prorated but its percentage is added to the percentage of the
  predominant fuel.

    (2) NOx reduction requirement.

------------------------------------------------------------------------
                                                              Percent
                                                           reduction of
                        Fuel type                            potential
                                                            combustion
                                                           concentration
------------------------------------------------------------------------
Gaseous fuels...........................................        25
Liquid fuels............................................        30
Solid fuels.............................................        65
------------------------------------------------------------------------

    (b) The emission limitations under paragraph (a) of this section do 
not apply to any affected facility which is combusting coal-derived 
liquid fuel and is operating under a commercial demonstration permit 
issued by the Administrator in accordance with the provisions of 
Sec. 60.45a.
    (c) Except as provided under paragraph (d) of this section, when two 
or more fuels are combusted simultaneously, the applicable standard is 
determined by proration using the following formula:

En=[86 w+130 x +210 y+260 z+340 v]/100

where:

En  is the applicable standard for nitrogen oxides when 
          multiple fuels are combusted simultaneously (ng/J heat input);
w is the percentage of total heat input derived from the combustion of 
          fuels subject to the 86 ng/J heat input standard;
x is the percentage of total heat input derived from the combustion of 
          fuels subject to the 130 ng/J heat input standard;
y is the percentage of total heat input derived from the combustion of 
          fuels subject to the 210 ng/J heat input standard;
z is the percentage of total heat input derived from the combustion of 
          fuels subject to the 260 ng/J heat input standard; and
v is the percentage of total heat input delivered from the combustion of 
          fuels subject to the 340 ng/J heat input standard.
    (d)(1) On and after the date on which the initial performance test 
required to be conducted under Sec. 60.8 is completed, no new source 
owner or operator subject to the provisions of this subpart shall cause 
to be discharged into the atmosphere from any affected facility for 
which construction commenced after July 9, 1997 any gases which contain 
nitrogen oxides (expressed as NO2) in excess of 200 nanograms 
per joule 1.6 pounds per megawatt-hour) gross energy output, based on a 
30-day rolling average.
    (2) On and after the date on which the initial performance test 
required to be conducted under Sec. 60.8 is completed, no existing 
source owner or operator

[[Page 93]]

subject to the provisions of this subpart shall cause to be discharged 
into the atmosphere from any affected facility for which modification or 
reconstruction commenced after July 9, 1997 any gases which contain 
nitrogen oxides (expressed as NO2) in excess of 65 ng/
JI (0.15 pounds per million Btu) heat input, based on a 30-
day rolling average.

[44 FR 33613, June 11, 1979, as amended at 54 FR 6664, Feb. 14, 1989; 63 
FR 49453, Sept. 16, 1998]



Sec. 60.45a  Commercial demonstration permit.

    (a) An owner or operator of an affected facility proposing to 
demonstrate an emerging technology may apply to the Administrator for a 
commercial demonstration permit. The Administrator will issue a 
commercial demonstration permit in accordance with paragraph (e) of this 
section. Commercial demonstration permits may be issued only by the 
Administrator, and this authority will not be delegated.
    (b) An owner or operator of an affected facility that combusts solid 
solvent refined coal (SRC-I) and who is issued a commercial 
demonstration permit by the Administrator is not subject to the SO2 
emission reduction requirements under Sec. 60.43a(c) but must, as a 
minimum, reduce SO2 emissions to 20 percent of the potential 
combustion concentration (80 percent reduction) for each 24-hour period 
of steam generator operation and to less than 520 ng/J (1.20 lb/million 
Btu) heat input on a 30-day rolling average basis.
    (c) An owner or operator of a fluidized bed combustion electric 
utility steam generator (atmospheric or pressurized) who is issued a 
commercial demonstration permit by the Administrator is not subject to 
the SO2 emission reduction requirements under Sec. 60.43a(a) 
but must, as a minimum, reduce SO2 emissions to 15 percent of 
the potential combustion concentration (85 percent reduction) on a 30-
day rolling average basis and to less than 520 ng/J (1.20 lb/million 
Btu) heat input on a 30-day rolling average basis.
    (d) The owner or operator of an affected facility that combusts 
coal-derived liquid fuel and who is issued a commercial demonstration 
permit by the Administrator is not subject to the applicable NOx 
emission limitation and percent reduction under Sec. 60.44a(a) but must, 
as a minimum, reduce emissions to less than 300 ng/J (0.70 lb/million 
Btu) heat input on a 30-day rolling average basis.
    (e) Commercial demonstration permits may not exceed the following 
equivalent MW electrical generation capacity for any one technology 
category, and the total equivalent MW electrical generation capacity for 
all commercial demonstration plants may not exceed 15,000 MW.

------------------------------------------------------------------------
                                                            Equivalent
                                                            electrical
                  Technology                   Pollutant   capacity (MW
                                                            electrical
                                                              output)
------------------------------------------------------------------------
Solid solvent refined coal (SRC I)...........        SO2    6,000-10,000
Fluidized bed combustion (atmospheric).......        SO2       400-3,000
Fluidized bed combustion (pressurized).......        SO2       400-1,200
Coal liquification...........................        NOx      750-10,000
                                                         ---------------
    Total allowable for all technologies.....  .........          15,000
------------------------------------------------------------------------



Sec. 60.46a  Compliance provisions.

    (a) Compliance with the particulate matter emission limitation under 
Sec. 60.42a(a)(1) constitutes compliance with the percent reduction 
requirements for particulate matter under Sec. 60.42a(a)(2) and (3).
    (b) Compliance with the nitrogen oxides emission limitation under 
Sec. 60.44a(a) constitutes compliance with the percent reduction 
requirements under Sec. 60.44a(a)(2).
    (c) The particulate matter emission standards under Sec. 60.42a and 
the nitrogen oxides emission standards under Sec. 60.44a apply at all 
times except during periods of startup, shutdown, or malfunction. The 
sulfur dioxide emission standards under Sec. 60.43a apply at all times 
except during periods of startup, shutdown, or when both emergency 
conditions exist and the procedures under paragraph (d) of this section 
are implemented.
    (d) During emergency conditions in the principal company, an 
affected facility with a malfunctioning flue gas

[[Page 94]]

desulfurization system may be operated if sulfur dioxide emissions are 
minimized by:
    (1) Operating all operable flue gas desulfurization system modules, 
and bringing back into operation any malfunctioned module as soon as 
repairs are completed,
    (2) Bypassing flue gases around only those flue gas desulfurization 
system modules that have been taken out of operation because they were 
incapable of any sulfur dioxide emission reduction or which would have 
suffered significant physical damage if they had remained in operation, 
and
    (3) Designing, constructing, and operating a spare flue gas 
desulfurization system module for an affected facility larger than 365 
MW (1,250 million Btu/hr) heat input (approximately 125 MW electrical 
output capacity). The Administrator may at his discretion require the 
owner or operator within 60 days of notification to demonstrate spare 
module capability. To demonstrate this capability, the owner or operator 
must demonstrate compliance with the appropriate requirements under 
paragraph (a), (b), (d), (e), and (h) under Sec. 60.43a for any period 
of operation lasting from 24 hours to 30 days when:
    (i) Any one flue gas desulfurization module is not operated,
    (ii) The affected facility is operating at the maximum heat input 
rate,
    (iii) The fuel fired during the 24-hour to 30-day period is 
representative of the type and average sulfur content of fuel used over 
a typical 30-day period, and
    (iv) The owner or operator has given the Administrator at least 30 
days notice of the date and period of time over which the demonstration 
will be performed.
    (e) After the initial performance test required under Sec. 60.8, 
compliance with the sulfur dioxide emission limitations and percentage 
reduction requirements under Sec. 60.43a and the nitrogen oxides 
emission limitations under Sec. 60.44a is based on the average emission 
rate for 30 successive boiler operating days. A separate performance 
test is completed at the end of each boiler operating day after the 
initial performance test, and a new 30 day average emission rate for 
both sulfur dioxide and nitrogen oxides and a new percent reduction for 
sulfur dioxide are calculated to show compliance with the standards.
    (f) For the initial performance test required under Sec. 60.8, 
compliance with the sulfur dioxide emission limitations and percent 
reduction requirements under Sec. 60.43a and the nitrogen oxides 
emission limitation under Sec. 60.44a is based on the average emission 
rates for sulfur dioxide, nitrogen oxides, and percent reduction for 
sulfur dioxide for the first 30 successive boiler operating days. The 
initial performance test is the only test in which at least 30 days 
prior notice is required unless otherwise specified by the 
Administrator. The initial performance test is to be scheduled so that 
the first boiler operating day of the 30 successive boiler operating 
days is completed within 60 days after achieving the maximum production 
rate at which the affected facility will be operated, but not later than 
180 days after initial startup of the facility.
    (g) Compliance is determined by calculating the arithmetic average 
of all hourly emission rates for SO2 and NOx for 
the 30 successive boiler operating days, except for data obtained during 
startup, shutdown, malfunction (NOx only), or emergency 
conditions (SO2 only). Compliance with the percentage 
reduction requirement for SO2 is determined based on the 
average inlet and average outlet SO2 emission rates for the 
30 successive boiler operating days.
    (h) If an owner or operator has not obtained the minimum quantity of 
emission data as required under Sec. 60.47a of this subpart, compliance 
of the affected facility with the emission requirements under 
Secs. 60.43a and 60.44a of this subpart for the day on which the 30-day 
period ends may be determined by the Administrator by following the 
applicable procedures in section 7 of Method 19.
    (i) Compliance provisions for sources subject to Sec. 60.44a(d). (1) 
The owner or operator of an affected facility subject to 
Sec. 60.44a(d)(1) (new source constructed after July 7, 1997) shall 
calculate NOX emissions by multiplying the average hourly 
NOX output concentration measured according to the provisions 
of Sec. 60.47a(c) by the average hourly flow

[[Page 95]]

rate measured according to the provisions of Sec. 60.47a(1) and divided 
by the average hourly gross heat rate measured according to the 
provisions of Sec. 60.47a(k).
    (2) The owner or operator of an affected facility subject to 
Sec. 60.44a(d)(2) (modified or reconstructed source after July 7, 1997) 
shall demonstrate compliance according to the provisions of paragraph 
(g) of this section.

[44 FR 33613, June 11, 1979, as amended at 54 FR 6664, Feb. 14, 1989; 63 
FR 49454, Sept. 16, 1998]



Sec. 60.47a  Emission monitoring.

    (a) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a continuous monitoring system, and 
record the output of the system, for measuring the opacity of emissions 
discharged to the atmosphere, except where gaseous fuel is the only fuel 
combusted. If opacity interference due to water droplets exists in the 
stack (for example, from the use of an FGD system), the opacity is 
monitored upstream of the interference (at the inlet to the FGD system). 
If opacity interference is experienced at all locations (both at the 
inlet and outlet of the sulfur dioxide control system), alternate 
parameters indicative of the particulate matter control system's 
performance are monitored (subject to the approval of the 
Administrator).
    (b) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a continuous monitoring system, and 
record the output of the system, for measuring sulfur dioxide emissions, 
except where natural gas is the only fuel combusted, as follows:
    (1) Sulfur dioxide emissions are monitored at both the inlet and 
outlet of the sulfur dioxide control device.
    (2) For a facility which qualifies under the provisions of 
Sec. 60.43a(d), sulfur dioxide emissions are only monitored as 
discharged to the atmosphere.
    (3) An ``as fired'' fuel monitoring system (upstream of coal 
pulverizers) meeting the requirements of Method 19 (appendix A) may be 
used to determine potential sulfur dioxide emissions in place of a 
continuous sulfur dioxide emission monitor at the inlet to the sulfur 
dioxide control device as required under paragraph (b)(1) of this 
section.
    (c)(1) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a continuous monitoring system, and 
record the output of the system, for measuring nitrogen oxides emissions 
discharged to the atmosphere; or
    (2) If the owner or operator has installed a nitrogen oxides 
emission rate continuous emission monitoring system (CEMS) to meet the 
requirements of part 75 of this chapter and is continuing to meet the 
ongoing requirements of part 75 of this chapter, that CEMS may be used 
to meet the requirements of this section, except that the owner or 
operator shall also meet the requirements of Sec. 60.49a. Data reported 
to meet the requirements of Sec. 60.49a shall not include data 
substituted using the missing data procedures in subpart D of part 75 of 
this chapter, nor shall the data have been bias adjusted according to 
the procedures of part 75 of this chapter.
    (d) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a continuous monitoring system, and 
record the output of the system, for measuring the oxygen or carbon 
dioxide content of the flue gases at each location where sulfur dioxide 
or nitrogen oxides emissions are monitored.
    (e) The continuous monitoring systems under paragraphs (b), (c), and 
(d) of this section are operated and data recorded during all periods of 
operation of the affected facility including periods of startup, 
shutdown, malfunction or emergency conditions, except for continuous 
monitoring system breakdowns, repairs, calibration checks, and zero and 
span adjustments.
    (f) The owner or operator shall obtain emission data for at least 18 
hours in at least 22 out of 30 successive boiler operating days. If this 
minimum data requirement cannot be met with a continuous monitoring 
system, the owner or operator shall supplement emission data with other 
monitoring systems approved by the Administrator or the reference 
methods and procedures as described in paragraph (h) of this section.

[[Page 96]]

    (g) The 1-hour averages required under paragraph Sec. 60.13(h) are 
expressed in ng/J (lbs/million Btu) heat input and used to calculate the 
average emission rates under Sec. 60.46a. The 1-hour averages are 
calculated using the data points required under Sec. 60.13(b). At least 
two data points must be used to calculate the 1-hour averages.
    (h) When it becomes necessary to supplement continuous monitoring 
system data to meet the minimum data requirements in paragraph (f) of 
this section, the owner or operator shall use the reference methods and 
procedures as specified in this paragraph. Acceptable alternative 
methods and procedures are given in paragraph (j) of this section.
    (1) Method 6 shall be used to determine the SO2 
concentration at the same location as the SO2 monitor. 
Samples shall be taken at 60-minute intervals. The sampling time and 
sample volume for each sample shall be at least 20 minutes and 0.020 
dscm (0.71 dscf). Each sample represents a 1-hour average.
    (2) Method 7 shall be used to determine the NOx 
concentration at the same location as the NOx monitor. 
Samples shall be taken at 30-minute intervals. The arithmetic average of 
two consecutive samples represents a 1-hour average.
    (3) The emission rate correction factor, integrated bag sampling and 
analysis procedure of Method 3B shall be used to determine the 
O2 or CO2 concentration at the same location as 
the O2 or CO2 monitor. Samples shall be taken for 
at least 309 minutes in each hour. Each sample represents a 1-hour 
average.
    (4) The procedures in Method 19 shall be used to compute each 1-hour 
average concentration in ng/J (1b/million Btu) heat input.
    (i) The owner or operator shall use methods and procedures in this 
paragraph to conduct monitoring system performance evaluations under 
Sec. 60.13(c) and calibration checks under Sec. 60.13(d). Acceptable 
alternative methods and procedures are given in paragraph (j) of this 
section.
    (1) Methods 6, 7, and 3B, as applicable, shall be used to determine 
O2, SO2, and NOx concentrations.
    (2) SO2 or NOx (NO), as applicable, shall be 
used for preparing the calibration gas mixtures (in N2, as 
applicable) under Performance Specification 2 of appendix B of this 
part.
    (3) For affected facilities burning only fossil fuel, the span value 
for a continuous monitoring system for measuring opacity is between 60 
and 80 percent and for a continuous monitoring system measuring nitrogen 
oxides is determined as follows:

------------------------------------------------------------------------
                                                       Span value for
                    Fossil fuel                        nitrogen oxides
                                                            (ppm)
------------------------------------------------------------------------
Gas...............................................                   500
Liquid............................................                   500
Solid.............................................                 1,000
Combination.......................................      500 (x+y)+1,000z
------------------------------------------------------------------------

where:
x is the fraction of total heat input derived from gaseous fossil fuel,
y is the fraction of total heat input derived from liquid fossil fuel, 
          and
z is the fraction of total heat input derived from solid fossil fuel.

    (4) All span values computed under paragraph (b)(3) of this section 
for burning combinations of fossil fuels are rounded to the nearest 500 
ppm.
    (5) For affected facilities burning fossil fuel, alone or in 
combination with non-fossil fuel, the span value of the sulfur dioxide 
continuous monitoring system at the inlet to the sulfur dioxide control 
device is 125 percent of the maximum estimated hourly potential 
emissions of the fuel fired, and the outlet of the sulfur dioxide 
control device is 50 percent of maximum estimated hourly potential 
emissions of the fuel fired.
    (j) The owner or operator may use the following as alternatives to 
the reference methods and procedures specified in this section:
    (1) For Method 6, Method 6A or 6B (whenever Methods 6 and 3 or 3B 
data are used) or 6C may be used. Each Method 6B sample obtained over 24 
hours represents 24 1-hour averages. If Method 6A or 6B is used under 
paragraph (i) of this section, the conditions under Sec. 60.46(d)(1) 
apply; these conditions do not apply under paragraph (h) of this 
section.
    (2) For Method 7, Method 7A, 7C, 7D, or 7E may be used. If Method 
7C, 7D, or 7E is used, the sampling time for each run shall be 1 hour.

[[Page 97]]

    (3) For Method 3, Method 3A or 3B may be used if the sampling time 
is 1 hour.
    (4) For Method 3B, Method 3A may be used.
    (k) The procedures specified in paragraphs (k)(1) through (k)(3) of 
this section shall be used to determine gross heat rate for sources 
demonstrating compliance with the output-based standard under 
Sec. 60.44a(d)(1).
    (1) The owner or operator of an affected facility with electricity 
generation shall install, calibrate, maintain, and operate a wattmeter; 
measure gross electrical output in megawatt-hour on a continuous basis; 
and record the output of the monitor.
    (2) The owner or operator of an affected facility with process steam 
generation shall install, calibrate, maintain, and operate meters for 
steam flow, temperature, and pressure; measure gross process steam 
output in joules per hour (or Btu per hour) on a continuous basis; and 
record the output of the monitor.
    (3) For affected facilities generating process steam in combination 
with electrical generation, the gross energy output is determined from 
the gross electrical output measured in accordance with paragraph (k)(1) 
of this section plus 50 percent of the gross thermal output of the 
process steam measured in accordance with paragraph (k)(2) of this 
section.
    (l) The owner or operator of an affected facility demonstrating 
compliance with the output-based standard under Sec. 60.44a(d)(1) shall, 
install, certify, operate, and maintain a continuous flow monitoring 
system, and record the output of the system, for measuring the flow of 
exhaust gases discharged to the atmosphere.

[44 FR 33613, June 11, 1979, as amended at 54 FR 6664, Feb. 14, 1989; 55 
FR 5212, Feb. 14, 1990; 55 FR 18876, May 7, 1990; 63 FR 49454, Sept. 16, 
1998]



Sec. 60.48a  Compliance determination procedures and methods.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the 
methods in appendix A of this part or the methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b). Section 
60.8(f) does not apply to this section for SO2 and 
NOx. Acceptable alternative methods are given in paragraph 
(e) of this section.
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.42a as follows:
    (1) The dry basis F factor (O2) procedures in Method 19 
shall be used to compute the emission rate of particulate matter.
    (2) For the particular matter concentration, Method 5 shall be used 
at affected facilities without wet FGD systems and Method 5B shall be 
used after wet FGD systems.
    (i) The sampling time and sample volume for each run shall be at 
least 120 minutes and 1.70 dscm (60 dscf). The probe and filter holder 
heating system in the sampling train may be set to provide an average 
gas temperature of no greater than 16014  deg. C 
(32025 deg. F).
    (ii) For each particulate run, the emission rate correction factor, 
integrated or grab sampling and analysis procedures of Method 3B shall 
be used to determine the O2 concentration. The O2 
sample shall be obtained simultaneously with, and at the same traverse 
points as, the particulate run. If the particulate run has more than 12 
traverse points, the O2 traverse points may be reduced to 12 
provided that Method 1 is used to locate the 12 O2 traverse 
points. If the grab sampling procedure is used, the O2 
concentration for the run shall be the arithmetic mean of all the 
individual O2 concentrations at each traverse point.
    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (c) The owner or operator shall determine compliance with the 
SO2 standards in Sec. 60.43a as follows:
    (1) The percent of potential SO2 emissions 
(%Ps) to the atmosphere shall be computed using the following 
equation:

%Ps=[(100--%Rf) (100--%Rg)]/100

where:
%Ps=percent of potential SO2 emissions, percent.
%Rf=percent reduction from fuel pretreatment, percent.
%Rg=percent reduction by SO2 control system, 
          percent.


[[Page 98]]


    (2) The procedures in Method 19 may be used to determine percent 
reduction (%Rf) of sulfur by such processes as fuel 
pretreatment (physical coal cleaning, hydrodesulfurization of fuel oil, 
etc.), coal pulverizers, and bottom and flyash interactions. This 
determination is optional.
    (3) The procedures in Method 19 shall be used to determine the 
percent SO2 reduction (%Rg of any SO2 
control system. Alternatively, a combination of an ``as fired'' fuel 
monitor and emission rates measured after the control system, following 
the procedures in Method 19, may be used if the percent reduction is 
calculated using the average emission rate from the SO2 
control device and the average SO2 input rate from the ``as 
fired'' fuel analysis for 30 successive boiler operating days.
    (4) The appropriate procedures in Method 19 shall be used to 
determine the emission rate.
    (5) The continuous monitoring system in Sec. 60.47a (b) and (d) 
shall be used to determine the concentrations of SO2 and 
CO2 or O2.
    (d) The owner or operator shall determine compliance with the 
NOx standard in Sec. 60.44a as follows:
    (1) The appropriate procedures in Method 19 shall be used to 
determine the emission rate of NOx.
    (2) The continous monitoring system in Sec. 60.47a (c) and (d) shall 
be used to determine the concentrations of NOx and 
CO2 or O2.
    (e) The owner or operator may use the following as alternatives to 
the reference methods and procedures specified in this section:
    (1) For Method 5 or 5B, Method 17 may be used at facilities with or 
without wet FGD systems if the stack temperature at the sampling 
location does not exceed an average temperature of 160  deg.C (320 
deg.F). The procedures of Secs. 2.1 and 2.3 of Method 5B may be used in 
Method 17 only if it is used after wet FGD systems. Method 17 shall not 
be used after wet FGD systems if the effluent is saturated or laden with 
water droplets.
    (2) The Fc factor (CO2) procedures in Method 
19 may be used to compute the emission rate of particulate matter under 
the stipulations of Sec. 60.46(d)(1). The CO2 shall be 
determined in the same manner as the O2 concentration.
    (f) Electric utility combined cycle gas turbines are performance 
tested for particulate matter, sulfur dioxide, and nitrogen oxides using 
the procedures of Method 19 (appendix A). The sulfur dioxide and 
nitrogen oxides emission rates from the gas turbine used in Method 19 
(appendix A) calculations are determined when the gas turbine is 
performance tested under subpart GG. The potential uncontrolled 
particulate matter emission rate from a gas turbine is defined as 17 ng/
J (0.04 lb/million Btu) heat input.

[44 FR 33613, June 11, 1979, as amended at 54 FR 6664, Feb. 14, 1989; 55 
FR 5212, Feb. 14, 1990]



Sec. 60.49a  Reporting requirements.

    (a) For sulfur dioxide, nitrogen oxides, and particulate matter 
emissions, the performance test data from the initial performance test 
and from the performance evaluation of the continuous monitors 
(including the transmissometer) are submitted to the Administrator.
    (b) For sulfur dioxide and nitrogen oxides the following information 
is reported to the Administrator for each 24-hour period.
    (1) Calendar date.
    (2) The average sulfur dioxide and nitrogen oxide emission rates 
(ng/J or lb/million Btu) for each 30 successive boiler operating days, 
ending with the last 30-day period in the quarter; reasons for non-
compliance with the emission standards; and, description of corrective 
actions taken.
    (3) Percent reduction of the potential combustion concentration of 
sulfur dioxide for each 30 successive boiler operating days, ending with 
the last 30-day period in the quarter; reasons for non-compliance with 
the standard; and, description of corrective actions taken.
    (4) Identification of the boiler operating days for which pollutant 
or dilutent data have not been obtained by an approved method for at 
least 18 hours of operation of the facility; justification for not 
obtaining sufficient data; and description of corrective actions taken.
    (5) Identification of the times when emissions data have been 
excluded

[[Page 99]]

from the calculation of average emission rates because of startup, 
shutdown, malfunction (NOx only), emergency conditions 
(SO2 only), or other reasons, and justification for excluding 
data for reasons other than startup, shutdown, malfunction, or emergency 
conditions.
    (6) Identification of ``F'' factor used for calculations, method of 
determination, and type of fuel combusted.
    (7) Identification of times when hourly averages have been obtained 
based on manual sampling methods.
    (8) Identification of the times when the pollutant concentration 
exceeded full span of the continuous monitoring system.
    (9) Description of any modifications to the continuous monitoring 
system which could affect the ability of the continuous monitoring 
system to comply with Performance Specifications 2 or 3.
    (c) If the minimum quantity of emission data as required by 
Sec. 60.47a is not obtained for any 30 successive boiler operating days, 
the following information obtained under the requirements of 
Sec. 60.46a(h) is reported to the Administrator for that 30-day period:
    (1) The number of hourly averages available for outlet emission 
rates (no) and inlet emission rates (ni) as 
applicable.
    (2) The standard deviation of hourly averages for outlet emission 
rates (so) and inlet emission rates (si) as 
applicable.
    (3) The lower confidence limit for the mean outlet emission rate 
(Eo*) and the upper confidence limit for the mean inlet 
emission rate (Ei*) as applicable.
    (4) The applicable potential combustion concentration.
    (5) The ratio of the upper confidence limit for the mean outlet 
emission rate (Eo*) and the allowable emission rate 
(Estd) as applicable.
    (d) If any standards under Sec. 60.43a are exceeded during emergency 
conditions because of control system malfunction, the owner or operator 
of the affected facility shall submit a signed statement:
    (1) Indicating if emergency conditions existed and requirements 
under Sec. 60.46a(d) were met during each period, and
    (2) Listing the following information:
    (i) Time periods the emergency condition existed;
    (ii) Electrical output and demand on the owner or operator's 
electric utility system and the affected facility;
    (iii) Amount of power purchased from interconnected neighboring 
utility companies during the emergency period;
    (iv) Percent reduction in emissions achieved;
    (v) Atmospheric emission rate (ng/J) of the pollutant discharged; 
and
    (vi) Actions taken to correct control system malfunction.
    (e) If fuel pretreatment credit toward the sulfur dioxide emission 
standard under Sec. 60.43a is claimed, the owner or operator of the 
affected facility shall submit a signed statement:
    (1) Indicating what percentage cleaning credit was taken for the 
calendar quarter, and whether the credit was determined in accordance 
with the provisions of Sec. 60.48a and Method 19 (appendix A); and
    (2) Listing the quantity, heat content, and date each pretreated 
fuel shipment was received during the previous quarter; the name and 
location of the fuel pretreatment facility; and the total quantity and 
total heat content of all fuels received at the affected facility during 
the previous quarter.
    (f) For any periods for which opacity, sulfur dioxide or nitrogen 
oxides emissions data are not available, the owner or operator of the 
affected facility shall submit a signed statement indicating if any 
changes were made in operation of the emission control system during the 
period of data unavailability. Operations of the control system and 
affected facility during periods of data unavailability are to be 
compared with operation of the control system and affected facility 
before and following the period of data unavailability.
    (g) The owner or operator of the affected facility shall submit a 
signed statement indicating whether:
    (1) The required continuous monitoring system calibration, span, and 
drift checks or other periodic audits

[[Page 100]]

have or have not been performed as specified.
    (2) The data used to show compliance was or was not obtained in 
accordance with approved methods and procedures of this part and is 
representative of plant performance.
    (3) The minimum data requirements have or have not been met; or, the 
minimum data requirements have not been met for errors that were 
unavoidable.
    (4) Compliance with the standards has or has not been achieved 
during the reporting period.
    (h) For the purposes of the reports required under Sec. 60.7, 
periods of excess emissions are defined as all 6-minute periods during 
which the average opacity exceeds the applicable opacity standards under 
Sec. 60.42a(b). Opacity levels in excess of the applicable opacity 
standard and the date of such excesses are to be submitted to the 
Administrator each calendar quarter.
    (i) The owner or operator of an affected facility shall submit the 
written reports required under this section and subpart A to the 
Administrator semiannually for each six-month period. All semiannual 
reports shall be postmarked by the 30th day following the end of each 
six-month period.
    (j) The owner or operator of an affected facility may submit 
electronic quarterly reports for SO2 and/or NOX 
and/or opacity in lieu of submitting the written reports required under 
paragraphs (b) and (h) of this section. The format of each quarterly 
electronic report shall be coordinated with the permitting authority. 
The electronic report(s) shall be submitted no later than 30 days after 
the end of the calendar quarter and shall be accompanied by a 
certification statement from the owner or operator, indicating whether 
compliance with the applicable emission standards and minimum data 
requirements of this subpart was achieved during the reporting period. 
Before submitting reports in the electronic format, the owner or 
operator shall coordinate with the permitting authority to obtain their 
agreement to submit reports in this alternative format.

[44 FR 33613, June 11, 1979, as amended at 63 FR 49454, Sept. 16, 1998; 
64 FR 7464, Feb. 12, 1999]



     Subpart Db--Standards of Performance for Industrial-Commercial-
                  Institutional Steam Generating Units



Sec. 60.40b  Applicability and delegation of authority.

    (a) The affected facility to which this subpart applies is each 
steam generating unit that commences construction, modification, or 
reconstruction after June 19, 1984, and that has a heat input capacity 
from fuels combusted in the steam generating unit of greater than 29 MW 
(100 million Btu/hour).
    (b) Any affected facility meeting the applicability requirements 
under paragraph (a) of this section and commencing construction, 
modification, or reconstruction after June 19, 1984, but on or before 
June 19, 1986, is subject to the following standards:
    (1) Coal-fired affected facilities having a heat input capacity 
between 29 and 73 MW (100 and 250 million Btu/hour), inclusive, are 
subject to the particulate matter and nitrogen oxides standards under 
this subpart.
    (2) Coal-fired affected facilities having a heat input capacity 
greater than 73 MW (250 million Btu/hour) and meeting the applicability 
requirements under subpart D (Standards of performance for fossil-fuel-
fired steam generators; Sec. 60.40) are subject to the particulate 
matter and nitrogen oxides standards under this subpart and to the 
sulfur dioxide standards under subpart D (Sec. 60.43).
    (3) Oil-fired affected facilities having a heat input capacity 
between 29 and 73 MW (100 and 250 million Btu/hour), inclusive, are 
subject to the nitrogen oxides standards under this subpart.
    (4) Oil-fired affected facilities having a heat input capacity 
greater than 73 MW (250 million Btu/hour) and meeting the applicability 
requirements under subpart D (Standards of performance for fossil-fuel-
fired steam generators; Sec. 60.40) are also subject to the nitrogen 
oxides standards under this subpart and the particulate matter and 
sulfur dioxide standards under subpart D (Sec. 60.42 and Sec. 60.43).
    (c) Affected facilities which also meet the applicability 
requirements under subpart J (Standards of performance for petroleum 
refineries; Sec. 60.104)

[[Page 101]]

are subject to the particulate matter and nitrogen oxides standards 
under this subpart and the sulfur dioxide standards under subpart J 
(Sec. 60.104).
    (d) Affected facilities which also meet the applicability 
requirements under subpart E (Standards of performance for incinerators; 
Sec. 60.50) are subject to the nitrogen oxides and particulate matter 
standards under this subpart.
    (e) Steam generating units meeting the applicability requirements 
under subpart Da (Standards of performance for electric utility steam 
generating units; Sec. 60.40a) are not subject to this subpart.
    (f) Any change to an existing steam generating unit for the sole 
purpose of combusting gases containing TRS as defined under Sec. 60.281 
is not considered a modification under Sec. 60.14 and the steam 
generating unit is not subject to this subpart.
    (g) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the following authorities shall 
be retained by the Administrator and not transferred to a State.
    (1) Section 60.44b(f).
    (2) Section 60.44b(g).
    (3) Section 60.49b(a)(4).
    (h) Affected facilities which meet the applicability requirements 
under subpart Eb (Standards of performance for municipal waste 
combustors; Sec. 60.50b) are not subject to this subpart.
    (i) Unless and until subpart GG of this part is revised to extend 
the applicability of subpart GG of this part to steam generator units 
subject to this subpart, this subpart will continue to apply to combined 
cycle gas turbines that are capable of combusting more than 29 MW (100 
million Btu/hour) heat input of fossil fuel in the steam generator. Only 
emissions resulting from combustion of fuels in the steam generating 
unit are subject to this subpart. (The gas turbine emissions are subject 
to subpart GG of this part.)

[52 FR 47842, Dec. 16, 1987, as amended at 63 FR 49454, Sept. 16, 1998]



Sec. 60.41b  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    Annual capacity factor means the ratio between the actual heat input 
to a steam generating unit from the fuels listed in Sec. 60.42b(a), 
Sec. 60.43b(a), or Sec. 60.44b(a), as applicable, during a calendar year 
and the potential heat input to the steam generating unit had it been 
operated for 8,760 hours during a calendar year at the maximum steady 
state design heat input capacity. In the case of steam generating units 
that are rented or leased, the actual heat input shall be determined 
based on the combined heat input from all operations of the affected 
facility in a calendar year.
    Byproduct/waste means any liquid or gaseous substance produced at 
chemical manufacturing plants or petroleum refineries (except natural 
gas, distillate oil, or residual oil) and combusted in a steam 
generating unit for heat recovery or for disposal. Gaseous substances 
with carbon dioxide levels greater than 50 percent or carbon monoxide 
levels greater than 10 percent are not byproduct/waste for the purposes 
of this subpart.
    Chemical manufacturing plants means industrial plants which are 
classified by the Department of Commerce under Standard Industrial 
Classification (SIC) Code 28.
    Coal means all solid fuels classified as anthracite, bituminous, 
subbituminous, or lignite by the American Society of Testing and 
Materials in ASTM D388-77, Standard Specification for Classification of 
Coals by Rank (IBR--see Sec. 60.17), coal refuse, and petroleum coke. 
Coal-derived synthetic fuels, including but not limited to solvent 
refined coal, gasified coal, coal-oil mixtures, and coal-water mixtures, 
are also included in this definition for the purposes of this subpart.
    Coal refuse means any byproduct of coal mining or coal cleaning 
operations with an ash content greater than 50 percent, by weight, and a 
heating value less than 13,900 kJ/kg (6,000 Btu/lb) on a dry basis.
    Combined cycle system means a system in which a separate source, 
such as a gas turbine, internal combustion engine, kiln, etc., provides 
exhaust gas to a heat recovery steam generating unit.

[[Page 102]]

    Conventional technology means wet flue gas desulfurization (FGD) 
technology, dry FGD technology, atmospheric fluidized bed combustion 
technology, and oil hydrodesulfurization technology.
    Distillate oil means fuel oils that contain 0.05 weight percent 
nitrogen or less and comply with the specifications for fuel oil numbers 
1 and 2, as defined by the American Society of Testing and Materials in 
ASTM D396-78, Standard Specifications for Fuel Oils (incorporated by 
reference--see Sec. 60.17).
    Dry flue gas desulfurization technology means a sulfur dioxide 
control system that is located downstream of the steam generating unit 
and removes sulfur oxides from the combustion gases of the steam 
generating unit by contacting the combustion gases with an alkaline 
slurry or solution and forming a dry powder material. This definition 
includes devices where the dry powder material is subsequently converted 
to another form. Alkaline slurries or solutions used in dry flue gas 
desulfurization technology include but are not limited to lime and 
sodium.
    Duct burner means a device that combusts fuel and that is placed in 
the exhaust duct from another source, such as a stationary gas turbine, 
internal combustion engine, kiln, etc., to allow the firing of 
additional fuel to heat the exhaust gases before the exhaust gases enter 
a heat recovery steam generating unit.
    Emerging technology means any sulfur dioxide control system that is 
not defined as a conventional technology under this section, and for 
which the owner or operator of the facility has applied to the 
Administrator and received approval to operate as an emerging technology 
under Sec. 60.49b(a)(4).
    Federally enforceable means all limitations and conditions that are 
enforceable by the Administrator, including the requirements of 40 CFR 
parts 60 and 61, requirements within any applicable State Implementation 
Plan, and any permit requirements established under 40 CFR 52.21 or 
under 40 CFR 51.18 and 40 CFR 51.24.
    Fluidized bed combustion technology means combustion of fuel in a 
bed or series of beds (including but not limited to bubbling bed units 
and circulating bed units) of limestone aggregate (or other sorbent 
materials) in which these materials are forced upward by the flow of 
combustion air and the gaseous products of combustion.
    Fuel pretreatment means a process that removes a portion of the 
sulfur in a fuel before combustion of the fuel in a steam generating 
unit.
    Full capacity means operation of the steam generating unit at 90 
percent or more of the maximum steady-state design heat input capacity.
    Heat input means heat derived from combustion of fuel in a steam 
generating unit and does not include the heat input from preheated 
combustion air, recirculated flue gases, or exhaust gases from other 
sources, such as gas turbines, internal combustion engines, kilns, etc.
    Heat release rate means the steam generating unit design heat input 
capacity (in MW or Btu/hour) divided by the furnace volume (in cubic 
meters or cubic feet); the furnace volume is that volume bounded by the 
front furnace wall where the burner is located, the furnace side 
waterwall, and extending to the level just below or in front of the 
first row of convection pass tubes.
    Heat transfer medium means any material that is used to transfer 
heat from one point to another point.
    High heat release rate means a heat release rate greater than 
730,000 J/sec-m\3\ (70,000 Btu/hour-ft\3\).
    Lignite means a type of coal classified as lignite A or lignite B by 
the American Society of Testing and Materials in ASTM D388-77, Standard 
Specification for Classification of Coals by Rank (IBR--see Sec. 60.17).
    Low heat release rate means a heat release rate of 730,000 J/sec-
m\3\ (70,000 Btu/hour-ft\3\) or less.
    Mass-feed stoker steam generating unit means a steam generating unit 
where solid fuel is introduced directly into a retort or is fed directly 
onto a grate where it is combusted.
    Maximum heat input capacity means the ability of a steam generating 
unit to combust a stated maximum amount of fuel on a steady state basis, 
as determined by the physical design and characteristics of the steam 
generating unit.

[[Page 103]]

    Municipal-type solid waste means refuse, more than 50 percent of 
which is waste consisting of a mixture of paper, wood, yard wastes, food 
wastes, plastics, leather, rubber, and other combustible materials, and 
noncombustible materials such as glass and rock.
    Natural gas means (1) a naturally occurring mixture of hydrocarbon 
and nonhydrocarbon gases found in geologic formations beneath the 
earth's surface, of which the principal constituent is methane; or (2) 
liquid petroleum gas, as defined by the American Society for Testing and 
Materials in ASTM D1835-82, ``Standard Specification for Liquid 
Petroleum Gases'' (IBR--see Sec. 60.17).
    Noncontinental area means the State of Hawaii, the Virgin Islands, 
Guam, American Samoa, the Commonwealth of Puerto Rico, or the Northern 
Mariana Islands.
    Oil means crude oil or petroleum or a liquid fuel derived from crude 
oil or petroleum, including distillate and residual oil.
    Petroleum refinery means industrial plants as classified by the 
Department of Commerce under Standard Industrial Classification (SIC) 
Code 29.
    Potential sulfur dioxide emission rate means the theoretical sulfur 
dioxide emissions (ng/J, lb/million Btu heat input) that would result 
from combusting fuel in an uncleaned state and without using emission 
control systems.
    Process heater means a device that is primarily used to heat a 
material to initiate or promote a chemical reaction in which the 
material participates as a reactant or catalyst.
    Pulverized coal-fired steam generating unit means a steam generating 
unit in which pulverized coal is introduced into an air stream that 
carries the coal to the combustion chamber of the steam generating unit 
where it is fired in suspension. This includes both conventional 
pulverized coal-fired and micropulverized coal-fired steam generating 
units.
    Residual oil means crude oil, fuel oil numbers 1 and 2 that have a 
nitrogen content greater than 0.05 weight percent, and all fuel oil 
numbers 4, 5 and 6, as defined by the American Society of Testing and 
Materials in ASTM D396-78, Standard Specifications for Fuel Oils (IBR--
see Sec. 60.17).
    Spreader stoker steam generating unit means a steam generating unit 
in which solid fuel is introduced to the combustion zone by a mechanism 
that throws the fuel onto a grate from above. Combustion takes place 
both in suspension and on the grate.
    Steam generating unit means a device that combusts any fuel or 
byproduct/waste to produce steam or to heat water or any other heat 
transfer medium. This term includes any municipal-type solid waste 
incinerator with a heat recovery steam generating unit or any steam 
generating unit that combusts fuel and is part of a cogeneration system 
or a combined cycle system. This term does not include process heaters 
as they are defined in this subpart.
    Steam generating unit operating day means a 24-hour period between 
12:00 midnight and the following midnight during which any fuel is 
combusted at any time in the steam generating unit. It is not necessary 
for fuel to be combusted continuously for the entire 24-hour period.
    Very low sulfur oil means an oil that contains no more than 0.5 
weight percent sulfur or that, when combusted without sulfur dioxide 
emission control, has a sulfur dioxide emission rate equal to or less 
than 215 ng/J (0.5 lb/million Btu) heat input.
    Wet flue gas desulfurization technology means a sulfur dioxide 
control system that is located downstream of the steam generating unit 
and removes sulfur oxides from the combustion gases of the steam 
generating unit by contacting the combustion gas with an alkaline slurry 
or solution and forming a liquid material. This definition applies to 
devices where the aqueous liquid material product of this contact is 
subsequently converted to other forms. Alkaline reagents used in wet 
flue gas desulfurization technology include, but are not limited to, 
lime, limestone, and sodium.
    Wet scrubber system means any emission control device that mixes an 
aqueous stream or slurry with the exhaust gases from a steam generating 
unit to control emissions of particulate matter or sulfur dioxide.

[[Page 104]]

    Wood means wood, wood residue, bark, or any derivative fuel or 
residue thereof, in any form, including, but not limited to, sawdust, 
sanderdust, wood chips, scraps, slabs, millings, shavings, and processed 
pellets made from wood or other forest residues.

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51819, Dec. 18, 1989]



Sec. 60.42b  Standard for sulfur dioxide.

    (a) Except as provided in paragraphs (b), (c), (d), or (j) of this 
section, on and after the date on which the performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts coal or oil shall cause to be discharged into the 
atmosphere any gases that contain sulfur dioxide in excess of 10 percent 
(0.10) of the potential sulfur dioxide emission rate (90 percent 
reduction) and that contain sulfur dioxide in excess of the emission 
limit determined according to the following formula:

Es=(Ka Ha+Kb Hb)/
          (Ha+Hb)

where:
Es is the sulfur dioxide emission limit, in ng/J or lb/
          million Btu heat input,
Ka is 520 ng/J (or 1.2 lb/million Btu),
Kb is 340 ng/J (or 0.80 lb/million Btu),
Ha is the heat input from the combustion of coal, in J 
          (million Btu),
Hb is the heat input from the combustion of oil, in J 
          (million Btu).


Only the heat input supplied to the affected facility from the 
combustion of coal and oil is counted under this section. No credit is 
provided for the heat input to the affected facility from the combustion 
of natural gas, wood, municipal-type solid waste, or other fuels or heat 
input to the affected facility from exhaust gases from another source, 
such as gas turbines, internal combustion engines, kilns, etc.
    (b) On and after the date on which the performance test is completed 
or required to be completed under Sec. 60.8 of this part, whichever 
comes first, no owner or operator of an affected facility that combusts 
coal refuse alone in a fluidized bed combustion steam generating unit 
shall cause to be discharged into the atmosphere any gases that contain 
sulfur dioxide in excess of 20 percent of the potential sulfur dioxide 
emission rate (80 percent reduction) and that contain sulfur dioxide in 
excess of 520 ng/J (1.2 lb/million Btu) heat input. If coal or oil is 
fired with coal refuse, the affected facility is subject to paragraph 
(a) or (d) of this section, as applicable.
    (c) On and after the date on which the performance test is completed 
or is required to be completed under Sec. 60.8 of this part, whichever 
comes first, no owner or operator of an affected facility that combusts 
coal or oil, either alone or in combination with any other fuel, and 
that uses an emerging technology for the control of sulfur dioxide 
emissions, shall cause to be discharged into the atmosphere any gases 
that contain sulfur dioxide in excess of 50 percent of the potential 
sulfur dioxide emission rate (50 percent reduction) and that contain 
sulfur dioxide in excess of the emission limit determined according to 
the following formula:

Es=(Kc Hc+Kd Hd)/
          Hc+Hd)

where:
Es is the sulfur dioxide emission limit, expressed in ng/J 
          (lb/million Btu) heat input,
Kc is 260 ng/J (0.60 lb/million Btu),
Kd is 170 ng/J (0.40 lb/million Btu),
Hc is the heat input from the combustion of coal, J (million 
          Btu),
Hd is the heat input from the combustion of oil, J (million 
          Btu).


Only the heat input supplied to the affected facility from the 
combustion of coal and oil is counted under this section. No credit is 
provided for the heat input to the affected facility from the combustion 
of natural gas, wood, municipal-type solid waste, or other fuels, or 
from the heat input to the affected facility from exhaust gases from 
another source, such as gas turbines, internal combustion engines, 
kilns, etc.
    (d) On and after the date on which the performance test is completed 
or required to be completed under Sec. 60.8 of this part, whichever 
comes first, no owner or operator of an affected facility listed in 
paragraphs (d) (1), (2), or (3) of this section shall cause to be 
discharged into the atmosphere any gases that contain sulfur dioxide in 
excess of 520 ng/J (1.2 lb/million Btu) heat input if the affected 
facility combusts coal, or 215 ng/J (0.5 lb/million Btu) heat

[[Page 105]]

input if the affected facility combusts oil other than very low sulfur 
oil. Percent reduction requirements are not applicable to affected 
facilities under this paragraph.
    (1) Affected facilities that have an annual capacity factor for coal 
and oil of 30 percent (0.30) or less and are subject to a Federally 
enforceable permit limiting the operation of the affected facility to an 
annual capacity factor for coal and oil of 30 percent (0.30) or less;
    (2) Affected facilities located in a noncontinental area; or
    (3) Affected facilities combusting coal or oil, alone or in 
combination with any other fuel, in a duct burner as part of a combined 
cycle system where 30 percent (0.30) or less of the heat input to the 
steam generating unit is from combustion of coal and oil in the duct 
burner and 70 percent (0.70) or more of the heat input to the steam 
generating unit is from the exhaust gases entering the duct burner.
    (e) Except as provided in paragraph (f) of this section, compliance 
with the emission limits, fuel oil sulfur limits, and/or percent 
reduction requirements under this section are determined on a 30-day 
rolling average basis.
    (f) Except as provided in paragraph (j)(2) of this section, 
compliance with the emission limits or fuel oil sulfur limits under this 
section is determined on a 24-hour average basis for affected facilities 
that (1) have a Federally enforceable permit limiting the annual 
capacity factor for oil to 10 percent or less, (2) combust only very low 
sulfur oil, and (3) do not combust any other fuel.
    (g) Except as provided in paragraph (i) of this section, the sulfur 
dioxide emission limits and percent reduction requirements under this 
section apply at all times, including periods of startup, shutdown, and 
malfunction.
    (h) Reductions in the potential sulfur dioxide emission rate through 
fuel pretreatment are not credited toward the percent reduction 
requirement under paragraph (c) of this section unless:
    (1) Fuel pretreatment results in a 50 percent or greater reduction 
in potential sulfur dioxide emissions and
    (2) Emissions from the pretreated fuel (without combustion or post 
combustion sulfur dioxide control) are equal to or less than the 
emission limits specified in paragraph (c) of this section.
    (i) An affected facility subject to paragraph (a), (b), or (c) of 
this section may combust very low sulfur oil or natural gas when the 
sulfur dioxide control system is not being operated because of 
malfunction or maintenance of the sulfur dioxide control system.
    (j) Percent reduction requirements are not applicable to affected 
facilities combusting only very low sulfur oil. The owner or operator of 
an affected facility combusting very low sulfur oil shall demonstrate 
that the oil meets the definition of very low sulfur oil by: (1) 
Following the performance testing procedures as described in 
Sec. 60.45b(c) or Sec. 60.45b(d), and following the monitoring 
procedures as described in Sec. 60.47b(a) or Sec. 60.47b(b) to determine 
sulfur dioxide emission rate or fuel oil sulfur content; or (2) 
maintaining fuel receipts as described in Sec. 60.49b(r).

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51819, Dec. 18, 1989]



Sec. 60.43b  Standard for particulate matter.

    (a) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of this part, 
whichever comes first, no owner or operator of an affected facility 
which combusts coal or combusts mixtures of coal with other fuels, shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain particulate matter in excess of the following 
emission limits:
    (1) 22 ng/J (0.05 lb/million Btu) heat input,
    (i) If the affected facility combusts only coal, or
    (ii) If the affected facility combusts coal and other fuels and has 
an annual capacity factor for the other fuels of 10 percent (0.10) or 
less.
    (2) 43 ng/J (0.10 lb/million Btu) heat input if the affected 
facility combusts coal and other fuels and has an annual capacity factor 
for the other fuels greater than 10 percent (0.10) and is

[[Page 106]]

subject to a federally enforceable requirement limiting operation of the 
affected facility to an annual capacity factor greater than 10 percent 
(0.10) for fuels other than coal.
    (3) 86 ng/J (0.20 lb/million Btu) heat input if the affected 
facility combusts coal or coal and other fuels and
    (i) Has an annual capacity factor for coal or coal and other fuels 
of 30 percent (0.30) or less,
    (ii) Has a maximum heat input capacity of 73 MW (250 million Btu/
hour) or less,
    (iii) Has a federally enforceable requirement limiting operation of 
the affected facility to an annual capacity factor of 30 percent (0.30) 
or less for coal or coal and other solid fuels, and
    (iv) Construction of the affected facility commenced after June 19, 
1984, and before November 25, 1986.
    (b) On and after the date on which the performance test is completed 
or required to be completed under 60.8 of this part, whichever date 
comes first, no owner or operator of an affected facility that combusts 
oil (or mixtures of oil with other fuels) and uses a conventional or 
emerging technology to reduce sulfur dioxide emissions shall cause to be 
discharged into the atmosphere from that affected facility any gases 
that contain particulate matter in excess of 43 ng/J (0.10 lb/million 
Btu) heat input.
    (c) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts wood, or wood with other fuels, except coal, shall cause 
to be discharged from that affected facility any gases that contain 
particulate matter in excess of the following emission limits:
    (1) 43 ng/J (0.10 lb/million Btu) heat input if the affected 
facility has an annual capacity factor greater than 30 percent (0.30) 
for wood.
    (2) 86 ng/J (0.20 lb/million Btu) heat input if
    (i) The affected facility has an annual capacity factor of 30 
percent (0.30) or less for wood,
    (ii) Is subject to a federally enforceable requirement limiting 
operation of the affected facility to an annual capacity factor of 30 
percent (0.30) or less for wood, and
    (iii) Has a maximum heat input capacity of 73 MW (250 million Btu/
hour) or less.
    (d) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts municipal-type solid waste or mixtures of municipal-type 
solid waste with other fuels, shall cause to be discharged into the 
atmosphere from that affected facility any gases that contain 
particulate matter in excess of the following emission limits:
    (1) 43 ng/J (0.10 lb/million Btu) heat input,
    (i) If the affected facility combusts only municipal-type solid 
waste, or
    (ii) If the affected facility combusts municipal-type solid waste 
and other fuels and has an annual capacity factor for the other fuels of 
10 percent (0.10) or less.
    (2) 86 ng/J (0.20 lb/million Btu) heat input if the affected 
facility combusts municipal-type solid waste or municipal-type solid 
waste and other fuels; and
    (i) Has an annual capacity factor for municipal-type solid waste and 
other fuels of 30 percent (0.30) or less,
    (ii) Has a maximum heat input capacity of 73 MW (250 million Btu/
hour) or less,
    (iii) Has a federally enforceable requirement limiting operation of 
the affected facility to an annual capacity factor of 30 percent (0.30) 
for municipal-type solid waste, or municipal-type solid waste and other 
fuels, and
    (iv) Construction of the affected facility commenced after June 19, 
1984, but before November 25, 1986.
    (e) For the purposes of this section, the annual capacity factor is 
determined by dividing the actual heat input to the steam generating 
unit during the calendar year from the combustion of coal, wood, or 
municipal-type solid waste, and other fuels, as applicable, by the 
potential heat input to the steam generating unit if the steam 
generating unit had been operated for 8,760 hours at the maximum design 
heat input capacity.

[[Page 107]]

    (f) On and after the date on which the initial performance test is 
completed or is required to be completed under 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts coal, oil, wood, or mixtures of these fuels with any other 
fuels shall cause to be discharged into the atmosphere any gases that 
exhibit greater than 20 percent opacity (6-minute average), except for 
one 6-minute period per hour of not more than 27 percent opacity.
    (g) The particulate matter and opacity standards apply at all times, 
except during periods of startup, shutdown or malfunction.

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51819, Dec. 18, 1989]



Sec. 60.44b  Standard for nitrogen oxides.

    (a) Except as provided under paragraphs (k) and (l) of this section, 
on and after the date on which the initial performance test is completed 
or is required to be completed under Sec. 60.8 of this part, whichever 
date comes first, no owner or operator of an affected facility that is 
subject to the provisions of this section and that combusts only coal, 
oil, or natural gas shall cause to be discharged into the atmosphere 
from that affected facility any gases that contain nitrogen oxides 
(expressed as NO2) in excess of the following emission 
limits:

------------------------------------------------------------------------
                                                          Nitrogen oxide
                                                             emission
                                                            limits ng/J
                                                            (lb/million
             Fuel/Steam generating unit type                   Btu)
                                                           (expressed as
                                                             NO2) heat
                                                               input
------------------------------------------------------------------------
(1) Natural gas and distillate oil, except (4):
  (i) Low heat release rate.............................       43 (0.10)
  (ii) High heat release rate...........................       86 (0.20)
(2) Residual oil:
  (i) Low heat release rate.............................      130 (0.30)
  (ii) High heat release rate...........................      170 (0.40)
(3) Coal:
  (i) Mass-feed stoker..................................      210 (0.50)
  (ii) Spreader stoker and fluidized bed combustion.....      260 (0.60)
  (iii) Pulverized coal.................................      300 (0.70)
  (iv) Lignite, except (v)..............................      260 (0.60)
  (v) Lignite mined in North Dakota, South Dakota, or         340 (0.80)
   Montana and combusted in a slag tap furnace..........
  (vi) Coal-derived synthetic fuels.....................      210 (0.50)
(4) Duct burner used in a combined cycle system:
  (i) Natural gas and distillate oil....................       86 (0.20)
  (ii) Residual oil.....................................      170 (0.40)
------------------------------------------------------------------------

    (b) Except as provided under paragraphs (k) and (l) of this section, 
on and after the date on which the initial performance test is completed 
or is required to be completed under Sec. 60.8 of this part, whichever 
date comes first, no owner or operator of an affected facility that 
simultaneously combusts mixtures of coal, oil, or natural gas shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain nitrogen oxides in excess of a limit determined 
by the use of the following formula:

En=[(ELgo Hgo)+(ELro 
          Hro)+(ELc Hc)]/
          (Hgo+Hro+Hc)

where:

En is the nitrogen oxides emission limit (expressed as 
          NO2), ng/J (lb/million Btu)
ELgo is the appropriate emission limit from paragraph (a)(1) 
          for combustion of natural gas or distillate oil, ng/J (lb/
          million Btu)
Hgo is the heat input from combustion of natural gas or 
          distillate oil,
ELro is the appropriate emission limit from paragraph (a)(2) 
          for combustion of residual oil,
Hro is the heat input from combustion of residual oil,
ELc is the appropriate emission limit from paragraph (a)(3) 
          for combustion of coal, and
Hc is the heat input from combustion of coal.

    (c) Except as provided under paragraph (l) of this section, on and 
after the date on which the initial performance test is completed or is 
required to be completed under Sec. 60.8 of this part, whichever date 
comes first, no owner or operator of an affected facility that 
simultaneously combusts coal or oil, or a mixture of these fuels with 
natural gas, and wood, municipal-type solid waste, or any other fuel 
shall cause to be discharged into the atmosphere any gases that contain 
nitrogen oxides in excess of the emission limit for the coal or oil, or 
mixtures of these fuels with natural gas combusted in the affected 
facility, as determined pursuant to paragraph (a) or (b) of this 
section, unless the affected facility has an annual capacity factor for 
coal or oil, or mixture of these fuels with natural gas of 10 percent 
(0.10) or less and is subject to a federally enforceable requirement 
that limits operation of the affected facility to an annual capacity 
factor of 10

[[Page 108]]

percent (0.10) or less for coal, oil, or a mixture of these fuels with 
natural gas.
    (d) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that simultaneously combusts natural gas with wood, municipal-type solid 
waste, or other solid fuel, except coal, shall cause to be discharged 
into the atmosphere from that affected facility any gases that contain 
nitrogen oxides in excess of 130 ng/J (0.30 lb/million Btu) heat input 
unless the affected facility has an annual capacity factor for natural 
gas of 10 percent (0.10) or less and is subject to a federally 
enforceable requirement that limits operation of the affected facility 
to an annual capacity factor of 10 percent (0.10) or less for natural 
gas.
    (e) Except as provided under paragraph (l) of this section, on and 
after the date on which the initial performance test is completed or is 
required to be completed under Sec. 60.8 of this part, whichever date 
comes first, no owner or operator of an affected facility that 
simultaneously combusts coal, oil, or natural gas with byproduct/waste 
shall cause to be discharged into the atmosphere any gases that contain 
nitrogen oxides in excess of the emission limit determined by the 
following formula unless the affected facility has an annual capacity 
factor for coal, oil, and natural gas of 10 percent (0.10) or less and 
is subject to a federally enforceable requirement that limits operation 
of the affected facility to an annual capacity factor of 10 percent 
(0.10) or less:

En=[(ELgo Hgo)+(ELro 
          Hro)+ (ELc Hc)]/
          (Hgo+Hro+Hc)

where:

En is the nitrogen oxides emission limit (expressed as 
          NO2), ng/J (lb/million Btu)
ELgo is the appropriate emission limit from paragraph (a)(1) 
          for combustion of natural gas or distillate oil, ng/J (lb/
          million Btu).
Hgo is the heat input from combustion of natural gas, 
          distillate oil and gaseous byproduct/waste, ng/J (lb/million 
          Btu).
ELro is the appropriate emission limit from paragraph (a)(2) 
          for combustion of residual oil, ng/J (lb/million Btu)
Hro is the heat input from combustion of residual oil and/or 
          liquid byproduct/waste.
ELc is the appropriate emission limit from paragraph (a)(3) 
          for combustion of coal, and
Hc is the heat input from combustion of coal.

    (f) Any owner or operator of an affected facility that combusts 
byproduct/waste with either natural gas or oil may petition the 
Administrator within 180 days of the initial startup of the affected 
facility to establish a nitrogen oxides emission limit which shall apply 
specifically to that affected facility when the byproduct/waste is 
combusted. The petition shall include sufficient and appropriate data, 
as determined by the Administrator, such as nitrogen oxides emissions 
from the affected facility, waste composition (including nitrogen 
content), and combustion conditions to allow the Administrator to 
confirm that the affected facility is unable to comply with the emission 
limits in paragraph (e) of this section and to determine the appropriate 
emission limit for the affected facility.
    (1) Any owner or operator of an affected facility petitioning for a 
facility-specific nitrogen oxides emission limit under this section 
shall:
    (i) Demonstrate compliance with the emission limits for natural gas 
and distillate oil in paragraph (a)(1) of this section or for residual 
oil in paragraph (a)(2) of this section, as appropriate, by conducting a 
30-day performance test as provided in Sec. 60.46b(e). During the 
performance test only natural gas, distillate oil, or residual oil shall 
be combusted in the affected facility; and
    (ii) Demonstrate that the affected facility is unable to comply with 
the emission limits for natural gas and distillate oil in paragraph 
(a)(1) of this section or for residual oil in paragraph (a)(2) of this 
section, as appropriate, when gaseous or liquid byproduct/waste is 
combusted in the affected facility under the same conditions and using 
the same technological system of emission reduction applied when 
demonstrating compliance under paragraph (f)(1)(i) of this section.
    (2) The nitrogen oxides emission limits for natural gas or 
distillate oil in paragraph (a)(1) of this section or for residual oil 
in paragraph (a)(2) of this section, as appropriate, shall be applicable 
to the affected facility until and

[[Page 109]]

unless the petition is approved by the Administrator. If the petition is 
approved by the Administrator, a facility-specific nitrogen oxides 
emission limit will be established at the nitrogen oxides emission level 
achievable when the affected facility is combusting oil or natural gas 
and byproduct/waste in a manner that the Administrator determines to be 
consistent with minimizing nitrogen oxides emissions.
    (g) Any owner or operator of an affected facility that combusts 
hazardous waste (as defined by 40 CFR part 261 or 40 CFR part 761) with 
natural gas or oil may petition the Administrator within 180 days of the 
initial startup of the affected facility for a waiver from compliance 
with the nitrogen oxides emission limit which applies specifically to 
that affected facility. The petition must include sufficient and 
appropriate data, as determined by the Administrator, on nitrogen oxides 
emissions from the affected facility, waste destruction efficiencies, 
waste composition (including nitrogen content), the quantity of specific 
wastes to be combusted and combustion conditions to allow the 
Administrator to determine if the affected facility is able to comply 
with the nitrogen oxides emission limits required by this section. The 
owner or operator of the affected facility shall demonstrate that when 
hazardous waste is combusted in the affected facility, thermal 
destruction efficiency requirements for hazardous waste specified in an 
applicable federally enforceable requirement preclude compliance with 
the nitrogen oxides emission limits of this section. The nitrogen oxides 
emission limits for natural gas or distillate oil in paragraph (a)(1) of 
this section or for residual oil in paragraph (a)(2) of this section, as 
appropriate, are applicable to the affected facility until and unless 
the petition is approved by the Administrator. (See 40 CFR 761.70 for 
regulations applicable to the incineration of materials containing 
polychlorinated biphenyls (PCB's).)
    (h) For purposes of paragraph (i) of this section, the nitrogen 
oxide standards under this section apply at all times including periods 
of startup, shutdown, or malfunction.
    (i) Except as provided under paragraph (j) of this section, 
compliance with the emission limits under this section is determined on 
a 30-day rolling average basis.
    (j) Compliance with the emission limits under this section is 
determined on a 24-hour average basis for the initial performance test 
and on a 3-hour average basis for subsequent performance tests for any 
affected facilities that:
    (1) Combust, alone or in combination, only natural gas, distillate 
oil, or residual oil with a nitrogen content of 0.30 weight percent or 
less;
    (2) Have a combined annual capacity factor of 10 percent or less for 
natural gas, distillate oil, and residual oil with a nitrogen content of 
0.30 weight percent or less; and
    (3) Are subject to a Federally enforceable requirement limiting 
operation of the affected facility to the firing of natural gas, 
distillate oil, and/or residual oil with a nitrogen content of 0.30 
weight percent or less and limiting operation of the affected facility 
to a combined annual capacity factor of 10 percent or less for natural 
gas, distillate oil, and residual oil and a nitrogen content of 0.30 
weight percent or less.
    (k) Affected facilities that meet the criteria described in 
paragraphs (j) (1), (2), and (3) of this section, and that have a heat 
input capacity of 73 MW (250 million Btu/hour) or less, are not subject 
to the nitrogen oxides emission limits under this section.
    (l) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
which commenced construction, modification, or reconstruction after July 
9, 1997 shall cause to be discharged into the atmosphere from that 
affected facility any gases that contain nitrogen oxides (expressed as 
NO2) in excess of the following limits:
    (1) If the affected facility combusts coal, oil, or natural gas, or 
a mixture of these fuels, or with any other fuels: A limit of 86 ng/
JI (0.20 lb/million Btu) heat input unless the affected 
facility has an annual capacity factor for coal, oil, and natural gas of 
10 percent (0.10)

[[Page 110]]

or less and is subject to a federally enforceable requirement that 
limits operation of the facility to an annual capacity factor of 10 
percent (0.10) or less for coal, oil, and natural gas; or
    (2) If the affected facility has a low heat release rate and 
combusts natural gas or distillate oil in excess of 30 percent of the 
heat input from the combustion of all fuels, a limit determined by use 
of the following formula:

En = [(0.10 * Hgo)+(0.20 * Hr)]/
(Hgo+Hr)
Where:

En is the NOX emission limit, (lb/million Btu),
Hgo is the heat input from combustion of natural gas or 
distillate oil, and
Hr is the heat input from combustion of any other fuel.

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51825, Dec. 18, 1989; 
63 FR 49454, Sept. 16, 1998]



Sec. 60.45b  Compliance and performance test methods and procedures for sulfur dioxide.

    (a) The sulfur dioxide emission standards under Sec. 60.42b apply at 
all times.
    (b) In conducting the performance tests required under Sec. 60.8, 
the owner or operator shall use the methods and procedures in appendix A 
of this part or the methods and procedures as specified in this section, 
except as provided in Sec. 60.8(b). Section 60.8(f) does not apply to 
this section. The 30-day notice required in Sec. 60.8(d) applies only to 
the initial performance test unless otherwise specified by the 
Administrator.
    (c) The owner or operator of an affected facility shall conduct 
performance tests to determine compliance with the percent of potential 
sulfur dioxide emission rate (% Ps) and the sulfur dioxide 
emission rate (Es) pursuant to Sec. 60.42b following the 
procedures listed below, except as provided under paragraph (d) of this 
section.
    (1) The initial performance test shall be conducted over the first 
30 consecutive operating days of the steam generating unit. Compliance 
with the sulfur dioxide standards shall be determined using a 30-day 
average. The first operating day included in the initial performance 
test shall be scheduled within 30 days after achieving the maximum 
production rate at which the affected facility will be operated, but not 
later than 180 days after initial startup of the facility.
    (2) If only coal or only oil is combusted, the following procedures 
are used:
    (i) The procedures in Method 19 are used to determine the hourly 
sulfur dioxide emission rate (Eho) and the 30-day average 
emission rate (Eao). The hourly averages used to compute the 
30-day averages are obtained from the continuous emission monitoring 
system of Sec. 60.47b (a) or (b).
    (ii) The percent of potential sulfur dioxide emission rate (% 
Ps) emitted to the atmosphere is computed using the following 
formula:

% Ps=100 (1-% Rg/100)(1-% Rf/100)

where:

% Rg is the sulfur dioxide removal efficiency of the control 
          device as determined by Method 19, in percent.
% Rf is the sulfur dioxide removal efficiency of fuel 
          pretreatment as determined by Method 19, in percent.

    (3) If coal or oil is combusted with other fuels, the same 
procedures required in paragraph (c)(2) of this section are used, except 
as provided in the following:
    (i) An adjusted hourly sulfur dioxide emission rate 
(Ehoo) is used in Equation 19-19 of Method 19 to 
compute an adjusted 30-day average emission rate 
(Eaoo). The Eho is computed using the 
following formula:

Ehoo=[Eho-Ew(1-Xk)
          ]/Xk
where:
Ehoo is the adjusted hourly sulfur dioxide 
          emission rate, ng/J (lb/million Btu).
Eho is the hourly sulfur dioxide emission rate, ng/J (lb/
          million Btu).
Ew is the sulfur dioxide concentration in fuels other than 
          coal and oil combusted in the affected facility, as determined 
          by the fuel sampling and analysis procedures in Method 19, ng/
          J (lb/million Btu). The value Ew for each fuel lot 
          is used for each hourly average during the time that the lot 
          is being combusted.
Xk is the fraction of total heat input from fuel combustion 
          derived from coal, oil, or coal and oil, as determined by 
          applicable procedures in Method 19.

    (ii) To compute the percent of potential sulfur dioxide emission 
rate (% Ps), an adjusted % Rg (% 
Rgo) is computed from the adjusted 
Eaoo from paragraph (b)(3)(i) of this section and 
an adjusted

[[Page 111]]

average sulfur dioxide inlet rate (Eaio) using the 
following formula:

% Rgo=100 (1.0-Eaoo/
          Eaio)


To compute Eaio, an adjusted hourly sulfur dioxide 
inlet rate (Ehio) is used. The 
Ehio is computed using the following formula:

Ehio=[Ehi-Ew(1-Xk)
          ]/Xk

where:

Ehio is the adjusted hourly sulfur dioxide inlet 
          rate, ng/J (lb/million Btu).
Ehi is the hourly sulfur dioxide inlet rate, ng/J (lb/million 
          Btu).

    (4) The owner or operator of an affected facility subject to 
paragraph (b)(3) of this section does not have to measure parameters 
Ew or Xk if the owner or operator elects to assume 
that Xk=1.0. Owners or operators of affected facilities who 
assume Xk=1.0 shall
    (i) Determine % Ps following the procedures in paragraph 
(c)(2) of this section, and
    (ii) Sulfur dioxide emissions (Es) are considered to be 
in compliance with sulfur dioxide emission limits under Sec. 60.42b.
    (5) The owner or operator of an affected facility that qualifies 
under the provisions of Sec. 60.42b(d) does not have to measure 
parameters Ew or Xk under paragraph (b)(3) of this 
section if the owner or operator of the affected facility elects to 
measure sulfur dioxide emission rates of the coal or oil following the 
fuel sampling and analysis procedures under Method 19.
    (d) Except as provided in paragraph (j), the owner or operator of an 
affected facility that combusts only very low sulfur oil, has an annual 
capacity factor for oil of 10 percent (0.10) or less, and is subject to 
a Federally enforceable requirement limiting operation of the affected 
facility to an annual capacity factor for oil of 10 percent (0.10) or 
less shall:
    (1) Conduct the initial performance test over 24 consecutive steam 
generating unit operating hours at full load;
    (2) Determine compliance with the standards after the initial 
performance test based on the arithmetic average of the hourly emissions 
data during each steam generating unit operating day if a continuous 
emission measurement system (CEMS) is used, or based on a daily average 
if Method 6B or fuel sampling and analysis procedures under Method 19 
are used.
    (e) The owner or operator of an affected facility subject to 
Sec. 60.42b(d)(1) shall demonstrate the maximum design capacity of the 
steam generating unit by operating the facility at maximum capacity for 
24 hours. This demonstration will be made during the initial performance 
test and a subsequent demonstration may be requested at any other time. 
If the 24-hour average firing rate for the affected facility is less 
than the maximum design capacity provided by the manufacturer of the 
affected facility, the 24-hour average firing rate shall be used to 
determine the capacity utilization rate for the affected facility, 
otherwise the maximum design capacity provided by the manufacturer is 
used.
    (f) For the initial performance test required under Sec. 60.8, 
compliance with the sulfur dioxide emission limits and percent reduction 
requirements under Sec. 60.42b is based on the average emission rates 
and the average percent reduction for sulfur dioxide for the first 30 
consecutive steam generating unit operating days, except as provided 
under paragraph (d) of this section. The initial performance test is the 
only test for which at least 30 days prior notice is required unless 
otherwise specified by the Administrator. The initial performance test 
is to be scheduled so that the first steam generating unit operating day 
of the 30 successive steam generating unit operating days is completed 
within 30 days after achieving the maximum production rate at which the 
affected facility will be operated, but not later than 180 days after 
initial startup of the facility. The boiler load during the 30-day 
period does not have to be the maximum design load, but must be 
representative of future operating conditions and include at least one 
24-hour period at full load.
    (g) After the initial performance test required under Sec. 60.8, 
compliance with the sulfur dioxide emission limits and percent reduction 
requirements under Sec. 60.42b is based on the average emission rates 
and the average percent reduction for sulfur dioxide for 30 successive 
steam generating unit operating

[[Page 112]]

days, except as provided under paragraph (d). A separate performance 
test is completed at the end of each steam generating unit operating day 
after the initial performance test, and a new 30-day average emission 
rate and percent reduction for sulfur dioxide are calculated to show 
compliance with the standard.
    (h) Except as provided under paragraph (i) of this section, the 
owner or operator of an affected facility shall use all valid sulfur 
dioxide emissions data in calculating % Ps and Eho 
under paragraph (c), of this section whether or not the minimum 
emissions data requirements under Sec. 60.46b are achieved. All valid 
emissions data, including valid sulfur dioxides emission data collected 
during periods of startup, shutdown and malfunction, shall be used in 
calculating % Ps and Eho pursuant to paragraph (c) 
of this section.
    (i) During periods of malfunction or maintenance of the sulfur 
dioxide control systems when oil is combusted as provided under 
Sec. 60.42b(i), emission data are not used to calculate % Ps 
or Es under Sec. 60.42b (a), (b) or (c), however, the 
emissions data are used to determine compliance with the emission limit 
under Sec. 60.42b(i).
    (j) The owner or operator of an affected facility that combusts very 
low sulfur oil is not subject to the compliance and performance testing 
requirements of this section if the owner or operator obtains fuel 
receipts as described in Sec. 60.49b(r).

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51820, 51825, Dec. 18, 
1989]



Sec. 60.46b  Compliance and performance test methods and procedures for particulate matter and nitrogen oxides.

    (a) The particulate matter emission standards and opacity limits 
under Sec. 60.43b apply at all times except during periods of startup, 
shutdown, or malfunction. The nitrogen oxides emission standards under 
Sec. 60.44b apply at all times.
    (b) Compliance with the particulate matter emission standards under 
Sec. 60.43b shall be determined through performance testing as described 
in paragraph (d) of this section.
    (c) Compliance with the nitrogen oxides emission standards under 
Sec. 60.44b shall be determined through performance testing under 
paragraph (e) or (f), or under paragraphs (g) and (h) of this section, 
as applicable.
    (d) To determine compliance with the particulate matter emission 
limits and opacity limits under Sec. 60.43b, the owner or operator of an 
affected facility shall conduct an initial performance test as required 
under Sec. 60.8 using the following procedures and reference methods:
    (1) Method 3B is used for gas analysis when applying Method 5 or 
Method 17.
    (2) Method 5, Method 5B, or Method 17 shall be used to measure the 
concentration of particulate matter as follows:
    (i) Method 5 shall be used at affected facilities without wet flue 
gas desulfurization (FGD) systems; and
    (ii) Method 17 may be used at facilities with or without wet 
scrubber systems provided the stack gas temperature does not exceed a 
temperature of 160  deg.C (320  deg.F). The procedures of sections 2.1 
and 2.3 of Method 5B may be used in Method 17 only if it is used after a 
wet FGD system. Do not use Method 17 after wet FGD systems if the 
effluent is saturated or laden with water droplets.
    (iii) Method 5B is to be used only after wet FGD systems.
    (3) Method 1 is used to select the sampling site and the number of 
traverse sampling points. The sampling time for each run is at least 120 
minutes and the minimum sampling volume is 1.7 dscm (60 dscf) except 
that smaller sampling times or volumes may be approved by the 
Administrator when necessitated by process variables or other factors.
    (4) For Method 5, the temperature of the sample gas in the probe and 
filter holder is monitored and is maintained at 160  deg.C (320  deg.F).
    (5) For determination of particulate matter emissions, the oxygen or 
carbon dioxide sample is obtained simultaneously with each run of Method 
5, Method 5B or Method 17 by traversing the duct at the same sampling 
location.
    (6) For each run using Method 5, Method 5B or Method 17, the 
emission

[[Page 113]]

rate expressed in nanograms per joule heat input is determined using:
    (i) The oxygen or carbon dioxide measurements and particulate matter 
measurements obtained under this section,
    (ii) The dry basis F factor, and
    (iii) The dry basis emission rate calculation procedure contained in 
Method 19 (appendix A).
    (7) Method 9 is used for determining the opacity of stack emissions.
    (e) To determine compliance with the emission limits for nitrogen 
oxides required under Sec. 60.44b, the owner or operator of an affected 
facility shall conduct the performance test as required under Sec. 60.8 
using the continuous system for monitoring nitrogen oxides under 
Sec. 60.48(b).
    (1) For the initial compliance test, nitrogen oxides from the steam 
generating unit are monitored for 30 successive steam generating unit 
operating days and the 30-day average emission rate is used to determine 
compliance with the nitrogen oxides emission standards under 
Sec. 60.44b. The 30-day average emission rate is calculated as the 
average of all hourly emissions data recorded by the monitoring system 
during the 30-day test period.
    (2) Following the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of this part, 
whichever date comes first, the owner or operator of an affected 
facility which combusts coal or which combusts residual oil having a 
nitrogen content greater than 0.30 weight percent shall determine 
compliance with the nitrogen oxides emission standards under Sec. 60.44b 
on a continuous basis through the use of a 30-day rolling average 
emission rate. A new 30-day rolling average emission rate is calculated 
each steam generating unit operating day as the average of all of the 
hourly nitrogen oxides emission data for the preceding 30 steam 
generating unit operating days.
    (3) Following the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of this part, 
whichever date comes first, the owner or operator of an affected 
facility which has a heat input capacity greater than 73 MW (250 million 
Btu/hour) and which combusts natural gas, distillate oil, or residual 
oil having a nitrogen content of 0.30 weight percent or less shall 
determine compliance with the nitrogen oxides standards under 
Sec. 60.44b on a continuous basis through the use of a 30-day rolling 
average emission rate. A new 30-day rolling average emission rate is 
calculated each steam generating unit operating day as the average of 
all of the hourly nitrogen oxides emission data for the preceding 30 
steam generating unit operating days.
    (4) Following the date on which the initial performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, the owner or operator of an affected 
facility which has a heat input capacity of 73 MW (250 million Btu/hour) 
or less and which combusts natural gas, distillate oil, or residual oil 
having a nitrogen content of 0.30 weight percent or less shall upon 
request determine compliance with the nitrogen oxides standards under 
Sec. 60.44b through the use of a 30-day performance test. During periods 
when performance tests are not requested, nitrogen oxides emissions data 
collected pursuant to Sec. 60.48b(g)(1) or Sec. 60.48b(g)(2) are used to 
calculate a 30-day rolling average emission rate on a daily basis and 
used to prepare excess emission reports, but will not be used to 
determine compliance with the nitrogen oxides emission standards. A new 
30-day rolling average emission rate is calculated each steam generating 
unit operating day as the average of all of the hourly nitrogen oxides 
emission data for the preceding 30 steam generating unit operating days.
    (5) If the owner or operator of an affected facility which combusts 
residual oil does not sample and analyze the residual oil for nitrogen 
content, as specified in Sec. 60.49b(e), the requirements of paragraph 
(iii) of this section apply and the provisions of paragraph (iv) of this 
section are inapplicable.
    (f) To determine compliance with the emission limit for nitrogen 
oxides required by Sec. 60.44b(a)(4) for duct burners used in combined 
cycle systems, the owner or operator of an affected facility shall 
conduct the performance test required under Sec. 60.8 using the nitrogen

[[Page 114]]

oxides and oxygen measurement procedures in 40 CFR part 60 appendix A, 
Method 20. During the performance test, one sampling site shall be 
located as close as practicable to the exhaust of the turbine, as 
provided by section 6.1.1 of Method 20. A second sampling site shall be 
located at the outlet to the steam generating unit. Measurements of 
nitrogen oxides and oxygen shall be taken at both sampling sites during 
the performance test. The nitrogen oxides emission rate from the 
combined cycle system shall be calculated by subtracting the nitrogen 
oxides emission rate measured at the sampling site at the outlet from 
the turbine from the nitrogen oxides emission rate measured at the 
sampling site at the outlet from the steam generating unit.
    (g) The owner or operator of an affected facility described in 
Sec. 60.44b(j) or Sec. 60.44b(k) shall demonstrate the maximum heat 
input capacity of the steam generating unit by operating the facility at 
maximum capacity for 24 hours. The owner or operator of an affected 
facility shall determine the maximum heat input capacity using the heat 
loss method described in sections 5 and 7.3 of the ASME Power Test Codes 
4.1 (see IBR Sec. 60.17(h)). This demonstration of maximum heat input 
capacity shall be made during the initial performance test for affected 
facilities that meet the criteria of Sec. 60.44b(j). It shall be made 
within 60 days after achieving the maximum production rate at which the 
affected facility will be operated, but not later than 180 days after 
initial start-up of each facility, for affected facilities meeting the 
criteria of Sec. 60.44b(k). Subsequent demonstrations may be required by 
the Administrator at any other time. If this demonstration indicates 
that the maximum heat input capacity of the affected facility is less 
than that stated by the manufacturer of the affected facility, the 
maximum heat input capacity determined during this demonstration shall 
be used to determine the capacity utilization rate for the affected 
facility. Otherwise, the maximum heat input capacity provided by the 
manufacturer is used.
    (h) The owner or operator of an affected facility described in 
Sec. 60.44b(j) that has a heat input capacity greater than 73 MW (250 
million Btu/hour) shall:
    (1) Conduct an initial performance test as required under Sec. 60.8 
over a minimum of 24 consecutive steam generating unit operating hours 
at maximum heat input capacity to demonstrate compliance with the 
nitrogen oxides emission standards under Sec. 60.44b using Method 7, 7A, 
7E, or other approved reference methods; and
    (2) Conduct subsequent performance tests once per calendar year or 
every 400 hours of operation (whichever comes first) to demonstrate 
compliance with the nitrogen oxides emission standards under Sec. 60.44b 
over a minimum of 3 consecutive steam generating unit operating hours at 
maximum heat input capacity using Method 7, 7A, 7E, or other approved 
reference methods.

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51820, 51825, Dec. 18, 
1989; 55 FR 18876, May 7, 1990]



Sec. 60.47b  Emission monitoring for sulfur dioxide.

    (a) Except as provided in paragraphs (b) and (f) of this section, 
the owner or operator of an affected facility subject to the sulfur 
dioxide standards under Sec. 60.42b shall install, calibrate, maintain, 
and operate continuous emission monitoring systems (CEMS) for measuring 
sulfur dioxide concentrations and either oxygen (O2) or 
carbon dioxide (CO2) concentrations and shall record the 
output of the systems. The sulfur dioxide and either oxygen or carbon 
dioxide concentrations shall both be monitored at the inlet and outlet 
of the sulfur dioxide control device.
    (b) As an alternative to operating CEMS as required under paragraph 
(a) of this section, an owner or operator may elect to determine the 
average sulfur dioxide emissions and percent reduction by:
    (1) Collecting coal or oil samples in an as-fired condition at the 
inlet to the steam generating unit and analyzing them for sulfur and 
heat content according to Method 19. Method 19 provides procedures for 
converting these measurements into the format to be used in calculating 
the average sulfur dioxide input rate, or

[[Page 115]]

    (2) Measuring sulfur dioxide according to Method 6B at the inlet or 
outlet to the sulfur dioxide control system. An initial stratification 
test is required to verify the adequacy of the Method 6B sampling 
location. The stratification test shall consist of three paired runs of 
a suitable sulfur dioxide and carbon dioxide measurement train operated 
at the candidate location and a second similar train operated according 
to the procedures in section 3.2 and the applicable procedures in 
section 7 of Performance Specification 2. Method 6B, Method 6A, or a 
combination of Methods 6 and 3 or 3B or Methods 6C and 3A are suitable 
measurement techniques. If Method 6B is used for the second train, 
sampling time and timer operation may be adjusted for the stratification 
test as long as an adequate sample volume is collected; however, both 
sampling trains are to be operated similarly. For the location to be 
adequate for Method 6B 24-hour tests, the mean of the absolute 
difference between the three paired runs must be less than 10 percent.
    (3) A daily sulfur dioxide emission rate, ED, shall be 
determined using the procedure described in Method 6A, section 7.6.2 
(Equation 6A-8) and stated in ng/J (lb/million Btu) heat input.
    (4) The mean 30-day emission rate is calculated using the daily 
measured values in ng/J (lb/million Btu) for 30 successive steam 
generating unit operating days using equation 19-20 of Method 19.
    (c) The owner or operator of an affected facility shall obtain 
emission data for at least 75 percent of the operating hours in at least 
22 out of 30 successive boiler operating days. If this minimum data 
requirement is not met with a single monitoring system, the owner or 
operator of the affected facility shall supplement the emission data 
with data collected with other monitoring systems as approved by the 
Administrator or the reference methods and procedures as described in 
paragraph (b) of this section.
    (d) The 1-hour average sulfur dioxide emission rates measured by the 
CEMS required by paragraph (a) of this section and required under 
Sec. 60.13(h) is expressed in ng/J or lb/million Btu heat input and is 
used to calculate the average emission rates under Sec. 60.42b. Each 1-
hour average sulfur dioxide emission rate must be based on more than 30 
minutes of steam generating unit operation and include at least 2 data 
points with each representing a 15-minute period. Hourly sulfur dioxide 
emission rates are not calculated if the affected facility is operated 
less than 30 minutes in a 1-hour period and are not counted toward 
determination of a steam generating unit operating day.
    (e) The procedures under Sec. 60.13 shall be followed for 
installation, evaluation, and operation of the CEMS.
    (1) All CEMS shall be operated in accordance with the applicable 
procedures under Performance Specifications 1, 2, and 3 (appendix B).
    (2) Quarterly accuracy determinations and daily calibration drift 
tests shall be performed in accordance with Procedure 1 (appendix F).
    (3) For affected facilities combusting coal or oil, alone or in 
combination with other fuels, the span value of the sulfur dioxide CEMS 
at the inlet to the sulfur dioxide control device is 125 percent of the 
maximum estimated hourly potential sulfur dioxide emissions of the fuel 
combusted, and the span value of the CEMS at the outlet to the sulfur 
dioxide control device is 50 percent of the maximum estimated hourly 
potential sulfur dioxide emissions of the fuel combusted.
    (f) The owner or operator of an affected facility that combusts very 
low sulfur oil is not subject to the emission monitoring requirements of 
this section if the owner or operator obtains fuel receipts as described 
in Sec. 60.49b(r).

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51820, Dec. 18, 1989; 
55 FR 5212, Feb. 14, 1990; 55 FR 18876, May 7, 1990]



Sec. 60.48b  Emission monitoring for particulate matter and nitrogen oxides.

    (a) The owner or operator of an affected facility subject to the 
opacity standard under Sec. 60.43b shall install, calibrate, maintain, 
and operate a continuous monitoring system for measuring the opacity of 
emissions discharged to the atmosphere and record the output of the 
system.
    (b) Except as provided under paragraphs (g), (h), and (i) of this 
section,

[[Page 116]]

the owner or operator of an affected facility shall comply with either 
paragraphs (b)(1) or (b)(2) of this section.
    (1) Install, calibrate, maintain, and operate a continuous 
monitoring system, and record the output of the system, for measuring 
nitrogen oxides emissions discharged to the atmosphere; or
    (2) If the owner or operator has installed a nitrogen oxides 
emission rate continuous emission monitoring system (CEMS) to meet the 
requirements of part 75 of this chapter and is continuing to meet the 
ongoing requirements of part 75 of this chapter, that CEMS may be used 
to meet the requirements of this section, except that the owner or 
operator shall also meet the requirements of Sec. 60.49b. Data reported 
to meet the requirements of Sec. 60.49b shall not include data 
substituted using the missing data procedures in subpart D of part 75 of 
this chapter, nor shall the data have been bias adjusted according to 
the procedures of part 75 of this chapter.
    (c) The continuous monitoring systems required under paragraph (b) 
of this section shall be operated and data recorded during all periods 
of operation of the affected facility except for continuous monitoring 
system breakdowns and repairs. Data is recorded during calibration 
checks, and zero and span adjustments.
    (d) The 1-hour average nitrogen oxides emission rates measured by 
the continuous nitrogen oxides monitor required by paragraph (b) of this 
section and required under Sec. 60.13(h) shall be expressed in ng/J or 
lb/million Btu heat input and shall be used to calculate the average 
emission rates under Sec. 60.44b. The 1-hour averages shall be 
calculated using the data points required under Sec. 60.13(b). At least 
2 data points must be used to calculate each 1-hour average.
    (e) The procedures under Sec. 60.13 shall be followed for 
installation, evaluation, and operation of the continuous monitoring 
systems.
    (1) For affected facilities combusting coal, wood or municipal-type 
solid waste, the span value for a continuous monitoring system for 
measuring opacity shall be between 60 and 80 percent.
    (2) For affected facilities combusting coal, oil, or natural gas, 
the span value for nitrogen oxides is determined as follows:

------------------------------------------------------------------------
                                                        Span values for
                         Fuel                           nitrogen oxides
                                                             (PPM)
------------------------------------------------------------------------
Natural gas..........................................                500
Oil..................................................                500
Coal.................................................              1,000
Mixtures.............................................    500(x+y)+1,000z
------------------------------------------------------------------------

where:

x is the fraction of total heat input derived from natural gas,
y is the fraction of total heat input derived from oil, and
z is the fraction of total heat input derived from coal.

    (3) All span values computed under paragraph (e)(2) of this section 
for combusting mixtures of regulated fuels are rounded to the nearest 
500 ppm.
    (f) When nitrogen oxides emission data are not obtained because of 
continuous monitoring system breakdowns, repairs, calibration checks and 
zero and span adjustments, emission data will be obtained by using 
standby monitoring systems, Method 7, Method 7A, or other approved 
reference methods to provide emission data for a minimum of 75 percent 
of the operating hours in each steam generating unit operating day, in 
at least 22 out of 30 successive steam generating unit operating days.
    (g) The owner or operator of an affected facility that has a heat 
input capacity of 73 MW (250 million Btu/hour) or less, and which has an 
annual capacity factor for residual oil having a nitrogen content of 
0.30 weight percent or less, natural gas, distillate oil, or any mixture 
of these fuels, greater than 10 percent (0.10) shall:
    (1) Comply with the provisions of paragraphs (b), (c), (d), (e)(2), 
(e)(3), and (f) of this section, or
    (2) Monitor steam generating unit operating conditions and predict 
nitrogen oxides emission rates as specified in a plan submitted pursuant 
to Sec. 60.49b(c).
    (h) The owner or operator of an affected facility which is subject 
to the nitrogen oxides standards of Sec. 60.44b(a)(4) is not required to 
install or operate a continuous monitoring system to measure nitrogen 
oxides emissions.
    (i) The owner or operator of an affected facility described in 
Sec. 60.44b(j) or

[[Page 117]]

Sec. 60.44b(k) is not required to install or operate a continuous 
monitoring system for measuring nitrogen oxides emissions.

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51825, Dec. 18, 1989; 
63 FR 49455, Sept. 16, 1998]



Sec. 60.49b  Reporting and recordkeeping requirements.

    (a) The owner or operator of each affected facility shall submit 
notification of the date of initial startup, as provided by Sec. 60.7. 
This notification shall include:
    (1) The design heat input capacity of the affected facility and 
identification of the fuels to be combusted in the affected facility,
    (2) If applicable, a copy of any Federally enforceable requirement 
that limits the annual capacity factor for any fuel or mixture of fuels 
under Secs. 60.42b(d)(1), 60.43b(a)(2), (a)(3)(iii), (c)(2)(ii), 
(d)(2)(iii), 60.44b(c), (d), (e), (i), (j), (k), 60.45b(d), (g), 
60.46b(h), or 60.48b(i),
    (3) The annual capacity factor at which the owner or operator 
anticipates operating the facility based on all fuels fired and based on 
each individual fuel fired, and,
    (4) Notification that an emerging technology will be used for 
controlling emissions of sulfur dioxide. The Administrator will examine 
the description of the emerging technology and will determine whether 
the technology qualifies as an emerging technology. In making this 
determination, the Administrator may require the owner or operator of 
the affected facility to submit additional information concerning the 
control device. The affected facility is subject to the provisions of 
Sec. 60.42b(a) unless and until this determination is made by the 
Administrator.
    (b) The owner or operator of each affected facility subject to the 
sulfur dioxide, particulate matter, and/or nitrogen oxides emission 
limits under Secs. 60.42b, 60.43b, and 60.44b shall submit to the 
Administrator the performance test data from the initial performance 
test and the performance evaluation of the CEMS using the applicable 
performance specifications in appendix B. The owner or operator of each 
affected facility described in Sec. 60.44b(j) or Sec. 60.44b(k) shall 
submit to the Administrator the maximum heat input capacity data from 
the demonstration of the maximum heat input capacity of the affected 
facility.
    (c) The owner or operator of each affected facility subject to the 
nitrogen oxides standard of Sec. 60.44b who seeks to demonstrate 
compliance with those standards through the monitoring of steam 
generating unit operating conditions under the provisions of 
Sec. 60.48b(g)(2) shall submit to the Administrator for approval a plan 
that identifies the operating conditions to be monitored under 
Sec. 60.48b(g)(2) and the records to be maintained under Sec. 60.49b(j). 
This plan shall be submitted to the Administrator for approval within 
360 days of the initial startup of the affected facility. The plan 
shall:
    (1) Identify the specific operating conditions to be monitored and 
the relationship between these operating conditions and nitrogen oxides 
emission rates (i.e., ng/J or lbs/million Btu heat input). Steam 
generating unit operating conditions include, but are not limited to, 
the degree of staged combustion (i.e., the ratio of primary air to 
secondary and/or tertiary air) and the level of excess air (i.e., flue 
gas oxygen level);
    (2) Include the data and information that the owner or operator used 
to identify the relationship between nitrogen oxides emission rates and 
these operating conditions;
    (3) Identify how these operating conditions, including steam 
generating unit load, will be monitored under Sec. 60.48b(g) on an 
hourly basis by the owner or operator during the period of operation of 
the affected facility; the quality assurance procedures or practices 
that will be employed to ensure that the data generated by monitoring 
these operating conditions will be representative and accurate; and the 
type and format of the records of these operating conditions, including 
steam generating unit load, that will be maintained by the owner or 
operator under Sec. 60.49b(j).

If the plan is approved, the owner or operator shall maintain records of 
predicted nitrogen oxide emission rates

[[Page 118]]

and the monitored operating conditions, including steam generating unit 
load, identified in the plan.
    (d) The owner or operator of an affected facility shall record and 
maintain records of the amounts of each fuel combusted during each day 
and calculate the annual capacity factor individually for coal, 
distillate oil, residual oil, natural gas, wood, and municipal-type 
solid waste for the reporting period. The annual capacity factor is 
determined on a 12-month rolling average basis with a new annual 
capacity factor calculated at the end of each calendar month.
    (e) For an affected facility that combusts residual oil and meets 
the criteria under Secs. 60.46b(e)(4), 60.44b (j), or (k), the owner or 
operator shall maintain records of the nitrogen content of the residual 
oil combusted in the affected facility and calculate the average fuel 
nitrogen content for the reporting period. The nitrogen content shall be 
determined using ASTM Method D3431-80, Test Method for Trace Nitrogen in 
Liquid Petroleum Hydrocarbons (IBR-see Sec. 60.17), or fuel suppliers. 
If residual oil blends are being combusted, fuel nitrogen specifications 
may be prorated based on the ratio of residual oils of different 
nitrogen content in the fuel blend.
    (f) For facilities subject to the opacity standard under 
Sec. 60.43b, the owner or operator shall maintain records of opacity.
    (g) Except as provided under paragraph (p) of this section, the 
owner or operator of an affected facility subject to the nitrogen oxides 
standards under Sec. 60.44b shall maintain records of the following 
information for each steam generating unit operating day:
    (1) Calendar date.
    (2) The average hourly nitrogen oxides emission rates (expressed as 
NO2) (ng/J or lb/million Btu heat input) measured or 
predicted.
    (3) The 30-day average nitrogen oxides emission rates (ng/J or lb/
million Btu heat input) calculated at the end of each steam generating 
unit operating day from the measured or predicted hourly nitrogen oxide 
emission rates for the preceding 30 steam generating unit operating 
days.
    (4) Identification of the steam generating unit operating days when 
the calculated 30-day average nitrogen oxides emission rates are in 
excess of the nitrogen oxides emissions standards under Sec. 60.44b, 
with the reasons for such excess emissions as well as a description of 
corrective actions taken.
    (5) Identification of the steam generating unit operating days for 
which pollutant data have not been obtained, including reasons for not 
obtaining sufficient data and a description of corrective actions taken.
    (6) Identification of the times when emission data have been 
excluded from the calculation of average emission rates and the reasons 
for excluding data.
    (7) Identification of ``F'' factor used for calculations, method of 
determination, and type of fuel combusted.
    (8) Identification of the times when the pollutant concentration 
exceeded full span of the continuous monitoring system.
    (9) Description of any modifications to the continuous monitoring 
system that could affect the ability of the continuous monitoring system 
to comply with Performance Specification 2 or 3.
    (10) Results of daily CEMS drift tests and quarterly accuracy 
assessments as required under appendix F, Procedure 1.
    (h) The owner or operator of any affected facility in any category 
listed in paragraphs (h) (1) or (2) of this section is required to 
submit excess emission reports for any excess emissions which occurred 
during the reporting period.
    (1) Any affected facility subject to the opacity standards under 
Sec. 60.43b(e) or to the operating parameter monitoring requirements 
under Sec. 60.13(i)(1).
    (2) Any affected facility that is subject to the nitrogen oxides 
standard of Sec. 60.44b, and that
    (i) Combusts natural gas, distillate oil, or residual oil with a 
nitrogen content of 0.3 weight percent or less, or
    (ii) Has a heat input capacity of 73 MW (250 million Btu/hour) or 
less and is required to monitor nitrogen oxides emissions on a 
continuous basis under Sec. 60.48b(g)(1) or steam generating unit 
operating conditions under Sec. 60.48b(g)(2).

[[Page 119]]

    (3) For the purpose of Sec. 60.43b, excess emissions are defined as 
all 6-minute periods during which the average opacity exceeds the 
opacity standards under Sec. 60.43b(f).
    (4) For purposes of Sec. 60.48b(g)(1), excess emissions are defined 
as any calculated 30-day rolling average nitrogen oxides emission rate, 
as determined under Sec. 60.46b(e), which exceeds the applicable 
emission limits in Sec. 60.44b.
    (i) The owner or operator of any affected facility subject to the 
continuous monitoring requirements for nitrogen oxides under 
Sec. 60.48(b) shall submit reports containing the information recorded 
under paragraph (g) of this section.
    (j) The owner or operator of any affected facility subject to the 
sulfur dioxide standards under Sec. 60.42b shall submit reports.
    (k) For each affected facility subject to the compliance and 
performance testing requirements of Sec. 60.45b and the reporting 
requirement in paragraph (j) of this section, the following information 
shall be reported to the Administrator:
    (1) Calendar dates covered in the reporting period.
    (2) Each 30-day average sulfur dioxide emission rate (ng/J or 1b/
million Btu heat input) measured during the reporting period, ending 
with the last 30-day period; reasons for noncompliance with the emission 
standards; and a description of corrective actions taken.
    (3) Each 30-day average percent reduction in sulfur dioxide 
emissions calculated during the reporting period, ending with the last 
30-day period; reasons for noncompliance with the emission standards; 
and a description of corrective actions taken.
    (4) Identification of the steam generating unit operating days that 
coal or oil was combusted and for which sulfur dioxide or diluent 
(oxygen or carbon dioxide) data have not been obtained by an approved 
method for at least 75 percent of the operating hours in the steam 
generating unit operating day; justification for not obtaining 
sufficient data; and description of corrective action taken.
    (5) Identification of the times when emissions data have been 
excluded from the calculation of average emission rates; justification 
for excluding data; and description of corrective action taken if data 
have been excluded for periods other than those during which coal or oil 
were not combusted in the steam generating unit.
    (6) Identification of ``F'' factor used for calculations, method of 
determination, and type of fuel combusted.
    (7) Identification of times when hourly averages have been obtained 
based on manual sampling methods.
    (8) Identification of the times when the pollutant concentration 
exceeded full span of the CEMS.
    (9) Description of any modifications to the CEMS that could affect 
the ability of the CEMS to comply with Performance Specification 2 or 3.
    (10) Results of daily CEMS drift tests and quarterly accuracy 
assessments as required under appendix F, Procedure 1.
    (11) The annual capacity factor of each fired as provided under 
paragraph (d) of this section.
    (l) For each affected facility subject to the compliance and 
performance testing requirements of Sec. 60.45b(d) and the reporting 
requirements of paragraph (j) of this section, the following information 
shall be reported to the Administrator:
    (1) Calendar dates when the facility was in operation during the 
reporting period;
    (2) The 24-hour average sulfur dioxide emission rate measured for 
each steam generating unit operating day during the reporting period 
that coal or oil was combusted, ending in the last 24-hour period in the 
quarter; reasons for noncompliance with the emission standards; and a 
description of corrective actions taken;
    (3) Identification of the steam generating unit operating days that 
coal or oil was combusted for which sulfur dioxide or diluent (oxygen or 
carbon dioxide) data have not been obtained by an approved method for at 
least 75 percent of the operating hours; justification for not obtaining 
sufficient data; and description of corrective action taken.
    (4) Identification of the times when emissions data have been 
excluded from the calculation of average emission rates; justification 
for excluding

[[Page 120]]

data; and description of corrective action taken if data have been 
excluded for periods other than those during which coal or oil were not 
combusted in the steam generating unit.
    (5) Identification of ``F'' factor used for calculations, method of 
determination, and type of fuel combusted.
    (6) Identification of times when hourly averages have been obtained 
based on manual sampling methods.
    (7) Identification of the times when the pollutant concentration 
exceeded full span of the CEMS.
    (8) Description of any modifications to the CEMS which could affect 
the ability of the CEMS to comply with Performance Specification 2 or 3.
    (9) Results of daily CEMS drift tests and quarterly accuracy 
assessments as required under appendix F, Procedure 1.
    (m) For each affected facility subject to the sulfur dioxide 
standards under Sec. 60.42(b) for which the minimum amount of data 
required under Sec. 60.47b(f) were not obtained during the reporting 
period, the following information is reported to the Administrator in 
addition to that required under paragraph (k) of this section:
    (1) The number of hourly averages available for outlet emission 
rates and inlet emission rates.
    (2) The standard deviation of hourly averages for outlet emission 
rates and inlet emission rates, as determined in Method 19, section 7.
    (3) The lower confidence limit for the mean outlet emission rate and 
the upper confidence limit for the mean inlet emission rate, as 
calculated in Method 19, section 7.
    (4) The ratio of the lower confidence limit for the mean outlet 
emission rate and the allowable emission rate, as determined in Method 
19, section 7.
    (n) If a percent removal efficiency by fuel pretreatment (i.e., % 
Rf) is used to determine the overall percent reduction (i.e., 
% Ro) under Sec. 60.45b, the owner or operator of the 
affected facility shall submit a signed statement with the report.
    (1) Indicating what removal efficiency by fuel pretreatment (i.e., % 
Rf) was credited during the reporting period;
    (2) Listing the quantity, heat content, and date each pre-treated 
fuel shipment was received during the reporting period, the name and 
location of the fuel pretreatment facility; and the total quantity and 
total heat content of all fuels received at the affected facility during 
the reporting period.
    (3) Documenting the transport of the fuel from the fuel pretreatment 
facility to the steam generating unit.
    (4) Including a signed statement from the owner or operator of the 
fuel pretreatment facility certifying that the percent removal 
efficiency achieved by fuel pretreatment was determined in accordance 
with the provisions of Method 19 (appendix A) and listing the heat 
content and sulfur content of each fuel before and after fuel 
pretreatment.
    (o) All records required under this section shall be maintained by 
the owner or operator of the affected facility for a period of 2 years 
following the date of such record.
    (p) The owner or operator of an affected facility described in 
Sec. 60.44b(j) or (k) shall maintain records of the following 
information for each steam generating unit operating day:
    (1) Calendar date,
    (2) The number of hours of operation, and
    (3) A record of the hourly steam load.
    (q) The owner or operator of an affected facility described in 
Sec. 60.44b(j) or Sec. 60.44b(k) shall submit to the Administrator a 
report containing:
    (1) The annual capacity factor over the previous 12 months;
    (2) The average fuel nitrogen content during the reporting period, 
if residual oil was fired; and
    (3) If the affected facility meets the criteria described in 
Sec. 60.44b(j), the results of any nitrogen oxides emission tests 
required during the reporting period, the hours of operation during the 
reporting period, and the hours of operation since the last nitrogen 
oxides emission test.
    (r) The owner or operator of an affected facility who elects to 
demonstrate that the affected facility combusts only very low sulfur oil 
under Sec. 60.42b(j)(2) shall obtain and maintain at the affected 
facility fuel receipts from the fuel supplier which certify

[[Page 121]]

that the oil meets the definition of distillate oil as defined in 
Sec. 60.41b. For the purposes of this section, the oil need not meet the 
fuel nitrogen content specification in the definition of distillate oil. 
Reports shall be submitted to the Administrator certifying that only 
very low sulfur oil meeting this definition was combusted in the 
affected facility during the reporting period.
    (s) The reporting period for the reports required under this subpart 
is each six-month period. All reports shall be submitted to the 
Administrator and shall be postmarked by the 30th day following the end 
of the reporting period.
    (t) Facility-specific nitrogen oxides standard for Rohm and Haas 
Kentucky Incorporated's Boiler No. 100 located in Louisville, Kentucky:
    (1) Definitions.
    Air ratio control damper is defined as the part of the low nitrogen 
oxides burner that is adjusted to control the split of total combustion 
air delivered to the reducing and oxidation portions of the combustion 
flame.
    Flue gas recirculation line is defined as the part of Boiler No. 100 
that recirculates a portion of the boiler flue gas back into the 
combustion air.
    (2) Standard for nitrogen oxides. (i) When fossil fuel alone is 
combusted, the nitrogen oxides emission limit for fossil fuel in 
Sec. 60.44b(a) applies.
    (ii) When fossil fuel and chemical by-product waste are 
simultaneously combusted, the nitrogen oxides emission limit is 473 ng/J 
(1.1 lb/million Btu), and the air ratio control damper tee handle shall 
be at a minimum of 5 inches (12.7 centimeters) out of the boiler, and 
the flue gas recirculation line shall be operated at a minimum of 10 
percent open as indicated by its valve opening position indicator.
    (3) Emission monitoring for nitrogen oxides. (i) The air ratio 
control damper tee handle setting and the flue gas recirculation line 
valve opening position indicator setting shall be recorded during each 
8-hour operating shift.
    (ii) The nitrogen oxides emission limit shall be determined by the 
compliance and performance test methods and procedures for nitrogen 
oxides in Sec. 60.46b.
    (iii) The monitoring of the nitrogen oxides emission limit shall be 
performed in accordance with Sec. 60.48b.
    (4) Reporting and recordkeeping requirements. (i) The owner or 
operator of Boiler No. 100 shall submit a report on any excursions from 
the limits required by paragraph (b)(2) of this section to the 
Administrator with the quarterly report required by Sec. 60.49b(i).
    (ii) The owner or operator of Boiler No. 100 shall keep records of 
the monitoring required by paragraph (b)(3) of this section for a period 
of 2 years following the date of such record.
    (iii) The owner of operator of Boiler No. 100 shall perform all the 
applicable reporting and recordkeeping requirements of Sec. 60.49b.
    (u) Site-specific standard for Merck & Co., Inc.'s Stonewall Plant 
in Elkton, Virginia. (1) This paragraph applies only to the 
pharmaceutical manufacturing facility, commonly referred to as the 
Stonewall Plant, located at Route 340 South, in Elkton, Virginia 
(``site'') and only to the natural gas-fired boilers installed as part 
of the powerhouse conversion required pursuant to 40 CFR 52.2454(g). The 
requirements of this paragraph shall apply, and the requirements of 
Secs. 60.40b through 60.49b(t) shall not apply, to the natural gas-fired 
boilers installed pursuant to 40 CFR 52.2454(g).
    (i) The site shall equip the natural gas-fired boilers with low 
nitrogen oxide (NOX) technology.
    (ii) The site shall install, calibrate, maintain, and operate a 
continuous monitoring and recording system for measuring NOX 
emissions discharged to the atmosphere and opacity using a continuous 
emissions monitoring system or a predictive emissions monitoring system.
    (iii) Within 180 days of the completion of the powerhouse 
conversion, as required by 40 CFR 52.2454, the site shall perform a 
stack test to quantify criteria pollutant emissions.
    (2) [Reserved]
    (v) The owner or operator of an affected facility may submit 
electronic quarterly reports for SO2 and/or NOX 
and/or opacity in lieu of submitting the written reports required under 
paragraphs (h), (i), (j), (k) or (l) of this section. The format of each 
quarterly

[[Page 122]]

electronic report shall be coordinated with the permitting authority. 
The electronic report(s) shall be submitted no later than 30 days after 
the end of the calendar quarter and shall be accompanied by a 
certification statement from the owner or operator, indicating whether 
compliance with the applicable emission standards and minimum data 
requirements of this subpart was achieved during the reporting period. 
Before submitting reports in the electronic format, the owner or 
operator shall coordinate with the permitting authority to obtain their 
agreement to submit reports in this alternative format.

[52 FR 47842, Dec. 16, 1987, as amended at 54 FR 51820, 51825, Dec. 18, 
1989; 60 FR 28062, May 30, 1995; 61 FR 14031, Mar. 29, 1996; 62 FR 
52641, Oct. 8, 1997; 63 FR 49455, Sept. 16, 1998; 64 FR 7464, Feb. 12, 
1999]



  Subpart Dc--Standards of Performance for Small Industrial-Commercial-
                  Institutional Steam Generating Units

    Source: 55 FR 37683, Sept. 12, 1990, unless otherwise noted.



Sec. 60.40c  Applicability and delegation of authority.

    (a) Except as provided in paragraph (d) of this section, the 
affected facility to which this subpart applies is each steam generating 
unit for which construction, modification, or reconstruction is 
commenced after June 9, 1989 and that has a maximum design heat input 
capacity of 29 megawatts (MW) (100 million Btu per hour (Btu/hr)) or 
less, but greater than or equal to 2.9 MW (10 million Btu/hr).
    (b) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Clean Air Act, Sec. 60.48c(a)(4) shall 
be retained by the Administrator and not transferred to a State.
    (c) Steam generating units which meet the applicability requirements 
in paragraph (a) of this section are not subject to the sulfur dioxide 
(SO2) or particulate matter (PM) emission limits, performance 
testing requirements, or monitoring requirements under this subpart 
(Secs. 60.42c, 60.43c, 60.44c, 60.45c, 60.46c, or 60.47c) during periods 
of combustion research, as defined in Sec. 60.41c.
    (d) Any temporary change to an existing steam generating unit for 
the purpose of conducting combustion research is not considered a 
modification under Sec. 60.14.

[55 FR 37683, Sept. 12, 1990, as amended at 61 FR 20736, May 8, 1996]



Sec. 60.41c  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Clean Air Act and in subpart A of this part.
    Annual capacity factor means the ratio between the actual heat input 
to a steam generating unit from an individual fuel or combination of 
fuels during a period of 12 consecutive calendar months and the 
potential heat input to the steam generating unit from all fuels had the 
steam ch a separate source (such as a stationary gas turbine, internal 
combustion engine, or kiln) provides exhaust gas to a steam generating 
unit.
    Coal means all solid fuels classified as anthracite, bituminous, 
subbituminous, or lignite by the American Society for Testing and 
Materials in ASTM D388-77, ``Standard Specification for Classification 
of Coals by Rank'' (incorporated by reference--see Sec. 60.17); coal 
refuse; and petroleum coke. Synthetic fuels derived from coal for the 
purpose of creating useful heat, including but not limited to solvent-
refined coal, gasified coal, coal-oil mixtures, and coal-water mixtures, 
are included in this definition for the purposes of this subpart.
    Coal refuse means any by-product of coal mining or coal cleaning 
operations with an ash content greater than 50 percent (by weight) and a 
heating value less than 13,900 kilojoules per kilogram (kJ/kg) (6,000 
Btu per pound (Btu/lb) on a dry basis.
    Cogeneration steam generating unit means a steam generating unit 
that simultaneously produces both electrical (or mechanical) and thermal 
energy from the same primary energy source.
    Combined cycle system means a system in which a separate source 
(such as a stationary gas turbine, internal combustion engine, or kiln) 
provides exhaust gas to a steam generating unit.

[[Page 123]]

    Combustion research means the experimental firing of any fuel or 
combination of fuels in a steam generating unit for the purpose of 
conducting research and development of more efficient combustion or more 
effective prevention or control of air pollutant emissions from 
combustion, provided that, during these periods of research and 
development, the heat generated is not used for any purpose other than 
preheating combustion air for use by that steam generating unit (i.e., 
the heat generated is released to the atmosphere without being used for 
space heating, process heating, driving pumps, preheating combustion air 
for other units, generating electricity, or any other purpose).
    Conventional technology means wet flue gas desulfurization 
technology, dry flue gas desulfurization technology, atmospheric 
fluidized bed combustion technology, and oil hydrodesulfurization 
technology.
    Distillate oil means fuel oil that complies with the specifications 
for fuel oil numbers 1 or 2, as defined by the American Society for 
Testing and Materials in ASTM D396-78, ``Standard Specification for Fuel 
Oils'' (incorporated by reference--see Sec. 60.17).
    Dry flue gas desulfurization technology means a sulfur dioxide 
(SO2) control system that is located between the steam 
generating unit and the exhaust vent or stack, and that removes sulfur 
oxides from the combustion gases of the steam generating unit by 
contacting the combustion gases with an alkaline slurry or solution and 
forming a dry powder material. This definition includes devices where 
the dry powder material is subsequently converted to another form. 
Alkaline reagents used in dry flue gas desulfurization systems include, 
but are not limited to, lime and sodium compounds.
    Duct burner means a device that combusts fuel and that is placed in 
the exhaust duct from another source (such as a stationary gas turbine, 
internal combustion engine, kiln, etc.) to allow the firing of 
additional fuel to heat the exhaust gases before the exhaust gases enter 
a steam generating unit.
    Emerging technology means any SO2 control system that is 
not defined as a conventional technology under this section, and for 
which the owner or operator of the affected facility has received 
approval from the Administrator to operate as an emerging technology 
under Sec. 60.48c(a)(4).
    Federally enforceable means all limitations and conditions that are 
enforceable by the Administrator, including the requirements of 40 CFR 
Parts 60 and 61, requirements within any applicable State implementation 
plan, and any permit requirements established under 40 CFR 52.21 or 
under 40 CFR 51.18 and 40 CFR 51.24.
    Fluidized bed combustion technology means a device wherein fuel is 
distributed onto a bed (or series of beds) of limestone aggregate (or 
other sorbent materials) for combustion; and these materials are forced 
upward in the device by the flow of combustion air and the gaseous 
products of combustion. Fluidized bed combustion technology includes, 
but is not limited to, bubbling bed units and circulating bed units.
    Fuel pretreatment means a process that removes a portion of the 
sulfur in a fuel before combustion of the fuel in a steam generating 
unit.
    Heat input means heat derived from combustion of fuel in a steam 
generating unit and does not include the heat derived from preheated 
combustion air, recirculated flue gases, or exhaust gases from other 
sources (such as stationary gas turbines, internal combustion engines, 
and kilns).
    Heat transfer medium means any material that is used to transfer 
heat from one point to another point.
    Maximum design heat input capacity means the ability of a steam 
generating unit to combust a stated maximum amount of fuel (or 
combination of fuels) on a steady state basis as determined by the 
physical design and characteristics of the steam generating unit.
    Natural gas means (1) a naturally occurring mixture of hydrocarbon 
and nonhydrocarbon gases found in geologic formations beneath the 
earth's surface, of which the principal constituent is methane, or (2) 
liquefied petroleum (LP) gas, as defined by the American Society for 
Testing and Materials in ASTM D1835-86, ``Standard Specification for 
Liquefied Petroleum

[[Page 124]]

Gases'' (incorporated by reference--see Sec. 60.17).
    Noncontinental area means the State of Hawaii, the Virgin Islands, 
Guam, American Samoa, the Commonwealth of Puerto Rico, or the Northern 
Mariana Islands.
    Oil means crude oil or petroleum, or a liquid fuel derived from 
crude oil or petroleum, including distillate oil and residual oil.
    Potential sulfur dioxide emission rate means the theoretical 
SO2 emissions (nanograms per joule [ng/J], or pounds per 
million Btu [lb/million Btu] heat input) that would result from 
combusting fuel in an uncleaned state and without using emission control 
systems.
    Process heater means a device that is primarily used to heat a 
material to initiate or promote a chemical reaction in which the 
material participates as a reactant or catalyst.
    Residual oil means crude oil, fuel oil that does not comply with the 
specifications under the definition of distillate oil, and all fuel oil 
numbers 4, 5, and 6, as defined by the American Society for Testing and 
Materials in ASTM D396-78, ``Standard Specification for Fuel Oils'' 
(incorporated by reference--see Sec. 60.17).
    Steam generating unit means a device that combusts any fuel and 
produces steam or heats water or any other heat transfer medium. This 
term includes any duct burner that combusts fuel and is part of a 
combined cycle system. This term does not include process heaters as 
defined in this subpart.
    Steam generating unit operating day means a 24-hour period between 
12:00 midnight and the following midnight during which any fuel is 
combusted at any time in the steam generating unit. It is not necessary 
for fuel to be combusted continuously for the entire 24-hour period.
    Wet flue gas desulfurization technology means an SO2 
control system that is located between the steam generating unit and the 
exhaust vent or stack, and that removes sulfur oxides from the 
combustion gases of the steam generating unit by contacting the 
combustion gases with an alkaline slurry or solution and forming a 
liquid material. This definition includes devices where the liquid 
material is subsequently converted to another form. Alkaline reagents 
used in wet flue gas desulfurization systems include, but are not 
limited to, lime, limestone, and sodium compounds.
    Wet scrubber system means any emission control device that mixes an 
aqueous stream or slurry with the exhaust gases from a steam generating 
unit to control emissions of particulate matter (PM) or SO2.
    Wood means wood, wood residue, bark, or any derivative fuel or 
residue thereof, in any form, including but not limited to sawdust, 
sanderdust, wood chips, scraps, slabs, millings, shavings, and processed 
pellets made from wood or other forest residues.

[55 FR 37683, Sept. 12, 1990, as amended at 61 FR 20736, May 8, 1996]



Sec. 60.42c  Standard for sulfur dioxide.

    (a) Except as provided in paragraphs (b), (c), and (e) of this 
section, on and after the date on which the initial performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, the owner the operator of an affected 
facility that combusts only coal shall neither: (1) cause to be 
discharged into the atmosphere from that affected facility any gases 
that contain SO2 in excess of 10 percent (0.10) of the 
potential SO2 emission rate (90 percent reduction); nor (2) 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain SO2 in excess of 520 ng/J (1.2 lb/
million Btu) heat input. If coal is combusted with other fuels, the 
affected facility is subject to the 90 percent SO2 reduction 
requirement specified in this paragraph and the emission limit is 
determined pursuant to paragraph (e)(2) of this section.
    (b) Except as provided in paragraphs (c) and (e) of this section, on 
and after the date on which the initial performance test is completed or 
required to be completed under Sec. 60.8 of this part, whichever date 
comes first, the owner or operator of an affected facility that:
    (1) Combusts coal refuse alone in a fluidized bed combustion steam 
generating unit shall neither:
    (i) Cause to be discharged into the atmosphere from that affected 
facility any gases that contain SO2 in excess of

[[Page 125]]

20 percent (0.20) of the potential SO2 emission rate (80 
percent reduction); nor
    (ii) Cause to be discharged into the atmosphere from that affected 
facility any gases that contain SO2 in excess of 520 ng/J 
(1.2 lb/million Btu) heat input. If coal is fired with coal refuse, the 
affected facility is subject to paragraph (a) of this section. If oil or 
any other fuel (except coal) is fired with coal refuse, the affected 
facility is subject to the 90 percent SO2 reduction 
requirement specified in paragraph (a) of this section and the emission 
limit determined pursuant to paragraph (e)(2) of this section.
    (2) Combusts only coal and that uses an emerging technology for the 
control of SO2 emissions shall neither:
    (i) Cause to be discharged into the atmosphere from that affected 
facility any gases that contain SO2 in excess of 50 percent 
(0.50) of the potential SO2 emission rate (50 percent 
reduction); nor
    (ii) Cause to be discharged into the atmosphere from that affected 
facility any gases that contain SO2 in excess of 260 ng/J 
(0.60 lb/million Btu) heat input. If coal is combusted with other fuels, 
the affected facility is subject to the 50 percent SO2 
reduction requirement specified in this paragraph and the emission limit 
determined pursuant to paragraph (e)(2) of this section.
    (c) On and after the date on which the initial performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts coal, alone or in combination with any other fuel, and is 
listed in paragraphs (c)(1), (2), (3), or (4) of this section shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain SO2 in excess of the emission limit 
determined pursuant to paragraph (e)(2) of this section. Percent 
reduction requirements are not applicable to affected facilities under 
this paragraph.
    (1) Affected facilities that have a heat input capacity of 22 MW (75 
million Btu/hr) or less.
    (2) Affected facilities that have an annual capacity for coal of 55 
percent (0.55) or less and are subject to a Federally enforceable 
requirement limiting operation of the affected facility to an annual 
capacity factor for coal of 55 percent (0.55) or less.
    (3) Affected facilities located in a noncontinental area.
    (4) Affected facilities that combust coal in a duct burner as part 
of a combined cycle system where 30 percent (0.30) or less of the heat 
entering the steam generating unit is from combustion of coal in the 
duct burner and 70 percent (0.70) or  more  of  the  heat  entering  the 
 steam  gen erating unit is from exhaust gases entering the duct burner.
    (d) On and after the date on which the initial performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts oil shall cause to be discharged into the atmosphere from 
that affected facility any gases that contain SO2 in excess 
of 215 ng/J (0.50 lb/million Btu) heat input; or, as an alternative, no 
owner or operator of an affected facility that combusts oil shall 
combust oil in the affected facility that contains greater than 0.5 
weight percent sulfur. The percent reduction requirements are not 
applicable to affected facilities under this paragraph.
    (e) On and after the date on which the initial performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts coal, oil, or coal and oil with any other fuel shall cause 
to be discharged into the atmosphere from that affected facility any 
gases that contain SO2 in excess of the following:
    (1) The percent of potential SO2 emission rate required 
under paragraph (a) or (b)(2) of this section, as applicable, for any 
affected facility that
    (i) Combusts coal in combination with any other fuel,
    (ii) Has a heat input capacity greater than 22 MW (75 million Btu/
hr), and
    (iii) Has an annual capacity factor for coal greater than 55 percent 
(0.55); and
    (2) The emission limit determined according to the following formula 
for any affected facility that combusts

[[Page 126]]

coal, oil, or coal and oil with any other fuel:

    Es=(Ka Ha+Kb 
Hb+Kc Hc)/
Ha+Hb+Hc)
where:
    Es  is the SO2 emission limit, expressed in 
ng/J or lb/million Btu heat input,
    Ka  is 520 ng/J (1.2 lb/million Btu),
    Kb  is 260 ng/J (0.60 lb/million Btu),
    Kc  is 215 ng/J (0.50 lb/million Btu),
    Ha  is the heat input from the combustion of coal, except 
coal combusted in an affected facility subject to paragraph (b)(2) of 
this section, in Joules (J) [million Btu]
    Hb  is the heat input from the combustion of coal in an 
affected facility subject to paragraph (b)(2) of this section, in J 
(million Btu)
    Hc  is the heat input from the combustion of oil, in J 
(million Btu).

    (f) Reduction in the potential SO2 emission rate through 
fuel pretreatment is not credited toward the percent reduction 
requirement under paragraph (b)(2) of this section unless:
    (1) Fuel pretreatment results in a 50 percent (0.50) or greater 
reduction in the potential SO2 emission rate; and
    (2) Emissions from the pretreated fuel (without either combustion or 
post-combustion SO2 control) are equal to or less than the 
emission limits specified under paragraph (b)(2) of this section.
    (g) Except as provided in paragraph (h) of this section, compliance 
with the percent reduction requirements, fuel oil sulfur limits, and 
emission limits of this section shall be determined on a 30-day rolling 
average basis.
    (h) For affected facilities listed under paragraphs (h)(1), (2), or 
(3) of this section, compliance with the emission limits or fuel oil 
sulfur limits under this section may be determined based on a 
certification from the fuel supplier, as described under 
Sec. 60.48c(f)(1), (2), or (3), as applicable.
    (1) Distillate oil-fired affected facilities with heat input 
capacities between 2.9 and 29 MW (10 and 100 million Btu/hr).
    (2) Residual oil-fired affected facilities with heat input 
capacities between 2.9 and 8.7 MW (10 and 30 million Btu/hr).
    (3) Coal-fired facilities with heat input capacities between 2.9 and 
8.7 MW (10 and 30 million Btu/hr).
    (i) The SO2 emission limits, fuel oil sulfur limits, and 
percent reduction requirements under this section apply at all times, 
including periods of startup, shutdown, and malfunction.
    (j) Only the heat input supplied to the affected facility from the 
combustion of coal and oil is counted under this section. No credit is 
provided for the heat input to the affected facility from wood or other 
fuels or for heat derived from exhaust gases from other sources, such as 
stationary gas turbines, internal combustion engines, and kilns.



Sec. 60.43c  Standard for particulate matter.

    (a) On and after the date on which the initial performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts coal or combusts mixtures of coal with other fuels and has 
a heat input capacity of 8.7 MW (30 million Btu/hr) or greater, shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain PM in excess of the following emission limits:
    (1) 22 ng/J (0.05 lb/million Btu) heat input if the affected 
facility combusts only coal, or combusts coal with other fuels and has 
an annual capacity factor for the other fuels of 10 percent (0.10) or 
less.
    (2) 43 ng/J (0.10 lb/million Btu) heat imput if the affected 
facility combusts coal with other fuels, has an annual capacity factor 
for the other fuels greater than 10 percent (0.10), and is subject to a 
federally enforceable requirement limiting operation of the affected 
facility to an annual capacity factor greater than 10 percent (0.10) for 
fuels other than coal.
    (b) On and after the date on which the initial performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts wood or combusts mixtures of wood with other fuels (except 
coal) and has a heat input capacity of 8.7 MW (30 million Btu/hr) or 
greater, shall cause to be discharged into the atmosphere from that 
affected facility any gases that contain PM in

[[Page 127]]

excess of the following emissions limits:
    (1) 43 ng/J (0.10 lb/million Btu) heat input if the affected 
facility has an annual capacity factor for wood greater than 30 percent 
(0.30); or
    (2) 130 ng/J (0.30 lb/million Btu) heat input if the affected 
facility has an annual capacity factor for wood of 30 percent (0.30) or 
less and is subject to a federally enforceable requirement limiting 
operation of the affected facility to an annual capacity factor for wood 
of 30 percent (0.30) or less.
    (c) On and after the date on which the initial performance test is 
completed or required to be completed under Sec. 60.8 of this part, 
whichever date comes first, no owner or operator of an affected facility 
that combusts coal, wood, or oil and has a heat input capacity of 8.7 MW 
(30 million Btu/hr) or greater shall cause to be discharged into the 
atmosphere from that affected facility any gases that exhibit greater 
than 20 percent opacity (6-minute average), except for one 6-minute 
period per hour of not more than 27 percent opacity.
    (d) The PM and opacity standards under this section apply at all 
times, except during periods of startup, shutdown, or malfunction.



Sec. 60.44c  Compliance and performance test methods and procedures for sulfur dioxide.

    (a) Except as provided in paragraphs (g) and (h) of this section and 
in Sec. 60.8(b), performance tests required under Sec. 60.8 shall be 
conducted following the procedures specified in paragraphs (b), (c), 
(d), (e), and (f) of this section, as applicable. Section 60.8(f) does 
not apply to this section. The 30-day notice required in Sec. 60.8(d) 
applies only to the initial performance test unless otherwise specified 
by the Administrator.
    (b) The initial performance test required under Sec. 60.8 shall be 
conducted over 30 consecutive operating days of the steam generating 
unit. Compliance with the percent reduction requirements and 
SO2 emission limits under Sec. 60.42c shall be determined 
using a 30-day average. The first operating day included in the initial 
performance test shall be scheduled within 30 days after achieving the 
maximum production rate at which the affect facility will be operated, 
but not later than 180 days after the initial startup of the facility. 
The steam generating unit load during the 30-day period does not have to 
be the maximum design heat input capacity, but must be representative of 
future operating conditions.
    (c) After the initial performance test required under paragraph (b) 
and Sec. 60.8, compliance with the percent reduction requirements and 
SO2 emission limits under Sec. 60.42c is based on the average 
percent reduction and the average S02 emission rates for 30 
consecutive steam generating unit operating days. A separate performance 
test is completed at the end of each steam generating unit operating 
day, and a new 30-day average percent reduction and SO2 
emission rate are calculated to show compliance with the standard.
    (d) If only coal, only oil, or a mixture of coal and oil is 
combusted in an affected facility, the procedures in Method 19 are used 
to determine the hourly SO2 emission rate (Eho) 
and the 30-day average SO2 emission rate (Eao). 
The hourly averages used to compute the 30-day averages are obtained 
from the continuous emission monitoring system (CEMS). Method 19 shall 
be used to calculate Eao when using daily fuel sampling or 
Method 6B.
    (e) If coal, oil, or coal and oil are combusted with other fuels:
    (1) An adjusted Eho (Ehoo) is used in Equation 
19-19 of Method 19 to compute the adjusted Eao 
(Eaoo). The Ehoo is computed using the following 
formula:

    Ehoo=[Eho-Ew(1-Xk)]/
Xk
where:
    Ehoo  is the adjusted Eho, ng/J (lb/million 
Btu)
    Eho  is the hourly SO2 emission rate, ng/J 
(lb/million Btu)
    Ew  is the SO2 concentration in fuels other 
than coal and oil combusted in the affected facility, as determined by 
fuel sampling and analysis procedures in Method 9, ng/J (lb/million 
Btu). The value Ew for each fuel lot is used for each hourly 
average during the time that the lot is being combusted. The owner or 
operator does not have to measure Ew if the owner or operator 
elects to assume Ew=0.
    Xk  is the fraction of the total heat input from fuel 
combustion derived from coal and oil, as determined by applicable 
procedures in Method 19.


[[Page 128]]


    (2) The owner or operator of an affected facility that qualifies 
under the provisions of Sec. 60.42c(c) or (d) [where percent reduction 
is not required] does not have to measure the parameters Ew 
or Xk if the owner or operator of the affected facility 
elects to measure emission rates of the coal or oil using the fuel 
sampling and analysis procedures under Method 19.
    (f) Affected facilities subject to the percent reduction 
requirements under Sec. 60.42c(a) or (b) shall determine compliance with 
the SO2 emission limits under Sec. 60.42c pursuant to 
paragraphs (d) or (e) of this section, and shall determine compliance 
with the percent reduction requirements using the following procedures:
    (1) If only coal is combusted, the percent of potential 
SO2 emission rate is computed using the following formula:

    %Ps=100(1-%Rg/100)(1-%Rf/100)
where
    %Ps  is the percent of potential SO2 emission 
rate, in percent
    %Rg  is the SO2 removal efficiency of the 
control device as determined by Method 19, in percent
    %Rf  is the SO2 removal efficiency of fuel 
pretreatment as determined by Method 19, in percent

    (2) If coal, oil, or coal and oil are combusted with other fuels, 
the same procedures required in paragraph (f)(1) of this section are 
used, except as provided for in the following:
    (i) To compute the %Ps, an adjusted %Rg 
(%Rgo) is computed from Eaoo from paragraph (e)(1) 
of this section and an adjusted average SO2 inlet rate 
(Eaio) using the following formula:

    %Rgo=100 [1.0- Eaoo/Eaio)]
where:
    %Rgo  is the adjusted %Rg, in percent
    Eaoo  is the adjusted Eao, ng/J (lb/million 
Btu)
    Eaio  is the adjusted average SO2 inlet rate, 
ng/J (lb/million Btu)

    (ii) To compute Eaio, an adjusted hourly SO2 
inlet rate (Ehio) is used. The Ehio is computed 
using the following formula:

    Ehio=[Ehi- Ew (1-Xk)]/
Xk
where:
    Ehio  is the adjusted Ehi, ng/J (lb/million 
Btu)
    Ehi  is the hourly SO2 inlet rate, ng/J (lb/
million Btu)
    Ew  is the SO2 concentration in fuels other 
than coal and oil combusted in the affected facility, as determined by 
fuel sampling and analysis procedures in Method 19, ng/J (lb/million 
Btu). The value Ew for each fuel lot is used for each hourly 
average during the time that the lot is being combusted. The owner or 
operator does not have to measure Ew if the owner or operator 
elects to assume Ew = O.
    Xk  is the fraction of the total heat input from fuel 
combustion derived from coal and oil, as determined by applicable 
procedures in Method 19.

    (g) For oil-fired affected facilities where the owner or operator 
seeks to demonstrate compliance with the fuel oil sulfur limits under 
Sec. 60.42c based on shipment fuel sampling, the initial performance 
test shall consist of sampling and analyzing the oil in the initial tank 
of oil to be fired in the steam generating unit to demonstrate that the 
oil contains 0.5 weight percent sulfur or less. Thereafter, the owner or 
operator of the affected facility shall sample the oil in the fuel tank 
after each new shipment of oil is received, as described under 
Sec. 60.46c(d)(2).
    (h) For affected facilities subject to Sec. 60.42c(h)(1), (2), or 
(3) where the owner or operator seeks to demonstrate compliance with the 
SO2 standards based on fuel supplier certification, the 
performance test shall consist of the certification, the certification 
from the fuel supplier, as described under Sec. 60.48c(f)(1), (2), or 
(3), as applicable.
    (i) The owner or operator of an affected facility seeking to 
demonstrate compliance with the SO2 standards under 
Sec. 60.42c(c)(2) shall demonstrate the maximum design heat input 
capacity of the steam generating unit by operating the steam generating 
unit at this capacity for 24 hours. This demonstration shall be made 
during the initial performance test, and a subsequent demonstration may 
be requested at any other time. If the demonstrated 24-hour averaged 
firing rate for the affected facility is less than the maximum design 
heat input capacity stated by the manufacturer of the affected facility, 
the demonstrated 24-hour average firing rate shall be used to determine 
the annual capacity factor for the

[[Page 129]]

affected facility; otherwise, the maximum design heat input capacity 
provided by the manufacturer shall be used.
    (j) The owner or operator of an affected facility shall use all 
valid SO2 emissions data in calculating %Ps and 
Eho under paragraphs (d), (e), or (f) of this section, as 
applicable, whether or not the minimum emissions data requirements under 
Sec. 60.46c(f) are achieved. All valid emissions data, including valid 
data collected during periods of startup, shutdown, and malfunction, 
shall be used in calculating %Ps or Eho pursuant 
to paragraphs (d), (e), or (f) of this section, as applicable.



Sec. 60.45c  Compliance and performance test methods and procedures for particulate matter.

    (a) The owner or operator of an affected facility subject to the PM 
and/or opacity standards under Sec. 60.43c shall conduct an initial 
performance test as required under Sec. 60.8, and shall conduct 
subsequent performance tests as requested by the Administrator, to 
determine compliance with the standards using the following procedures 
and reference methods.
    (1) Method 1 shall be used to select the sampling site and the 
number of traverse sampling points. The sampling time for each run shall 
be at least 120 minutes and the minimum sampling volume shall be 1.7 dry 
square cubic meters (dscm) [60 dry square cubic feet (dscf)] except that 
smaller sampling times or volumes may be approved by the Administrator 
when necessitated by process variables or other factors.
    (2) Method 3 shall be used for gas analysis when applying Method 5, 
Method 5B, of Method 17.
    (3) Method 5, Method 5B, or Method 17 shall be used to measure the 
concentration of PM as follows:
    (i) Method 5 may be used only at affected facilities without wet 
scrubber systems.
    (ii) Method 17 may be used at affected facilities with or without 
wet scrubber systems provided the stack gas temperature does not exceed 
a temperature of 160  deg.C (320  deg.F). The procedures of Sections 2.1 
and 2.3 of Method 5B may be used in Method 17 only if Method 17 is used 
in conjuction with a wet scrubber system. Method 17 shall not be used in 
conjuction with a wet scrubber system if the effluent is saturated or 
laden with water droplets.
    (iii) Method 5B may be used in conjunction with a wet scrubber 
system.
    (4) For Method 5 or Method 5B, the temperature of the sample gas in 
the probe and filter holder shall be monitored and maintained at 160 
deg.C (320  deg.F).
    (5) For determination of PM emissions, an oxygen or carbon dioxide 
measurement shall be obtained simultaneously with each run of Method 5, 
Method 5B, or Method 17 by traversing the duct at the same sampling 
location.
    (6) For each run using Method 5, Method 5B, or Method 17, the 
emission rates expressed in ng/J (lb/million Btu) heat input shall be 
determined using:
    (i) The oxygen or carbon dioxide measurements and PM measurements 
obtained under this section,
    (ii) The dry basis F-factor, and
    (iii) The dry basis emission rate calculation procedure contained in 
Method 19 (appendix A).
    (7) Method 9 (6-minute average of 24 observations) shall be used for 
determining the opacity of stack emissions.
    (b) The owner or operator of an affected facility seeking to 
demonstrate compliance with the PM standards under Sec. 60.43c(b)(2) 
shall demonstrate the maximum design heat input capacity of the steam 
generating unit by operating the steam generating unit at this capacity 
for 24 hours. This demonstration shall be made during the initial 
performance test, and a subsequent demonstration may be requested at any 
other time. If the demonstrated 24-hour average firing rate for the 
affected facility is less than the maximum design heat input capacity 
stated by the manufacturer of the affected facility, the demonstrated 
24-hour average firing rate shall be used to determine the annual 
capacity factor for the affected facility; otherwise, the maximum design 
heat input capacity provided by the manufacturer shall be used.



Sec. 60.46c  Emission monitoring for sulfur dioxide

    (a) Except as provided in paragraphs (d) and (e) of this section, 
the owner or

[[Page 130]]

operator of an affected facility subject to the SO2 emission 
limits under Sec. 60.42c shall install, calibrate, maintain, and operate 
a CEMS for measuring SO2 concentrations and either oxygen or 
carbon dioxide concentrations at the outlet of the SO2 
control device (or the outlet of the steam generating unit if no 
SO2 control device is used), and shall record the output of 
the system. The owner or operator of an affected facility subject to the 
percent reduction requirements under Sec. 60.42c shall measure 
SO2 concentrations and either oxygen or carbon dioxide 
concentrations at both the inlet and outlet of the SO2 
control device.
    (b) The 1-hour average SO2 emission rates measured by a 
CEM shall be expressed in ng/J or lb/million Btu heat input and shall be 
used to calculate the average emission rates under Sec. 60.42c. Each 1-
hour average SO2 emission rate must be based on at least 30 
minutes of operation and include at least 2 data points representing two 
15-minute periods. Hourly SO2 emission rates are not 
calculated if the affected facility is operated less than 30 minutes in 
a 1-hour period and are not counted toward determination of a steam 
generating unit operating day.
    (c) The procedures under Sec. 60.13 shall be followed for 
installation, evaluation, and operation of the CEMS.
    (1) All CEMS shall be operated in accordance with the applicable 
procedures under Performance Specifications 1, 2, and 3 (appendix B).
    (2) Quarterly accuracy determinations and daily calibration drift 
tests shall be performed in accordance with Procedure 1 (appendix F).
    (3) For affected facilities subject to the percent reduction 
requirements under Sec. 60.42c, the span value of the SO2 
CEMS at the inlet to the SO2 control device shall be 125 
percent of the maximum estimated hourly potential SO2 
emission rate of the fuel combusted, and the span value of the 
SO2 CEMS at the outlet from the SO2 control device 
shall be 50 percent of the maximum estimated hourly potential 
SO2 emission rate of the fuel combusted.
    (4) For affected facilities that are not subject to the percent 
reduction requirements of Sec. 60.42c, the span value of the 
SO2 CEMS at the outlet from the SO2 control device 
(or outlet of the steam generating unit if no SO2 control 
device is used) shall be 125 percent of the maximum estimated hourly 
potential SO2 emission rate of the fuel combusted.
    (d) As an alternative to operating a CEMS at the inlet to the 
SO2 control device (or outlet of the steam generating unit if 
no SO2 control device is used) as required under paragraph 
(a) of this section, an owner or operator may elect to determine the 
average SO2 emission rate by sampling the fuel prior to 
combustion. As an alternative to operating a CEM at the outlet from the 
SO2 control device (or outlet of the steam generating unit if 
no SO2 control device is used) as required under paragraph 
(a) of this section, an owner or operator may elect to determine the 
average SO2 emission rate by using Method 6B. Fuel sampling 
shall be conducted pursuant to either paragraph (d)(1) or (d)(2) of this 
section. Method 6B shall be conducted pursuant to paragraph (d)(3) of 
this section.
    (1) For affected facilities combusting coal or oil, coal or oil 
samples shall be collected daily in an as-fired condition at the inlet 
to the steam generating unit and analyzed for sulfur content and heat 
content according the Method 19. Method 19 provides procedures for 
converting these measurements into the format to be used in calculating 
the average SO2 input rate.
    (2) As an alternative fuel sampling procedure for affected 
facilities combusting oil, oil samples may be collected from the fuel 
tank for each steam generating unit immediately after the fule tank is 
filled and before any oil is combusted. The owner or operator of the 
affected facility shall analyze the oil sample to determine the sulfur 
content of the oil. If a partially empty fuel tank is refilled, a new 
sample and analysis of the fuel in the tank would be required upon 
filling. Results of the fuel analysis taken after each new shipment of 
oil is received shall be used as the daily value when calculating the 
30-day rolling average until the next shipment is received. If the fuel 
analysis shows that the sulfur content in the fuel tank is greater than 
0.5 weight percent sulfur, the owner or operator shall ensure that the 
sulfur

[[Page 131]]

content of subsequent oil shipments is low enough to cause the 30-day 
rolling average sulfur content to be 0.5 weight percent sulfur or less.
    (3) Method 6B may be used in lieu of CEMS to measure SO2 
at the inlet or outlet of the SO2 control system. An initial 
stratification test is required to verify the adequacy of the Method 6B 
sampling location. The stratification test shall consist of three paired 
runs of a suitable SO2 and carbon dioxide measurement train 
operated at the candidate location and a second similar train operated 
according to the procedures in Sec. 3.2 and the applicable procedures in 
section 7 of Performance Specification 2 (appendix B). Method 6B, Method 
6A, or a combination of Methods 6 and 3 or Methods 6C and 3A are 
suitable measurement techniques. If Method 6B is used for the second 
train, sampling time and timer operation may be adjusted for the 
stratification test as long as an adequate sample volume is collected; 
however, both sampling trains are to be operated similarly. For the 
location to be adequate for Method 6B 24-hour tests, the mean of the 
absolute difference between the three paired runs must be less than 10 
percent (0.10).
    (e) The monitoring requirements of paragraphs (a) and (d) of this 
section shall not apply to affected facilities subject to Sec. 60.42c(h) 
(1), (2), or (3) where the owner or operator of the affected facility 
seeks to demonstrate compliance with the SO2 standards based 
on fuel supplier certification, as described under Sec. 60.48c(f) (1), 
(2), or (3), as applicable.
    (f) The owner or operator of an affected facility operating a CEMS 
pursuant to paragraph (a) of this section, or conducting as-fired fuel 
sampling pursuant to paragraph (d)(1) of this section, shall obtain 
emission data for at least 75 percent of the operating hours in at least 
22 out of 30 successive steam generating unit operating days. If this 
minimum data requirement is not met with a single monitoring system, the 
owner or operator of the affected facility shall supplement the emission 
data with data collected with other monitoring systems as approved by 
the Administrator.



Sec. 60.47c  Emission monitoring for particulate matter.

    (a) The owner or operator of an affected facility combusting coal, 
residual oil, or wood that is subject to the opacity standards under 
Sec. 60.43c shall install, calibrate, maintain, and operate a CEMS for 
measuring the opacity of the emissions discharged to the atmosphere and 
record the output of the system.
    (b) All CEMS for measuring opacity shall be operated in accordance 
with the applicable procedures under Performance Specification 1 
(appendix B). The span value of the opacity CEMS shall be between 60 and 
80 percent.



Sec. 60.48c  Reporting and recordkeeping requirements.

    (a) The owner or operator of each affected facility shall submit 
notification of the date of construction or reconstruction, anticipated 
startup, and actual startup, as provided by Sec. 60.7 of this part. This 
notification shall include:
    (1) The design heat input capacity of the affected facility and 
identification of fuels to be combusted in the affected facility.
    (2) If applicable, a copy of any Federally enforceable requirement 
that limits the annual capacity factor for any fuel or mixture of fuels 
under Sec. 60.42c, or Sec. 60.43c.
    (3) The annual capacity factor at which the owner or operator 
anticipates operating the affected facility based on all fuels fired and 
based on each individual fuel fired.
    (4) Notification if an emerging technology will be used for 
controlling SO2 emissions. The Administrator will examine the 
description of the control device and will determine whether the 
technology qualifies as an emerging technology. In making this 
determination, the Administrator may require the owner or operator of 
the affected facility to submit additional information concerning the 
control device. The affected facility is subject to the provisions of 
Sec. 60.42c(a) or (b)(1), unless and until this determination is made by 
the Administrator.
    (b) The owner or operator of each affected facility subject to the 
SO2 emission limits of Sec. 60.42c, or the PM or

[[Page 132]]

opacity limits of Sec. 60.43c, shall submit to the Administrator the 
performance test data from the initial and any subsequent performance 
tests and, if applicable, the performance evaluation of the CEMS using 
the applicable performance specifications in appendix B.
    (c) The owner or operator of each coal-fired, residual oil-fired, or 
wood-fired affected facility subject to the opacity limits under 
Sec. 60.43c(c) shall submit excess emission reports for any excess 
emissions from the affected facility which occur during the reporting 
period.
    (d) The owner or operator of each affected facility subject to the 
SO2 emission limits, fuel oil sulfur limits, or percent 
reduction requirements under Sec. 60.42c shall submit reports to the 
Administrator.
    (e) The owner or operator of each affected facility subject to the 
SO2 emission limits, fuel oil sulfur limits, or percent 
reduction requirements under Sec. 60.43c shall keep records and submit 
reports as required under paragraph (d) of this section, including the 
following information, as applicable.
    (1) Calendar dates covered in the reporting period.
    (2) Each 30-day average SO2 emission rate (nj/J or lb/
million Btu), or 30-day average sulfur content (weight percent), 
calculated during the reporting period, ending with the last 30-day 
period; reasons for any noncompliance with the emission standards; and a 
description of corrective actions taken.
    (3) Each 30-day average percent of potential SO2 emission 
rate calculated during the reporting period, ending with the last 30-day 
period; reasons for any noncompliance with the emission standards; and a 
description of the corrective actions taken.
    (4) Identification of any steam generating unit operating days for 
which SO2 or diluent (oxygen or carbon dioxide) data have not 
been obtained by an approved method for at least 75 percent of the 
operating hours; justification for not obtaining sufficient data; and a 
description of corrective actions taken.
    (5) Identification of any times when emissions data have been 
excluded from the calculation of average emission rates; justification 
for excluding data; and a description of corrective actions taken if 
data have been excluded for periods other than those during which coal 
or oil were not combusted in the steam generating unit.
    (6) Identification of the F factor used in calculations, method of 
determination, and type of fuel combusted.
    (7) Identification of whether averages have been obtained based on 
CEMS rather than manual sampling methods.
    (8) If a CEMS is used, identification of any times when the 
pollutant concentration exceeded the full span of the CEMS.
    (9) If a CEMS is used, description of any modifications to the CEMS 
that could affect the ability of the CEMS to comply with Performance 
Specifications 2 or 3 (appendix B).
    (10) If a CEMS is used, results of daily CEMS drift tests and 
quarterly accuracy assessments as required under appendix F, Procedure 
1.
    (11) If fuel supplier certification is used to demonstrate 
compliance, records of fuel supplier certification is used to 
demonstrate compliance, records of fuel supplier certification as 
described under paragraph (f)(1), (2), or (3) of this section, as 
applicable. In addition to records of fuel supplier certifications, the 
report shall include a certified statement signed by the owner or 
operator of the affected facility that the records of fuel supplier 
certifications submitted represent all of the fuel combusted during the 
reporting period.
    (f) Fuel supplier certification shall include the following 
information:
    (1) For distillate oil:
    (i) The name of the oil supplier; and
    (ii) A statement from the oil supplier that the oil complies with 
the specifications under the definition of distillate oil in 
Sec. 60.41c.
    (2) For residual oil:
    (i) The name of the oil supplier;
    (ii) The location of the oil when the sample was drawn for analysis 
to determine the sulfur content of the oil, specifically including 
whether the oil was sampled as delivered to the affected facility, or 
whether the sample was drawn from oil in storage at the oil supplier's 
or oil refiner's facility, or other location;

[[Page 133]]

    (iii) The sulfur content of the oil from which the shipment came (or 
of the shipment itself); and
    (iv) The method used to determine the sulfur content of the oil.
    (3) For coal:
    (i) The name of the coal supplier;
    (ii) The location of the coal when the sample was collected for 
analysis to determine the properties of the coal, specifically including 
whether the coal was sampled as delivered to the affected facility or 
whether the sample was collected from coal in storage at the mine, at a 
coal preparation plant, at a coal supplier's facility, or at another 
location. The certification shall include the name of the coal mine (and 
coal seam), coal storage facility, or coal preparation plant (where the 
sample was collected);
    (iii) The results of the analysis of the coal from which the 
shipment came (or of the shipment itself) including the sulfur content, 
moisture content, ash content, and heat content; and
    (iv) The methods used to determine the properties of the coal.
    (g) The owner or operator of each affected facility shall record and 
maintain records of the amounts of each fuel combusted during each day.
    (h) The owner or operator of each affected facility subject to a 
Federally enforceable requirement limiting the annual capacity factor 
for any fuel or mixture of fuels under Sec. 60.42c or Sec. 60.43c shall 
calculate the annual capacity factor individually for each fuel 
combusted. The annual capacity factor is determined on a 12-month 
rolling average basis with a new annual capacity factor calculated at 
the end of the calendar month.
    (i) All records required under this section shall be maintained by 
the owner or operator of the affected facility for a period of two years 
following the date of such record.
    (j) The reporting period for the reports required under this subpart 
is each six-month period. All reports shall be submitted to the 
Administrator and shall be postmarked by the 30th day following the end 
of the reporting period.

[55 FR 37683, Sept. 12, 1990, as amended at 64 FR 7465, Feb. 12, 1999]



          Subpart E--Standards of Performance for Incinerators



Sec. 60.50  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to each 
incinerator of more than 45 metric tons per day charging rate (50 tons/
day), which is the affected facility.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after August 17, 1971, is subject to the 
requirements of this subpart.

[42 FR 37936, July 25, 1977]



Sec. 60.51  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Incinerator means any furnace used in the process of burning 
solid waste for the purpose of reducing the volume of the waste by 
removing combustible matter.
    (b) Solid waste means refuse, more than 50 percent of which is 
municipal type waste consisting of a mixture of paper, wood, yard 
wastes, food wastes, plastics, leather, rubber, and other combustibles, 
and noncombustible materials such as glass and rock.
    (c) Day means 24 hours.

[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 20792, June 14, 1974]



Sec. 60.52  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this part shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain 
particulate matter in excess of 0.18 g/dscm (0.08 gr/dscf) corrected to 
12 percent CO2.

[39 FR 20792, June 14, 1974]



Sec. 60.53  Monitoring of operations.

    (a) The owner or operator of any incinerator subject to the 
provisions of this part shall record the daily charging rates and hours 
of operation.

[[Page 134]]



Sec. 60.54  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standard in Sec. 60.52 as follows:
    (1) The emission rate (c12) of particulate matter, 
corrected to 12 percent CO2, shall be computed for each run 
using the following equation:

c12 = cs (12/%CO2)

where:
c12=concentration of particulate matter, corrected to 12 
          percent CO2, g/dscm (gr/dscf).
cs=concentration of particulate matter, g/dscm (gr/dscf).
%CO2=CO2 concentration, percent dry basis.

    (2) Method 5 shall be used to determine the particulate matter 
concentration (cs). The sampling time and sample volume for 
each run shall be at least 60 minutes and 0.85 dscm (30 dscf).
    (3) The emission rate correction factor, integrated or grab sampling 
and analysis procedure of Method 3B shall be used to determine 
CO2 concentration (%CO2).
    (i) The CO2 sample shall be obtained simultaneously with, 
and at the same traverse points as, the particulate run. If the 
particulate run has more than 12 traverse points, the CO2 
traverse points may be reduced to 12 if Method 1 is used to locate the 
12 CO2 traverse points. If individual CO2 samples 
are taken at each traverse point, the CO2 concentration 
(%CO2) used in the correction equation shall be the 
arithmetic mean of all the individual CO2 sample 
concentrations at each traverse point.
    (ii) If sampling is conducted after a wet scrubber, an ``adjusted'' 
CO2 concentration [(%CO2)adj], which 
accounts for the effects of CO2 absorption and dilution air, 
may be used instead of the CO2 concentration determined in 
this paragraph. The adjusted CO2 concentration shall be 
determined by either of the procedures in paragraph (c) of this section.
    (c) The owner or operator may use either of the following procedures 
to determine the adjusted CO2 concentration.
    (1) The volumetric flow rates at the inlet and outlet of the wet 
scrubber and the inlet CO2 concentration may be used to 
determine the adjusted CO2 concentration 
[(%CO2)adj] using the following equation:

(%CO2)adj=(%CO2)di 
          (Qdi/Qdo)

where:

(%CO2)adj=adjusted outlet CO2 
          concentration, percent dry basis.
(%CO2)di=CO2 concentration measured 
          before the scrubber, percent dry basis.
Qdi=volumetric flow rate of effluent gas before the wet 
          scrubber, dscm/min (dscf/min).
Qdo=volumetric flow rate of effluent gas after the wet 
          scrubber, dscm/min (dscf/min).

    (i) At the outlet, Method 5 is used to determine the volumetric flow 
rate (Qdo) of the effluent gas.
    (ii) At the inlet, Method 2 is used to determine the volumetric flow 
rate (Qdi) of the effluent gas as follows: Two full velocity 
traverses are conducted, one immediately before and one immediately 
after each particulate run conducted at the outlet, and the results are 
averaged.
    (iii) At the inlet, the emission rate correction factor, integrated 
sampling and analysis procedure of Method 3B is used to determine the 
CO2 concentration [(%CO2)di] as 
follows: At least nine sampling points are selected randomly from the 
velocity traverse points and are divided randomly into three sets, equal 
in number of points; the first set of three or more points is used for 
the first run, the second set for the second run, and the third set for 
the third run. The CO2 sample is taken simultaneously with 
each particulate run being conducted at the outlet, by traversing the 
three sampling points (or more) and sampling at each point for equal 
increments of time.
    (2) Excess air measurements may be used to determine the adjusted 
CO2 concentration [(%CO2)adj] using the 
following equation:

(%CO2)adj=(%CO2)di 
          [(100+%EAi)/(100+%EAo)]

where:
(%CO2)adj=adjusted outlet CO2 
          concentration, percent dry basis.
(%CO2)di=CO2 concentration at the inlet 
          of the wet scrubber, percent dry basis.

[[Page 135]]

%EAi=excess air at the inlet of the scrubber, percent.
%EAo=excess air at the outlet of the scrubber, percent.

    (i) A gas sample is collected as in paragraph (c)(1)(iii) of this 
section and the gas samples at both the inlet and outlet locations are 
analyzed for CO2, O2, and N2.
    (ii) Equation 3B-3 of Method 3B is used to compute the percentages 
of excess air at the inlet and outlet of the wet scrubber.

[54 FR 6665, Feb. 14, 1989, as amended at 55 FR 5212, Feb. 14, 1990]



Subpart Ea--Standards of Performance for Municipal Waste Combustors for 
Which Construction is Commenced After December 20, 1989 and on or Before 
                           September 20, 1994

    Source: 56 FR 5507, Feb. 11, 1991, unless otherwise noted.



Sec. 60.50a  Applicability and delegation of authority.

    (a) The affected facility to which this subpart applies is each 
municipal waste combustor unit with a municipal waste combustor unit 
capacity greater than 225 megagrams per day (250 tons per day) of 
municipal solid waste for which construction, modification, or 
reconstruction is commenced as specified in paragraphs (a)(1) and (a)(2) 
of this section.
    (1) Construction is commenced after December 20, 1989 and on or 
before September 20, 1994.
    (2) Modification or reconstruction is commenced after December 20, 
1989 and on or before June 19, 1996.
    (b) [Reserved]
    (c) Any unit combusting a single-item waste stream of tires is not 
subject to this subpart if the owner or operator of the unit:
    (1) Notifies the Administrator of an exemption claim; and
    (2) Provides data documenting that the unit qualifies for this 
exemption.
    (d) Any cofired combustor, as defined under Sec. 60.51a, located at 
a plant that meets the capacity specifications in paragraph (a) of this 
section is not subject to this subpart if the owner or operator of the 
cofired combustor:
    (1) Notifies the Administrator of an exemption claim;
    (2) Provides a copy of the federally enforceable permit (specified 
in the definition of cofired combustor in this section); and
    (3) Keeps a record on a calendar quarter basis of the weight of 
municipal solid waste combusted at the cofired combustor and the weight 
of all other fuels combusted at the cofired combustor.
    (e) Any cofired combustor that is subject to a federally enforceable 
permit limiting the operation of the combustor to no more than 225 
megagrams per day (250 tons per day) of municipal solid waste is not 
subject to this subpart.
    (f) Physical or operational changes made to an existing municipal 
waste combustor unit primarily for the purpose of complying with 
emission guidelines under subpart Cb are not considered a modification 
or reconstruction and do not result in an existing municipal waste 
combustor unit becoming subject to this subpart.
    (g) A qualifying small power production facility, as defined in 
section 3(17)(C) of the Federal Power Act (16 U.S.C. 796(17)(C)), that 
burns homogeneous waste (such as automotive tires or used oil, but not 
including refuse-derived fuel) for the production of electric energy is 
not subject to this subpart if the owner or operator of the facility 
notifies the Administrator of an exemption claim and provides data 
documenting that the facility qualifies for this exemption.
    (h) A qualifying cogeneration facility, as defined in section 
3(18)(B) of the Federal Power Act (16 U.S.C. 796(18)(B)), that burns 
homogeneous waste (such as automotive tires or used oil, but not 
including refuse-derived fuel) for the production of electric energy and 
steam or forms of useful energy (such as heat) that are used for 
industrial, commercial, heating, or cooling purposes, is not subject to 
this subpart if the owner or operator of the facility notifies the 
Administrator of an exemption claim and provides data documenting that 
the facility qualifies for this exemption.

[[Page 136]]

    (i) Any unit required to have a permit under section 3005 of the 
Solid Waste Disposal Act is not subject to this subpart.
    (j) Any materials recovery facility (including primary or secondary 
smelters) that combusts waste for the primary purpose of recovering 
metals is not subject to this subpart.
    (k) Pyrolysis/combustion units that are an integrated part of a 
plastics/rubber recycling unit (as defined in Sec. 60.51a) are not 
subject to this subpart if the owner or operator of the plastics/rubber 
recycling unit keeps records of: the weight of plastics, rubber, and/or 
rubber tires processed on a calendar quarter basis; the weight of 
chemical plant feedstocks and petroleum refinery feedstocks produced and 
marketed on a calendar quarter basis; and the name and address of the 
purchaser of the feedstocks. The combustion of gasoline, diesel fuel, 
jet fuel, fuel oils, residual oil, refinery gas, petroleum coke, 
liquified petroleum gas, propane, or butane produced by chemical plants 
or petroleum refineries that use feedstocks produced by plastics/rubber 
recycling units are not subject to this subpart.
    (l) The following authorities shall be retained by the Administrator 
and not transferred to a State:
    None.
    (m) This subpart shall become effective on August 12, 1991.

[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65384, Dec. 19, 1995]



Sec. 60.51a  Definitions.

    ASME means the American Society of Mechanical Engineers.
    Batch MWC means an MWC unit designed such that it cannot combust MSW 
continuously 24 hours per day because the design does not allow waste to 
be fed to the unit or ash to be removed while combustion is occurring.
    Bubbling fluidized bed combustor means a fluidized bed combustor in 
which the majority of the bed material remains in a fluidized state in 
the primary combustion zone.
    Calendar quarter means a consecutive 3-month period (nonoverlapping) 
beginning on January 1, April 1, July 1, and October 1.
    Chief facility operator means the person in direct charge and 
control of the operation of an MWC and who is responsible for daily on-
site supervision, technical direction, management, and overall 
performance of the facility.
    Circulating fluidized bed combustor means a fluidized bed combustor 
in which the majority of the fluidized bed material is carried out of 
the primary combustion zone and is transported back to the primary zone 
through a recirculation loop.
    Clean wood means untreated wood or untreated wood products including 
clean untreated lumber, tree stumps (whole or chipped), and tree limbs 
(whole or chipped). Clean wood does not include yard waste, which is 
defined elsewhere in this section, or construction, renovation, and 
demolition wastes (which includes but is not limited to railroad ties 
and telephone poles), which are exempt from the definition of municipal 
solid waste in this section.
    Cofired combustor means a unit combusting municipal solid waste with 
nonmunicipal solid waste fuel (e.g., coal, industrial process waste) and 
subject to a federally enforceable permit limiting the unit to 
combusting a fuel feed stream, 30 percent or less of the weight of which 
is comprised, in aggregate, of municipal solid waste as measured on a 
calendar quarter basis.
    Continuous emission monitoring system or CEMS means a monitoring 
system for continuously measuring the emissions of a pollutant from an 
affected facility.
    Dioxin/furan means total tetra- through octachlorinated dibenzo-p-
dioxins and dibenzofurans.
    Federally-enforceable means all limitations and conditions that are 
enforceable by the Administrator including the requirements of 40 CFR 
parts 60 and 61, requirements within any applicable State implementation 
plan, and any permit requirements established under 40 CFR 52.21 or 
under 40 CFR 51.18 and 40 CFR 51.24.
    Four-hour block average or 4-hour block average means the average of 
all hourly emission rates when the affected facility is operating and 
combusting MSW measured over 4-hour periods of time from 12 midnight to 
4

[[Page 137]]

a.m., 4 a.m. to 8 a.m., 8 a.m. to 12 noon, 12 noon to 4 p.m., 4 p.m. to 
8 p.m., and 8 p.m. to 12 midnight.
    Large municipal waste combustor plant means a municipal waste 
combustor plant with a municipal waste combustor aggregate plant 
capacity for affected facilities that is greater than 225 megagrams per 
day (250 tons per day) of municipal solid waste.
    Mass burn refractory municipal waste combustor means a field-erected 
combustor that combusts municipal solid waste in a refractory wall 
furnace. Unless otherwise specified, this includes combustors with a 
cylindrical rotary refractory wall furnace.
    Mass burn rotary waterwall municipal waste combustor means a field-
erected combustor that combusts municipal solid waste in a cylindrical 
rotary waterwall furnace.
    Mass burn waterwall municipal waste combustor means a field-erected 
combustor that combusts municipal solid waste in a waterwall furnace.
    Maximum demonstrated municipal waste combustor unit load means the 
highest 4-hour arithmetic average municipal waste combustor unit load 
achieved during four consecutive hours during the most recent dioxin/
furan performance test demonstrating compliance with the applicable 
limit for municipal waste combustor organics specified under 
Sec. 60.53a.
    Maximum demonstrated particulate matter control device temperature 
means the highest 4-hour arithmetic average flue gas temperature 
measured at the particulate matter control device inlet during four 
consecutive hours during the most recent dioxin/furan performance test 
demonstrating compliance with the applicable limit for municipal waste 
combustor organics specified under Sec. 60.53a.
    Modification or modified municipal waste combustor unit means a 
municipal waste combustor unit to which changes have been made if the 
cumulative cost of the changes, over the life of the unit, exceed 50 
percent of the original cost of construction and installation of the 
unit (not including the cost of any land purchased in connection with 
such construction or installation) updated to current costs; or any 
physical change in the municipal waste combustor unit or change in the 
method of operation of the municipal waste combustor unit increases the 
amount of any air pollutant emitted by the unit for which standards have 
been established under section 129 or section 111. Increases in the 
amount of any air pollutant emitted by the municipal waste combustor 
unit are determined at 100-percent physical load capability and 
downstream of all air pollution control devices, with no consideration 
given for load restrictions based on permits or other nonphysical 
operational restrictions.
    Modular excess air MWC means a combustor that combusts MSW and that 
is not field-erected and has multiple combustion chambers, all of which 
are designed to operate at conditions with combustion air amounts in 
excess of theoretical air requirements.
    Modular starved air MWC means a combustor that combusts MSW and that 
is not field-erected and has multiple combustion chambers in which the 
primary combustion chamber is designed to operate at substoichiometric 
conditions.
    Municipal solid waste or municipal-type solid waste or MSW means 
household, commercial/retail, and/or institutional waste. Household 
waste includes material discarded by single and multiple residential 
dwellings, hotels, motels, and other similar permanent or temporary 
housing establishments or facilities. Commercial/retail waste includes 
material discarded by stores, offices, restaurants, warehouses, 
nonmanufacturing activities at industrial facilities, and other similar 
establishments or facilities. Institutional waste includes material 
discarded by schools, nonmedical waste discarded by hospitals, material 
discarded by nonmanufacturing activities at prisons and government 
facilities, and material discarded by other similar establishments or 
facilities. Household, commercial/retail, and institutional waste does 
not include used oil; sewage sludge; wood pallets; construction, 
renovation, and demolition wastes (which includes but is not limited to 
railroad ties and telephone poles); clean wood; industrial process or 
manufacturing wastes; medical waste; or motor vehicles (including motor 
vehicle parts or vehicle fluff).

[[Page 138]]

Household, commercial/retail, and institutional wastes include:
    (1) Yard waste;
    (2) Refuse-derived fuel; and
    (3) Motor vehicle maintenance materials limited to vehicle batteries 
and tires except as specified in Sec. 60.50a(c).
    Municipal waste combustor, MWC, or municipal waste combustor unit: 
(1) Means any setting or equipment that combusts solid, liquid, or 
gasified MSW including, but not limited to, field-erected incinerators 
(with or without heat recovery), modular incinerators (starved-air or 
excess-air), boilers (i.e., steam-generating units), furnaces (whether 
suspension-fired, grate-fired, mass-fired, air curtain incinerators, or 
fluidized bed-fired), and pyrolysis/combustion units. Municipal waste 
combustors do not include pyrolysis/combustion units located at 
plastics/ rubber recycling units (as specified in Sec. 60.50a(k) of this 
section). Municipal waste combustors do not include internal combustion 
engines, gas turbines, or other combustion devices that combust landfill 
gases collected by landfill gas collection systems.
    (2) The boundaries of an MWC are defined as follows. The MWC unit 
includes, but is not limited to, the MSW fuel feed system, grate system, 
flue gas system, bottom ash system, and the combustor water system. The 
MWC boundary starts at the MSW pit or hopper and extends through:
    (i) The combustor flue gas system, which ends immediately following 
the heat recovery equipment or, if there is no heat recovery equipment, 
immediately following the combustion chamber;
    (ii) The combustor bottom ash system, which ends at the truck 
loading station or similar ash handling equipment that transfer the ash 
to final disposal, including all ash handling systems that are connected 
to the bottom ash handling system; and
    (iii) The combustor water system, which starts at the feed water 
pump and ends at the piping exiting the steam drum or superheater.
    (3) The MWC unit does not include air pollution control equipment, 
the stack, water treatment equipment, or the turbine generator set.
    Municipal waste combustor plant means one or more MWC units at the 
same location for which construction, modification, or reconstruction is 
commenced after December 20, 1989 and on or before September 20, 1994.
    Municipal waste combustor plant capacity means the aggregate MWC 
unit capacity of all MWC units at an MWC plant for which construction, 
modification, or reconstruction of the units commenced after December 
20, 1989 and on or before September 20, 1994. Any MWC units for which 
construction, modification, or reconstruction is commenced on or before 
December 20, 1989 or after September 20, 1994 are not included for 
determining applicability under this subpart.
    Municipal waste combustor unit capacity means the maximum design 
charging rate of an MWC unit expressed in megagrams per day (tons per 
day) of MSW combusted, calculated according to the procedures under 
Sec. 60.58a(j). Municipal waste combustor unit capacity is calculated 
using a design heating value of 10,500 kilojoules per kilogram (4,500 
British thermal units per pound) for MSW. The calculational procedures 
under Sec. 60.58a(j) include procedures for determining MWC unit 
capacity for continuous and batch feed MWC's.
    Municipal waste combustor unit load means the steam load of the MWC 
unit measured as specified in Sec. 60.58a(h)(6).
    MWC acid gases means all acid gases emitted in the exhaust gases 
from MWC units including, but not limited to, sulfur dioxide and 
hydrogen chloride gases.
    MWC metals means metals and metal compounds emitted in the exhaust 
gases from MWC units.
    MWC organics means organic compounds emitted in the exhaust gases 
from MWC units and includes total tetra- through octa-chlorinated 
dibenzo-p-dioxins and dibenzofurans.
    Particulate matter means total particulate matter emitted from MWC 
units as measured by Method 5 (see Sec. 60.58a).
    Plastics/rubber recycling unit means an integrated processing unit 
where plastics, rubber, and/or rubber tires are the only feed materials 
(incidental contaminants may be included in the feed materials) and they 
are processed into

[[Page 139]]

a chemical plant feedstock or petroleum refinery feedstock, where the 
feedstock is marketed to and used by a chemical plant or petroleum 
refinery as input feedstock. The combined weight of the chemical plant 
feedstock and petroleum refinery feedstock produced by the plastics/
rubber recycling unit on a calendar quarter basis shall be more than 70 
percent of the combined weight of the plastics, rubber, and rubber tires 
processed by the plastics/rubber recycling unit on a calendar quarter 
basis. The plastics, rubber, and/or rubber tire feed materials to the 
plastics/rubber recycling unit may originate from the separation or 
diversion of plastics, rubber, or rubber tires from MSW or industrial 
solid waste, and may include manufacturing scraps, trimmings, and off-
specification plastics, rubber, and rubber tire discards. The plastics, 
rubber, and rubber tire feed materials to the plastics/rubber recycling 
unit may contain incidental contaminants (e.g., paper labels on plastic 
bottles, metal rings on plastic bottle caps, etc.).
    Potential hydrogen chloride emission rate means the hydrogen 
chloride emission rate that would occur from combustion of MSW in the 
absence of any hydrogen chloride emissions control.
    Potential sulfur dioxide emission rate means the sulfur dioxide 
emission rate that would occur from combustion of MSW in the absence of 
any sulfur dioxide emissions control.
    Pulverized coal/refuse-derived fuel mixed fuel-fired combustor or 
pulverized coal/RDF mixed fuel-fired combustor means a combustor that 
fires coal and RDF simultaneously, in which pulverized coal is 
introduced into an air stream that carries the coal to the combustion 
chamber of the unit where it is fired in suspension. This includes both 
conventional pulverized coal and micropulverized coal.
    Pyrolysis/combustion unit means a unit that produces gases, liquids, 
or solids through the heating of MSW, and the gases, liquids, or solids 
produced are combusted and emissions vented to the atmosphere.
    Reconstruction means rebuilding an MWC unit for which the cumulative 
costs of the construction over the life of the unit exceed 50 percent of 
the original cost of construction and installation of the unit (not 
including any cost of land purchased in connection with such 
construction or installation) updated to current costs (current 
dollars).
    Refractory unit or refractory wall furnace means a combustion unit 
having no energy recovery (e.g., via a waterwall) in the furnace (i.e., 
radiant heat transfer section) of the combustor.
    Refuse-derived fuel or RDF means a type of MSW produced by 
processing MSW through shredding and size classification.
    This includes all classes of RDF including low density fluff RDF 
through densified RDF and RDF fuel pellets.
    RDF stoker means a steam generating unit that combusts RDF in a 
semi-suspension firing mode using air-fed distributors.
    Same location means the same or contiguous property that is under 
common ownership or control, including properties that are separated 
only by a street, road, highway, or other public right-of-way. Common 
ownership or control includes properties that are owned, leased, or 
operated by the same entity, parent entity, subsidiary, subdivision, or 
any combination thereof, including any municipality or other 
governmental unit, or any quasigovernmental authority (e.g., a public 
utility district or regional waste disposal authority).
    Shift supervisor means the person in direct charge and control of 
the operation of an MWC and who is responsible for on-site supervision, 
technical direction, management, and overall performance of the facility 
during an assigned shift.
    Spreader stoker coal/refuse-derived fuel mixed fuel-fired combustor 
or spreader stoker coal/RDF mixed fuel-fired combustor means a combustor 
that fires coal and refuse-derived fuel simultaneously, in which coal is 
introduced to the combustion zone by a mechanism that throws the fuel 
onto a grate from above. Combustion takes place both in suspension and 
on the grate.
    Standard conditions means a temperature of 20  deg.C (68  deg.F) and 
a pressure of 101.3 kilopascals (29.92 inches of mercury).

[[Page 140]]

    Twenty-four hour daily average or 24-hour daily average means the 
arithmetic or geometric mean (as specified in Sec. 60.58a (e), (g), or 
(h) as applicable) of all hourly emission rates when the affected 
facility is operating and firing MSW measured over a 24-hour period 
between 12 midnight and the following midnight.
    Untreated lumber means wood or wood products that have been cut or 
shaped and include wet, air-dried, and kiln-dried wood products. 
Untreated lumber does not include wood products that have been painted, 
pigment-stained, or ``pressure-treated.'' Pressure-treating compounds 
include, but are not limited to, chromate copper arsenate, 
pentachlorophenol, and creosote.
    Waterwall furnace means a combustion unit having energy (heat) 
recovery in the furnace (i.e., radiant heat transfer section) of the 
combustor.
    Yard waste means grass, grass clippings, bushes, shrubs, and 
clippings from bushes and shrubs that are generated by residential, 
commercial/retail, institutional, and/or industrial sources as part of 
maintenance activities associated with yards or other private or public 
lands. Yard waste does not include construction, renovation, and 
demolition wastes, which are exempt from the definition of MSW in this 
section. Yard waste does not include clean wood, which is exempt from 
the definition of MSW in this section.

[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65384, Dec. 19, 1995]



Sec. 60.52a  Standard for municipal waste combustor metals.

    (a) On and after the date on which the initial compliance test is 
completed or is required to be completed under Sec. 60.8, no owner or 
operator of an affected facility located within a large MWC plant shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain particulate matter in excess of 34 milligrams per 
dry standard cubic meter (0.015 grains per dry standard cubic foot), 
corrected to 7 percent oxygen (dry basis).
    (b) On and after the date on which the initial compliance test is 
completed or is required to be completed under Sec. 60.8, no owner or 
operator of an affected facility subject to the particulate matter 
emission limit under paragraph (a) of this section shall cause to be 
discharged into the atmosphere from that affected facility any gases 
that exhibit greater than 10 percent opacity (6-minute average).
    (c) [Reserved]



Sec. 60.53a  Standard for municipal waste combustor organics.

    (a) [Reserved]
    (b) On and after the date on which the initial compliance test is 
completed or is required to be completed under Sec. 60.8, no owner or 
operator of an affected facility located within a large MWC plant shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain dioxin/furan emissions that exceed 30 nanograms 
per dry standard cubic meter (12 grains per billion dry standard cubic 
feet), corrected to 7 percent oxygen (dry basis).



Sec. 60.54a  Standard for municipal waste combustor acid gases.

    (a)--(b) [Reserved]
    (c) On and after the date on which the initial compliance test is 
completed or is required to be completed under Sec. 60.8, no owner or 
operator of an affected facility located within a large MWC plant shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain sulfur dioxide in excess of 20 percent of the 
potential sulfur dioxide emission rate (80 percent reduction by weight 
or volume) or 30 parts per million by volume, corrected to 7 percent 
oxygen (dry basis), whichever is less stringent. The averaging time is 
specified in Sec. 60.58a(e).
    (d) On and after the date on which the initial compliance test is 
completed or is required to be completed under Sec. 60.8, no owner or 
operator of an affected facility located within a large MWC plant shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain hydrogen chloride in excess of 5 percent of the 
potential hydrogen chloride emission rate (95 percent reduction by 
weight or volume) or 25 parts per million by volume, corrected to 7 
percent

[[Page 141]]

oxygen (dry basis), whichever is less stringent.



Sec. 60.55a  Standard for nitrogen oxides.

    On and after the date on which the initial compliance test is 
completed or is required to be completed under Sec. 60.8, no owner or 
operator of an affected facility located within a large MWC plant shall 
cause to be discharged into the atmosphere from that affected facility 
any gases that contain nitrogen oxides in excess of 180 parts per 
million by volume, corrected to 7 percent oxygen (dry basis). The 
averaging time is specified under Sec. 60.58a(g).



Sec. 60.56a  Standards for municipal waste combustor operating practices.

    (a) On and after the date on which the initial compliance test is 
completed or is required to be completed under Sec. 60.8, no owner or 
operator of an affected facility located within a large MWC plant shall 
cause such facility to exceed the carbon monoxide standards shown in 
table 1.

                    Table 1--MWC Operating Standards
------------------------------------------------------------------------
                                                              Carbon
                                                             monoxide
                                                          emission limit
                     MWC technology                         (parts per
                                                            million by
                                                            volume) \1\
------------------------------------------------------------------------
Mass burn waterwall.....................................             100
Mass burn refractory....................................             100
Mass burn rotary waterwall..............................             100
Modular starved air.....................................              50
Modular excess air......................................              50
RDF stoker..............................................             150
Bubbling fluidized bed combustor........................             100
Circulating fluidized bed combustor.....................             100
Pulverized coal/RDF mixed fuel-fired combustor..........             150
Spreader stoker coal/RDF mixed fuel-fird combustor......             150
------------------------------------------------------------------------
\1\ Measured at the combustor outlet in conjunction with a measurement
  of oxygen concentration, corrected to 7 percent oxygen (dry basis).
  The averaging times are specified in Sec.  60.58a(h).

    (b) No owner or operator of an affected facility located within a 
large MWC plant shall cause such facility to operate at a load level 
greater than 110 percent of the maximum demonstrated MWC unit load as 
defined in Sec. 60.51a. The averaging time is specified under 
Sec. 60.58a(h).
    (c) No owner or operator of an affected facility located within a 
large MWC plant shall cause such facility to operate at a temperature, 
measured at the final particulate matter control device inlet, exceeding 
17  deg.Centigrade (30  deg.Fahrenheit) above the maximum demonstrated 
particulate matter control device temperature as defined in Sec. 60.51a. 
The averaging time is specified under Sec. 60.58a(h).
    (d) Within 24 months from the date of start-up of an affected 
facility or before February 11, 1993, whichever is later, each chief 
facility operator and shift supervisor of an affected faciltiy located 
within a large MWC plant shall obtain and keep current either a 
provisional or operator certification in accordance with ASME QRO-1-1994 
(incorporated by reference, see Sec. 60.17) or an equivalent State-
approved certification program.
    (e) No owner or operator of an affected facility shall allow such 
affected facility located at a large MWC plant to operate at any time 
without a certified shift supervisor, as provided under paragraph (d) of 
this section, on duty at the affected facility. This requirement shall 
take effect 24 months after the date of start-up of the affected 
facility or on and after February 11, 1993, whichever is later.
    (f) The owner or operator of an affected facility located within a 
large MWC plant shall develop and update on a yearly basis a 
sitespecific operating manual that shall, at a minimum, address the 
following elements of MWC unit operation:
    (1) Summary of the applicable standards under this subpart;
    (2) Description of basic combustion theory applicable to an MWC 
unit;
    (3) Procedures for receiving, handling, and feeding MSW;
    (4) MWC unit start-up, shutdown, and malfunction procedures;
    (5) Procedures for maintaining proper combustion air supply levels;
    (6) Procedures for operating the MWC unit within the standards 
established under this subpart;
    (7) Procedures for responding to periodic upset or off-specification 
conditions;
    (8) Procedures for minimizing particulate matter carryover;
    (9) [Reserved]
    (10) Procedures for handling ash;
    (11) Procedures for monitoring MWC unit emissions; and

[[Page 142]]

    (12) Reporting and recordkeeping procedures.
    (g) The owner or operator of an affected facility located within a 
large MWC plant shall establish a program for reviewing the operating 
manual annually with each person who has responsibilities affecting the 
operation of an affected facility including, but not limited to, chief 
facility operators, shift supervisors, control room operators, ash 
handlers, maintenance personnel, and crane/load handlers.
    (h) The initial review of the operating manual, as specified under 
paragraph (g) of this section, shall be conducted prior to assumption of 
responsibilities affecting MWC unit operation by any person required to 
undergo training under paragraph (g) of this section. Subsequent reviews 
of the manual shall be carried out annually by each such person.
    (i) The operating manual shall be kept in a readily accessible 
location for all persons required to undergo training under paragraph 
(g) of this section. The operating manual and records of training shall 
be available for inspection by EPA or its delegated enforcement agent 
upon request.
    (j)--(k) [Reserved]

[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65386, Dec. 19, 1995]



Sec. 60.57a  [Reserved]



Sec. 60.58a  Compliance and performance testing.

    (a) The standards under this subpart apply at all times, except 
during periods of start-up, shutdown, or malfunction; provided, however, 
that the duration of start-up, shutdown, or malfunction shall not exceed 
3 hours per occurrence.
    (1) The start-up period commences when the affected facility begins 
the continuous burning of MSW and does not include any warm-up period 
when the affected facility is combusting only a fossil fuel or other 
non-MSW fuel and no MSW is being combusted.
    (2) Continuous burning is the continuous, semicontinuous, or batch 
feeding of MSW for purposes of waste disposal, energy production, or 
providing heat to the combustion system in preparation for waste 
disposal or energy production. The use of MSW solely to provide thermal 
protection of grate or hearth during the start-up period shall not be 
considered to be continuous burning.
    (b) The following procedures and test methods shall be used to 
determine compliance with the emission limits for particulate matter 
under Sec. 60.52a:
    (1) Method 1 shall be used to select sampling site and number of 
traverse points.
    (2) Method 3 shall be used for gas analysis.
    (3) Method 5 shall be used for determining compliance with the 
particulate matter emission standard. The minimum sample volume shall be 
1.7 cubic meters (60 cubic feet). The probe and filter holder heating 
systems in the sample train shall be set to provide a gas temperature no 
greater than 160 deg.14  deg.Centigrade 
(320 deg.25  deg.Fahrenheit). An oxygen or carbon dioxide 
measurement shall be obtained simultaneously with each Method 5 run.
    (4) For each Method 5 run, the emission rate shall be determined 
using:
    (i) Oxygen or carbon dioxide measurements,
    (ii) Dry basis F factor, and
    (iii) Dry basis emission rate calculation procedures in Method 19.
    (5) An owner or operator may request that compliance be determined 
using carbon dioxide measurements corrected to an equivalent of 7 
percent oxygen. The relationship between oxygen and carbon dioxide 
levels for the affected facility shall be established during the initial 
compliance test.
    (6) The owner or operator of an affected facility shall conduct an 
initial compliance test for particulate matter and opacity as required 
under Sec. 60.8.
    (7) Method 9 shall be used for determining compliance with the 
opacity limit.
    (8) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a CEMS for measuring opacity and record 
the output of the system on a 6-minute average basis.
    (9) Following the date the initial compliance test for particulate 
matter is completed or is required to be completed under Sec. 60.8 for 
an affected facility located within a large MWC plant,

[[Page 143]]

the owner or operator shall conduct a performance test for particulate 
matter on an annual basis (no more than 12 calendar months following the 
previous compliance test).
    (10) [Reserved]
    (c) [Reserved]
    (d) The following procedures and test methods shall be used to 
determine compliance with the limits for dioxin/furan emissions under 
Sec. 60.53a:
    (1) Method 23 shall be used for determining compliance with the 
dioxin/furan emission limits. The minimum sample time shall be 4 hours 
per test run.
    (2) The owner or operator of an affected facility shall conduct an 
initial compliance test for dioxin/furan emissions as required under 
Sec. 60.8.
    (3) Following the date of the initial compliance test or the date on 
which the initial compliance test is required to be completed under 
Sec. 60.8, the owner or operator of an affected facility located within 
a large MWC plant shall conduct a performance test for dioxin/furan 
emissions on an annual basis (no more than 12 calendar months following 
the previous compliance test).
    (4) [Reserved]
    (5) An owner or operator may request that compliance with the 
dioxin/furan emissions limit be determined using carbon dioxide 
measurements corrected to an equivalent of 7 percent oxygen. The 
relationship between oxygen and carbon dioxide levels for the affected 
facility shall be established during the initial compliance test.
    (e) The following procedures and test methods shall be used for 
determining compliance with the sulfur dioxide limit under Sec. 60.54a:
    (1) Method 19, section 5.4, shall be used to determine the daily 
geometric average percent reduction in the potential sulfur dioxide 
emission rate.
    (2) Method 19, section 4.3, shall be used to determine the daily 
geometric average sulfur dioxide emission rate.
    (3) An owner or operator may request that compliance with the sulfur 
dioxide emissions limit be determined using carbon dioxide measurements 
corrected to an equivalent of 7 percent oxygen. The relationship between 
oxygen and carbon dioxide levels for the affected facility shall be 
established during the initial compliance test.
    (4) The owner or operator of an affected facility shall conduct an 
initial compliance test for sulfur dioxide as required under Sec. 60.8. 
Compliance with the sulfur dioxide emission limit and percent reduction 
is determined by using a CEMS to measure sulfur dioxide and calculating 
a 24-hour daily geometric mean emission rate and daily geometric mean 
percent reduction using Method 19 sections 4.3 and 5.4, as applicable, 
except as provided under paragraph (e)(5) of this section.
    (5) For batch MWC's or MWC units that do not operate continuously, 
compliance shall be determined using a daily geometric mean of all 
hourly average values for the hours during the day that the affected 
facility is combusting MSW.
    (6) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a CEMS for measuring sulfur dioxide 
emissions discharged to the atmosphere and record the output of the 
system.
    (7) Following the date of the initial compliance test or the date on 
which the initial compliance test is required to be completed under 
Sec. 60.8, compliance with the sulfur dioxide emission limit or percent 
reduction shall be determined based on the geometric mean of the hourly 
arithmetic average emission rates during each 24-hour daily period 
measured between 12:00 midnight and the following midnight using: CEMS 
inlet and outlet data, if compliance is based on a percent reduction; or 
CEMS outlet data only if compliance is based on an emission limit.
    (8) At a minimum, valid CEMS data shall be obtained for 75 percent 
of the hours per day for 75 percent of the days per month the affected 
facility is operated and combusting MSW.
    (9) The 1-hour arithmetic averages required under paragraph (e)(7) 
of this section shall be expressed in parts per million (dry basis) and 
used to calculate the 24-hour daily geometric mean emission rates. The 
1-hour arithmetic averages shall be calculated using the data points 
required under Sec. 60.13(e)(2). At least two data points shall be used 
to calculate each 1-hour arithmetic average.

[[Page 144]]

    (10) All valid CEMS data shall be used in calculating emission rates 
and percent reductions even if the minimum CEMS data requirements of 
paragraph (e)(8) of this Section are not met.
    (11) The procedures under Sec. 60.1 3 shall be followed for 
installation, evaluation, and operation of the CEMS.
    (12) The CEMS shall be operated according to Performance 
Specifications 1, 2, and 3 (appendix B of part 60).
    (13) Quarterly accuracy determinations and daily calibration drift 
tests shall be performed in accordance with Procedure 1 (appendix F of 
part 60).
    (14) The span value of the CEMS at the inlet to the sulfur dioxide 
control device is 125 percent of the maximum estimated hourly potential 
sulfur dioxide emissions of the MWC unit, and the span value of the CEMS 
at the outlet to the sulfur dioxide control device is 50 percent of the 
maximum estimated hourly potential sulfur dioxide emissions of the MWC 
unit.
    (15) When sulfur dioxide emissions data are not obtained because of 
CEMS breakdowns, repairs, calibration checks and zero and span 
adjustments, emissions data shall be obtained by using other monitoring 
systems as approved by the Administrator or Method 19 to provide as 
necessary valid emission data for a minimum of 75 percent of the hours 
per day for 75 percent of the days per month the unit is operated and 
combusting MSW.
    (16) Not operating a sorbent injection system for the sole purpose 
of testing in order to demonstrate compliance with the percent reduction 
standards for MWC acid gases shall not be considered a physical change 
in the method of operation under 40 CFR 52.21, or under regulations 
approved pursuant to 40 CFR 51.166 or 40 CFR 51.165 (a) and (b).
    (f) The following procedures and test methods shall be used for 
determining compliance with the hydrogen chloride limits under 
Sec. 60.54a:
    (1) The percentage reduction in the potential hydrogen chloride 
emissions (%PHCl) is computed using the following formula:
[GRAPHIC] [TIFF OMITTED] TC16NO91.003

where:
    Ei is the potential hydrogen chloride emission rate.
    Eo is the hydrogen chloride emission rate measured at the 
outlet of the acid gas control device.

    (2) Method 26 shall be used for determining the hydrogen chloride 
emission rate. The minimum sampling time for Method 26 shall be 1 hour.
    (3) An owner or operator may request that compliance with the 
hydrogen chloride emissions limit be determined using carbon dioxide 
measurements corrected to an equivalent of 7 percent oxygen. The 
relationship between oxygen and carbon dioxide levels for the affected 
facility shall be established during the initial compliance test.
    (4) The owner or operator of an affected facility shall conduct an 
initial compliance test for hydrogen chloride as required under 
Sec. 60.8.
    (5) Following the date of the initial compliance test or the date on 
which the initial compliance test is required under Sec. 60.8, the owner 
or operator of an affected facility located within a large MWC plant 
shall conduct a performance test for hydrogen chloride on an annual 
basis (no more than 12 calendar months following the previous compliance 
test).
    (6) [Reserved]
    (7) Not operating a sorbent injection system for the sole purpose of 
testing in order to demonstrate compliance with the percent reduction 
standards for MWC acid gases shall not be considered a physical change 
in the method of operation under 40 CFR 52.21, or under regulations 
approved pursuant to 40 CFR 51.166 or 40 CFR 51.165 (a) and (b).
    (g) The following procedures and test methods shall be used to 
determine compliance with the nitrogen oxides limit under Sec. 60.55a:
    (1) Method 19, section 4.1, shall be used for determining the daily 
arithmetic average nitrogen oxides emission rate.
    (2) An owner or operator may request that compliance with the 
nitrogen oxides emissions limit be determined using carbon dioxide 
measurements corrected to an equivalent of 7 percent oxygen. The 
relationship between oxygen and carbon dioxide levels for the affected 
facility shall be established during the initial compliance test.

[[Page 145]]

    (3) The owner or operator of an affected facility subject to the 
nitrogen oxides limit under Sec. 60.55a shall conduct an initial 
compliance test for nitrogen oxides as required under Sec. 60.8. 
Compliance with the nitrogen oxides emission standard shall be 
determined by using a CEMS for measuring nitrogen oxides and calculating 
a 24-hour daily arithmetic average emission rate using Method 19, 
section 4.1, except as specified under paragraph (g)(4) of this section.
    (4) For batch MWC's or MWC's that do not operate continuously, 
compliance shall be determined using a daily arithmetic average of all 
hourly average values for the hours during the day that the affected 
facility is combusting MSW.
    (5) The owner or operator of an affected facility subject to the 
nitrogen oxides emissions limit under Sec. 60.55a shall install, 
calibrate, maintain, and operate a CEMS for measuring nitrogen oxides 
discharged to the atmosphere and record the output of the system.
    (6) Following the initial compliance test or the date on which the 
initial compliance test is required to be completed under Sec. 60.8, 
compliance with the emission limit for nitrogen oxides required under 
Sec. 60.55a shall be determined based on the arithmetic average of the 
arithmetic average hourly emission rates during each 24-hour daily 
period measured between 12:00 midnight and the following midnight using 
CEMS data.
    (7) At a minimum valid CEMS data shall be obtained for 75 percent of 
the hours per day for 75 percent of the days per month the affected 
facility is operated and combusting MSW.
    (8) The 1-hour arithmetic averages required by paragraph (g)(6) of 
this section shall be expressed in parts per million volume (dry basis) 
and used to calculate the 24-hour daily arithmetic average emission 
rates. The 1-hour arithmetic averages shall be calculated using the data 
points required under Sec. 60.13(b). At least two data points shall be 
used to calculate each 1-hour arithmetic average.
    (9) All valid CEMS data must be used in calculating emission rates 
even if the minimum CEMS data requirements of paragraph (g)(7) of this 
section are not met.
    (10) The procedures under Sec. 60.13 shall be followed for 
installation, evaluation, and operation of the CEMS.
    (11) Quarterly accuracy determinations and daily calibration drift 
tests shall be performed in accordance with Procedure 1 (appendix F of 
part 60).
    (12) When nitrogen oxides emissions data are not obtained because of 
CEMS breakdowns, repairs, calibration checks, and zero and span 
adjustments, emission data calculations to determine compliance shall be 
made using other monitoring systems as approved by the Administrator or 
Method 19 to provide as necessary valid emission data for a minimum of 
75 percent of the hours per day for 75 percent of the days per month the 
unit is operated and combusting MSW.
    (h) The following procedures shall be used for determining 
compliance with the operating standards under Sec. 60.56a:
    (1) Compliance with the carbon monoxide emission limits in 
Sec. 60.56a(a) shall be determined using a 4-hour block arithmetic 
average for all types of affected facilities except mass burn rotary 
waterwall MWC's, RDF stokers, and spreader stoker/RDF mixed fuel-fired 
combustors.
    (2) For affected mass burn rotary waterwall MWC's, RDF stokers, and 
spreader stoker/RDF mixed fuel-fired combustors, compliance with the 
carbon monoxide emission limits in Sec. 60.56a(a) shall be determined 
using a 24-hour daily arithmetic average.
    (3) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a CEMS for measuring carbon monoxide at 
the combustor outlet and record the output of the system.
    (4) The 4-hour and 24-hour daily arithmetic averages in paragraphs 
(h) (1) and (2) of this section shall be calculated from 1-hour 
arithmetic averages expressed in parts per million by volume (dry 
basis). The 1-hour arithmetic averages shall be calculated using the 
data points generated by the CEMS. At least two data points shall be 
used to calculate each 1-hour arithmetic average.

[[Page 146]]

    (5) An owner or operator may request that compliance with the carbon 
monoxide emission limit be determined using carbon dioxide measurements 
corrected to an equivalent of 7 percent oxygen. The relationship between 
oxygen and carbon dioxide levels for the affected facility shall be 
established during the initial compliance test.
    (6) The following procedures shall be used to determine compliance 
with load level requirements under Sec. 60.56a(b):
    (i) The owner or operator of an affected facility with steam 
generation capability shall install, calibrate, maintain, and operate a 
steam flow meter or a feedwater flow meter; measure steam or feedwater 
flow in kilograms per hour (pounds per hour) on a continuous basis; and 
record the output of the monitor. Steam or feedwater flow shall be 
calculated in 4-hour block arithmetic averages.
    (ii) The method included in ``American Society of Mechanical 
Engineers Power Test Codes: Test Code for Steam Generating Units, Power 
Test Code 4.1--1964'', Section 4 (incorporated by reference, see 
Sec. 60.17) shall be used for calculating the steam (or feedwater flow) 
required under paragraph (h)(6)(i) of this section. The recommendations 
of ``American Society of Mechanical Engineers Interim Supplement 19.5 on 
Instruments and Apparatus: Application, Part II of Fluid Meters, 6th 
edition (1971),'' chapter 4 (incorporated by reference, see Sec. 60.17) 
shall be followed for design, construction, installation, calibration, 
and use of nozzles and orifices except as specified in (h)(6)(iii) of 
this section.
    (iii) Measurement devices such as flow nozzles and orifices are not 
required to be recalibrated after they are installed.
    (iv) All signal conversion elements associated with steam (or 
feedwater flow) measurements must be calibrated according to the 
manufacturer's instructions before each dioxin/furan compliance and 
performance test, and at least once per year.
    (v) The owner or operator of an affected facility without heat 
recovery shall:
    (A) [Reserved]
    (7) To determine compliance with the maximum particulate matter 
control device temperature requirements under Sec. 60.56a(c), the owner 
or operator of an affected facility shall install, calibrate, maintain, 
and operate a device for measuring temperature of the flue gas stream at 
the inlet to the final particulate matter control device on a continuous 
basis and record the output of the device. Temperature shall be 
calculated in 4-hour block arithmetic averages.
    (8) Maximum demonstrated MWC unit load shall be determined during 
the initial compliance test for dioxins/furans and each subsequent 
performance test during which compliance with the dioxin/furan emission 
limit under Sec. 60.53a is achieved. Maximum demonstrated MWC unit load 
shall be the maximum 4-hour arithmetic average load achieved during the 
most recent test during which compliance with the dioxin/furan limit was 
achieved.
    (9) The maximum demonstrated particulate matter control device 
temperature shall be determined during the initial compliance test for 
dioxins/furans and each subsequent performance test during which 
compliance with the dioxin/furan emission limit under Sec. 60.53a is 
achieved. Maximum demonstrated particulate matter control device 
temperature shall be the maximum 4-hour arithmetic average temperature 
achieved at the final particulate matter control device inlet during the 
most recent test during which compliance with the dioxin/furan limit was 
achieved.
    (10) At a minimum, valid CEMS data for carbon monoxide, steam or 
feedwater flow, and particulate matter control device inlet temperature 
shall be obtained 75 percent of the hours per day for 75 percent of the 
days per month the affected facility is operated and combusting MSW.
    (11) All valid data must be used in calculating the parameters 
specified under paragraph (h) of this section even if the minimum data 
requirements of paragraph (h)(10) of this section are not met.
    (12) Quarterly accuracy determinations and daily calibration drift 
tests for carbon monoxide CEMS shall be

[[Page 147]]

performed in accordance with Procedure 1 (appendix F).
    (i) [Reserved]
    (j) The following procedures shall be used for calculating MWC unit 
capacity as defined under Sec. 60.51a:
    (1) For MWC units capable of combusting MSW continuously for a 24-
hour period, MWC unit capacity, in megagrams per day (tons per day) of 
MSW combusted, shall be calculated based on 24 hours of operation at the 
maximum design charging rate. The design heating values under paragraph 
(j)(4) of this section shall be used in calculating the design charging 
rate.
    (2) For batch MWC units, MWC unit capacity, in megagrams per day 
(tons per day) of MSW combusted, shall be calculated as the maximum 
design amount of MSW that can be charged per batch multiplied by the 
maximum number of batches that could be processed in a 24-hour period. 
The maximum number of batches that could be processed in a 24-hour 
period is calculated as 24 hours divided by the design number of hours 
required to process one batch of MSW, and may include fractional 
batches.\1\ The design heating values under paragraph (j)(4) of this 
section shall be used in calculating the MWC unit capacity in megagrams 
per day (tons per day) of MSW.
---------------------------------------------------------------------------

    \1\ For example, if one batch requires 16 hours, then 24/16, or 1.5 
batches, could be combusted in a 24-hour period.
---------------------------------------------------------------------------

    (3) [Reserved]
    (4) The MWC unit capacity shall be calculated using a design heating 
value of 10,500 kilojoules per kilogram (4,500 British thermal units per 
pound) for all MSW.

[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65387, Dec. 19, 1995]



Sec. 60.59a  Reporting and recordkeeping requirements.

    (a) The owner or operator of an affected facility located at an MWC 
plant with a capacity greater than 225 megagrams per day (250 tons per 
day) shall provide notification of intent to construct and of planned 
initial start-up date and the type(s) of fuels that they plan to combust 
in the affected facility. The MWC unit capacity and MWC plant capacity 
and supporting capacity calculations shall be provided at the time of 
the notification of construction.
    (b) The owner or operator of an affected facility located within a 
small or large MWC plant and subject to the standards under Sec. 60.52a, 
Sec. 60.53a, Sec. 60.54a, Sec. 60.55a, Sec. 60.56a, or Sec. 60.57a shall 
maintain records of the following information for each affected facility 
for a period of at least 2 years:
    (1) Calendar date.
    (2) The emission rates and parameters measured using CEMS as 
specified under (b)(2) (i) and (ii) of this section:
    (i) The following measurements shall be recorded in computer-
readable format and on paper:
    (A) All 6-minute average opacity levels required under 
Sec. 60.58a(b).
    (B) All 1 hour average sulfur dioxide emission rates at the inlet 
and outlet of the acid gas control device if compliance is based on a 
percent reduction, or at the outlet only if compliance is based on the 
outlet emission limit, as specified under Sec. 60.58a(e).
    (C) All 1-hour average nitrogen oxides emission rates as specified 
under Sec. 60.58a(g).
    (D) All 1-hour average carbon monoxide emission rates, MWC unit load 
measurements, and particulate matter control device inlet temperatures 
as specified under Sec. 60.58a(h).
    (ii) The following average rates shall be computed and recorded:
    (A) All 24-hour daily geometric average percent reductions in sulfur 
dioxide emissions and all 24-hour daily geometric average sulfur dioxide 
emission rates as specified under Sec. 60.58a(e).
    (B) All 24-hour daily arithmetic average nitrogen oxides emission 
rates as specified under Sec. 60.58a(g).
    (C) All 4-hour block or 24-hour daily arithmetic average carbon 
monoxide emission rates, as applicable, as specified under 
Sec. 60.58a(h).
    (D) All 4-hour block arithmetic average MWC unit load levels and 
particulate matter control device inlet temperatures as specified under 
Sec. 60.58a(h).
    (3) Identification of the operating days when any of the average 
emission rates, percent reductions, or operating parameters specified 
under paragraph (b)(2)(ii) of this section or the opacity

[[Page 148]]

level exceeded the applicable limits, with reasons for such exceedances 
as well as a description of corrective actions taken.
    (4) Identification of operating days for which the minimum number of 
hours of sulfur dioxide or nitrogen oxides emissions or operational data 
(carbon monoxide emissions, unit load, particulate matter control device 
temperature) have not been obtained, including reasons for not obtaining 
sufficient data and a description of corrective actions taken.
    (5) Identification of the times when sulfur dioxide or nitrogen 
oxides emission or operational data (carbon monoxide emissions, unit 
load, particulate matter control device temperature) have been excluded 
from the calculation of average emission rates or parameters and the 
reasons for excluding data.
    (6) The results of daily sulfur dioxide, nitrogen oxides, and carbon 
monoxide CEMS drift tests and accuracy assessments as required under 
appendix F, Procedure 1.
    (7) The results of all annual performance tests conducted to 
determine compliance with the particulate matter, dioxin/furan and 
hydrogen chloride limits. For all annual dioxin/furan tests, the maximum 
demonstrated MWC unit load and maximum demonstrated particulate matter 
control device temperature shall be recorded along with supporting 
calculations.
    (8)--(15) [Reserved]
    (c) Following the initial compliance test as required under 
Sec. Sec. 60.8 and 60.58a, the owner or operator of an affected facility 
located within a large MWC plant shall submit the initial compliance 
test data, the performance evaluation of the CEMS using the applicable 
performance specifications in appendix B, and the maximum demonstrated 
MWC unit load and maximum demonstrated particulate matter control device 
temperature established during the dioxin/furan compliance test.
    (d) [Reserved]
    (e)(1) The owner or operator of an affected facility located within 
a large MWC plant shall submit annual compliance reports for sulfur 
dioxide, nitrogen oxide (if applicable), carbon monoxide, load level, 
and particulate matter control device temperature to the Administrator 
containing the information recorded under paragraphs (b)(1), (2)(ii), 
(4), (5), and (6) of this section for each pollutant or parameter. The 
hourly average values recorded under paragraph (b)(2)(i) of this section 
are not required to be included in the annual reports. Combustors firing 
a mixture of medical waste and other MSW shall also provide the 
information under paragraph (b)(15) of this section, as applicable, in 
each annual report. The owner or operator of an affected facility must 
submit reports semiannually once the affected facility is subject to 
permitting requirements under Title V of the Act.
    (2) The owner or operator shall submit a semiannual report for any 
pollutant or parameter that does not comply with the pollutant or 
parameter limits specified in this subpart. Such report shall include 
the information recorded under paragraph (b)(3) of this section. For 
each of the dates reported, include the sulfur dioxide, nitrogen oxide, 
carbon monoxide, load level, and particulate matter control device 
temperature data, as applicable, recorded under paragraphs (b)(2)(ii)(A) 
through (D) of this section.
    (3) Reports shall be postmarked no later than the 30th day following 
the end of the annual or semiannual period, as applicable.
    (f)(1) The owner or operator of an affected facility located within 
a large MWC plant shall submit annual compliance reports, as applicable, 
for opacity. The annual report shall list the percent of the affected 
facility operating time for the reporting period that the opacity CEMS 
was operating and collecting valid data. Once the unit is subject to 
permitting requirements under Title V of the Act, the owner or operator 
of an affected facility must submit these reports semiannually.
    (2) The owner or operator shall submit a semiannual report for all 
periods when the 6-minute average levels exceeded the opacity limit 
under Sec. 60.52a. The semiannual report shall include all information 
recorded under paragraph (b)(3) of this section which pertains to 
opacity, and a listing of the 6-minute average opacity levels recorded 
under

[[Page 149]]

paragraph (b)(2)(i)(A) of this section, which exceeded the opacity 
limit.
    (3) Reports shall be postmarked no later than the 30th day following 
the end of the annual of semiannual period, as applicable.
    (g)(1) The owner or operator of an affected facility located within 
a large MWC plant shall submit reports to the Administrator of all 
annual performance tests for particulate matter, dioxin/furan, and 
hydrogen chloride as recorded under paragraph (b)(7) of this section, as 
applicable, from the affected facility. For each annual dioxin/furan 
compliance test, the maximum demonstrated MWC unit load and maximum 
demonstrated particulate matter control device temperature shall be 
reported. Such reports shall be submitted when available and in no case 
later than the date of required submittal of the annual report specified 
under paragraphs (e) and (f) of this section, or within six months of 
the date the test was conducted, whichever is earlier.
    (2) The owner or operator shall submit a report of test results 
which document any particulate matter, dioxin/furan, and hydrogen 
chloride levels that were above the applicable pollutant limit. The 
report shall include a copy of the test report documenting the emission 
levels and shall include the corrective action taken. Such reports shall 
be submitted when available and in no case later than the date required 
for submittal of any semiannual report required in paragraphs (e) or (f) 
of this section, or within six months of the date the test was 
conducted, whichever is earlier.
    (h) [Reserved]
    (i) Records of CEMS data for opacity, sulfur dioxide, nitrogen 
oxides, and carbon monoxide, load level data, and particulate matter 
control device temperature data shall be maintained for at least 2 years 
after date of recordation and be made available for inspection upon 
request.
    (j) Records showing the names of persons who have completed review 
of the operating manual, including the date of the initial review and 
all subsequent annual reviews, shall be maintained for at least 2 years 
after date of review and be made available for inspection upon request.

[56 FR 5507, Feb. 11, 1991, as amended at 60 FR 65387, Dec. 19, 1995; 64 
FR 7465, Feb. 12, 1999]



     Subpart Eb--Standards of Performance for Large Municipal Waste 
Combustors for Which Construction is Commenced After September 20, 1994 
or for Which Modification or Reconstruction is Commenced After June 19, 
                                  1996

    Source: 60 FR 65419, Dec. 19, 1995, unless otherwise noted.



Sec. 60.50b  Applicability and delegation of authority.

    (a) The affected facility to which this subpart applies is each 
municipal waste combustor unit with a combustion capacity greater than 
250 tons per day of municipal solid waste for which construction is 
commenced after September 20, 1994 or for which modification or 
reconstruction is commenced after June 19, 1996.
    (b) Any waste combustion unit that is capable of combusting more 
than 250 tons per day of municipal solid waste and is subject to a 
federally enforceable permit limiting the maximum amount of municipal 
solid waste that may be combusted in the unit to less than or equal to 
11 tons per day is not subject to this subpart if the owner or operator:
    (1) Notifies the EPA Administrator of an exemption claim;
    (2) Provides a copy of the federally enforceable permit that limits 
the firing of municipal solid waste to less than 11 tons per day; and
    (3) Keeps records of the amount of municipal solid waste fired on a 
daily basis.
    (c) An affected facility to which this subpart applies is not 
subject to subpart E or Ea of this part.
    (d) Physical or operational changes made to an existing municipal 
waste combustor unit primarily for the purpose of complying with 
emission guidelines under subpart Cb are not considered a modification 
or reconstruction

[[Page 150]]

and do not result in an existing municipal waste combustor unit becoming 
subject to this subpart.
    (e) A qualifying small power production facility, as defined in 
section 3(17)(C) of the Federal Power Act (16 U.S.C. 796(17)(C)), that 
burns homogeneous waste (such as automotive tires or used oil, but not 
including refuse-derived fuel) for the production of electric energy is 
not subject to this subpart if the owner or operator of the facility 
notifies the EPA Administrator of this exemption and provides data 
documenting that the facility qualifies for this exemption.
    (f) A qualifying cogeneration facility, as defined in section 
3(18)(B) of the Federal Power Act (16 U.S.C. 796(18)(B)), that burns 
homogeneous waste (such as automotive tires or used oil, but not 
including refuse-derived fuel) for the production of electric energy and 
steam or forms of useful energy (such as heat) that are used for 
industrial, commercial, heating, or cooling purposes, is not subject to 
this subpart if the owner or operator of the facility notifies the EPA 
Administrator of this exemption and provides data documenting that the 
facility qualifies for this exemption.
    (g) Any unit combusting a single-item waste stream of tires is not 
subject to this subpart if the owner or operator of the unit:
    (1) Notifies the EPA Administrator of an exemption claim; and
    (2) [Reserved]
    (3) Provides data documenting that the unit qualifies for this 
exemption.
    (h) Any unit required to have a permit under section 3005 of the 
Solid Waste Disposal Act is not subject to this subpart.
    (i) Any materials recovery facility (including primary or secondary 
smelters) that combusts waste for the primary purpose of recovering 
metals is not subject to this subpart.
    (j) Any cofired combustor, as defined under Sec. 60.51b, that meets 
the capacity specifications in paragraph (a) of this section is not 
subject to this subpart if the owner or operator of the cofired 
combustor:
    (1) Notifies the EPA Administrator of an exemption claim;
    (2) Provides a copy of the federally enforceable permit (specified 
in the definition of cofired combustor in this section); and
    (3) Keeps a record on a calendar quarter basis of the weight of 
municipal solid waste combusted at the cofired combustor and the weight 
of all other fuels combusted at the cofired combustor.
    (k) Air curtain incinerators, as defined under Sec. 60.51b, located 
at a plant that meet the capacity specifications in paragraph (a) of 
this section and that combust a fuel stream composed of 100 percent yard 
waste are exempt from all provisions of this subpart except the opacity 
limit under Sec. 60.56b, the testing procedures under Sec. 60.58b(l), 
and the reporting and recordkeeping provisions under Sec. 60.59b (e) and 
(i).
    (l) Air curtain incinerators located at plants that meet the 
capacity specifications in paragraph (a) of this section combusting 
municipal solid waste other than yard waste are subject to all 
provisions of this subpart.
    (m) Pyrolysis/combustion units that are an integrated part of a 
plastics/rubber recycling unit (as defined in Sec. 60.51b) are not 
subject to this subpart if the owner or operator of the plastics/rubber 
recycling unit keeps records of the weight of plastics, rubber, and/or 
rubber tires processed on a calendar quarter basis; the weight of 
chemical plant feedstocks and petroleum refinery feedstocks produced and 
marketed on a calendar quarter basis; and the name and address of the 
purchaser of the feedstocks. The combustion of gasoline, diesel fuel, 
jet fuel, fuel oils, residual oil, refinery gas, petroleum coke, 
liquified petroleum gas, propane, or butane produced by chemical plants 
or petroleum refineries that use feedstocks produced by plastics/rubber 
recycling units are not subject to this subpart.
    (n) The following authorities shall be retained by the Administrator 
and not transferred to a State: None.
    (o) This subpart shall become effective June 19, 1996.
    (p) Cement kilns firing municipal solid waste are not subject to 
this subpart.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45120, 45125, Aug. 25, 
1997]

[[Page 151]]



Sec. 60.51b  Definitions.

    Air curtain incinerator means an incinerator that operates by 
forcefully projecting a curtain of air across an open chamber or pit in 
which burning occurs. Incinerators of this type can be constructed above 
or below ground and with or without refractory walls and floor.
    Batch municipal waste combustor means a municipal waste combustor 
unit designed so that it cannot combust municipal solid waste 
continuously 24 hours per day because the design does not allow waste to 
be fed to the unit or ash to be removed while combustion is occurring.
    Bubbling fluidized bed combustor means a fluidized bed combustor in 
which the majority of the bed material remains in a fluidized state in 
the primary combustion zone.
    Calendar quarter means a consecutive 3-month period (nonoverlapping) 
beginning on January 1, April 1, July 1, and October 1.
    Calendar year means the period including 365 days starting January 1 
and ending on December 31.
    Chief facility operator means the person in direct charge and 
control of the operation of a municipal waste combustor and who is 
responsible for daily onsite supervision, technical direction, 
management, and overall performance of the facility.
    Circulating fluidized bed combustor means a fluidized bed combustor 
in which the majority of the fluidized bed material is carried out of 
the primary combustion zone and is transported back to the primary zone 
through a recirculation loop.
    Clean wood means untreated wood or untreated wood products including 
clean untreated lumber, tree stumps (whole or chipped), and tree limbs 
(whole or chipped). Clean wood does not include yard waste, which is 
defined elsewhere in this section, or construction, renovation, and 
demolition wastes (including but not limited to railroad ties and 
telephone poles), which are exempt from the definition of municipal 
solid waste in this section.
    Cofired combustor means a unit combusting municipal solid waste with 
nonmunicipal solid waste fuel (e.g., coal, industrial process waste) and 
subject to a federally enforceable permit limiting the unit to 
combusting a fuel feed stream, 30 percent or less of the weight of which 
is comprised, in aggregate, of municipal solid waste as measured on a 
calendar quarter basis.
    Continuous emission monitoring system means a monitoring system for 
continuously measuring the emissions of a pollutant from an affected 
facility.
    Dioxin/furan means tetra- through octa- chlorinated dibenzo-p-
dioxins and dibenzofurans.
    Federally enforceable means all limitations and conditions that are 
enforceable by the Administrator including the requirements of 40 CFR 
parts 60, 61, and 63, requirements within any applicable State 
implementation plan, and any permit requirements established under 40 
CFR 52.21 or under 40 CFR 51.18 and 40 CFR 51.24.
    First calendar half means the period starting on January 1 and 
ending on June 30 in any year.
    Four-hour block average or 4-hour block average means the average of 
all hourly emission concentrations when the affected facility is 
operating and combusting municipal solid waste measured over 4-hour 
periods of time from 12:00 midnight to 4 a.m., 4 a.m. to 8 a.m., 8 a.m. 
to 12:00 noon, 12:00 noon to 4 p.m., 4 p.m. to 8 p.m., and 8 p.m. to 
12:00 midnight.
    Mass burn refractory municipal waste combustor means a field-erected 
combustor that combusts municipal solid waste in a refractory wall 
furnace. Unless otherwise specified, this includes combustors with a 
cylindrical rotary refractory wall furnace.
    Mass burn rotary waterwall municipal waste combustor means a field-
erected combustor that combusts municipal solid waste in a cylindrical 
rotary waterwall furnace.
    Mass burn waterwall municipal waste combustor means a field-erected 
combustor that combusts municipal solid waste in a waterwall furnace.
    Materials separation plan means a plan that identifies both a goal 
and an approach to separate certain components of municipal solid waste 
for a given service area in order to make the separated materials 
available for recycling. A materials separation plan may

[[Page 152]]

include elements such as dropoff facilities, buy-back or deposit-return 
incentives, curbside pickup programs, or centralized mechanical 
separation systems. A materials separation plan may include different 
goals or approaches for different subareas in the service area, and may 
include no materials separation activities for certain subareas or, if 
warranted, an entire service area.
    Maximum demonstrated municipal waste combustor unit load means the 
highest 4-hour arithmetic average municipal waste combustor unit load 
achieved during four consecutive hours during the most recent dioxin/
furan performance test demonstrating compliance with the applicable 
limit for municipal waste combustor organics specified under 
Sec. 60.52b(c).
    Maximum demonstrated particulate matter control device temperature 
means the highest 4-hour arithmetic average flue gas temperature 
measured at the particulate matter control device inlet during four 
consecutive hours during the most recent dioxin/furan performance test 
demonstrating compliance with the applicable limit for municipal waste 
combustor organics specified under Sec. 60.52b(c).
    Modification or modified municipal waste combustor unit means a 
municipal waste combustor unit to which changes have been made after 
June 19, 1996 if the cumulative cost of the changes, over the life of 
the unit, exceed 50 percent of the original cost of construction and 
installation of the unit (not including the cost of any land purchased 
in connection with such construction or installation) updated to current 
costs; or any physical change in the municipal waste combustor unit or 
change in the method of operation of the municipal waste combustor unit 
increases the amount of any air pollutant emitted by the unit for which 
standards have been established under section 129 or section 111. 
Increases in the amount of any air pollutant emitted by the municipal 
waste combustor unit are determined at 100-percent physical load 
capability and downstream of all air pollution control devices, with no 
consideration given for load restrictions based on permits or other 
nonphysical operational restrictions.
    Modular excess-air municipal waste combustor means a combustor that 
combusts municipal solid waste and that is not field-erected and has 
multiple combustion chambers, all of which are designed to operate at 
conditions with combustion air amounts in excess of theoretical air 
requirements.
    Modular starved-air municipal waste combustor means a combustor that 
combusts municipal solid waste and that is not field-erected and has 
multiple combustion chambers in which the primary combustion chamber is 
designed to operate at substoichiometric conditions.
    Municipal solid waste or municipal-type solid waste or MSW means 
household, commercial/retail, and/or institutional waste. Household 
waste includes material discarded by single and multiple residential 
dwellings, hotels, motels, and other similar permanent or temporary 
housing establishments or facilities. Commercial/retail waste includes 
material discarded by stores, offices, restaurants, warehouses, 
nonmanufacturing activities at industrial facilities, and other similar 
establishments or facilities. Institutional waste includes material 
discarded by schools, nonmedical waste discarded by hospitals, material 
discarded by nonmanufacturing activities at prisons and government 
facilities, and material discarded by other similar establishments or 
facilities. Household, commercial/retail, and institutional waste does 
not include used oil; sewage sludge; wood pallets; construction, 
renovation, and demolition wastes (which includes but is not limited to 
railroad ties and telephone poles); clean wood; industrial process or 
manufacturing wastes; medical waste; or motor vehicles (including motor 
vehicle parts or vehicle fluff). Household, commercial/retail, and 
institutional wastes include:
    (1) Yard waste;
    (2) Refuse-derived fuel; and
    (3) Motor vehicle maintenance materials limited to vehicle batteries 
and tires except as specified in Sec. 60.50b(g).
    Municipal waste combustor, MWC, or municipal waste combustor unit: 
(1) Means any setting or equipment that

[[Page 153]]

combusts solid, liquid, or gasified municipal solid waste including, but 
not limited to, field-erected incinerators (with or without heat 
recovery), modular incinerators (starved-air or excess-air), boilers 
(i.e., steam generating units), furnaces (whether suspension-fired, 
grate-fired, mass-fired, air curtain incinerators, or fluidized bed-
fired), and pyrolysis/combustion units. Municipal waste combustors do 
not include pyrolysis/combustion units located at a plastics/rubber 
recycling unit (as specified in Sec. 60.50b(m)). Municipal waste 
combustors do not include cement kilns firing municipal solid waste (as 
specified in Sec. 60.50b(p)). Municipal waste combustors do not include 
internal combustion engines, gas turbines, or other combustion devices 
that combust landfill gases collected by landfill gas collection 
systems.
    (2) The boundaries of a municipal solid waste combustor are defined 
as follows. The municipal waste combustor unit includes, but is not 
limited to, the municipal solid waste fuel feed system, grate system, 
flue gas system, bottom ash system, and the combustor water system. The 
municipal waste combustor boundary starts at the municipal solid waste 
pit or hopper and extends through:
    (i) The combustor flue gas system, which ends immediately following 
the heat recovery equipment or, if there is no heat recovery equipment, 
immediately following the combustion chamber,
    (ii) The combustor bottom ash system, which ends at the truck 
loading station or similar ash handling equipment that transfer the ash 
to final disposal, including all ash handling systems that are connected 
to the bottom ash handling system; and
    (iii) The combustor water system, which starts at the feed water 
pump and ends at the piping exiting the steam drum or superheater.
    (3) The municipal waste combustor unit does not include air 
pollution control equipment, the stack, water treatment equipment, or 
the turbine-generator set.
    Municipal waste combustor acid gases means all acid gases emitted in 
the exhaust gases from municipal waste combustor units including, but 
not limited to, sulfur dioxide and hydrogen chloride gases.
    Municipal waste combustor metals means metals and metal compounds 
emitted in the exhaust gases from municipal waste combustor units.
    Municipal waste combustor organics means organic compounds emitted 
in the exhaust gases from municipal waste combustor units and includes 
tetra-through octa- chlorinated dibenzo-p-dioxins and dibenzofurans.
    Municipal waste combustor plant means one or more affected 
facilities (as defined in Sec. 60.50b) at the same location.
    Municipal waste combustor unit capacity means the maximum charging 
rate of a municipal waste combustor unit expressed in tons per day of 
municipal solid waste combusted, calculated according to the procedures 
under Sec. 60.58b(j). Section 60.58b(j) includes procedures for 
determining municipal waste combustor unit capacity for continuous and 
batch feed municipal waste combustors.
    Municipal waste combustor unit load means the steam load of the 
municipal waste combustor unit measured as specified in 
Sec. 60.58b(i)(6).
    Particulate matter means total particulate matter emitted from 
municipal waste combustor units as measured by EPA Reference Method 5 
(see Sec. 60.58b(c)).
    Plastics/rubber recycling unit means an integrated processing unit 
where plastics, rubber, and/or rubber tires are the only feed materials 
(incidental contaminants may be included in the feed materials) and they 
are processed into a chemical plant feedstock or petroleum refinery 
feedstock, where the feedstock is marketed to and used by a chemical 
plant or petroleum refinery as input feedstock. The combined weight of 
the chemical plant feedstock and petroleum refinery feedstock produced 
by the plastics/rubber recycling unit on a calendar quarter basis shall 
be more than 70 percent of the combined weight of the plastics, rubber, 
and rubber tires processed by the plastics/rubber recycling unit on a 
calendar quarter basis. The plastics, rubber, and/or rubber tire feed 
materials to the plastics/rubber recycling unit may

[[Page 154]]

originate from the separation or diversion of plastics, rubber, or 
rubber tires from MSW or industrial solid waste, and may include 
manufacturing scraps, trimmings, and off-specification plastics, rubber, 
and rubber tire discards. The plastics, rubber, and rubber tire feed 
materials to the plastics/rubber recycling unit may contain incidental 
contaminants (e.g., paper labels on plastic bottles, metal rings on 
plastic bottle caps, etc.).
    Potential hydrogen chloride emission concentration means the 
hydrogen chloride emission concentration that would occur from 
combustion of municipal solid waste in the absence of any emission 
controls for municipal waste combustor acid gases.
    Potential mercury emission concentration means the mercury emission 
concentration that would occur from combustion of municipal solid waste 
in the absence of any mercury emissions control.
    Potential sulfur dioxide emissions means the sulfur dioxide emission 
concentration that would occur from combustion of municipal solid waste 
in the absence of any emission controls for municipal waste combustor 
acid gases.
    Pulverized coal/refuse-derived fuel mixed fuel-fired combustor means 
a combustor that fires coal and refuse-derived fuel simultaneously, in 
which pulverized coal is introduced into an air stream that carries the 
coal to the combustion chamber of the unit where it is fired in 
suspension. This includes both conventional pulverized coal and 
micropulverized coal.
    Pyrolysis/combustion unit means a unit that produces gases, liquids, 
or solids through the heating of municipal solid waste, and the gases, 
liquids, or solids produced are combusted and emissions vented to the 
atmosphere.
    Reconstruction means rebuilding a municipal waste combustor unit for 
which the reconstruction commenced after June 19, 1996, and the 
cumulative costs of the construction over the life of the unit exceed 50 
percent of the original cost of construction and installation of the 
unit (not including any cost of land purchased in connection with such 
construction or installation) updated to current costs (current 
dollars).
    Refractory unit or refractory wall furnace means a combustion unit 
having no energy recovery (e.g., via a waterwall) in the furnace (i.e., 
radiant heat transfer section) of the combustor.
    Refuse-derived fuel means a type of municipal solid waste produced 
by processing municipal solid waste through shredding and size 
classification. This includes all classes of refuse-derived fuel 
including low-density fluff refuse-derived fuel through densified 
refuse-derived fuel and pelletized refuse-derived fuel.
    Refuse-derived fuel stoker means a steam generating unit that 
combusts refuse-derived fuel in a semisuspension firing mode using air-
fed distributors.
    Same location means the same or contiguous property that is under 
common ownership or control including properties that are separated only 
by a street, road, highway, or other public right-of-way. Common 
ownership or control includes properties that are owned, leased, or 
operated by the same entity, parent entity, subsidiary, subdivision, or 
any combination thereof including any municipality or other governmental 
unit, or any quasi-governmental authority (e.g., a public utility 
district or regional waste disposal authority).
    Second calendar half means the period starting July 1 and ending on 
December 31 in any year.
    Shift supervisor means the person who is in direct charge and 
control of the operation of a municipal waste combustor and who is 
responsible for onsite supervision, technical direction, management, and 
overall performance of the facility during an assigned shift.
    Spreader stoker coal/refuse-derived fuel mixed fuel-fired combustor 
means a combustor that fires coal and refuse-derived fuel 
simultaneously, in which coal is introduced to the combustion zone by a 
mechanism that throws the fuel onto a grate from above. Combustion takes 
place both in suspension and on the grate.
    Standard conditions means a temperature of 20  deg.C and a pressure 
of 101.3 kilopascals.
    Total mass dioxin/furan or total mass means the total mass of tetra- 
through octa- chlorinated dibenzo-p-dioxins and

[[Page 155]]

dibenzofurans, as determined using EPA Reference Method 23 and the 
procedures specified under Sec. 60.58b(g).
    Twenty-four hour daily average or 24-hour daily average means either 
the arithmetic mean or geometric mean (as specified) of all hourly 
emission concentrations when the affected facility is operating and 
combusting municipal solid waste measured over a 24-hour period between 
12:00 midnight and the following midnight.
    Untreated lumber means wood or wood products that have been cut or 
shaped and include wet, air-dried, and kiln-dried wood products. 
Untreated lumber does not include wood products that have been painted, 
pigment-stained, or ``pressure-treated.'' Pressure-treating compounds 
include, but are not limited to, chromate copper arsenate, 
pentachlorophenol, and creosote.
    Waterwall furnace means a combustion unit having energy (heat) 
recovery in the furnace (i.e., radiant heat transfer section) of the 
combustor.
    Yard waste means grass, grass clippings, bushes, shrubs, and 
clippings from bushes and shrubs that are generated by residential, 
commercial/retail, institutional, and/or industrial sources as part of 
maintenance activities associated with yards or other private or public 
lands. Yard waste does not include construction, renovation, and 
demolition wastes, which are exempt from the definition of municipal 
solid waste in this section. Yard waste does not include clean wood, 
which is exempt from the definition of municipal solid waste in this 
section.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45121, 45126, Aug. 25, 
1997]



Sec. 60.52b  Standards for municipal waste combustor metals, acid gases, organics, and nitrogen oxides.

    (a) The limits for municipal waste combustor metals are specified in 
paragraphs (a)(1) through (a)(5) of this section.
    (1) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from that affected facility any gases 
that contain particulate matter in excess of 24 milligrams per dry 
standard cubic meter, corrected to 7 percent oxygen.
    (2) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from that affected facility any gases 
that exhibit greater than 10 percent opacity (6-minute average).
    (3) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from that affected facility any gases 
that contain cadmium in excess of 0.020 milligrams per dry standard 
cubic meter, corrected to 7 percent oxygen.
    (4) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from the affected facility any gases 
that contain lead in excess of 0.20 milligrams per dry standard cubic 
meter, corrected to 7 percent oxygen.
    (5) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from the affected facility any gases 
that contain mercury in excess of 0.080 milligrams per dry standard 
cubic meter or 15 percent of the potential mercury emission 
concentration (85-percent reduction by weight), corrected to 7 percent 
oxygen, whichever is less stringent.
    (b) The limits for municipal waste combustor acid gases are 
specified in paragraphs (b)(1) and (b)(2) of this section.
    (1) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged into

[[Page 156]]

the atmosphere from that affected facility any gases that contain sulfur 
dioxide in excess of 30 parts per million by volume or 20 percent of the 
potential sulfur dioxide emission concentration (80-percent reduction by 
weight or volume), corrected to 7 percent oxygen (dry basis), whichever 
is less stringent. The averaging time is specified under Sec. 60.58b(e).
    (2) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from that affected facility any gases 
that contain hydrogen chloride in excess of 25 parts per million by 
volume or 5 percent of the potential hydrogen chloride emission 
concentration (95-percent reduction by weight or volume), corrected to 7 
percent oxygen (dry basis), whichever is less stringent.
    (c) The limits for municipal waste combustor organics are specified 
in paragraphs (c)(1) and (c)(2) of this section.
    (1) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility for which 
construction, modification or reconstruction commences on or before 
November 20, 1997 shall cause to be discharged into the atmosphere from 
that affected facility any gases that contain dioxin/furan emissions 
that exceed 30 nanograms per dry standard cubic meter (total mass), 
corrected to 7 percent oxygen, for the first 3 years following the date 
of initial startup. After the first 3 years following the date of 
initial startup, no owner or operator shall cause to be discharged into 
the atmosphere from that affected facility any gases that contain 
dioxin/furan total mass emissions that exceed 13 nanograms per dry 
standard cubic meter (total mass), corrected to 7 percent oxygen.
    (2) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility for which 
construction, modification, or reconstruction commences after November 
20, 1997 shall cause to be discharged into the atmosphere from that 
affected facility any gases that contain dioxin/furan total mass 
emissions that exceed 13 nanograms per dry standard cubic meter (total 
mass), corrected to 7 percent oxygen.
    (d) The limits for nitrogen oxides are specified in paragraphs 
(d)(1) and (d)(2) of this section.
    (1) During the first year of operation after the date on which the 
initial performance test is completed or is required to be completed 
under Sec. 60.8 of subpart A of this part, no owner or operator of an 
affected facility shall cause to be discharged into the atmosphere from 
that affected facility any gases that contain nitrogen oxides in excess 
of 180 parts per million by volume, corrected to 7 percent oxygen (dry 
basis). The averaging time is specified under Sec. 60.58b(h).
    (2) After the first year of operation following the date on which 
the initial performance test is completed or is required to be completed 
under Sec. 60.8 of subpart A of this part, no owner or operator of an 
affected facility shall cause to be discharged into the atmosphere from 
that affected facility any gases that contain nitrogen oxides in excess 
of 150 parts per million by volume, corrected to 7 percent oxygen (dry 
basis). The averaging time is specified under Sec. 60.58b(h).

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45121, 45126, Aug. 25, 
1997]



Sec. 60.53b  Standards for municipal waste combustor operating practices.

    (a) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from that affected facility any gases 
that contain carbon monoxide in excess of the emission limits specified 
in table 1 of this subpart.

[[Page 157]]



         Table 1.--Municipal Waste Combustor Operating Standards
------------------------------------------------------------------------
                                       Carbon monoxide
                                       emission limit
Municipal waste combustor technology     (parts per      Averaging time
                                         million by         (hours) b
                                          volume) a
------------------------------------------------------------------------
Mass burn waterwall.................               100                 4
Mass burn refractory................               100                 4
Mass burn rotary waterwall..........               100                24
Modular starved air.................                50                 4
Modular excess air..................                50                 4
Refuse-derived fuel stoker..........               150                24
Bubbling fluidized bed combustor....               100                 4
Circulating fluidized bed combustor.               100                 4
Pulverized coal/refuse-derived fuel                150                 4
 mixed fuel-fired combustor.........
Spreader stoker coal/refuse-derived                150                24
 fuel mixed fuel-fired combustor....
------------------------------------------------------------------------
a  Measured at the combustor outlet in conjunction with a measurement of
  oxygen concentration, corrected to 7 percent oxygen (dry basis). The
  averaging times are specified in greater detail in Sec.  60.58b(i).
b  Averaging times are 4-hour or 24-hour block averages.

    (b) No owner or operator of an affected facility shall cause such 
facility to operate at a load level greater than 110 percent of the 
maximum demonstrated municipal waste combustor unit load as defined in 
Sec. 60.51b, except as specified in paragraphs (b)(1) and (b)(2) of this 
section. The averaging time is specified under Sec. 60.58b(i).
    (1) During the annual dioxin/furan performance test and the 2 weeks 
preceding the annual dioxin/furan performance test, no municipal waste 
combustor unit load limit is applicable.
    (2) The municipal waste combustor unit load limit may be waived in 
accordance with permission granted by the Administrator or delegated 
State regulatory authority for the purpose of evaluating system 
performance, testing new technology or control technologies, diagnostic 
testing, or related activities for the purpose of improving facility 
performance or advancing the state-of-the-art for controlling facility 
emissions.
    (c) No owner or operator of an affected facility shall cause such 
facility to operate at a temperature, measured at the particulate matter 
control device inlet, exceeding 17  deg.C above the maximum demonstrated 
particulate matter control device temperature as defined in Sec. 60.51b, 
except as specified in paragraphs (c)(1) and (c)(2) of this section. The 
averaging time is specified under Sec. 60.58b(i). The requirements 
specified in this paragraph apply to each particulate matter control 
device utilized at the affected facility.
    (1) During the annual dioxin/furan performance test and the 2 weeks 
preceding the annual dioxin/furan performance test, no particulate 
matter control device temperature limitations are applicable.
    (2) The particulate matter control device temperature limits may be 
waived in accordance with permission granted by the Administrator or 
delegated State regulatory authority for the purpose of evaluating 
system performance, testing new technology or control technologies, 
diagnostic testing, or related activities for the purpose of improving 
facility performance or advancing the state-of-the-art for controlling 
facility emissions.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]



Sec. 60.54b  Standards for municipal waste combustor operator training and certification.

    (a) No later than the date 6 months after the date of startup of an 
affected facility or on December 19, 1996, whichever is later, each 
chief facility operator and shift supervisor shall obtain and maintain a 
current provisional operator certification from either the American 
Society of Mechanical Engineers [QRO-1-1994 (incorporated by reference--
see Sec. 60.17 of subpart A of this part)] or a State certification 
program.
    (b) Not later than the date 6 months after the date of startup of an 
affected facility or on December 19, 1996, whichever is later, each 
chief facility operator and shift supervisor shall have completed full 
certification or shall

[[Page 158]]

have scheduled a full certification exam with either the American 
Society of Mechanical Engineers [QRO-1-1994 (incorporated by reference--
see Sec. 60.17 of subpart A of this part)] or a State certification 
program.
    (c) No owner or operator of an affected facility shall allow the 
facility to be operated at any time unless one of the following persons 
is on duty and at the affected facility: A fully certified chief 
facility operator, a provisionally certified chief facility operator who 
is scheduled to take the full certification exam according to the 
schedule specified in paragraph (b) of this section, a fully certified 
shift supervisor, or a provisionally certified shift supervisor who is 
scheduled to take the full certification exam according to the schedule 
specified in paragraph (b) of this section.
    (1) The requirement specified in paragraph (c) of this section shall 
take effect 6 months after the date of startup of the affected facility 
or on December 19, 1996, whichever is later.
    (2) If one of the persons listed in paragraph (c) of this section 
must leave the affected facility during their operating shift, a 
provisionally certified control room operator who is onsite at the 
affected facility may fulfill the requirement in paragraph (c) of this 
section.
    (d) All chief facility operators, shift supervisors, and control 
room operators at affected facilities must complete the EPA or State 
municipal waste combustor operator training course no later than the 
date 6 months after the date of startup of the affected facility or by 
December 19, 1996, whichever is later.
    (e) The owner or operator of an affected facility shall develop and 
update on a yearly basis a site-specific operating manual that shall, at 
a minimum, address the elements of municipal waste combustor unit 
operation specified in paragraphs (e)(1) through (e)(11) of this 
section.
    (1) A summary of the applicable standards under this subpart;
    (2) A description of basic combustion theory applicable to a 
municipal waste combustor unit;
    (3) Procedures for receiving, handling, and feeding municipal solid 
waste;
    (4) Municipal waste combustor unit startup, shutdown, and 
malfunction procedures;
    (5) Procedures for maintaining proper combustion air supply levels;
    (6) Procedures for operating the municipal waste combustor unit 
within the standards established under this subpart;
    (7) Procedures for responding to periodic upset or off-specification 
conditions;
    (8) Procedures for minimizing particulate matter carryover;
    (9) Procedures for handling ash;
    (10) Procedures for monitoring municipal waste combustor unit 
emissions; and
    (11) Reporting and recordkeeping procedures.
    (f) The owner or operator of an affected facility shall establish a 
training program to review the operating manual according to the 
schedule specified in paragraphs (f)(1) and (f)(2) of this section with 
each person who has responsibilities affecting the operation of an 
affected facility including, but not limited to, chief facility 
operators, shift supervisors, control room operators, ash handlers, 
maintenance personnel, and crane/load handlers.
    (1) Each person specified in paragraph (f) of this section shall 
undergo initial training no later than the date specified in paragraph 
(f)(1)(i), (f)(1)(ii), or (f)(1)(iii) of this section whichever is 
later.
    (i) The date 6 months after the date of startup of the affected 
facility;
    (ii) The date prior to the day the person assumes responsibilities 
affecting municipal waste combustor unit operation; or
    (iii) December 19, 1996.
    (2) Annually, following the initial review required by paragraph 
(f)(1) of this section.
    (g) The operating manual required by paragraph (e) of this section 
shall be kept in a readily accessible location for all persons required 
to undergo training under paragraph (f) of this section. The operating 
manual and records of

[[Page 159]]

training shall be available for inspection by the EPA or its delegated 
enforcement agency upon request.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]



Sec. 60.55b  Standards for municipal waste combustor fugitive ash emissions.

    (a) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, no owner or operator of an affected facility shall cause to 
be discharged to the atmosphere visible emissions of combustion ash from 
an ash conveying system (including conveyor transfer points) in excess 
of 5 percent of the observation period (i.e., 9 minutes per 3-hour 
period), as determined by EPA Reference Method 22 observations as 
specified in Sec. 60.58b(k), except as provided in paragraphs (b) and 
(c) of this section.
    (b) The emission limit specified in paragraph (a) of this section 
does not cover visible emissions discharged inside buildings or 
enclosures of ash conveying systems; however, the emission limit 
specified in paragraph (a) of this section does cover visible emissions 
discharged to the atmosphere from buildings or enclosures of ash 
conveying systems.
    (c) The provisions specified in paragraph (a) of this section do not 
apply during maintenance and repair of ash conveying systems.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]



Sec. 60.56b  Standards for air curtain incinerators.

    On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, the owner or operator of an air curtain incinerator with the 
capacity to combust greater than 250 tons per day of municipal solid 
waste and that combusts a fuel feed stream composed of 100 percent yard 
waste and no other municipal solid waste materials shall at no time 
cause to be discharged into the atmosphere from that incinerator any 
gases that exhibit greater than 10-percent opacity (6-minute average), 
except that an opacity level of up to 35 percent (6-minute average) is 
permitted during startup periods during the first 30 minutes of 
operation of the unit.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]



Sec. 60.57b  Siting requirements.

    (a) The owner or operator of an affected facility for which the 
initial application for a construction permit under 40 CFR part 51, 
subpart I, or part 52, as applicable, is submitted after December 19, 
1995, shall prepare a materials separation plan, as defined in 
Sec. 60.51b, for the affected facility and its service area, and shall 
comply with the requirements specified in paragraphs (a)(1) through 
(a)(10) of this section. The initial application is defined as 
representing a good faith submittal for complying with the requirements 
under 40 CFR part 51, subpart I, or part 52, as applicable, as 
determined by the Administrator.
    (1) The owner or operator shall prepare a preliminary draft 
materials separation plan and shall make the plan available to the 
public as specified in paragraphs (a)(1)(i) and (a)(1)(ii) of this 
section.
    (i) The owner or operator shall distribute the preliminary draft 
materials separation plan to the principal public libraries in the area 
where the affected facility is to be constructed.
    (ii) The owner or operator shall publish a notification of a public 
meeting in the principal newspaper(s) serving the area where the 
affected facility is to be constructed and where the waste treated by 
the affected facility will primarily be collected. As a minimum, the 
notification shall include the information specified in paragraphs 
(a)(1)(ii)(A) through (a)(1)(ii)(D) of this section.
    (A) The date, time, and location of the public meeting.
    (B) The location of the public libraries where the preliminary draft 
materials separation plan may be found, including normal business hours 
of the libraries.
    (C) An agenda of the issues to be discussed at the public meeting.
    (D) The dates that the public comment period on the preliminary 
draft

[[Page 160]]

materials separation plan begins and ends.
    (2) The owner or operator shall conduct a public meeting, accept 
comments on the preliminary draft materials separation plan, and comply 
with the requirements specified in paragraphs (a)(2)(i) through 
(a)(2)(iv) of this section.
    (i) The public meeting shall be conducted in the county where the 
affected facility is to be located.
    (ii) The public meeting shall be scheduled to occur 30 days or more 
after making the preliminary draft materials separation plan available 
to the public as specified under paragraph (a)(1) of this section.
    (iii) Suggested issues to be addressed at the public meeting are 
listed in paragraphs (a)(2)(iii)(A) through (a)(2)(iii)(H) of this 
section.
    (A) The expected size of the service area for the affected facility.
    (B) The amount of waste generation anticipated for the service area.
    (C) The types and estimated amounts of materials proposed for 
separation.
    (D) The methods proposed for materials separation.
    (E) The amount of residual waste to be disposed.
    (F) Alternate disposal methods for handling the residual waste.
    (G) Identification of the location(s) where responses to public 
comment on the preliminary draft materials separation plan will be 
available for inspection, as specified in paragraphs (a)(3) and (a)(4) 
of this section.
    (H) Identification of the locations where the final draft materials 
separation plan will be available for inspection, as specified in 
paragraph (a)(7).
    (iv) Nothing in this section shall preclude an owner or operator 
from combining this public meeting with any other public meeting 
required as part of any other Federal, State, or local permit review 
process except the public meeting required under paragraph (b)(4) of 
this section.
    (3) Following the public meeting required by paragraph (a)(2) of 
this section, the owner or operator shall prepare responses to the 
comments received at the public meeting.
    (4) The owner or operator shall make the document summarizing 
responses to public comments available to the public (including 
distribution to the principal public libraries used to announce the 
meeting) in the service area where the affected facility is to be 
located.
    (5) The owner or operator shall prepare a final draft materials 
separation plan for the affected facility considering the public 
comments received at the public meeting.
    (6) As required under Sec. 60.59b(a), the owner or operator shall 
submit to the Administrator a copy of the notification of the public 
meeting, a transcript of the public meeting, the document summarizing 
responses to public comments, and copies of both the preliminary and 
final draft materials separation plans on or before the time the 
facility's application for a construction permit is submitted under 40 
CFR part 51, subpart I, or part 52, as applicable.
    (7) As part of the distribution of the siting analysis required 
under paragraph (b)(3) of this section, the owner or operator shall make 
the final draft materials separation plan required under paragraph 
(a)(5) of this section available to the public, as specified in 
paragraph (b)(3) of this section.
    (8) As part of the public meeting for review of the siting analysis 
required under paragraph (b)(4) of this section, the owner or operator 
shall address questions concerning the final draft materials separation 
plan required by paragraph (a)(5) of this section including discussion 
of how the final draft materials separation plan has changed from the 
preliminary draft materials separation plan that was discussed at the 
first public meeting required by paragraph (a)(2) of this section.
    (9) If the owner or operator receives any comments on the final 
draft materials separation plan during the public meeting required in 
paragraph (b)(4) of this section, the owner or operator shall respond to 
those comments in the document prepared in accordance with paragraph 
(b)(5) of this section.
    (10) The owner or operator shall prepare a final materials 
separation plan and shall submit, as required under 
Sec. 60.59b(b)(5)(ii), the final materials separation plan as part of 
the initial notification of construction.

[[Page 161]]

    (b) The owner or operator of an affected facility for which the 
initial application for a construction permit under 40 CFR part 51, 
subpart I, or part 52, as applicable, is submitted after December 19, 
1995 shall prepare a siting analysis in accordance with paragraphs 
(b)(1) and (b)(2) of this section and shall comply with the requirements 
specified in paragraphs (b)(3) through (b)(7) of this section.
    (1) The siting analysis shall be an analysis of the impact of the 
affected facility on ambient air quality, visibility, soils, and 
vegetation.
    (2) The analysis shall consider air pollution control alternatives 
that minimize, on a site-specific basis, to the maximum extent 
practicable, potential risks to the public health or the environment.
    (3) The owner or operator shall make the siting analysis and final 
draft materials separation plan required by paragraph (a)(5) of this 
section available to the public as specified in paragraphs (b)(3)(i) and 
(b)(3)(ii) of this section.
    (i) The owner or operator shall distribute the siting analysis and 
final draft materials separation plan to the principal public libraries 
in the area where the affected facility is to be constructed.
    (ii) The owner or operator shall publish a notification of a public 
meeting in the principal newspaper(s) serving the area where the 
affected facility is to be constructed and where the waste treated by 
the affected facility will primarily be collected. As a minimum, the 
notification shall include the information specified in paragraphs 
(b)(3)(ii)(A) through (b)(3)(ii)(D) of this section.
    (A) The date, time, and location of the public meeting.
    (B) The location of the public libraries where the siting analyses 
and final draft materials separation plan may be found, including normal 
business hours.
    (C) An agenda of the issues to be discussed at the public meeting.
    (D) The dates that the public comment period on the siting analyses 
and final draft materials separation plan begins and ends.
    (4) The owner or operator shall conduct a public meeting and accept 
comments on the siting analysis and the final draft materials separation 
plan required under paragraph (a)(5) of this section. The public meeting 
shall be conducted in the county where the affected facility is to be 
located and shall be scheduled to occur 30 days or more after making the 
siting analysis available to the public as specified under paragraph 
(b)(3) of this section.
    (5) The owner or operator shall prepare responses to the comments on 
the siting analysis and the final draft materials separation plan that 
are received at the public meeting.
    (6) The owner or operator shall make the document summarizing 
responses to public comments available to the public (including 
distribution to all public libraries) in the service area where the 
affected facility is to be located.
    (7) As required under Sec. 60.59b(b)(5), the owner or operator shall 
submit a copy of the notification of the public meeting, a transcript of 
the public meeting, the document summarizing responses to public 
comments, and the siting analysis as part of the initial notification of 
construction.
    (c) The owner or operator of an affected facility for which 
construction is commenced after September 20, 1994 shall prepare a 
siting analysis in accordance with 40 CFR part 51, Subpart I, or part 
52, as applicable, and shall submit the siting analysis as part of the 
initial notification of construction. Affected facilities subject to 
paragraphs (a) and (b) of this section are not subject to this 
paragraph.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]



Sec. 60.58b  Compliance and performance testing.

    (a) The provisions for startup, shutdown, and malfunction are 
provided in paragraphs (a)(1) and (a)(2) of this section.
    (1) Except as provided by Sec. 60.56b, the standards under this 
subpart apply at all times except during periods of startup, shutdown, 
or malfunction. Duration of startup, shutdown, or malfunction periods 
are limited to 3 hours per occurrence.

[[Page 162]]

    (i) The startup period commences when the affected facility begins 
the continuous burning of municipal solid waste and does not include any 
warmup period when the affected facility is combusting fossil fuel or 
other nonmunicipal solid waste fuel, and no municipal solid waste is 
being fed to the combustor.
    (ii) Continuous burning is the continuous, semicontinuous, or batch 
feeding of municipal solid waste for purposes of waste disposal, energy 
production, or providing heat to the combustion system in preparation 
for waste disposal or energy production. The use of municipal solid 
waste solely to provide thermal protection of the grate or hearth during 
the startup period when municipal solid waste is not being fed to the 
grate is not considered to be continuous burning.
    (2) The opacity limits for air curtain incinerators specified in 
Sec. 60.56b apply at all times as specified under Sec. 60.56b except 
during periods of malfunction. Duration of malfunction periods are 
limited to 3 hours per occurrence.
    (b) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a continuous emission monitoring system 
and record the output of the system for measuring the oxygen or carbon 
dioxide content of the flue gas at each location where carbon monoxide, 
sulfur dioxide, or nitrogen oxides emissions are monitored and shall 
comply with the test procedures and test methods specified in paragraphs 
(b)(1) through (b)(7) of this section.
    (1) The span value of the oxygen (or carbon dioxide) monitor shall 
be 25 percent oxygen (or carbon dioxide).
    (2) The monitor shall be installed, evaluated, and operated in 
accordance with Sec. 60.13 of subpart A of this part.
    (3) The initial performance evaluation shall be completed no later 
than 180 days after the date of initial startup of the affected 
facility, as specified under Sec. 60.8 of subpart A of this part.
    (4) The monitor shall conform to Performance Specification 3 in 
appendix B of this part except for section 2.3 (relative accuracy 
requirement).
    (5) The quality assurance procedures of appendix F of this part 
except for section 5.1.1 (relative accuracy test audit) shall apply to 
the monitor.
    (6) If carbon dioxide is selected for use in diluent corrections, 
the relationship between oxygen and carbon dioxide levels shall be 
established during the initial performance test according to the 
procedures and methods specified in paragraphs (b)(6)(i) through 
(b)(6)(iv) of this section. This relationship may be reestablished 
during performance compliance tests.
    (i) The fuel factor equation in Method 3B shall be used to determine 
the relationship between oxygen and carbon dioxide at a sampling 
location. Method 3, 3A, or 3B, as applicable, shall be used to determine 
the oxygen concentration at the same location as the carbon dioxide 
monitor.
    (ii) Samples shall be taken for at least 30 minutes in each hour.
    (iii) Each sample shall represent a 1-hour average.
    (iv) A minimum of three runs shall be performed.
    (7) The relationship between carbon dioxide and oxygen 
concentrations that is established in accordance with paragraph (b)(6) 
of this section shall be submitted to the EPA Administrator as part of 
the initial performance test report and, if applicable, as part of the 
annual test report if the relationship is reestablished during the 
annual performance test.
    (c) The procedures and test methods specified in paragraphs (c)(1) 
through (c)(11) of this section shall be used to determine compliance 
with the emission limits for particulate matter and opacity under 
Sec. 60.52b(a)(1) and (a)(2).
    (1) The EPA Reference Method 1 shall be used to select sampling site 
and number of traverse points.
    (2) The EPA Reference Method 3, 3A, or 3B, as applicable, shall be 
used for gas analysis.
    (3) The EPA Reference Method 5 shall be used for determining 
compliance with the particulate matter emission limit. The minimum 
sample volume shall be 1.7 cubic meters. The probe and filter holder 
heating systems in the sample train shall be set to provide a gas 
temperature no greater than 160#14  deg.C. An oxygen or 
carbon dioxide measurement shall be obtained simultaneously with each 
Method 5 run.

[[Page 163]]

    (4) The owner or operator of an affected facility may request that 
compliance with the particulate matter emission limit be determined 
using carbon dioxide measurements corrected to an equivalent of 7 
percent oxygen. The relationship between oxygen and carbon dioxide 
levels for the affected facility shall be established as specified in 
paragraph (b)(6) of this section.
    (5) As specified under Sec. 60.8 of subpart A of this part, all 
performance tests shall consist of three test runs. The average of the 
particulate matter emission concentrations from the three test runs is 
used to determine compliance.
    (6) In accordance with paragraphs (c)(7) and (c)(11) of this 
section, EPA Reference Method 9 shall be used for determining compliance 
with the opacity limit except as provided under Sec. 60.11(e) of subpart 
A of this part.
    (7) The owner or operator of an affected facility shall conduct an 
initial performance test for particulate matter emissions and opacity as 
required under Sec. 60.8 of subpart A of this part.
    (8) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a continuous opacity monitoring system 
for measuring opacity and shall follow the methods and procedures 
specified in paragraphs (c)(8)(i) through (c)(8)(iv) of this section.
    (i) The output of the continuous opacity monitoring system shall be 
recorded on a 6-minute average basis.
    (ii) The continuous opacity monitoring system shall be installed, 
evaluated, and operated in accordance with Sec. 60.13 of subpart A of 
this part.
    (iii) The continuous opacity monitoring system shall conform to 
Performance Specification 1 in appendix B of this part.
    (iv) The initial performance evaluation shall be completed no later 
than 180 days after the date of the initial startup of the municipal 
waste combustor unit, as specified under Sec. 60.8 of subpart A of this 
part.
    (9) Following the date that the initial performance test for 
particulate matter is completed or is required to be completed under 
Sec. 60.8 of subpart A of this part for an affected facility, the owner 
or operator shall conduct a performance test for particulate matter on 
an annual basis (no more than 12 calendar months following the previous 
performance test).
    (10) [Reserved]
    (11) Following the date that the initial performance test for 
opacity is completed or is required to be completed under Sec. 60.8 of 
subpart A of this part for an affected facility, the owner or operator 
shall conduct a performance test for opacity on an annual basis (no more 
than 12 calendar months following the previous performance test) using 
the test method specified in paragraph (c)(6) of this section.
    (d) The procedures and test methods specified in paragraphs (d)(1) 
and (d)(2) of this section shall be used to determine compliance with 
the emission limits for cadmium, lead, and mercury under Sec. 60.52b(a).
    (1) The procedures and test methods specified in paragraphs 
(d)(1)(i) through (d)(1)(ix) of this section shall be used to determine 
compliance with the emission limits for cadmium and lead under 
Sec. 60.52b(a) (3) and (4).
    (i) The EPA Reference Method 1 shall be used for determining the 
location and number of sampling points.
    (ii) The EPA Reference Method 3, 3A, or 3B, as applicable, shall be 
used for flue gas analysis.
    (iii) The EPA Reference Method 29 shall be used for determining 
compliance with the cadmium and lead emission limits.
    (iv) An oxygen or carbon dioxide measurement shall be obtained 
simultaneously with each Method 29 test run for cadmium and lead 
required under paragraph (d)(1)(iii) of this section.
    (v) The owner or operator of an affected facility may request that 
compliance with the cadmium or lead emission limit be determined using 
carbon dioxide measurements corrected to an equivalent of 7 percent 
oxygen. The relationship between oxygen and carbon dioxide levels for 
the affected facility shall be established as specified in paragraph 
(b)(6) of this section.
    (vi) All performance tests shall consist of a minimum of three test 
runs conducted under representative full load operating conditions. The 
average of the cadmium or lead emission concentrations from three test 
runs or

[[Page 164]]

more shall be used to determine compliance.
    (vii) Following the date of the initial performance test or the date 
on which the initial performance test is required to be completed under 
Sec. 60.8 of subpart A of this part, the owner or operator of an 
affected facility shall conduct a performance test for compliance with 
the emission limits for cadmium and lead on an annual basis (no more 
than 12 calendar months following the previous performance test).
    (viii)-(ix) [Reserved]
    (2) The procedures and test methods specified in paragraphs 
(d)(2)(i) through (d)(2)(xi) of this section shall be used to determine 
compliance with the mercury emission limit under Sec. 60.52b(a)(5).
    (i) The EPA Reference Method 1 shall be used for determining the 
location and number of sampling points.
    (ii) The EPA Reference Method 3, 3A, or 3B, as applicable, shall be 
used for flue gas analysis.
    (iii) The EPA Reference Method 29 shall be used to determine the 
mercury emission concentration. The minimum sample volume when using 
Method 29 for mercury shall be 1.7 cubic meters.
    (iv) An oxygen (or carbon dioxide) measurement shall be obtained 
simultaneously with each Method 29 test run for mercury required under 
paragraph (d)(2)(iii) of this section.
    (v) The percent reduction in the potential mercury emissions (%PHg) 
is computed using equation 1:
[GRAPHIC] [TIFF OMITTED] TR19DE95.001

where:

%PHg = percent reduction of the potential mercury emissions 
          achieved.
Ei = potential mercury emission concentration measured at the 
          control device inlet, corrected to 7 percent oxygen (dry 
          basis).
Eo = controlled mercury emission concentration measured at 
          the mercury control device outlet, corrected to 7 percent 
          oxygen (dry basis).

    (vi) All performance tests shall consist of a minimum of three test 
runs conducted under representative full load operating conditions. The 
average of the mercury emission concentrations or percent reductions 
from three test runs or more is used to determine compliance.
    (vii) The owner or operator of an affected facility may request that 
compliance with the mercury emission limit be determined using carbon 
dioxide measurements corrected to an equivalent of 7 percent oxygen. The 
relationship between oxygen and carbon dioxide levels for the affected 
facility shall be established as specified in paragraph (b)(6) of this 
section.
    (viii) The owner or operator of an affected facility shall conduct 
an initial performance test for mercury emissions as required under 
Sec. 60.8 of subpart A of this part.
    (ix) Following the date that the initial performance test for 
mercury is completed or is required to be completed under Sec. 60.8 of 
subpart A of this part, the owner or operator of an affected facility 
shall conduct a performance test for mercury emissions on a annual basis 
(no more than 12 calendar months from the previous performance test).
    (x) [Reserved]
    (xi) The owner or operator of an affected facility where activated 
carbon injection is used to comply with the mercury emission limit shall 
follow the procedures specified in paragraph (m) of this section for 
measuring and calculating carbon usage.
    (e) The procedures and test methods specified in paragraphs (e)(1) 
through (e)(14) of this section shall be used for determining compliance 
with the sulfur dioxide emission limit under Sec. 60.52b(b)(1).
    (1) The EPA Reference Method 19, section 4.3, shall be used to 
calculate the daily geometric average sulfur dioxide emission 
concentration.
    (2) The EPA Reference Method 19, section 5.4, shall be used to 
determine the daily geometric average percent reduction in the potential 
sulfur dioxide emission concentration.
    (3) The owner or operator of an affected facility may request that 
compliance with the sulfur dioxide emission limit be determined using 
carbon dioxide measurements corrected to an equivalent of 7 percent 
oxygen. The relationship between oxygen and carbon dioxide levels for 
the affected facility

[[Page 165]]

shall be established as specified in paragraph (b)(6) of this section.
    (4) The owner or operator of an affected facility shall conduct an 
initial performance test for sulfur dioxide emissions as required under 
Sec. 60.8 of subpart A of this part. Compliance with the sulfur dioxide 
emission limit (concentration or percent reduction) shall be determined 
by using the continuous emission monitoring system specified in 
paragraph (e)(5) of this section to measure sulfur dioxide and 
calculating a 24-hour daily geometric average emission concentration or 
a 24-hour daily geometric average percent reduction using EPA Reference 
Method 19, sections 4.3 and 5.4, as applicable.
    (5) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a continuous emission monitoring system 
for measuring sulfur dioxide emissions discharged to the atmosphere and 
record the output of the system.
    (6) Following the date that the initial performance test for sulfur 
dioxide is completed or is required to be completed under Sec. 60.8 of 
subpart A of this part, compliance with the sulfur dioxide emission 
limit shall be determined based on the 24-hour daily geometric average 
of the hourly arithmetic average emission concentrations using 
continuous emission monitoring system outlet data if compliance is based 
on an emission concentration, or continuous emission monitoring system 
inlet and outlet data if compliance is based on a percent reduction.
    (7) At a minimum, valid continuous monitoring system hourly averages 
shall be obtained as specified in paragraphs (e)(7)(i) and (e)(7)(ii) 
for 75 percent of the operating hours per day for 90 percent of the 
operating days per calendar quarter that the affected facility is 
combusting municipal solid waste.
    (i) At least two data points per hour shall be used to calculate 
each 1-hour arithmetic average.
    (ii) Each sulfur dioxide 1-hour arithmetic average shall be 
corrected to 7 percent oxygen on an hourly basis using the 1-hour 
arithmetic average of the oxygen (or carbon dioxide) continuous emission 
monitoring system data.
    (8) The 1-hour arithmetic averages required under paragraph (e)(6) 
of this section shall be expressed in parts per million corrected to 7 
percent oxygen (dry basis) and used to calculate the 24-hour daily 
geometric average emission concentrations and daily geometric average 
emission percent reductions. The 1-hour arithmetic averages shall be 
calculated using the data points required under Sec. 60.13(e)(2) of 
subpart A of this part.
    (9) All valid continuous emission monitoring system data shall be 
used in calculating average emission concentrations and percent 
reductions even if the minimum continuous emission monitoring system 
data requirements of paragraph (e)(7) of this section are not met.
    (10) The procedures under Sec. 60.13 of subpart A of this part shall 
be followed for installation, evaluation, and operation of the 
continuous emission monitoring system.
    (11) The initial performance evaluation shall be completed no later 
than 180 days after the date of initial startup of the municipal waste 
combustor as specified under Sec. 60.8 of subpart A of this part.
    (12) The continuous emission monitoring system shall be operated 
according to Performance Specification 2 in appendix B of this part.
    (i) During each relative accuracy test run of the continuous 
emission monitoring system required by Performance Specification 2 in 
appendix B of this part, sulfur dioxide and oxygen (or carbon dioxide) 
data shall be collected concurrently (or within a 30- to 60-minute 
period) by both the continuous emission monitors and the test methods 
specified in paragraphs (e)(12)(i)(A) and (e)(12)(i)(B) of this section.
    (A) For sulfur dioxide, EPA Reference Method 6, 6A, or 6C shall be 
used.
    (B) For oxygen (or carbon dioxide), EPA Reference Method 3, 3A, or 
3B, as applicable shall be used.
    (ii) The span value of the continuous emissions monitoring system at 
the inlet to the sulfur dioxide control device shall be 125 percent of 
the maximum estimated hourly potential sulfur dioxide emissions of the 
municipal waste combustor unit. The span value

[[Page 166]]

of the continuous emission monitoring system at the outlet of the sulfur 
dioxide control device shall be 50 percent of the maximum estimated 
hourly potential sulfur dioxide emissions of the municipal waste 
combustor unit.
    (13) Quarterly accuracy determinations and daily calibration drift 
tests shall be performed in accordance with procedure 1 in appendix F of 
this part.
    (14) When sulfur dioxide emissions data are not obtained because of 
continuous emission monitoring system breakdowns, repairs, calibration 
checks, and zero and span adjustments, emissions data shall be obtained 
by using other monitoring systems as approved by the Administrator or 
EPA Reference Method 19 to provide, as necessary, valid emissions data 
for a minimum of 75 percent of the hours per day that the affected 
facility is operated and combusting municipal solid waste for 90 percent 
of the days per calendar quarter that the affected facility is operated 
and combusting municipal solid waste.
    (f) The procedures and test methods specified in paragraphs (f)(1) 
through (f)(8) of this section shall be used for determining compliance 
with the hydrogen chloride emission limit under Sec. 60.52b(b)(2).
    (1) The EPA Reference Method 26 or 26A, as applicable, shall be used 
to determine the hydrogen chloride emission concentration. The minimum 
sampling time for Method 26 shall be 1 hour.
    (2) An oxygen (or carbon dioxide) measurement shall be obtained 
simultaneously with each Method 26 test run for hydrogen chloride 
required by paragraph (f)(1) of this section.
    (3) The percent reduction in potential hydrogen chloride emissions 
(% PHCl) is computed using equation 2:
[GRAPHIC] [TIFF OMITTED] TR19DE95.002

where:

%PHCl=percent reduction of the potential hydrogen chloride 
          emissions achieved.
Ei=potential hydrogen chloride emission concentration 
          measured at the control device inlet, corrected to 7 percent 
          oxygen (dry basis).

Eo=controlled hydrogen chloride emission concentration 
          measured at the control device outlet, corrected to 7 percent 
          oxygen (dry basis).
    (4) The owner or operator of an affected facility may request that 
compliance with the hydrogen chloride emission limit be determined using 
carbon dioxide measurements corrected to an equivalent of 7 percent 
oxygen. The relationship between oxygen and carbon dioxide levels for 
the affected facility shall be established as specified in paragraph 
(b)(6) of this section.
    (5) As specified under Sec. 60.8 of subpart A of this part, all 
performance tests shall consist of three test runs. The average of the 
hydrogen chloride emission concentrations or percent reductions from the 
three test runs is used to determine compliance.
    (6) The owner or operator of an affected facility shall conduct an 
initial performance test for hydrogen chloride as required under 
Sec. 60.8 of subpart A of this part.
    (7) Following the date that the initial performance test for 
hydrogen chloride is completed or is required to be completed under 
Sec. 60.8 of subpart A of this part, the owner or operator of an 
affected facility shall conduct a performance test for hydrogen chloride 
emissions on an annual basis (no more than 12 calendar months following 
the previous performance test).
    (8) [Reserved]
    (g) The procedures and test methods specified in paragraphs (g)(1) 
through (g)(9) of this section shall be used to determine compliance 
with the limits for dioxin/furan emissions under Sec. 60.52b(c).
    (1) The EPA Reference Method 1 shall be used for determining the 
location and number of sampling points.
    (2) The EPA Reference Method 3, 3A, or 3B, as applicable, shall be 
used for flue gas analysis.
    (3) The EPA Reference Method 23 shall be used for determining the 
dioxin/furan emission concentration.
    (i) The minimum sample time shall be 4 hours per test run.
    (ii) An oxygen (or carbon dioxide) measurement shall be obtained 
simultaneously with each Method 23 test run for dioxins/furans.
    (4) The owner or operator of an affected facility shall conduct an 
initial

[[Page 167]]

performance test for dioxin/furan emissions in accordance with paragraph 
(g)(3) of this section, as required under Sec. 60.8 of subpart A of this 
part.
    (5) Following the date that the initial performance test for 
dioxins/furans is completed or is required to be completed under 
Sec. 60.8 of subpart A of this part, the owner or operator of an 
affected facility shall conduct performance tests for dioxin/furan 
emissions in accordance with paragraph (g)(3) of this section, according 
to one of the schedules specified in paragraphs (g)(5)(i) through 
(g)(5)(iii) of this section.
    (i) For affected facilities, performance tests shall be conducted on 
an annual basis (no more than 12 calendar months following the previous 
performance test.)
    (ii) [Reserved]
    (iii) Where all performance tests over a 2-year period indicate that 
dioxin/furan emissions are less than or equal to 7 nanograms per dry 
standard cubic meter (total mass) for all affected facilities located 
within a municipal waste combustor plant, the owner or operator of the 
municipal waste combustor plant may elect to conduct annual performance 
tests for one affected facility (i.e., unit) per year at the municipal 
waste combustor plant. At a minimum, a performance test for dioxin/furan 
emissions shall be conducted annually (no more than 12 months following 
the previous performance test) for one affected facility at the 
municipal waste combustor plant. Each year a different affected facility 
at the municipal waste combustor plant shall be tested, and the affected 
facilities at the plant shall be tested in sequence (e.g., unit 1, unit 
2, unit 3, as applicable). If each annual performance test continues to 
indicate a dioxin/furan emission level less than or equal to 7 nanograms 
per dry standard cubic meter (total mass), the owner or operator may 
continue conducting a performance test on only one affected facility per 
year. If any annual performance test indicates a dioxin/furan emission 
level greater than 7 nanograms per dry standard cubic meter (total 
mass), performance tests thereafter shall be conducted annually on all 
affected facilities at the plant until and unless all annual performance 
tests for all affected facilities at the plant over a 2-year period 
indicate a dioxin/furan emission level less than or equal to 7 nanograms 
per dry standard cubic meter (total mass).
    (6) The owner or operator of an affected facility that selects to 
follow the performance testing schedule specified in paragraph 
(g)(5)(iii) of this section shall follow the procedures specified in 
Sec. 60.59b(g)(4) for reporting the selection of this schedule.
    (7) The owner or operator of an affected facility where activated 
carbon is used to comply with the dioxin/furan emission limits specified 
in Sec. 60.52b(c) or the dioxin/furan emission level specified in 
paragraph (g)(5)(iii) of this section shall follow the procedures 
specified in paragraph (m) of this section for measuring and calculating 
the carbon usage rate.
    (8) The owner or operator of an affected facility may request that 
compliance with the dioxin/furan emission limit be determined using 
carbon dioxide measurements corrected to an equivalent of 7 percent 
oxygen. The relationship between oxygen and carbon dioxide levels for 
the affected facility shall be established as specified in paragraph 
(b)(6) of this section.
    (9) As specified under Sec. 60.8 of subpart A of this part, all 
performance tests shall consist of three test runs. The average of the 
dioxin/furan emission concentrations from the three test runs is used to 
determine compliance.
    (h) The procedures and test methods specified in paragraphs (h)(1) 
through (h)(12) of this section shall be used to determine compliance 
with the nitrogen oxides emission limit for affected facilities under 
Sec. 60.52b(d).
    (1) The EPA Reference Method 19, section 4.1, shall be used for 
determining the daily arithmetic average nitrogen oxides emission 
concentration.
    (2) The owner or operator of an affected facility may request that 
compliance with the nitrogen oxides emission limit be determined using 
carbon dioxide measurements corrected to an equivalent of 7 percent 
oxygen. The relationship between oxygen and carbon dioxide levels for 
the affected facility

[[Page 168]]

shall be established as specified in paragraph (b)(6) of this section.
    (3) The owner or operator of an affected facility subject to the 
nitrogen oxides limit under Sec. 60.52b(d) shall conduct an initial 
performance test for nitrogen oxides as required under Sec. 60.8 of 
subpart A of this part. Compliance with the nitrogen oxides emission 
limit shall be determined by using the continuous emission monitoring 
system specified in paragraph (h)(4) of this section for measuring 
nitrogen oxides and calculating a 24-hour daily arithmetic average 
emission concentration using EPA Reference Method 19, section 4.1.
    (4) The owner or operator of an affected facility subject to the 
nitrogen oxides emission limit under Sec. 60.52b(d) shall install, 
calibrate, maintain, and operate a continuous emission monitoring system 
for measuring nitrogen oxides discharged to the atmosphere, and record 
the output of the system.
    (5) Following the date that the initial performance test for 
nitrogen oxides is completed or is required to be completed under 
Sec. 60.8 of subpart A of this part, compliance with the emission limit 
for nitrogen oxides required under Sec. 60.52b(d) shall be determined 
based on the 24-hour daily arithmetic average of the hourly emission 
concentrations using continuous emission monitoring system outlet data.
    (6) At a minimum, valid continuous emission monitoring system hourly 
averages shall be obtained as specified in paragraphs (h)(6)(i) and 
(h)(6)(ii) of this section for 75 percent of the operating hours per day 
for 90 percent of the operating days per calendar quarter that the 
affected facility is combusting municipal solid waste.
    (i) At least 2 data points per hour shall be used to calculate each 
1-hour arithmetic average.
    (ii) Each nitrogen oxides 1-hour arithmetic average shall be 
corrected to 7 percent oxygen on an hourly basis using the 1-hour 
arithmetic average of the oxygen (or carbon dioxide) continuous emission 
monitoring system data.
    (7) The 1-hour arithmetic averages required by paragraph (h)(5) of 
this section shall be expressed in parts per million by volume (dry 
basis) and used to calculate the 24-hour daily arithmetic average 
concentrations. The 1-hour arithmetic averages shall be calculated using 
the data points required under Sec. 60.13(e)(2) of subpart A of this 
part.
    (8) All valid continuous emission monitoring system data must be 
used in calculating emission averages even if the minimum continuous 
emission monitoring system data requirements of paragraph (h)(6) of this 
section are not met.
    (9) The procedures under Sec. 60.13 of subpart A of this part shall 
be followed for installation, evaluation, and operation of the 
continuous emission monitoring system. The initial performance 
evaluation shall be completed no later than 180 days after the date of 
initial startup of the municipal waste combustor unit, as specified 
under Sec. 60.8 of subpart A of this part.
    (10) The owner or operator of an affected facility shall operate the 
continuous emission monitoring system according to Performance 
Specification 2 in appendix B of this part and shall follow the 
procedures and methods specified in paragraphs (h)(10)(i) and 
(h)(10)(ii) of this section.
    (i) During each relative accuracy test run of the continuous 
emission monitoring system required by Performance Specification 2 of 
appendix B of this part, nitrogen oxides and oxygen (or carbon dioxide) 
data shall be collected concurrently (or within a 30- to 60-minute 
period) by both the continuous emission monitors and the test methods 
specified in paragraphs (h)(10)(i)(A) and (h)(10)(i)(B) of this section.
    (A) For nitrogen oxides, EPA Reference Method 7, 7A, 7C, 7D, or 7E 
shall be used.
    (B) For oxygen (or carbon dioxide), EPA Reference Method 3, 3A, or 
3B, as applicable shall be used.
    (ii) The span value of the continuous emission monitoring system 
shall be 125 percent of the maximum estimated hourly potential nitrogen 
oxide emissions of the municipal waste combustor unit.
    (11) Quarterly accuracy determinations and daily calibration drift 
tests shall be performed in accordance with procedure 1 in appendix F of 
this part.
    (12) When nitrogen oxides continuous emissions data are not obtained 
because of continuous emission monitoring system breakdowns, repairs,

[[Page 169]]

calibration checks, and zero and span adjustments, emissions data shall 
be obtained using other monitoring systems as approved by the 
Administrator or EPA Reference Method 19 to provide, as necessary, valid 
emissions data for a minimum of 75 percent of the hours per day for 90 
percent of the days per calendar quarter the unit is operated and 
combusting municipal solid waste.
    (i) The procedures specified in paragraphs (i)(1) through (i)(12) of 
this section shall be used for determining compliance with the operating 
requirements under Sec. 60.53b.
    (1) Compliance with the carbon monoxide emission limits in 
Sec. 60.53b(a) shall be determined using a 4-hour block arithmetic 
average for all types of affected facilities except mass burn rotary 
waterwall municipal waste combustors and refuse-derived fuel stokers.
    (2) For affected mass burn rotary waterwall municipal waste 
combustors and refuse-derived fuel stokers, compliance with the carbon 
monoxide emission limits in Sec. 60.53b(a) shall be determined using a 
24-hour daily arithmetic average.
    (3) The owner or operator of an affected facility shall install, 
calibrate, maintain, and operate a continuous emission monitoring system 
for measuring carbon monoxide at the combustor outlet and record the 
output of the system and shall follow the procedures and methods 
specified in paragraphs (i)(3)(i) through (i)(3)(iii) of this section.
    (i) The continuous emission monitoring system shall be operated 
according to Performance Specification 4A in appendix B of this part.
    (ii) During each relative accuracy test run of the continuous 
emission monitoring system required by Performance Specification 4A in 
appendix B of this part, carbon monoxide and oxygen (or carbon dioxide) 
data shall be collected concurrently (or within a 30- to 60-minute 
period) by both the continuous emission monitors and the test methods 
specified in paragraphs (i)(3)(ii)(A) and (i)(3)(ii)(B) of this section.
    (A) For carbon monoxide, EPA Reference Method 10, 10A, or 10B shall 
be used.
    (B) For oxygen (or carbon dioxide), EPA Reference Method 3, 3A, or 
3B, as applicable shall be used.
    (iii) The span value of the continuous emission monitoring system 
shall be 125 percent of the maximum estimated hourly potential carbon 
monoxide emissions of the municipal waste combustor unit.
    (4) The 4-hour block and 24-hour daily arithmetic averages specified 
in paragraphs (i)(1) and (i)(2) of this section shall be calculated from 
1-hour arithmetic averages expressed in parts per million by volume 
corrected to 7 percent oxygen (dry basis). The 1-hour arithmetic 
averages shall be calculated using the data points generated by the 
continuous emission monitoring system. At least two data points shall be 
used to calculate each 1-hour arithmetic average.
    (5) The owner or operator of an affected facility may request that 
compliance with the carbon monoxide emission limit be determined using 
carbon dioxide measurements corrected to an equivalent of 7 percent 
oxygen. The relationship between oxygen and carbon dioxide levels for 
the affected facility shall be established as specified in paragraph 
(b)(6) of this section.
    (6) The procedures specified in paragraphs (i)(6)(i) through 
(i)(6)(v) of this section shall be used to determine compliance with 
load level requirements under Sec. 60.53b(b).
    (i) The owner or operator of an affected facility with steam 
generation capability shall install, calibrate, maintain, and operate a 
steam flow meter or a feedwater flow meter; measure steam (or feedwater) 
flow in kilograms per hour (or pounds per hour) on a continuous basis; 
and record the output of the monitor. Steam (or feedwater) flow shall be 
calculated in 4-hour block arithmetic averages.
    (ii) The method included in the ``American Society of Mechanical 
Engineers Power Test Codes: Test Code for Steam Generating Units, Power 
Test Code 4.1--1964 (R1991)'' section 4 (incorporated by reference, see 
Sec. 60.17 of subpart A of this part) shall be used for calculating the 
steam (or feedwater) flow required under paragraph (i)(6)(i) of this 
section. The recommendations

[[Page 170]]

in ``American Society of Mechanical Engineers Interim Supplement 19.5 on 
Instruments and Apparatus: Application, Part II of Fluid Meters, 6th 
edition (1971),'' chapter 4 (incorporated by reference--see Sec. 60.17 
of subpart A of this part) shall be followed for design, construction, 
installation, calibration, and use of nozzles and orifices except as 
specified in (i)(6)(iii) of this section.
    (iii) Measurement devices such as flow nozzles and orifices are not 
required to be recalibrated after they are installed.
    (iv) All signal conversion elements associated with steam (or 
feedwater flow) measurements must be calibrated according to the 
manufacturer's instructions before each dioxin/furan performance test, 
and at least once per year.
    (7) To determine compliance with the maximum particulate matter 
control device temperature requirements under Sec. 60.53b(c), the owner 
or operator of an affected facility shall install, calibrate, maintain, 
and operate a device for measuring on a continuous basis the temperature 
of the flue gas stream at the inlet to each particulate matter control 
device utilized by the affected facility. Temperature shall be 
calculated in 4-hour block arithmetic averages.
    (8) The maximum demonstrated municipal waste combustor unit load 
shall be determined during the initial performance test for dioxins/
furans and each subsequent performance test during which compliance with 
the dioxin/furan emission limit specified in Sec. 60.52b(c) is achieved. 
The maximum demonstrated municipal waste combustor unit load shall be 
the highest 4-hour arithmetic average load achieved during four 
consecutive hours during the most recent test during which compliance 
with the dioxin/furan emission limit was achieved.
    (9) For each particulate matter control device employed at the 
affected facility, the maximum demonstrated particulate matter control 
device temperature shall be determined during the initial performance 
test for dioxins/furans and each subsequent performance test during 
which compliance with the dioxin/furan emission limit specified in 
Sec. 60.52b(c) is achieved. The maximum demonstrated particulate matter 
control device temperature shall be the highest 4-hour arithmetic 
average temperature achieved at the particulate matter control device 
inlet during four consecutive hours during the most recent test during 
which compliance with the dioxin/furan limit was achieved.
    (10) At a minimum, valid continuous emission monitoring system 
hourly averages shall be obtained as specified in paragraphs (i)(10)(i) 
and (i)(10)(ii) of this section for 75 percent of the operating hours 
per day for 90 percent of the operating days per calendar quarter that 
the affected facility is combusting municipal solid waste.
    (i) At least two data points per hour shall be used to calculate 
each 1-hour arithmetic average.
    (ii) At a minimum, each carbon monoxide 1-hour arithmetic average 
shall be corrected to 7 percent oxygen on an hourly basis using the 1-
hour arithmetic average of the oxygen (or carbon dioxide) continuous 
emission monitoring system data.
    (11) All valid continuous emission monitoring system data must be 
used in calculating the parameters specified under paragraph (i) of this 
section even if the minimum data requirements of paragraph (i)(10) of 
this section are not met. When carbon monoxide continuous emission data 
are not obtained because of continuous emission monitoring system 
breakdowns, repairs, calibration checks, and zero and span adjustments, 
emissions data shall be obtained using other monitoring systems as 
approved by the Administrator or EPA Reference Method 10 to provide, as 
necessary, the minimum valid emission data.
    (12) Quarterly accuracy determinations and daily calibration drift 
tests for the carbon monoxide continuous emission monitoring system 
shall be performed in accordance with procedure 1 in appendix F of this 
part.
    (j) The procedures specified in paragraphs (j)(1) and (j)(2) of this 
section shall be used for calculating municipal waste combustor unit 
capacity as defined under Sec. 60.51b.
    (1) For municipal waste combustor units capable of combusting 
municipal solid waste continuously for a 24-hour

[[Page 171]]

period, municipal waste combustor unit capacity shall be calculated 
based on 24 hours of operation at the maximum charging rate. The maximum 
charging rate shall be determined as specified in paragraphs (j)(1)(i) 
and (j)(1)(ii) of this section as applicable.
    (i) For combustors that are designed based on heat capacity, the 
maximum charging rate shall be calculated based on the maximum design 
heat input capacity of the unit and a heating value of 12,800 kilojoules 
per kilogram for combustors firing refuse-derived fuel and a heating 
value of 10,500 kilojoules per kilogram for combustors firing municipal 
solid waste that is not refuse-derived fuel.
    (ii) For combustors that are not designed based on heat capacity, 
the maximum charging rate shall be the maximum design charging rate.
    (2) For batch feed municipal waste combustor units, municipal waste 
combustor unit capacity shall be calculated as the maximum design amount 
of municipal solid waste that can be charged per batch multiplied by the 
maximum number of batches that could be processed in a 24-hour period. 
The maximum number of batches that could be processed in a 24-hour 
period is calculated as 24 hours divided by the design number of hours 
required to process one batch of municipal solid waste, and may include 
fractional batches (e.g., if one batch requires 16 hours, then 24/16, or 
1.5 batches, could be combusted in a 24-hour period). For batch 
combustors that are designed based on heat capacity, the design heating 
value of 12,800 kilojoules per kilogram for combustors firing refuse-
derived fuel and a heating value of 10,500 kilojoules per kilogram for 
combustors firing municipal solid waste that is not refuse-derived fuel 
shall be used in calculating the municipal waste combustor unit capacity 
in megagrams per day of municipal solid waste.
    (k) The procedures specified in paragraphs (k)(1) through (k)(4) of 
this section shall be used for determining compliance with the fugitive 
ash emission limit under Sec. 60.55b.
    (1) The EPA Reference Method 22 shall be used for determining 
compliance with the fugitive ash emission limit under Sec. 60.55b. The 
minimum observation time shall be a series of three 1-hour observations. 
The observation period shall include times when the facility is 
transferring ash from the municipal waste combustor unit to the area 
where ash is stored or loaded into containers or trucks.
    (2) The average duration of visible emissions per hour shall be 
calculated from the three 1-hour observations. The average shall be used 
to determine compliance with Sec. 60.55b.
    (3) The owner or operator of an affected facility shall conduct an 
initial performance test for fugitive ash emissions as required under 
Sec. 60.8 of subpart A of this part.
    (4) Following the date that the initial performance test for 
fugitive ash emissions is completed or is required to be completed under 
Sec. 60.8 of subpart A of this part for an affected facility, the owner 
or operator shall conduct a performance test for fugitive ash emissions 
on an annual basis (no more than 12 calendar months following the 
previous performance test).
    (l) The procedures specified in paragraphs (l)(1) through (l)(3) of 
this section shall be used to determine compliance with the opacity 
limit for air curtain incinerators under Sec. 60.56b.
    (1) The EPA Reference Method 9 shall be used for determining 
compliance with the opacity limit.
    (2) The owner or operator of the air curtain incinerator shall 
conduct an initial performance test for opacity as required under 
Sec. 60.8 of subpart A of this part.
    (3) Following the date that the initial performance test is 
completed or is required to be completed under Sec. 60.8 of subpart A of 
this part, the owner or operator of the air curtain incinerator shall 
conduct a performance test for opacity on an annual basis (no more than 
12 calendar months following the previous performance test).
    (m) The owner or operator of an affected facility where activated 
carbon injection is used to comply with the mercury emission limit under 
Sec. 60.52b(a)(5), or the dioxin/furan emission limits under 
Sec. 60.52(b)(c), or the dioxin/furan emission level specified in

[[Page 172]]

Sec. 60.58b(g)(5)(iii) shall follow the procedures specified in 
paragraphs (m)(1) through (m)(3) of this section.
    (1) During the performance tests for dioxins/furans and mercury, as 
applicable, the owner or operator shall estimate an average carbon mass 
feed rate based on carbon injection system operating parameters such as 
the screw feeder speed, hopper volume, hopper refill frequency, or other 
parameters appropriate to the feed system being employed, as specified 
in paragraphs (m)(1)(i) and (m)(1)(ii) of this section.
    (i) An average carbon mass feed rate in kilograms per hour or pounds 
per hour shall be estimated during the initial performance test for 
mercury emissions and each subsequent performance test for mercury 
emissions.
    (ii) An average carbon mass feed rate in kilograms per hour or 
pounds per hour shall be estimated during the initial performance test 
for dioxin/furan emissions and each subsequent performance test for 
dioxin/furan emissions.
    (2) During operation of the affected facility, the carbon injection 
system operating parameter(s) that are the primary indicator(s) of the 
carbon mass feed rate (e.g., screw feeder setting) must equal or exceed 
the level(s) documented during the performance tests specified under 
paragraphs (m)(1)(i) and (m)(1)(ii) of this section.
    (3) The owner or operator of an affected facility shall estimate the 
total carbon usage of the plant (kilograms or pounds) for each calendar 
quarter by two independent methods, according to the procedures in 
paragraphs (m)(3)(i) and (m)(3)(ii) of this section.
    (i) The weight of carbon delivered to the plant.
    (ii) Estimate the average carbon mass feed rate in kilograms per 
hour or pounds per hour for each hour of operation for each affected 
facility based on the parameters specified under paragraph (m)(1) of 
this section, and sum the results for all affected facilities at the 
plant for the total number of hours of operation during the calendar 
quarter.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45126, Aug. 25, 1997]



Sec. 60.59b  Reporting and recordkeeping requirements.

    (a) The owner or operator of an affected facility with a capacity to 
combust greater than 250 tons per day shall submit, on or before the 
date the application for a construction permit is submitted under 40 CFR 
part 51, subpart I, or part 52, as applicable, the items specified in 
paragraphs (a)(1) through (a)(4) of this section.
    (1) The preliminary and final draft materials separation plans 
required by Sec. 60.57b(a)(1) and (a)(5).
    (2) A copy of the notification of the public meeting required by 
Sec. 60.57b(a)(1)(ii).
    (3) A transcript of the public meeting required by 
Sec. 60.57b(a)(2).
    (4) A copy of the document summarizing responses to public comments 
required by Sec. 60.57b(a)(3).
    (b) The owner or operator of an affected facility with a capacity to 
combust greater than 250 tons per day shall submit a notification of 
construction, which includes the information specified in paragraphs 
(b)(1) through (b)(5) of this section.
    (1) Intent to construct.
    (2) Planned initial startup date.
    (3) The types of fuels that the owner or operator plans to combust 
in the affected facility.
    (4) The municipal waste combustor unit capacity, and supporting 
capacity calculations prepared in accordance with Sec. 60.58b(j).
    (5) Documents associated with the siting requirements under 
Sec. 60.57b (a) and (b), as specified in paragraphs (b)(5)(i) through 
(b)(5)(v) of this section.
    (i) The siting analysis required by Sec. 60.57b (b)(1) and (b)(2).
    (ii) The final materials separation plan for the affected facility 
required by Sec. 60.57b(a)(10).
    (iii) A copy of the notification of the public meeting required by 
Sec. 60.57b(b)(3)(ii).
    (iv) A transcript of the public meeting required by 
Sec. 60.57b(b)(4).
    (v) A copy of the document summarizing responses to public comments 
required by Sec. 60.57b (a)(9) and (b)(5).
    (c) The owner or operator of an air curtain incinerator subject to 
the opacity limit under Sec. 60.56b shall provide a

[[Page 173]]

notification of construction that includes the information specified in 
paragraphs (b)(1) through (b)(4) of this section.
    (d) The owner or operator of an affected facility subject to the 
standards under Secs. 60.52b, 60.53b, 60.54b, 60.55b, and 60.57b shall 
maintain records of the information specified in paragraphs (d)(1) 
through (d)(15) of this section, as applicable, for each affected 
facility for a period of at least 5 years.
    (1) The calendar date of each record.
    (2) The emission concentrations and parameters measured using 
continuous monitoring systems as specified under paragraphs (d)(2)(i) 
and (d)(2)(ii) of this section.
    (i) The measurements specified in paragraphs (d)(2)(i)(A) through 
(d)(2)(i)(D) of this section shall be recorded and be available for 
submittal to the Administrator or review onsite by an inspector.
    (A) All 6-minute average opacity levels as specified under 
Sec. 60.58b(c).
    (B) All 1-hour average sulfur dioxide emission concentrations as 
specified under Sec. 60.58b(e).
    (C) All 1-hour average nitrogen oxides emission concentrations as 
specified under Sec. 60.58b(h).
    (D) All 1-hour average carbon monoxide emission concentrations, 
municipal waste combustor unit load measurements, and particulate matter 
control device inlet temperatures as specified under Sec. 60.58b(i).
    (ii) The average concentrations and percent reductions, as 
applicable, specified in paragraphs (d)(2)(ii)(A) through (d)(2)(ii)(D) 
of this section shall be computed and recorded, and shall be available 
for submittal to the Administrator or review on-site by an inspector.
    (A) All 24-hour daily geometric average sulfur dioxide emission 
concentrations and all 24-hour daily geometric average percent 
reductions in sulfur dioxide emissions as specified under 
Sec. 60.58b(e).
    (B) All 24-hour daily arithmetic average nitrogen oxides emission 
concentrations as specified under Sec. 60.58b(h).
    (C) All 4-hour block or 24-hour daily arithmetic average carbon 
monoxide emission concentrations, as applicable, as specified under 
Sec. 60.58b(i).
    (D) All 4-hour block arithmetic average municipal waste combustor 
unit load levels and particulate matter control device inlet 
temperatures as specified under Sec. 60.58b(i).
    (3) Identification of the calendar dates when any of the average 
emission concentrations, percent reductions, or operating parameters 
recorded under paragraphs (d)(2)(ii)(A) through (d)(2)(ii)(D) of this 
section, or the opacity levels recorded under paragraph (d)(2)(i)(A) of 
this section are above the applicable limits, with reasons for such 
exceedances and a description of corrective actions taken.
    (4) For affected facilities that apply activated carbon for mercury 
or dioxin/furan control, the records specified in paragraphs (d)(4)(i) 
through (d)(4)(v) of this section.
    (i) The average carbon mass feed rate (in kilograms per hour or 
pounds per hour) estimated as required under Sec. 60.58b(m)(1)(i) of 
this section during the initial mercury performance test and all 
subsequent annual performance tests, with supporting calculations.
    (ii) The average carbon mass feed rate (in kilograms per hour or 
pounds per hour) estimated as required under Sec. 60.58b(m)(1)(ii) of 
this section during the initial dioxin/furan performance test and all 
subsequent annual performance tests, with supporting calculations.
    (iii) The average carbon mass feed rate (in kilograms per hour or 
pounds per hour) estimated for each hour of operation as required under 
Sec. 60.58b(m)(3)(ii) of this section, with supporting calculations.
    (iv) The total carbon usage for each calendar quarter estimated as 
specified by paragraph 60.58b(m)(3) of this section, with supporting 
calculations.
    (v) Carbon injection system operating parameter data for the 
parameter(s) that are the primary indicator(s) of carbon feed rate 
(e.g., screw feeder speed).
    (5) [Reserved]
    (6) Identification of the calendar dates for which the minimum 
number of hours of any of the data specified in paragraphs (d)(6)(i) 
through (d)(6)(v) of

[[Page 174]]

this section have not been obtained including reasons for not obtaining 
sufficient data and a description of corrective actions taken.
    (i) Sulfur dioxide emissions data;
    (ii) Nitrogen oxides emissions data;
    (iii) Carbon monoxide emissions data;
    (iv) Municipal waste combustor unit load data; and
    (v) Particulate matter control device temperature data.
    (7) Identification of each occurrence that sulfur dioxide emissions 
data, nitrogen oxides emissions data (large municipal waste combustors 
only), or operational data (i.e., carbon monoxide emissions, unit load, 
and particulate matter control device temperature) have been excluded 
from the calculation of average emission concentrations or parameters, 
and the reasons for excluding the data.
    (8) The results of daily drift tests and quarterly accuracy 
determinations for sulfur dioxide, nitrogen oxides, and carbon monoxide 
continuous emission monitoring systems, as required under appendix F of 
this part, procedure 1.
    (9) The test reports documenting the results of the initial 
performance test and all annual performance tests listed in paragraphs 
(d)(9)(i) and (d)(9)(ii) of this section shall be recorded along with 
supporting calculations.
    (i) The results of the initial performance test and all annual 
performance tests conducted to determine compliance with the particulate 
matter, opacity, cadmium, lead, mercury, dioxins/furans, hydrogen 
chloride, and fugitive ash emission limits.
    (ii) For the initial dioxin/furan performance test and all 
subsequent dioxin/furan performance tests recorded under paragraph 
(d)(9)(i) of this section, the maximum demonstrated municipal waste 
combustor unit load and maximum demonstrated particulate matter control 
device temperature (for each particulate matter control device).
    (10) [Reserved]
    (11) For each affected facility subject to the siting provisions 
under Sec. 60.57b, the siting analysis, the final materials separation 
plan, a record of the location and date of the public meetings, and the 
documentation of the responses to public comments received at the public 
meetings.
    (12) The records specified in paragraphs (d)(12)(i) through 
(d)(12)(iii) of this section.
    (i) Records showing the names of the municipal waste combustor chief 
facility operator, shift supervisors, and control room operators who 
have been provisionally certified by the American Society of Mechanical 
Engineers or an equivalent State-approved certification program as 
required by Sec. 60.54b(a) including the dates of initial and renewal 
certifications and documentation of current certification.
    (ii) Records showing the names of the municipal waste combustor 
chief facility operator, shift supervisors, and control room operators 
who have been fully certified by the American Society of Mechanical 
Engineers or an equivalent State-approved certification program as 
required by Sec. 60.54b(b) including the dates of initial and renewal 
certifications and documentation of current certification.
    (iii) Records showing the names of the municipal waste combustor 
chief facility operator, shift supervisors, and control room operators 
who have completed the EPA municipal waste combustor operator training 
course or a State-approved equivalent course as required by 
Sec. 60.54b(d) including documentation of training completion.
    (13) Records showing the names of persons who have completed a 
review of the operating manual as required by Sec. 60.54b(f) including 
the date of the initial review and subsequent annual reviews.
    (14) For affected facilities that apply activated carbon for mercury 
or dioxin/furan control, identification of the calendar dates when the 
average carbon mass feed rates recorded under (d)(4)(iii) of this 
section were less than either of the hourly carbon feed rates estimated 
during performance tests for mercury or dioxin/furan emissions and 
recorded under paragraphs (d)(4)(i) and (d)(4)(ii) of this section, 
respectively, with reasons for such feed rates and a description of 
corrective actions taken.
    (15) For affected facilities that apply activated carbon for mercury 
or dioxin/furan control, identification of the calendar dates when the 
carbon injection

[[Page 175]]

system operating parameter(s) that are the primary indicator(s) of 
carbon mass feed rate (e.g., screw feeder speed) recorded under 
paragraph (d)(4)(v) of this section are below the level(s) estimated 
during the performance tests as specified in Sec. 60.58b(m)(1)(i) and 
Sec. 60.58b(m)(1)(ii) of this section, with reasons for such occurrences 
and a description of corrective actions taken.
    (e) The owner or operator of an air curtain incinerator subject to 
the opacity limit under Sec. 60.56b shall maintain records of results of 
the initial opacity performance test and subsequent performance tests 
required by Sec. 60.58b(l) for a period of at least 5 years.
    (f) The owner or operator of an affected facility shall submit the 
information specified in paragraphs (f)(1) through (f)(6) of this 
section in the initial performance test report.
    (1) The initial performance test data as recorded under paragraphs 
(d)(2)(ii)(A) through (d)(2)(ii)(D) of this section for the initial 
performance test for sulfur dioxide, nitrogen oxides, carbon monoxide, 
municipal waste combustor unit load level, and particulate matter 
control device inlet temperature.
    (2) The test report documenting the initial performance test 
recorded under paragraph (d)(9) of this section for particulate matter, 
opacity, cadmium, lead, mercury, dioxins/furans, hydrogen chloride, and 
fugitive ash emissions.
    (3) The performance evaluation of the continuous emission monitoring 
system using the applicable performance specifications in appendix B of 
this part.
    (4) The maximum demonstrated municipal waste combustor unit load and 
maximum demonstrated particulate matter control device inlet 
temperature(s) established during the initial dioxin/furan performance 
test as recorded under paragraph (d)(9) of this section.
    (5) For affected facilities that apply activated carbon injection 
for mercury control, the owner or operator shall submit the average 
carbon mass feed rate recorded under paragraph (d)(4)(i) of this 
section.
    (6) For those affected facilities that apply activated carbon 
injection for dioxin/furan control, the owner or operator shall submit 
the average carbon mass feed rate recorded under paragraph (d)(4)(ii) of 
this section.
    (g) Following the first year of municipal combustor operation, the 
owner or operator of an affected facility shall submit an annual report 
including the information specified in paragraphs (g)(1) through (g)(4) 
of this section, as applicable, no later than February 1 of each year 
following the calendar year in which the data were collected (once the 
unit is subject to permitting requirements under Title V of the Act, the 
owner or operator of an affected facility must submit these reports 
semiannually).
    (1) A summary of data collected for all pollutants and parameters 
regulated under this subpart, which includes the information specified 
in paragraphs (g)(1)(i) through (g)(1)(v) of this section.
    (i) A list of the particulate matter, opacity, cadmium, lead, 
mercury, dioxins/furans, hydrogen chloride, and fugitive ash emission 
levels achieved during the performance tests recorded under paragraph 
(d)(9) of this section.
    (ii) A list of the highest emission level recorded for sulfur 
dioxide, nitrogen oxides, carbon monoxide, municipal waste combustor 
unit load level, and particulate matter control device inlet temperature 
based on the data recorded under paragraphs (d)(2)(ii)(A) through 
(d)(2)(ii)(D) of this section.
    (iii) List the highest opacity level measured, based on the data 
recorded under paragraph (d)(2)(i)(A) of this section.
    (iv) The total number of days that the minimum number of hours of 
data for sulfur dioxide, nitrogen oxides, carbon monoxide, municipal 
waste combustor unit load, and particulate matter control device 
temperature data were not obtained based on the data recorded under 
paragraph (d)(6) of this section.
    (v) The total number of hours that data for sulfur dioxide, nitrogen 
oxides, carbon monoxide, municipal waste combustor unit load, and 
particulate matter control device temperature were excluded from the 
calculation of average emission concentrations or parameters based on 
the data recorded under paragraph (d)(7) of this section.

[[Page 176]]

    (2) The summary of data reported under paragraph (g)(1) of this 
section shall also provide the types of data specified in paragraphs 
(g)(1)(i) through (g)(1)(vi) of this section for the calendar year 
preceding the year being reported, in order to provide the Administrator 
with a summary of the performance of the affected facility over a 2-year 
period.
    (3) The summary of data including the information specified in 
paragraphs (g)(1) and (g)(2) of this section shall highlight any 
emission or parameter levels that did not achieve the emission or 
parameter limits specified under this subpart.
    (4) A notification of intent to begin the reduced dioxin/furan 
performance testing schedule specified in Sec. 60.58b(g)(5)(iii) of this 
section during the following calendar year.
    (h) The owner or operator of an affected facility shall submit a 
semiannual report that includes the information specified in paragraphs 
(h)(1) through (h)(5) of this section for any recorded pollutant or 
parameter that does not comply with the pollutant or parameter limit 
specified under this subpart, according to the schedule specified under 
paragraph (h)(6) of this section.
    (1) The semiannual report shall include information recorded under 
paragraph (d)(3) of this section for sulfur dioxide, nitrogen oxides, 
carbon monoxide, municipal waste combustor unit load level, particulate 
matter control device inlet temperature, and opacity.
    (2) For each date recorded as required by paragraph (d)(3) of this 
section and reported as required by paragraph (h)(1) of this section, 
the semiannual report shall include the sulfur dioxide, nitrogen oxides, 
carbon monoxide, municipal waste combustor unit load level, particulate 
matter control device inlet temperature, or opacity data, as applicable, 
recorded under paragraphs (d)(2)(ii)(A) through (d)(2)(ii)(D) and 
(d)(2)(i)(A) of this section, as applicable.
    (3) If the test reports recorded under paragraph (d)(9) of this 
section document any particulate matter, opacity, cadmium, lead, 
mercury, dioxins/furans, hydrogen chloride, and fugitive ash emission 
levels that were above the applicable pollutant limits, the semiannual 
report shall include a copy of the test report documenting the emission 
levels and the corrective actions taken.
    (4) The semiannual report shall include the information recorded 
under paragraph (d)(15) of this section for the carbon injection system 
operating parameter(s) that are the primary indicator(s) of carbon mass 
feed rate.
    (5) For each operating date reported as required by paragraph (h)(4) 
of this section, the semiannual report shall include the carbon feed 
rate data recorded under paragraph (d)(4)(iii) of this section.
    (6) Semiannual reports required by paragraph (h) of this section 
shall be submitted according to the schedule specified in paragraphs 
(h)(6)(i) and (h)(6)(ii) of this section.
    (i) If the data reported in accordance with paragraphs (h)(1) 
through (h)(5) of this section were collected during the first calendar 
half, then the report shall be submitted by August 1 following the first 
calendar half.
    (ii) If the data reported in accordance with paragraphs (h)(1) 
through (h)(5) of this section were collected during the second calendar 
half, then the report shall be submitted by February 1 following the 
second calendar half.
    (i) The owner or operator of an air curtain incinerator subject to 
the opacity limit under Sec. 60.56b shall submit the results of the 
initial opacity performance test and all subsequent annual performance 
tests recorded under paragraph (e) of this section. Annual performance 
tests shall be submitted by February 1 of the year following the year of 
the performance test.
    (j) All reports specified under paragraphs (a), (b), (c), (f), (g), 
(h), and (i) of this section shall be submitted as a paper copy, 
postmarked on or before the submittal dates specified under these 
paragraphs, and maintained onsite as a paper copy for a period of 5 
years.
    (k) All records specified under paragraphs (d) and (e) of this 
section shall be maintained onsite in either paper copy or computer-
readable format, unless an alternative format is approved by the 
Administrator.

[[Page 177]]

    (l) If the owner or operator of an affected facility would prefer a 
different annual or semiannual date for submitting the periodic reports 
required by paragraphs (g), (h) and (i) of this section, then the dates 
may be changed by mutual agreement between the owner or operator and the 
Administrator according to the procedures specified in Sec. 60.19(c) of 
subpart A of this part.

[60 FR 65419, Dec. 19, 1995, as amended at 62 FR 45121, 45127, Aug. 25, 
1997]



  Subpart Ec--Standards of Performance for Hospital/Medical/Infectious 
 Waste Incinerators for Which Construction is Commenced After June 20, 
                                  1996

    Source: 62 FR 48382, Sept. 15, 1997, unless otherwise noted.



Sec. 60.50c  Applicability and delegation of authority.

    (a) Except as provided in paragraphs (b) through (h) of this 
section, the affected facility to which this subpart applies is each 
individual hospital/medical/infectious waste incinerator (HMIWI) for 
which construction is commenced after June 20, 1996 or for which 
modification is commenced after March 16, 1998.
    (b) A combustor is not subject to this subpart during periods when 
only pathological waste, low-level radioactive waste, and/or 
chemotherapeutic waste (all defined in Sec. 60.51c) is burned, provided 
the owner or operator of the combustor:
    (1) Notifies the Administrator of an exemption claim; and
    (2) Keeps records on a calendar quarter basis of the periods of time 
when only pathological waste, low-level radioactivewaste and/or 
chemotherapeutic waste is burned.
    (c) Any co-fired combustor (defined in Sec. 60.51c) is not subject 
to this subpart if the owner or operator of the co-fired combustor:
    (1) Notifies the Administrator of an exemption claim;
    (2) Provides an estimate of the relative amounts of hospital waste, 
medical/infectious waste, and other fuels and wastes to be combusted; 
and
    (3) Keeps records on a calendar quarter basis of the weight of 
hospital waste and medical/infectious waste combusted, and the weight of 
all other fuels and wastes combusted at the co-fired combustor.
    (d) Any combustor required to have a permit under section 3005 of 
the Solid Waste Disposal Act is not subject to this subpart.
    (e) Any combustor which meets the applicability requirements under 
subpart Cb, Ea, or Eb of this part (standards or guidelines for certain 
municipal waste combustors) is not subject to this subpart.
    (f) Any pyrolysis unit (defined in Sec. 60.51c) is not subject to 
this subpart.
    (g) Cement kilns firing hospital waste and/or medical/infectious 
waste are not subject to this subpart.
    (h) Physical or operational changes made to an existing HMIWI solely 
for the purpose of complying with emission guidelines under subpart Ce 
are not considered a modification and do not result in an existing HMIWI 
becoming subject to this subpart.
    (i) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Clean Air Act, the following 
authorities shall be retained by the Administrator and not transferred 
to a State:
    (1) The requirements of Sec. 60.56c(i) establishing operating 
parameters when using controls other than those listed in 
Sec. 60.56c(d).
    (2) Alternative methods of demonstrating compliance under Sec. 60.8.
    (j) Affected facilities subject to this subpart are not subject to 
the requirements of 40 CFR part 64.
    (k) The requirements of this subpart shall become effective March 
16, 1998
    (l) Beginning September 15, 2000, or on the effective date of an 
EPA-approved operating permit program under Clean Air Act title V and 
the implementing regulations under 40 CFR part 70 in the State in which 
the unit is located, whichever date is later, affected facilities 
subject to this subpart shall operate pursuant to a permit issued under 
the EPA approved State operating permit program.

[[Page 178]]



Sec. 60.51c  Definitions.

    Batch HMIWI means an HMIWI that is designed such that neither waste 
charging nor ash removal can occur during combustion.
    Biologicals means preparations made from living organisms and their 
products, including vaccines, cultures, etc., intended for use in 
diagnosing, immunizing, or treating humans or animals or in research 
pertaining thereto.
    Blood products means any product derived from human blood, including 
but not limited to blood plasma, platelets, red or white blood 
corpuscles, and other derived licensed products, such as interferon, 
etc.
    Body fluids means liquid emanating or derived from humans and 
limited to blood; dialysate; amniotic, cerebrospinal, synovial, pleural, 
peritoneal and pericardial fluids; and semen and vaginal secretions.
    Bypass stack means a device used for discharging combustion gases to 
avoid severe damage to the air pollution control device or other 
equipment.
    Chemotherapeutic waste means waste material resulting from the 
production or use of antineoplastic agents used for the purpose of 
stopping or reversing the growth of malignant cells.
    Co-fired combustor means a unit combusting hospital waste and/or 
medical/infectious waste with other fuels or wastes (e.g., coal, 
municipal solid waste) and subject to an enforceable requirement 
limiting the unit to combusting a fuel feed stream, 10 percent or less 
of the weight of which is comprised, in aggregate, of hospital waste and 
medical/infectious waste as measured on a calendar quarter basis. For 
purposes of this definition, pathological waste, chemotherapeutic waste, 
and low-level radioactive waste are considered ``other'' wastes when 
calculating the percentage of hospital waste and medical/infectious 
waste combusted.
    Continuous emission monitoring system or CEMS means a monitoring 
system for continuously measuring and recording the emissions of a 
pollutant from an affected facility.
    Continuous HMIWI means an HMIWI that is designed to allow waste 
charging and ash removal during combustion.
    Dioxins/furans means the combined emissions of tetra-through octa-
chlorinated dibenzo-para-dioxins and dibenzofurans, as measured by EPA 
Reference Method 23.
    Dry scrubber means an add-on air pollution control system that 
injects dry alkaline sorbent (dry injection) or sprays an alkaline 
sorbent (spray dryer) to react with and neutralize acid gases in the 
HMIWI exhaust stream forming a dry powder material.
    Fabric filter or baghouse means an add-on air pollution control 
system that removes particulate matter (PM) and nonvaporous metals 
emissions by passing flue gas through filter bags.
    Facilities manager means the individual in charge of purchasing, 
maintaining, and operating the HMIWI or the owner's or operator's 
representative responsible for the management of the HMIWI. Alternative 
titles may include director of facilities or vice president of support 
services.
    High-air phase means the stage of the batch operating cycle when the 
primary chamber reaches and maintains maximum operating temperatures.
    Hospital means any facility which has an organized medical staff, 
maintains at least six inpatient beds, and where the primary function of 
the institution is to provide diagnostic and therapeutic patient 
services and continuous nursing care primarily to human inpatients who 
are not related and who stay on average in excess of 24 hours per 
admission. This definition does not include facilities maintained for 
the sole purpose of providing nursing or convalescent care to human 
patients who generally are not acutely ill but who require continuing 
medical supervision.
    Hospital/medical/infectious waste incinerator or HMIWI or HMIWI unit 
means any device that combusts any amount of hospital waste and/or 
medical/infectious waste.
    Hospital/medical/infectious waste incinerator operator or HMIWI 
operator means any person who operates, controls or supervises the day-
to-day operation of an HMIWI.
    Hospital waste means discards generated at a hospital, except unused 
items returned to the manufacturer. The definition of hospital waste 
does

[[Page 179]]

not include human corpses, remains, and anatomical parts that are 
intended for interment or cremation.
    Infectious agent means any organism (such as a virus or bacteria) 
that is capable of being communicated by invasion and multiplication in 
body tissues and capable of causing disease or adverse health impacts in 
humans.
    Intermittent HMIWI means an HMIWI that is designed to allow waste 
charging, but not ash removal, during combustion.
    Large HMIWI means:
    (1) Except as provided in (2);
    (i) An HMIWI whose maximum design waste burning capacity is more 
than 500 pounds per hour; or
    (ii) A continuous or intermittent HMIWI whose maximum charge rate is 
more than 500 pounds per hour; or
    (iii) A batch HMIWI whose maximum charge rate is more than 4,000 
pounds per day.
    (2) The following are not large HMIWI:
    (i) A continuous or intermittent HMIWI whose maximum charge rate is 
less than or equal to 500 pounds per hour; or
    (ii) A batch HMIWI whose maximum charge rate is less than or equal 
to 4,000 pounds per day.
    Low-level radioactive waste means waste material which contains 
radioactive nuclides emitting primarily beta or gamma radiation, or 
both, in concentrations or quantities that exceed applicable federal or 
State standards for unrestricted release. Low-level radioactive waste is 
not high-level radioactive waste, spent nuclear fuel, or by-product 
material as defined by the Atomic Energy Act of 1954 (42 U.S.C. 
2014(e)(2)).
    Malfunction means any sudden, infrequent, and not reasonably 
preventable failure of air pollution control equipment, process 
equipment, or a process to operate in a normal or usual manner. Failures 
that are caused, in part, by poor maintenance or careless operation are 
not malfunctions. During periods of malfunction the operator shall 
operate within established parameters as much as possible, and 
monitoring of all applicable operating parameters shall continue until 
all waste has been combusted or until the malfunction ceases, whichever 
comes first.
    Maximum charge rate means:
    (1) For continuous and intermittent HMIWI, 110 percent of the lowest 
3-hour average charge rate measured during the most recent performance 
test demonstrating compliance with all applicable emission limits.
    (2) For batch HMIWI, 110 percent of the lowest daily charge rate 
measured during the most recent performance test demonstrating 
compliance with all applicable emission limits.
    Maximum design waste burning capacity means:
    (1) For intermittent and continuous HMIWI,

C=PV  x  15,000/8,500
Where:
C=HMIWI capacity, lb/hr
PV=primary chamber volume, ft\3\
15,000=primary chamber heat release rate factor, Btu/ft\3\/hr
68,500=standard waste heating value, Btu/lb;

    (2) For batch HMIWI,

C=PV  x  4.5/8

Where:
C=HMIWI capacity, lb/hr
PV=primary chamber volume, ft\3\
164.5=waste density, lb/ft\3\
8=typical hours of operation of a batch HMIWI, hours.

    Maximum fabric filter inlet temperature means 110 percent of the 
lowest 3-hour average temperature at the inlet to the fabric filter 
(taken, at a minimum, once every minute) measured during the most recent 
performance test demonstrating compliance with the dioxin/furan emission 
limit.
    Maximum flue gas temperature means 110 percent of the lowest 3-hour 
average temperature at the outlet from the wet scrubber (taken, at a 
minimum, once every minute) measured during the most recent performance 
test demonstrating compliance with the mercury (Hg) emission limit.
    Medical/infectious waste means any waste generated in the diagnosis, 
treatment, or immunization of human beings or animals, in research 
pertaining thereto, or in the production or testing of biologicals that 
is listed in

[[Page 180]]

paragraphs (1) through (7) of this definition. The definition of 
medical/infectious waste does not include hazardous waste identified or 
listed under the regulations in part 261 of this chapter; household 
waste, as defined in Sec. 261.4(b)(1) of this chapter; ash from 
incineration of medical/infectious waste, once the incineration process 
has been completed; human corpses, remains, and anatomical parts that 
are intended for interment mation; and domestic sewage materials 
identified in Sec. 261.4(a)(1) of this chapter.
    (1) Cultures and stocks of infectious agents and associated 
biologicals, including: cultures from medical and pathological 
laboratories; cultures and stocks of infectious agents from research and 
industrial laboratories; wastes from the production of biologicals; 
discarded live and attenuated vaccines; and culture dishes and devices 
used to transfer, inoculate, and mix cultures.
    (2) Human pathological waste, including tissues, organs, and body 
parts and body fluids that are removed during surgery or autopsy, or 
other medical procedures, and specimens of body fluids and their 
containers.
    (3) Human blood and blood products including:
    (i) Liquid waste human blood;
    (ii) Products of blood;
    (iii) Items saturated and/or dripping with human blood; or
    (iv) Items that were saturated and/or dripping with human blood that 
are now caked with dried human blood; including serum, plasma, and other 
blood components, and their containers, which were used or intended for 
use in either patient care, testing and laboratory analysis or the 
development of pharmaceuticals. Intravenous bags are also include in 
this category.
    (4) Sharps that have been used in animal or human patient care or 
treatment or in medical, research, or industrial laboratories, including 
hypodermic needles, syringes (with or without the attached needle), 
pasteur pipettes, scalpel blades, blood vials, needles with attached 
tubing, and culture dishes (regardless of presence of infectious 
agents). Also included are other types of broken or unbroken glassware 
that were in contact with infectious agents, such as used slides and 
cover slips.
    (5) Animal waste including contaminated animal carcasses, body 
parts, and bedding of animals that were known to have been exposed to 
infectious agents during research (including research in veterinary 
hospitals), production of biologicals or testing of pharmaceuticals.
    (6) Isolation wastes including biological waste and discarded 
materials contaminated with blood, excretions, exudates, or secretions 
from humans who are isolated to protect others from certain highly 
communicable diseases, or isolated animals known to be infected with 
highly communicable diseases.
    (7) Unused sharps including the following unused, discarded sharps: 
hypodermic needles, suture needles, syringes, and scalpel blades.
    Medium HMIWI means:
    (1) Except as provided in paragraph (2);
    (i) An HMIWI whose maximum design waste burning capacity is more 
than 200 pounds per hour but less than or equal to 500 pounds per hour; 
or
    (ii) A continuous or intermittent HMIWI whose maximum charge rate is 
more than 200 pounds per hour but less than or equal to 500 pounds per 
hour; or
    (iii) A batch HMIWI whose maximum charge rate is more than 1,600 
pounds per day but less than or equal to 4,000 pounds per day.
    (2) The following are not medium HMIWI:
    (i) A continuous or intermittent HMIWI whose maximum charge rate is 
less than or equal to 200 pounds per hour or more than 500 pounds per 
hour; or
    (ii) A batch HMIWI whose maximum charge rate is more than 4,000 
pounds per day or less than or equal to 1,600 pounds per day.
    Minimum dioxin/furan sorbent flow rate means 90 percent of the 
highest 3-hour average dioxin/furan sorbent flow rate (taken, at a 
minimum, once every hour) measured during the most recent performance 
test demonstrating compliance with the dioxin/furan emission limit.

[[Page 181]]

    Minimum Hg sorbent flow rate means 90 percent of the highest 3-hour 
average Hg sorbent flow rate (taken, at a minimum, once every hour) 
measured during the most recent performance test demonstrating 
compliance with the Hg emission limit.
    Minimum hydrogen chloride (HCl) sorbent flow rate means 90 percent 
of the highest 3-hour average HCl sorbent flow rate (taken, at a 
minimum, once every hour) measured during the most recent performance 
test demonstrating compliance with the HCl emission limit.
    Minimum horsepower or amperage means 90 percent of the highest 3-
hour average horsepower or amperage to the wet scrubber (taken, at a 
minimum, once every minute) measured during the most recent performance 
test demonstrating compliance with the applicable emission limits.
    Minimum pressure drop across the wet scrubber means 90 percent of 
the highest 3-hour average pressure drop across the wet scrubber PM 
control device (taken, at a minimum, once every minute) measured during 
the most recent performance test demonstrating compliance with the PM 
emission limit.
    Minimum scrubber liquor flow rate means 90 percent of the highest 3-
hour average liquor flow rate at the inlet to the wet scrubber (taken, 
at a minimum, once every minute) measured during the most recent 
performance test demonstrating compliance with all applicable emission 
limits.
    Minimum scrubber liquor pH means 90 percent of the highest 3-hour 
average liquor pH at the inlet to the wet scrubber (taken, at a minimum, 
once every minute) measured during the most recent performance test 
demonstrating compliance with the HCl emission limit.
    Minimum secondary chamber temperature means 90 percent of the 
highest 3-hour average secondary chamber temperature (taken, at a 
minimum, once every minute) measured during the most recent performance 
test demonstrating compliance with the PM, CO, or dioxin/furan emission 
limits.
    Modification or Modified HMIWI means any change to an HMIWI unit 
after the effective date of these standards such that:
    (1) The cumulative costs of the modifications, over the life of the 
unit, exceed 50 per centum of the original cost of the construction and 
installation of the unit (not including the cost of any land purchased 
in connection with such construction or installation) updated to current 
costs, or
    (2) The change involves a physical change in or change in the method 
of operation of the unit which increases the amount of any air pollutant 
emitted by the unit for which standards have been established under 
section 129 or section 111.
    Operating day means a 24-hour period between 12:00 midnight and the 
following midnight during which any amount of hospital waste or medical/
infectious waste is combusted at any time in the HMIWI.
    Operation means the period during which waste is combusted in the 
incinerator excluding periods of startup or shutdown.
    Particulate matter or PM means the total particulate matter emitted 
from an HMIWI as measured by EPA Reference Method 5 or EPA Reference 
Method 29.
    Pathological waste means waste material consisting of only human or 
animal remains, anatomical parts, and/or tissue, the bags/containers 
used to collect and transport the waste material, and animal bedding (if 
applicable).
    Primary chamber means the chamber in an HMIWI that receives waste 
material, in which the waste is ignited, and from which ash is removed.
    Pyrolysis means the endothermic gasification of hospital waste and/
or medical/infectious waste using external energy.
    Secondary chamber means a component of the HMIWI that receives 
combustion gases from the primary chamber and in which the combustion 
process is completed.
    Shutdown means the period of time after all waste has been combusted 
in the primary chamber. For continuous HMIWI, shutdown shall commence no 
less than 2 hours after the last charge to the incinerator. For 
intermittent HMIWI, shutdown shall commence no less than 4 hours after 
the last charge

[[Page 182]]

to the incinerator. For batch HMIWI, shutdown shall commence no less 
than 5 hours after the high-air phase of combustion has been completed.
    Small HMIWI means:
    (1) Except as provided in (2);
    (i) An HMIWI whose maximum design waste burning capacity is less 
than or equal to 200 pounds per hour; or
    (ii) A continuous or intermittent HMIWI whose maximum charge rate is 
less than or equal to 200 pounds per hour; or
    (iii) A batch HMIWI whose maximum charge rate is less than or equal 
to 1,600 pounds per day.
    (2) The following are not small HMIWI:
    (i) A continuous or intermittent HMIWI whose maximum charge rate is 
more than 200 pounds per hour;
    (ii) A batch HMIWI whose maximum charge rate is more than 1,600 
pounds per day.
    Standard conditions means a temperature of 20  deg.C and a pressure 
of 101.3 kilopascals.
    Startup means the period of time between the activation of the 
system and the first charge to the unit. For batch HMIWI, startup means 
the period of time between activation of the system and ignition of the 
waste.
    Wet scrubber means an add-on air pollution control device that 
utilizes an alkaline scrubbing liquor to collect particulate matter 
(including nonvaporous metals and condensed organics) and/or to absorb 
and neutralize acid gases.



Sec. 60.52c  Emission limits.

    (a) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8, whichever date 
comes first, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from that affected facility any gases 
that contain stack emissions in excess of the limits presented in Table 
1 of this subpart.
    (b) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8, whichever date 
comes first, no owner or operator of an affected facility shall cause to 
be discharged into the atmosphere from the stack of that affected 
facility any gases that exhibit greater than 10 percent opacity (6-
minute block average).
    (c) On and after the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8, whichever date 
comes first, no owner or operator of an affected facility utilizing a 
large HMIWI shall cause to be discharged into the atmosphere visible 
emissions of combustion ash from an ash conveying system (including 
conveyor transfer points) in excess of 5 percent of the observation 
period (i.e., 9 minutes per 3-hour period), as determined by EPA 
Reference Method 22, except as provided in paragraphs (d) and (e) of 
this section.
    (d) The emission limit specified in paragraph (c) of this section 
does not cover visible emissions discharged inside buildings or 
enclosures of ash conveying systems; however, the emission limit does 
cover visible emissions discharged to the atmosphere from buildings or 
enclosures of ash conveying systems.
    (e) The provisions specified in paragraph (c) of this section do not 
apply during maintenance and repair of ash conveying systems. 
Maintenance and/or repair shall not exceed 10 operating days per 
calendar quarter unless the owner or operator obtains written approval 
from the State agency establishing a date whereby all necessary 
maintenance and repairs of ash conveying systems shall be completed.



Sec. 60.53c  Operator training and qualification requirements.

    (a) No owner or operator of an affected facility shall allow the 
affected facility to operate at any time unless a fully trained and 
qualified HMIWI operator is accessible, either at the facility or 
available within 1 hour. The trained and qualified HMIWI operator may 
operate the HMIWI directly or be the direct supervisor of one or more 
HMIWI operators.
    (b) Operator training and qualification shall be obtained through a 
State-approved program or by completing the requirements included in 
paragraphs (c) through (g) of this section.

[[Page 183]]

    (c) Training shall be obtained by completing an HMIWI operator 
training course that includes, at a minimum, the following provisions:
    (1) 24 hours of training on the following subjects:
    (i) Environmental concerns, including pathogen destruction and types 
of emissions;
    (ii) Basic combustion principles, including products of combustion;
    (iii) Operation of the type of incinerator to be used by the 
operator, including proper startup, waste charging, and shutdown 
procedures;
    (iv) Combustion controls and monitoring;
    (v) Operation of air pollution control equipment and factors 
affecting performance (if applicable);
    (vi) Methods to monitor pollutants (continuous emission monitoring 
systems and monitoring of HMIWI and air pollution control device 
operating parameters) and equipment calibration procedures (where 
applicable);
    (vii) Inspection and maintenance of the HMIWI, air pollution control 
devices, and continuous emission monitoring systems;
    (viii) Actions to correct malfunctions or conditions that may lead 
to malfunction;
    (ix) Bottom and fly ash characteristics and handling procedures;
    (x) Applicable Federal, State, and local regulations;
    (xi) Work safety procedures;
    (xii) Pre-startup inspections; and
    (xiii) Recordkeeping requirements.
    (2) An examination designed and administered by the instructor.
    (3) Reference material distributed to the attendees covering the 
course topics.
    (d) Qualification shall be obtained by:
    (1) Completion of a training course that satisfies the criteria 
under paragraph (c) of this section; and
    (2) Either 6 months experience as an HMIWI operator, 6 months 
experience as a direct supervisor of an HMIWI operator, or completion of 
at least two burn cycles under the observation of two qualified HMIWI 
operators.
    (e) Qualification is valid from the date on which the examination is 
passed or the completion of the required experience, whichever is later.
    (f) To maintain qualification, the trained and qualified HMIWI 
operator shall complete and pass an annual review or refresher course of 
at least 4 hours covering, at a minimum, the following:
    (1) Update of regulations;
    (2) Incinerator operation, including startup and shutdown 
procedures;
    (3) Inspection and maintenance;
    (4) Responses to malfunctions or conditions that may lead to 
malfunction; and
    (5) Discussion of operating problems encountered by attendees.
    (g) A lapsed qualification shall be renewed by one of the following 
methods:
    (1) For a lapse of less than 3 years, the HMIWI operator shall 
complete and pass a standard annual refresher course described in 
paragraph (f) of this section.
    (2) For a lapse of 3 years or more, the HMIWI operator shall 
complete and pass a training course with the minimum criteria described 
in paragraph (c) of this section.
    (h) The owner or operator of an affected facility shall maintain 
documentation at the facility that address the following:
    (1) Summary of the applicable standards under this subpart;
    (2) Description of basic combustion theory applicable to an HMIWI;
    (3) Procedures for receiving, handling, and charging waste;
    (4) HMIWI startup, shutdown, and malfunction procedures;
    (5) Procedures for maintaining proper combustion air supply levels;
    (6) Procedures for operating the HMIWI and associated air pollution 
control systems within the standards established under this subpart;
    (7) Procedures for responding to periodic malfunction or conditions 
that may lead to malfunction;
    (8) Procedures for monitoring HMIWI emissions;
    (9) Reporting and recordkeeping procedures; and
    (10) Procedures for handling ash.
    (i) The owner or operator of an affected facility shall establish a 
program for reviewing the information listed in paragraph (h) of this 
section

[[Page 184]]

annually with each HMIWI operator (defined in Sec. 60.51c).
    (1) The initial review of the information listed in paragraph (h) of 
this section shall be conducted within 6 months after the effective date 
of this subpart or prior to assumption of responsibilities affecting 
HMIWI operation, whichever date is later.
    (2) Subsequent reviews of the information listed in paragraph (h) of 
this section shall be conducted annually.
    (j) The information listed in paragraph (h) of this section shall be 
kept in a readily accessible location for all HMIWI operators. This 
information, along with records of training shall be available for 
inspection by the EPA or its delegated enforcement agent upon request.



Sec. 60.54c  Siting requirements.

    (a) The owner or operator of an affected facility for which 
construction is commenced after September 15, 1997 shall prepare an 
analysis of the impacts of the affected facility. The analysis shall 
consider air pollution control alternatives that minimize, on a site-
specific basis, to the maximum extent practicable, potential risks to 
public health or the environment. In considering such alternatives, the 
analysis may consider costs, energy impacts, non-air environmental 
impacts, or any other factors related to the practicability of the 
alternatives.
    (b) Analyses of facility impacts prepared to comply with State, 
local, or other Federal regulatory requirements may be used to satisfy 
the requirements of this section, as long as they include the 
consideration of air pollution control alternatives specified in 
paragraph (a) of this section.
    (c) The owner or operator of the affected facility shall complete 
and submit the siting requirements of this section as required under 
Sec. 60.58c(a)(1)(iii).



Sec. 60.55c  Waste management plan.

    The owner or operator of an affected facility shall prepare a waste 
management plan. The waste management plan shall identify both the 
feasibility and the approach to separate certain components of solid 
waste from the health care waste stream in order to reduce the amount of 
toxic emissions from incinerated waste. A waste management plan may 
include, but is not limited to, elements such as paper, cardboard, 
plastics, glass, battery, or metal recycling; or purchasing recycled or 
recyclable products. A waste management plan may include different goals 
or approaches for different areas or departments of the facility and 
need not include new waste management goals for every waste stream. It 
should identify, where possible, reasonably available additional waste 
management measures, taking into account the effectiveness of waste 
management measures already in place, the costs of additional measures, 
the emission reductions expected to be achieved, and any other 
environmental or energy impacts they might have. The American Hospital 
Association publication entitled ``An Ounce of Prevention: Waste 
Reduction Strategies for Health Care Facilities'' (incorporated by 
reference, see Sec. 60.17) shall be considered in the development of the 
waste management plan.



Sec. 60.56c  Compliance and performance testing.

    (a) The emission limits under this subpart apply at all times except 
during periods of startup, shutdown, or malfunction, provided that no 
hospital waste or medical/infectious waste is charged to the affected 
facility during startup, shutdown, or malfunction.
    (b) The owner or operator of an affected facility shall conduct an 
initial performance test as required under Sec. 60.8 to determine 
compliance with the emission limits using the procedures and test 
methods listed in paragraphs (b)(1) through (b)(12) of this section. The 
use of the bypass stack during a performance test shall invalidate the 
performance test.
    (1) All performance tests shall consist of a minimum of three test 
runs conducted under representative operating conditions.
    (2) The minimum sample time shall be 1 hour per test run unless 
otherwise indicated.
    (3) EPA Reference Method 1 of appendix A of this part shall be used 
to select the sampling location and number of traverse points.

[[Page 185]]

    (4) EPA Reference Method 3 or 3A of appendix A of this part shall be 
used for gas composition analysis, including measurement of oxygen 
concentration. EPA Reference Method 3 or 3A of appendix A of this part 
shall be used simultaneously with each reference method.
    (5) The pollutant concentrations shall be adjusted to 7 percent 
oxygen using the following equation:

Cadj=Cmeas (20.9--7)/(20.9--%O2) where:

Cadj=pollutant concentration adjusted to 7 percent oxygen;
Cmeas=pollutant concentration measured on a dry basis (20.9--
7)=20.9 percent oxygen--7 percent oxygen (defined oxygen correction 
basis);
20.9=oxygen concentration in air, percent; and
%O2=oxygen concentration measured on a dry basis, percent.

    (6) EPA Reference Method 5 or 29 of appendix A of this part shall be 
used to measure the particulate matter emissions.
    (7) EPA Reference Method 9 of appendix A of this part shall be used 
to measure stack opacity.
    (8) EPA Reference Method 10 or 10B of appendix A of this part shall 
be used to measure the CO emissions.
    (9) EPA Reference Method 23 of appendix A of this part shall be used 
to measure total dioxin/furan emissions. The minimum sample time shall 
be 4 hours per test run. If the affected facility has selected the toxic 
equivalency standards for dioxin/furans, under Sec. 60.52c, the 
following procedures shall be used to determine compliance:
    (i) Measure the concentration of each dioxin/furan tetra-through 
octa-congener emitted using EPA Reference Method 23.
    (ii) For each dioxin/furan congener measured in accordance with 
paragraph (b)(9)(i) of this section, multiply the congener concentration 
by its corresponding toxic equivalency factor specified in Table 2 of 
this subpart.
    (iii) Sum the products calculated in accordance with paragraph 
(b)(9)(ii) of this section to obtain the total concentration of dioxins/
furans emitted in terms of toxic equivalency.
    (10) EPA Reference Method 26 of appendix A of this part shall be 
used to measure HCl emissions. If the affected facility has selected the 
percentage reduction standards for HCl under Sec. 60.52c, the percentage 
reduction in HCl emissions (%RHCl) is computed using the 
following formula:
[GRAPHIC] [TIFF OMITTED] TR15SE97.000

Where:
%RHCl=percentage reduction of HCl emissions achieved;
Ei=HCl emission concentration measured at the control device 
inlet, corrected to 7 percent oxygen (dry basis); and
Eo=HCl emission concentration measured at the control device 
outlet, corrected to 7 percent oxygen (dry basis).

    (11) EPA Reference Method 29 of appendix A of this part shall be 
used to measure Pb, Cd, and Hg emissions. If the affected facility has 
selected the percentage reduction standards for metals under 
Sec. 60.52c, the percentage reduction in emissions (%Rmetal) 
is computed using the following formula:
[GRAPHIC] [TIFF OMITTED] TC16NO91.251

Where:
%Rmetal=percentage reduction of metal emission (Pb, Cd, or 
Hg) achieved;
Ei=metal emission concentration (Pb, Cd, or Hg) measured at 
the control device inlet, corrected to 7 percent oxygen (dry basis); and
Eo=metal emission concentration (Pb, Cd, or Hg) measured at 
the control device outlet, corrected to 7 percent oxygen (dry basis).

    (12) The EPA Reference Method 22 of appendix A of this part shall be 
used to determine compliance with the fugitive ash emission limit under 
Sec. 60.52c(c). The minimum observation time shall be a series of three 
1-hour observations.
    (c) Following the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8, whichever date 
comes first, the owner or operator of an affected facility shall:
    (1) Determine compliance with the opacity limit by conducting an 
annual performance test (no more than 12

[[Page 186]]

months following the previous performance test) using the applicable 
procedures and test methods listed in paragraph (b) of this section.
    (2) Determine compliance with the PM, CO, and HCl emission limits by 
conducting an annual performance test (no more than 12 months following 
the previous performance test) using the applicable procedures and test 
methods listed in paragraph (b) of this section. If all three 
performance tests over a 3-year period indicate compliance with the 
emission limit for a pollutant (PM, CO, or HCl), the owner or operator 
may forego a performance test for that pollutant for the subsequent 2 
years. At a minimum, a performance test for PM, CO, and HCl shall be 
conducted every third year (no more than 36 months following the 
previous performance test). If a performance test conducted every third 
year indicates compliance with the emission limit for a pollutant (PM, 
CO, or HCl), the owner or operator may forego a performance test for 
that pollutant for an additional 2 years. If any performance test 
indicates noncompliance with the respective emission limit, a 
performance test for that pollutant shall be conducted annually until 
all annual performance tests over a 3-year period indicate compliance 
with the emission limit. The use of the bypass stack during a 
performance test shall invalidate the performance test.
    (3) For large HMIWI, determine compliance with the visible emission 
limits for fugitive emissions from flyash/bottom ash storage and 
handling by conducting a performance test using EPA Reference Method 22 
on an annual basis (no more than 12 months following the previous 
performance test).
    (4) Facilities using a CEMS to demonstrate compliance with any of 
the emission limits under Sec. 60.52c shall:
    (i) Determine compliance with the appropriate emission limit(s) 
using a 12-hour rolling average, calculated each hour as the average of 
the previous 12 operating hours (not including startup, shutdown, or 
malfunction).
    (ii) Operate all CEMS in accordance with the applicable procedures 
under appendices B and F of this part.
    (d) The owner or operator of an affected facility equipped with a 
dry scrubber followed by a fabric filter, a wet scrubber, or a dry 
scrubber followed by a fabric filter and wet scrubber shall:
    (1) Establish the appropriate maximum and minimum operating 
parameters, indicated in Table 3 of this subpart for each control 
system, as site specific operating parameters during the initial 
performance test to determine compliance with the emission limits; and
    (2) Following the date on which the initial performance test is 
completed or is required to be completed under Sec. 60.8, whichever date 
comes first, ensure that the affected facility does not operate above 
any of the applicable maximum operating parameters or below any of the 
applicable minimum operating parameters listed in Table 3 of this 
subpart and measured as 3-hour rolling averages (calculated each hour as 
the average of the previous 3 operating hours) at all times except 
during periods of startup, shutdown and malfunction. Operating parameter 
limits do not apply during performance tests. Operation above the 
established maximum or below the established minimum operating 
parameter(s) shall constitute a violation of established operating 
parameter(s).
    (e) Except as provided in paragraph (h) of this section, for 
affected facilities equipped with a dry scrubber followed by a fabric 
filter:
    (1) Operation of the affected facility above the maximum charge rate 
and below the minimum secondary chamber temperature (each measured on a 
3-hour rolling average) simultaneously shall constitute a violation of 
the CO emission limit.
    (2) Operation of the affected facility above the maximum fabric 
filter inlet temperature, above the maximum charge rate, and below the 
minimum dioxin/furan sorbent flow rate (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the 
dioxin/furan emission limit.
    (3) Operation of the affected facility above the maximum charge rate 
and below the minimum HCl sorbent flow rate (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the HCl 
emission limit.

[[Page 187]]

    (4) Operation of the affected facility above the maximum charge rate 
and below the minimum Hg sorbent flow rate (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the Hg 
emission limit.
    (5) Use of the bypass stack (except during startup, shutdown, or 
malfunction) shall constitute a violation of the PM, dioxin/furan, HCl, 
Pb, Cd and Hg emission limits.
    (f) Except as provided in paragraph (h) of this section, for 
affected facilities equipped with a wet scrubber:
    (1) Operation of the affected facility above the maximum charge rate 
and below the minimum pressure drop across the wet scrubber or below the 
minimum horsepower or amperage to the system (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the PM 
emission limit.
    (2) Operation of the affected facility above the maximum charge rate 
and below the minimum secondary chamber temperature (each measured on a 
3-hour rolling average) simultaneously shall constitute a violation of 
the CO emission limit.
    (3) Operation of the affected facility above the maximum charge 
rate, below the minimum secondary chamber temperature, and below the 
minimum scrubber liquor flow rate (each measured on a 3-hour rolling 
average) simultaneously shall constitute a violation of the dioxin/furan 
emission limit.
    (4) Operation of the affected facility above the maximum charge rate 
and below the minimum scrubber liquor pH (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the HCl 
emission limit.
    (5) Operation of the affected facility above the maximum flue gas 
temperature and above the maximum charge rate (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the Hg 
emission limit.
    (6) Use of the bypass stack (except during startup, shutdown, or 
malfunction) shall constitute a violation of the PM, dioxin/furan, HCl, 
Pb, Cd and Hg emission limits.
    (g) Except as provided in paragraph (h) of this section, for 
affected facilities equipped with a dry scrubber followed by a fabric 
filter and a wet scrubber:
    (1) Operation of the affected facility above the maximum charge rate 
and below the minimum secondary chamber temperature (each measured on a 
3-hour rolling average) simultaneously shall constitute a violation of 
the CO emission limit.
    (2) Operation of the affected facility above the maximum fabric 
filter inlet temperature, above the maximum charge rate, and below the 
minimum dioxin/furan sorbent flow rate (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the 
dioxin/furan emission limit.
    (3) Operation of the affected facility above the maximum charge rate 
and below the minimum scrubber liquor pH (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the HCl 
emission limit.
    (4) Operation of the affected facility above the maximum charge rate 
and below the minimum Hg sorbent flow rate (each measured on a 3-hour 
rolling average) simultaneously shall constitute a violation of the Hg 
emission limit.
    (5) Use of the bypass stack (except during startup, shutdown, or 
malfunction) shall constitute a violation of the PM, dioxin/furan, HCl, 
Pb, Cd and Hg emission limits.
    (h) The owner or operator of an affected facility may conduct a 
repeat performance test within 30 days of violation of applicable 
operating parameter(s) to demonstrate that the affected facility is not 
in violation of the applicable emission limit(s). Repeat performance 
tests conducted pursuant to this paragraph shall be conducted using the 
identical operating parameters that indicated a violation under 
paragraph (e), (f), or (g) of this section.
    (i) The owner or operator of an affected facility using an air 
pollution control device other than a dry scrubber followed by a fabric 
filter, a wet scrubber, or a dry scrubber followed by a fabric filter 
and a wet scrubber to comply with the emission limits under Sec. 60.52c 
shall petition the Administrator for other site-specific operating 
parameters to be established during

[[Page 188]]

the initial performance test and continuously monitored thereafter. The 
owner or operator shall not conduct the initial performance test until 
after the petition has been approved by the Administrator.
    (j) The owner or operator of an affected facility may conduct a 
repeat performance test at any time to establish new values for the 
operating parameters. The Administrator may request a repeat performance 
test at any time.



Sec. 60.57c  Monitoring requirements.

    (a) The owner or operator of an affected facility shall install, 
calibrate (to manufacturers' specifications), maintain, and operate 
devices (or establish methods) for monitoring the applicable maximum and 
minimum operating parameters listed in Table 3 of this subpart such that 
these devices (or methods) measure and record values for these operating 
parameters at the frequencies indicated in Table 3 of this subpart at 
all times except during periods of startup and shutdown.
    (b) The owner or operator of an affected facility shall install, 
calibrate (to manufacturers' specifications), maintain, and operate a 
device or method for measuring the use of the bypass stack including 
date, time, and duration.
    (c) The owner or operator of an affected facility using something 
other than a dry scrubber followed by a fabric filter, a wet scrubber, 
or a dry scrubber followed by a fabric filter and a wet scrubber to 
comply with the emission limits under Sec. 60.52c shall install, 
calibrate (to the manufacturers' specifications), maintain, and operate 
the equipment necessary to monitor the site-specific operating 
parameters developed pursuant to Sec. 60.56c(i).
    (d) The owner or operator of an affected facility shall obtain 
monitoring data at all times during HMIWI operation except during 
periods of monitoring equipment malfunction, calibration, or repair. At 
a minimum, valid monitoring data shall be obtained for 75 percent of the 
operating hours per day and for 90 percent of the operating days per 
calendar quarter that the affected facility is combusting hospital waste 
and/or medical/infectious waste.



Sec. 60.58c  Reporting and recordkeeping requirements.

    (a) The owner or operator of an affected facility shall submit 
notifications, as provided by Sec. 60.7. In addition, the owner or 
operator shall submit the following information:
    (1) Prior to commencement of construction;
    (i) A statement of intent to construct;
    (ii) The anticipated date of commencement of construction; and
    (iii) All documentation produced as a result of the siting 
requirements of Sec. 60.54c.
    (2) Prior to initial startup;
    (i) The type(s) of waste to be combusted;
    (ii) The maximum design waste burning capacity;
    (iii) The anticipated maximum charge rate; and
    (iv) If applicable, the petition for site-specific operating 
parameters under Sec. 60.56c(i).
    (b) The owner or operator of an affected facility shall maintain the 
following information (as applicable) for a period of at least 5 years:
    (1) Calendar date of each record;
    (2) Records of the following data:
    (i) Concentrations of any pollutant listed in Sec. 60.52c or 
measurements of opacity as determined by the continuous emission 
monitoring system (if applicable);
    (ii) Results of fugitive emissions (by EPA Reference Method 22) 
tests, if applicable;
    (iii) HMIWI charge dates, times, and weights and hourly charge 
rates;
    (iv) Fabric filter inlet temperatures during each minute of 
operation, as applicable;
    (v) Amount and type of dioxin/furan sorbent used during each hour of 
operation, as applicable;
    (vi) Amount and type of Hg sorbent used during each hour of 
operation, as applicable;
    (vii) Amount and type of HCl sorbent used during each hour of 
operation, as applicable;
    (viii) Secondary chamber temperatures recorded during each minute of 
operation;

[[Page 189]]

    (ix) Liquor flow rate to the wet scrubber inlet during each minute 
of operation, as applicable;
    (x) Horsepower or amperage to the wet scrubber during each minute of 
operation, as applicable;
    (xi) Pressure drop across the wet scrubber system during each minute 
of operation, as applicable,
    (xii) Temperature at the outlet from the wet scrubber during each 
minute of operation, as applicable;
    (xiii) pH at the inlet to the wet scrubber during each minute of 
operation, as applicable,
    (xiv) Records indicating use of the bypass stack, including dates, 
times, and durations, and
    (xv) For affected facilities complying with Secs. 60.56c(i) and 
60.57c(c), the owner or operator shall maintain all operating parameter 
data collected.
    (3) Identification of calendar days for which data on emission rates 
or operating parameters specified under paragraph (b)(2) of this section 
have not been obtained, with an identification of the emission rates or 
operating parameters not measured, reasons for not obtaining the data, 
and a description of corrective actions taken.
    (4) Identification of calendar days, times and durations of 
malfunctions, a description of the malfunction and the corrective action 
taken.
    (5) Identification of calendar days for which data on emission rates 
or operating parameters specified under paragraph (b)(2) of this section 
exceeded the applicable limits, with a description of the exceedances, 
reasons for such exceedances, and a description of corrective actions 
taken.
    (6) The results of the initial, annual, and any subsequent 
performance tests conducted to determine compliance with the emission 
limits and/or to establish operating parameters, as applicable.
    (7) All documentation produced as a result of the siting 
requirements of Sec. 60.54c;
    (8) Records showing the names of HMIWI operators who have completed 
review of the information in Sec. 60.53c(h) as required by 
Sec. 60.53c(i), including the date of the initial review and all 
subsequent annual reviews;
    (9) Records showing the names of the HMIWI operators who have 
completed the operator training requirements, including documentation of 
training and the dates of the training;
    (10) Records showing the names of the HMIWI operators who have met 
the criteria for qualification under Sec. 60.53c and the dates of their 
qualification; and
    (11) Records of calibration of any monitoring devices as required 
under Sec. 60.57c (a), (b), and (c).
    (c) The owner or operator of an affected facility shall submit the 
information specified in paragraphs (c)(1) through (c)(3) of this 
section no later than 60 days following the initial performance test. 
All reports shall be signed by the facilities manager.
    (1) The initial performance test data as recorded under Sec. 60.56c 
(b)(1) through (b)(12), as applicable.
    (2) The values for the site-specific operating parameters 
established pursuant to Sec. 60.56c (d) or (i), as applicable.
    (3) The waste management plan as specified in Sec. 60.55c.
    (d) An annual report shall be submitted 1 year following the 
submission of the information in paragraph (c) of this section and 
subsequent reports shall be submitted no more than 12 months following 
the previous report (once the unit is subject to permitting requirements 
under Title V of the Clean Air Act, the owner or operator of an affected 
facility must submit these reports semiannually). The annual report 
shall include the information specified in paragraphs (d)(1) through 
(d)(8) of this section. All reports shall be signed by the facilities 
manager.
    (1) The values for the site-specific operating parameters 
established pursuant to Sec. 60.56c (d) or (i), as applicable.
    (2) The highest maximum operating parameter and the lowest minimum 
operating parameter, as applicable, for each operating parameter 
recorded for the calendar year being reported, pursuant to 
Sec. 60.56c(d) or (i), as applicable.
    (3) The highest maximum operating parameter and the lowest minimum 
operating parameter, as applicable for each operating parameter recorded

[[Page 190]]

pursuant to Sec. 60.56c (d) or (i) for the calendar year preceding the 
year being reported, in order to provide the Administrator with a 
summary of the performance of the affected facility over a 2-year 
period.
    (4) Any information recorded under paragraphs (b)(3) through (b)(5) 
of this section for the calendar year being reported.
    (5) Any information recorded under paragraphs (b)(3) through (b)(5) 
of this section for the calendar year preceding the year being reported, 
in order to provide the Administrator with a summary of the performance 
of the affected facility over a 2-year period.
    (6) If a performance test was conducted during the reporting period, 
the results of that test.
    (7) If no exceedances or malfunctions were reported under paragraphs 
(b)(3) through (b)(5) of this section for the calendar year being 
reported, a statement that no exceedances occurred during the reporting 
period.
    (8) Any use of the bypass stack, the duration, reason for 
malfunction, and corrective action taken.
    (e) The owner or operator of an affected facility shall submit 
semiannual reports containing any information recorded under paragraphs 
(b)(3) through (b)(5) of this section no later than 60 days following 
the reporting period. The first semiannual reporting period ends 6 
months following the submission of information in paragraph (c) of this 
section. Subsequent reports shall be submitted no later than 6 calendar 
months following the previous report. All reports shall be signed by the 
facilities manager.
    (f) All records specified under paragraph (b) of this section shall 
be maintained onsite in either paper copy or computer-readable format, 
unless an alternative format is approved by the Administrator.

                    Table 1 to Subpart Ec--Emission Limits for Small, Medium, and Large HMIWI
----------------------------------------------------------------------------------------------------------------
                                                                             Emission limits
                                                        --------------------------------------------------------
           Pollutant                Units (7 percent                            HMIWI size
                                   oxygen, dry basis)   --------------------------------------------------------
                                                               Small              Medium             Large
----------------------------------------------------------------------------------------------------------------
Particulate matter.............  Milligrams per dry      69 (0.03)........  34 (0.015).......  34 (0.015).
                                  standard cubic meter
                                  (grains per dry
                                  standard cubic foot).
Carbon monoxide................  Parts per million by    40...............  40...............  40.
                                  volume.
Dioxins/furans.................  Nanograms per dry       125 (55) or 2.3    25 (11) or 0.6     25 (11) or 0.6
                                  standard cubic meter    (1.0).             (0.26).            (0.26).
                                  total dioxins/furans
                                  (grains per billion
                                  dry standard cubic
                                  feet) or nanograms
                                  per dry standard
                                  cubic meter total
                                  dioxins/furans TEQ
                                  (grains per billion
                                  dry standard cubic
                                  feet).
Hydrogen chloride..............  Parts per million or    15 or 99%........  15 or 99%........  15 or 99%.
                                  percent reduction.
Sulfur dioxide.................  Parts per million by    55...............  55...............  55.
                                  volume.
Nitrogen oxides................  Parts per million by    250..............  250..............  250.
                                  volume.
Lead...........................  Milligrams per dry      1.2 (0.52) or 70%  0.07 (0.03) or     0.07 (0.03) or
                                  standard cubic meter                       98%.               98%.
                                  (grains per thousand
                                  dry standard cubic
                                  feet) or percent
                                  reduction.
Cadmium........................  Milligrams per dry      0.16 (0.07) or     0.04 (0.02) or     0.04 (0.02) or
                                  standard cubic meter    65%.               90%.               90%.
                                  (grains per thousand
                                  dry standard cubic
                                  feet) or percent
                                  reduction.
Mercury........................  Milligrams per dry      0.55 (0.24) or     0.55 (0.24) or     0.55 (0.24) or
                                  standard cubic meter    85%.               85%.               85%.
                                  (grains per thousand
                                  dry standard cubic
                                  feet) or percent
                                  reduction.
----------------------------------------------------------------------------------------------------------------


            Table 2 To Supbart Ec--Toxic Equivalency Factors
------------------------------------------------------------------------
                                                                Toxic
                   Dioxin/furan congener                     equivalency
                                                               factor
------------------------------------------------------------------------
2,3,7,8-tetrachlorinated dibenzo-p-dioxin.................         1
1,2,3,7,8-pentachlorinated dibenzo-p-dioxin...............         0.5
1,2,3,4,7,8-hexachlorinated dibenzo-p-dioxin..............         0.1
1,2,3,7,8,9-hexachlorinated dibenzo-p-dioxin..............         0.1
1,2,3,6,7,8-hexachlorinated dibenzo-p-dioxin..............         0.1
1,2,3,4,6,7,8-heptachlorinated dibenzo-p-dioxin...........         0.01
octachlorinated dibenzo-p-dioxin..........................         0.001
2,3,7,8-tetrachlorinated dibenzofuran.....................         0.1
2,3,4,7,8-pentachlorinated dibenzofuran...................         0.5

[[Page 191]]

 
1,2,3,7,8-pentachlorinated dibenzofuran...................         0.05
1,2,3,4,7,8-hexachlorinated dibenzofuran..................         0.1
1,2,3,6,7,8-hexachlorinated dibenzofuran..................         0.1
1,2,3,7,8,9-hexachlorinated dibenzofuran..................         0.1
2,3,4,6,7,8-hexachlorinated dibenzofuran..................         0.1
1,2,3,4,6,7,8-heptachlorinated dibenzofuran...............         0.01
1,2,3,4,7,8,9-heptachlorinated dibenzofuran...............         0.01
Octachlorinated dibenzofuran..............................         0.001
------------------------------------------------------------------------


                      Table 3 to Subpart Ec--Operating Parameters to be Monitored and Minimum Measurement and Recording Frequencies
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                    Minimum frequency                                        Control system
                                          --------------------------------------------------------------------------------------------------------------
                                                                                                                                            Dry scrubber
   Operating parameters to be monitored                                                                         Dry scrubber                 followed by
                                                    Data measurement                   Data recording            followed by  Wet scrubber     fabric
                                                                                                                   fabric                    filter and
                                                                                                                   filter                   wet scrubber
--------------------------------------------------------------------------------------------------------------------------------------------------------
Maximum operating parameters:
    Maximum charge rate..................  Continuous.......................  1 x hour........................                    
    Maximum fabric filter inlet            Continuous.......................  1 x minute......................         ............      
     temperature.
    Maximum flue gas temperature.........  Continuous.......................  1 x minute......................             
Minimum operating parameters:
    Minimum secondary chamber temperature  Continuous.......................  1 x minute......................                    
    Minimum dioxin/furan sorbent flow      Hourly...........................  1 x hour........................         ............      
     rate.
    Minimum HCI sorbent flow rate........  Hourly...........................  1 x hour........................         ............      
    Minimum mercury (Hg) sorbent flow      Hourly...........................  1 x hour........................         ............      
     rate.
    Minimum pressure drop across the wet   Continuous.......................  1 x minute......................  ............             
     scrubber or minimum horsepower or
     amperage to wet scrubber.
    Minimum scrubber liquor flow rate....  Continuous.......................  1 x minute......................  ............             
    Minimum scrubber liquor pH...........  Continuous.......................  1 x minute......................  ............             
--------------------------------------------------------------------------------------------------------------------------------------------------------



     Subpart F--Standards of Performance for Portland Cement Plants



Sec. 60.60  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in portland cement plants: Kiln, clinker cooler, raw 
mill system, finish mill system, raw mill dryer, raw material storage, 
clinker storage, finished product storage, conveyor transfer points, 
bagging and bulk loading and unloading systems.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after August 17, 1971, is subject to the 
requirements of this subpart.

[42 FR 37936, July 25, 1977]



Sec. 60.61  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Portland cement plant means any facility manufacturing portland 
cement by either the wet or dry process.
    (b) Bypass means any system that prevents all or a portion of the 
kiln or clinker cooler exhaust gases from entering the main control 
device and

[[Page 192]]

ducts the gases through a separate control device. This does not include 
emergency systems designed to duct exhaust gases directly to the 
atmosphere in the event of a malfunction of any control device 
controlling kiln or clinker cooler emissions.
    (c) Bypass stack means the stack that vents exhaust gases to the 
atmosphere from the bypass control device.
    (d) Monovent means an exhaust configuration of a building or 
emission control device (e.g., positive-pressure fabric filter) that 
extends the length of the structure and has a width very small in 
relation to its length (i.e., length to width ratio is typically greater 
than 5:1). The exhaust may be an open vent with or without a roof, 
louvered vents, or a combination of such features.

[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 20793, June 13, 1974; 
53 FR 50363, Dec. 14, 1988]



Sec. 60.62  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any kiln any gases which:
    (1) Contain particulate matter in excess of 0.15 kg per metric ton 
of feed (dry basis) to the kiln (0.30 lb per ton).
    (2) Exhibit greater than 20 percent opacity.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any clinker cooler any gases which:
    (1) Contain particulate matter in excess of 0.050 kg per metric ton 
of feed (dry basis) to the kiln (0.10 lb per ton).
    (2) Exhibit 10 percent opacity, or greater.
    (c) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility other than the kiln and clinker 
cooler any gases which exhibit 10 percent opacity, or greater.

[39 FR 20793, June 14, 1974, as amended at 39 FR 39874, Nov. 12, 1974; 
40 FR 46258, Oct. 6, 1975]



Sec. 60.63  Monitoring of operations.

    (a) The owner or operator of any portland cement plant subject to 
the provisions of this part shall record the daily production rates and 
kiln feed rates.
    (b) Except as provided in paragraph (c) of this section, each owner 
or operator of a kiln or clinker cooler that is subject to the 
provisions of this subpart shall install, calibrate, maintain, and 
operate in accordance with Sec. 60.13 a continuous opacity monitoring 
system to measure the opacity of emissions discharged into the 
atmosphere from any kiln or clinker cooler. Except as provided in 
paragraph (c) of this section, a continuous opacity monitoring system 
shall be installed on each stack of any multiple stack device 
controlling emissions from any kiln or clinker cooler. If there is a 
separate bypass installed, each owner or operator of a kiln or clinker 
cooler shall also install, calibrate, maintain, and operate a continuous 
opacity monitoring system on each bypass stack in addition to the main 
control device stack. Each owner or operator of an affected kiln or 
clinker cooler for which the performance test required under Sec. 60.8 
has been completed on or prior to December 14, 1988, shall install the 
continuous opacity monitoring system within 180 days after December 14, 
1988.
    (c) Each owner or operator of a kiln or clinker cooler subject to 
the provisions of this subpart using a positive-pressure fabric filter 
with multiple stacks, or a negative-pressure fabric filter with multiple 
stacks, or an electrostatic precipitator with multiple stacks may, in 
lieu of installing the continuous opacity monitoring system required by 
Sec. 60.63(b), monitor visible emissions at least once per day by using 
a certified visible emissions observer. If the control device exhausts 
gases through a monovent, visible emission observations in lieu of a 
continuous opacity monitoring system are required. These observations 
shall be taken in accordance with EPA Method

[[Page 193]]

9. Visible emissions shall be observed during conditions representative 
of normal operation. Observations shall be recorded for at least three 
6-minute periods each day. In the event that visible emissions are 
observed for a number of emission sites from the control device with 
multiple stacks, Method 9 observations shall be recorded for the 
emission site with the highest opacity. All records of visible emissions 
shall be maintained for a period of 2 years.
    (d) For the purpose of reports under Sec. 60.65, periods of excess 
emissions that shall be reported are defined as all 6-minute periods 
during which the average opacity exceeds that allowed by 
Sec. 60.62(a)(2) or Sec. 60.62(b)(2).
    (e) The provisions of paragraphs (a), (b), and (c) of this section 
apply to kilns and clinker coolers for which construction, modification, 
or reconstruction commenced after August 17, 1971.

[36 FR 24877, Dec. 23, 1971, as amended at 53 FR 50363, Dec. 14, 1988]



Sec. 60.64  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standard in Sec. 60.62 as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:

    E=(cs Qsd)/(P K)

where:
E=emission rate of particulate matter, kg/metric ton (lb/ton) of kiln 
          feed.
cs=concentration of particulate matter, g/dscm (g/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
P=total kiln feed (dry basis) rate, metric ton/hr (ton/hr).
K=conversion factor, 1000 g/kg (453.6 g/lb).

    (2) Method 5 shall be used to determine the particulate matter 
concentration (cs) and the volumetric flow rate 
(Qsd) of the effluent gas.

The sampling time and sample volume for each run shall be at least 60 
minutes and 0.85 dscm (30.0 dscf) for the kiln and at least 60 minutes 
and 1.15 dscm (40.6 dscf) for the clinker cooler.
    (3) Suitable methods shall be used to determine the kiln feed rate 
(P), except fuels, for each run. Material balance over the production 
system shall be used to confirm the feed rate.
    (4) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6666, Feb. 14, 1989]



Sec. 60.65  Recordkeeping and reporting requirements.

    (a) Each owner or operator required to install a continuous opacity 
monitoring system under Sec. 60.63(b) shall submit reports of excess 
emissions as defined in Sec. 60.63(d). The content of these reports must 
comply with the requirements in Sec. 60.7(c). Notwithstanding the 
provisions of Sec. 60.7(c), such reports shall be submitted 
semiannually.
    (b) Each owner or operator monitoring visible emissions under 
Sec. 60.63(c) shall submit semiannual reports of observed excess 
emissions as defined in Sec. 60.63(d).
    (c) Each owner or operator of facilities subject to the provisions 
of Sec. 60.63(c) shall submit semiannual reports of the malfunction 
information required to be recorded by Sec. 60.7(b). These reports shall 
include the frequency, duration, and cause of any incident resulting in 
deenergization of any device controlling kiln emissions or in the 
venting of emissions directly to the atmosphere.
    (d) The requirements of this section remain in force until and 
unless the Agency, in delegating enforcement authority to a State under 
section 111(c) of the Clean Air Act, 42 U.S.C. 7411, approves reporting 
requirements or an alternative means of compliance surveillance adopted 
by such States. In that event, affected sources within the State will be 
relieved of the obligation to comply with this section, provided that 
they comply with the requirements established by the State.

[53 FR 50364, Dec. 14, 1988]



Sec. 60.66  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State

[[Page 194]]

under section 111(c) of the Act, the authorities contained in paragraph 
(b) of this section shall be retained by the Administrator and not 
transferred to a State.
    (b) Authorities which will not be delegated to States: No 
restrictions.

[53 FR 50364, Dec. 14, 1988]



       Subpart G--Standards of Performance for Nitric Acid Plants



Sec. 60.70  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to each nitric 
acid production unit, which is the affected facility.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after August 17, 1971, is subject to the 
requirements of this subpart.

[42 FR 37936, July 25, 1977]



Sec. 60.71  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Nitric acid production unit means any facility producing weak 
nitric acid by either the pressure or atmospheric pressure process.
    (b) Weak nitric acid means acid which is 30 to 70 percent in 
strength.



Sec. 60.72  Standard for nitrogen oxides.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which:
    (1) Contain nitrogen oxides, expressed as NO2, in excess 
of 1.5 kg per metric ton of acid produced (3.0 lb per ton), the 
production being expressed as 100 percent nitric acid.
    (2) Exhibit 10 percent opacity, or greater.

[39 FR 20794, June 14, 1974, as amended at 40 FR 46258, Oct. 6, 1975]



Sec. 60.73  Emission monitoring.

    (a) The source owner or operator shall install, calibrate, maintain, 
and operate a continuous monitoring system for measuring nitrogen oxides 
(NOx). The pollutant gas mixtures under Performance 
Specification 2 and for calibration checks under Sec. 60.13(d) of this 
part shall be nitrogen dioxide (NO2). The span value shall be 
500 ppm of NO2. Method 7 shall be used for the performance 
evaluations under Sec. 60.13(c). Acceptable alternative methods to 
Method 7 are given in Sec. 60.74(c).
    (b) The owner or operator shall establish a conversion factor for 
the purpose of converting monitoring data into units of the applicable 
standard (kg/metric ton, lb/ton). The conversion factor shall be 
established by measuring emissions with the continuous monitoring system 
concurrent with measuring emissions with the applicable reference method 
tests. Using only that portion of the continuous monitoring emission 
data that represents emission measurements concurrent with the reference 
method test periods, the conversion factor shall be determined by 
dividing the reference method test data averages by the monitoring data 
averages to obtain a ratio expressed in units of the applicable standard 
to units of the monitoring data, i.e., kg/metric ton per ppm (lb/ton per 
ppm). The conversion factor shall be reestablished during any 
performance test under Sec. 60.8 or any continuous monitoring system 
performance evaluation under Sec. 60.13(c).
    (c) The owner or operator shall record the daily production rate and 
hours of operation.
    (d) [Reserved]
    (e) For the purpose of reports required under Sec. 60.7(c), periods 
of excess emissions that shall be reported are defined as any 3-hour 
period during which the average nitrogen oxides emissions (arithmetic 
average of three contiguous 1-hour periods) as measured by a continuous 
monitoring system exceed the standard under Sec. 60.72(a).

[39 FR 20794, June 14, 1974, as amended at 40 FR 46258, Oct. 6, 1975; 50 
FR 15894, Apr. 22, 1985; 54 FR 6666, Feb. 14, 1989]



Sec. 60.74  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods

[[Page 195]]

and procedures the test methods in appendix A of this part or other 
methods and procedures as specified in this section, except as provided 
in Sec. 60.8(b). Acceptable alternative methods and procedures are given 
in paragraph (c) of this section.
    (b) The owner or operator shall determine compliance with the 
NOx standard in Sec. 60.72 as follows:
    (1) The emission rate (E) of NOx shall be computed for 
each run using the following equation:

E=(Cs Qsd)/(P K)

where:
E=emission rate of NOx as NO2, kg/metric ton (lb/
          ton) of 100 percent nitric acid.
Cs=concentration of NOx as NO2, g/dscm 
          (lb/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
P=acid production rate, metric ton/hr (ton/hr) or 100 percent nitric 
          acid.
K=conversion factor, 1000 g/kg (1.0 lb/lb).

    (2) Method 7 shall be used to determine the NOx 
concentration of each grab sample. Method 1 shall be used to select the 
sampling site, and the sampling point shall be the centroid of the stack 
or duct or at a point no closer to the walls than 1 m (3.28 ft). Four 
grab samples shall be taken at approximately 15-minute intervals. The 
arithmetic mean of the four sample concentrations shall constitute the 
run value (Cs).
    (3) Method 2 shall be used to determine the volumetric flow rate 
(Qsd) of the effluent gas. The measurement site shall be the 
same as for the NOx sample. A velocity traverse shall be made 
once per run within the hour that the NOx samples are taken.
    (4) The methods of Sec. 60.73(c) shall be used to determine the 
production rate (P) of 100 percent nitric acid for each run. Material 
balance over the production system shall be used to confirm the 
production rate.
    (c) The owner or operator may use the following as alternatives to 
the reference methods and procedures specified in this section:
    (1) For Method 7, Method 7A, 7B, 7C, or 7D may be used. If Method 7C 
or 7D is used, the sampling time shall be at least 1 hour.
    (d) The owner or operator shall use the procedure in Sec. 60.73(b) 
to determine the conversion factor for converting the monitoring data to 
the units of the standard.

[54 FR 6666, Feb. 14, 1989]



      Subpart H--Standards of Performance for Sulfuric Acid Plants



Sec. 60.80  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to each sulfuric 
acid production unit, which is the affected facility.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after August 17, 1971, is subject to the 
requirements of this subpart.

[42 FR 37936, July 25, 1977]



Sec. 60.81  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Sulfuric acid production unit means any facility producing 
sulfuric acid by the contact process by burning elemental sulfur, 
alkylation acid, hydrogen sulfide, organic sulfides and mercaptans, or 
acid sludge, but does not include facilities where conversion to 
sulfuric acid is utilized primarily as a means of preventing emissions 
to the atmosphere of sulfur dioxide or other sulfur compounds.
    (b) Acid mist means sulfuric acid mist, as measured by Method 8 of 
appendix A to this part or an equivalent or alternative method.

[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 20794, June 14, 1974]



Sec. 60.82  Standard for sulfur dioxide.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain sulfur 
dioxide in excess of 2 kg per metric ton of acid produced (4 lb per 
ton), the production being expressed as 100 percent 
H2SO4.

[39 FR 20794, June 14, 1974]

[[Page 196]]



Sec. 60.83  Standard for acid mist.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which:
    (1) Contain acid mist, expressed as H2SO4, in 
excess of 0.075 kg per metric ton of acid produced (0.15 lb per ton), 
the production being expressed as 100 percent 
H2SO4.
    (2) Exhibit 10 percent opacity, or greater.

[39 FR 20794, June 14, 1974, as amended at 40 FR 46258, Oct. 6, 1975]



Sec. 60.84  Emission monitoring.

    (a) A continuous monitoring system for the measurement of sulfur 
dioxide shall be installed, calibrated, maintained, and operated by the 
owner or operator. The pollutant gas used to prepare calibration gas 
mixtures under Performance Specification 2 and for calibration checks 
under Sec. 60.13(d), shall be sulfur dioxide (SO2). Method 8 
shall be used for conducting monitoring system performance evaluations 
under Sec. 60.13(c) except that only the sulfur dioxide portion of the 
Method 8 results shall be used. The span value shall be set at 1000 ppm 
of sulfur dioxide.
    (b) The owner or operator shall establish a conversion factor for 
the purpose of converting monitoring data into units of the applicable 
standard (kg/metric ton, lb/ton). The conversion factor shall be 
determined, as a minimum, three times daily by measuring the 
concentration of sulfur dioxide entering the converter using suitable 
methods (e.g., the Reich test, National Air Pollution Control 
Administration Publication No. 999-AP-13) and calculating the 
appropriate conversion factor for each eight-hour period as follows:
CF=k[(1.000-0.015r)/(r-s)]
where:
CF=conversion factor (kg/metric ton per ppm, lb/ton per ppm).
k=constant derived from material balance. For determining CF in metric 
          units, k=0.0653. For determining CF in English units, 
          k=0.1306.
r=percentage of sulfur dioxide by volume entering the gas converter. 
          Appropriate corrections must be made for air injection plants 
          subject to the Administrator's approval.
s=percentage of sulfur dioxide by volume in the emissions to the 
          atmosphere determined by the continuous monitoring system 
          required under paragraph (a) of this section.

    (c) The owner or operator shall record all conversion factors and 
values under paragraph (b) of this section from which they were computed 
(i.e., CF, r, and s).
    (d) Alternatively, a source that processes elemental sulfur or an 
ore that contains elemental sulfur and uses air to supply oxygen may use 
the following continuous emission monitoring approach and calculation 
procedures in determining SO2 emission rates in terms of the 
standard. This procedure is not required, but is an alternative that 
would alleviate problems encountered in the measurement of gas 
velocities or production rate. Continuous emission monitoring of 
SO2, O2, and CO2 (if required) shall be 
installed, calibrated, maintained, and operated by the owner or operator 
and subjected to the certification procedures in Performance 
Specifications 2 and 3. The calibration procedure and span value for 
this SO2 monitor shall be as specified in paragraph (b) of 
this section. The span value for CO2 (if required) shall be 
10 percent and for O2 shall be 20.9 percent (air). A 
conversion factor based on process rate data is not necessary. Calculate 
the SO2 emission rate as follows:
Es=(Cs S)/[0.265-(0.126 %O2)-(A 
          %CO2)]

where:
Es=emission rate of SO2, kg/metric ton (lb/ton) of 
          100 percent of H2SO4 produced.
Cs=concentration of SO2, kg/dscm (lb/dscf).
S=acid production rate factor, 368 dscm/metric ton (11,800 dscf/ton) of 
          100 percent H2SO4 produced.
%O2=oxygen concentration, percent dry basis.
A=auxiliary fuel factor,
=0.00 for no fuel.
=0.0226 for methane.
=0.0217 for natural gas.
=0.0196 for propane.
=0.0172 for No 2 oil.
=0.0161 for No 6 oil.
=0.0148 for coal.
=0.0126 for coke.
%CO2= carbon dioxide concentration, percent dry basis.

[[Page 197]]

    Note: It is necessary in some cases to convert measured 
concentration units to other units for these calculations:

Use the following table for such conversions:

------------------------------------------------------------------------
              From--                        To--           Multiply by--
------------------------------------------------------------------------
g/scm.............................  kg/scm..............            10-3
mg/scm............................  kg/scm..............            10-6
ppm (SO2).........................  kg/scm..............    2.660 x 10-6
ppm (SO2).........................  lb/scf..............    1.660 x 10-7
------------------------------------------------------------------------

    (e) For the purpose of reports under Sec. 60.7(c), periods of excess 
emissions shall be all three-hour periods (or the arithmetic average of 
three consecutive one-hour periods) during which the integrated average 
sulfur dioxide emissions exceed the applicable standards under 
Sec. 60.82.

[39 FR 20794, June 14, 1974, as amended at 40 FR 46258, Oct. 6, 1975; 48 
FR 23611, May 25, 1983; 48 FR 4700, Sept. 29, 1983; 48 FR 48669, Oct. 
20, 1983; 54 FR 6666, Feb. 14, 1989]



Sec. 60.85  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b). 
Acceptable alternative methods and procedures are given in paragraph (c) 
of this section.
    (b) The owner or operator shall determine compliance with the 
SO2 acid mist, and visible emission standards in Secs. 60.82 
and 60.83 as follows:
    (1) The emission rate (E) of acid mist or SO2 shall be 
computed for each run using the following equation:

E=(CQsd)/(PK)

where:
E=emission rate of acid mist or SO2 kg/metric ton (lb/ton) of 
          100 percent H2SO4 produced.
C=concentration of acid mist or SO2, g/dscm (lb/dscf).
Qsd=volumetric flow rate of the effluent gas, dscm/hr (dscf/
          hr).
P=production rate of 100 percent H2SO4, metric 
          ton/hr (ton/hr).
K=conversion factor, 1000 g/kg (1.0 lb/lb).

    (2) Method 8 shall be used to determine the acid mist and 
SO2 concentrations (C's) and the volumetric flow rate 
(Qsd) of the effluent gas. The moisture content may be 
considered to be zero. The sampling time and sample volume for each run 
shall be at least 60 minutes and 1.15 dscm (40.6 dscf).
    (3) Suitable methods shall be used to determine the production rate 
(P) of 100 percent H2SO4 for each run. Material 
balance over the production system shall be used to confirm the 
production rate.
    (4) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (c) The owner or operator may use the following as alternatives to 
the reference methods and procedures specified in this section:
    (1) If a source processes elemental sulfur or an ore that contains 
elemental sulfur and uses air to supply oxygen, the following procedure 
may be used instead of determining the volumetric flow rate and 
production rate:
    (i) The integrated technique of Method 3 is used to determine the 
O2 concentration and, if required, CO2 
concentration.
    (ii) The SO2 or acid mist emission rate is calculated as 
described in Sec. 60.84(d), substituting the acid mist concentration for 
Cs as appropriate.

[54 FR 6666, Feb. 14, 1989]



   Subpart I--Standards of Performance for Hot Mix Asphalt Facilities



Sec. 60.90  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each hot mix asphalt facility. For the purpose of this subpart, 
a hot mix asphalt facility is comprised only of any combination of the 
following: dryers; systems for screening, handling, storing, and 
weighing hot aggregate; systems for loading, transferring, and storing 
mineral filler, systems for mixing hot mix asphalt; and the loading, 
transfer, and storage systems associated with emission control systems.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after June 11, 1973, is subject to the 
requirements of this subpart.

[42 FR 37936, July 25, 1977, as amended at 51 FR 12325, Apr. 10, 1986]

[[Page 198]]



Sec. 60.91  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Hot mix asphalt facility means any facility, as described in 
Sec. 60.90, used to manufacture hot mix asphalt by heating and drying 
aggregate and mixing with asphalt cements.

[51 FR 12325, Apr. 10, 1986]



Sec. 60.92  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall discharge or cause the discharge 
into the atmosphere from any affected facility any gases which:
    (1) Contain particulate matter in excess of 90 mg/dscm (0.04 gr/
dscf).
    (2) Exhibit 20 percent opacity, or greater.

[39 FR 9314, Mar. 8, 1974, as amended at 40 FR 46259, Oct. 6, 1975]



Sec. 60.93  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.92 as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration. The sampling time and sample volume for each run shall be 
at least 60 minutes and 0.90 dscm (31.8 dscf).
    (2) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6667, Feb. 14, 1989]



      Subpart J--Standards of Performance for Petroleum Refineries



Sec. 60.100  Applicability, designation of affected facility, and reconstruction.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in petroleum refineries: fluid catalytic cracking 
unit catalyst regenerators, fuel gas combustion devices, and all Claus 
sulfur recovery plants except Claus plants of 20 long tons per day (LTD) 
or less. The Claus sulfur recovery plant need not be physically located 
within the boundaries of a petroleum refinery to be an affected 
facility, provided it processes gases produced within a petroleum 
refinery.
    (b) Any fluid catalytic cracking unit catalyst regenerator or fuel 
gas combustion device under paragraph (a) of this section which 
commences construction or modification after June 11, 1973, or any Claus 
sulfur recovery plant under paragraph (a) of this section which 
commences construction or modification after October 4, 1976, is subject 
to the requirements of this subpart except as provided under paragraphs 
(c) and (d) of this section.
    (c) Any fluid catalytic cracking unit catalyst regenerator under 
paragraph (b) of this section which commences construction or 
modification on or before January 17, 1984, is exempted from 
Sec. 60.104(b).
    (d) Any fluid catalytic cracking unit in which a contact material 
reacts with petroleum derivatives to improve feedstock quality and in 
which the contact material is regenerated by burning off coke and/or 
other deposits and that commences construction or modification on or 
before January 17, 1984, is exempt from this subpart.
    (e) For purposes of this subpart, under Sec. 60.15, the ``fixed 
capital cost of the new components'' includes the fixed capital cost of 
all depreciable components which are or will be replaced pursuant to all 
continuous programs of component replacement which are commenced within 
any 2-year period following January 17, 1984. For purposes of this 
paragraph, ``commenced'' means that an owner or operator has undertaken 
a continuous program of component replacement or

[[Page 199]]

that an owner or operator has entered into a contractual obligation to 
undertake and complete, within a reasonable time, a continuous program 
of component replacement.

[43 FR 10868, Mar. 15, 1978, as amended at 44 FR 61543, Oct. 25, 1979; 
54 FR 34026, Aug. 17, 1989]



Sec. 60.101  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A.
    (a) Petroleum refinery means any facility engaged in producing 
gasoline, kerosene, distillate fuel oils, residual fuel oils, 
lubricants, or other products through distillation of petroleum or 
through redistillation, cracking or reforming of unfinished petroleum 
derivatives.
    (b) Petroleum means the crude oil removed from the earth and the 
oils derived from tar sands, shale, and coal.
    (c) Process gas means any gas generated by a petroleum refinery 
process unit, except fuel gas and process upset gas as defined in this 
section.
    (d) Fuel gas means any gas which is generated at a petroleum 
refinery and which is combusted. Fuel gas also includes natural gas when 
the natural gas is combined and combusted in any proportion with a gas 
generated at a refinery. Fuel gas does not include gases generated by 
catalytic cracking unit catalyst regenerators and fluid coking burners.
    (e) Process upset gas means any gas generated by a petroleum 
refinery process unit as a result of start-up, shut-down, upset or 
malfunction.
    (f) Refinery process unit means any segment of the petroleum 
refinery in which a specific processing operation is conducted.
    (g) Fuel gas combustion device means any equipment, such as process 
heaters, boilers and flares used to combust fuel gas, except facilities 
in which gases are combusted to produce sulfur or sulfuric acid.
    (h) Coke burn-off means the coke removed from the surface of the 
fluid catalytic cracking unit catalyst by combustion in the catalyst 
regenerator. The rate of coke burn-off is calculated by the formula 
specified in Sec. 60.106.
    (i) Claus sulfur recovery plant means a process unit which recovers 
sulfur from hydrogen sulfide by a vapor-phase catalytic reaction of 
sulfur dioxide and hydrogen sulfide.
    (j) Oxidation control system means an emission control system which 
reduces emissions from sulfur recovery plants by converting these 
emissions to sulfur dioxide.
    (k) Reduction control system means an emission control system which 
reduces emissions from sulfur recovery plants by converting these 
emissions to hydrogen sulfide.
    (l) Reduced sulfur compounds means hydrogen sulfide 
(H2S), carbonyl sulfide (COS) and carbon disulfide 
(CS2).
    (m) Fluid catalytic cracking unit means a refinery process unit in 
which petroleum derivatives are continuously charged; hydrocarbon 
molecules in the presence of a catalyst suspended in a fluidized bed are 
fractured into smaller molecules, or react with a contact material 
suspended in a fluidized bed to improve feedstock quality for additional 
processing; and the catalyst or contact material is continuously 
regenerated by burning off coke and other deposits. The unit includes 
the riser, reactor, regenerator, air blowers, spent catalyst or contact 
material stripper, catalyst or contact material recovery equipment, and 
regenerator equipment for controlling air pollutant emissions and for 
heat recovery.
    (n) Fluid catalytic cracking unit catalyst regenerator means one or 
more regenerators (multiple regenerators) which comprise that portion of 
the fluid catalytic cracking unit in which coke burn-off and catalyst or 
contact material regeneration occurs, and includes the regenerator 
combustion air blower(s).
    (o) Fresh feed means any petroleum derivative feedstock stream 
charged directly into the riser or reactor of a fluid catalytic cracking 
unit except for petroleum derivatives recycled within the fluid 
catalytic cracking unit, fractionator, or gas recovery unit.
    (p) Contact material means any substance formulated to remove 
metals, sulfur, nitrogen, or any other contaminant from petroleum 
derivatives.

[[Page 200]]

    (q) Valid day means a 24-hour period in which at least 18 valid 
hours of data are obtained. A ``valid hour'' is one in which at least 2 
valid data points are obtained.

[39 FR 9315, Mar. 8, 1974, as amended at 43 FR 10868, Mar. 15, 1978; 44 
FR 13481, Mar. 12, 1979; 45 FR 79453, Dec. 1, 1980; 54 FR 34027, Aug. 
17, 1989]



Sec. 60.102  Standard for particulate matter.

    Each owner or operator of any fluid catalytic cracking unit catalyst 
regenerator that is subject to the requirements of this subpart shall 
comply with the emission limitations set forth in this section on and 
after the date on which the initial performance test, required by 
Sec. 60.8, is completed, but not later than 60 days after achieving the 
maximum production rate at which the fluid catalytic cracking unit 
catalyst regenerator will be operated, or 180 days after initial 
startup, whichever comes first.
    (a) No owner or operator subject to the provisions of this subpart 
shall discharge or cause the discharge into the atmosphere from any 
fluid catalytic cracking unit catalyst regenerator:
    (1) Particulate matter in excess of 1.0 kg/1000 kg (1.0 lb/1000 lb) 
of coke burn-off in the catalyst regenerator.
    (2) Gases exhibiting greater than 30 percent opacity, except for one 
six-minute average opacity reading in any one hour period.
    (b) Where the gases discharged by the fluid catalytic cracking unit 
catalyst regenerator pass through an incinerator or waste heat boiler in 
which auxiliary or supplemental liquid or solid fossil fuel is burned, 
particulate matter in excess of that permitted by paragraph (a)(1) of 
this section may be emitted to the atmosphere, except that the 
incremental rate of particulate matter emissions shall not exceed 43.0 
g/MJ (0.10 lb/million Btu) of heat input attributable to such liquid or 
solid fossil fuel.

[39 FR 9315, Mar. 8, 1974, as amended at 42 FR 32427, June 24, 1977; 42 
FR 39389, Aug. 4, 1977; 43 FR 10868, Feb. 15, 1978; 54 FR 34027, Aug. 
17, 1989]



Sec. 60.103  Standard for carbon monoxide.

    Each owner or operator of any fluid catalytic cracking unit catalyst 
regenerator that is subject to the requirements of this subpart shall 
comply with the emission limitations set forth in this section on and 
after the date on which the initial performance test, required by 
Sec. 60.8, is completed, but not later than 60 days after achieving the 
maximum production rate at which the fluid catalytic cracking unit 
catalyst regenerator will be operated, or 180 days after initial 
startup, whichever comes first.
    (a) No owner or operator subject to the provisions of this subpart 
shall discharge or cause the discharge into the atmosphere from any 
fluid catalytic cracking unit catalyst regenerator any gases that 
contain carbon monoxide (CO) in excess of 500 ppm by volume (dry basis).

[54 FR 34027, Aug. 17, 1989, as amended at 55 FR 40175, Oct. 2, 1990]



Sec. 60.104  Standards for sulfur oxides.

    Each owner or operator that is subject to the requirements of this 
subpart shall comply with the emission limitations set forth in this 
section on and after the date on which the initial performance test, 
required by Sec. 60.8, is completed, but not later than 60 days after 
achieving the maximum production rate at which the affected facility 
will be operated, or 180 days after initial startup, whichever comes 
first.
    (a) No owner or operator subject to the provisions of this subpart 
shall:
    (1) Burn in any fuel gas combustion device any fuel gas that 
contains hydrogen sulfide (H2S) in excess of 230 mg/dscm 
(0.10 gr/dscf). The combustion in a flare of process upset gases or fuel 
gas that is released to the flare as a result of relief valve leakage or 
other emergency malfunctions is exempt from this paragraph.
    (2) Discharge or cause the discharge of any gases into the 
atmosphere from any Claus sulfur recovery plant containing in excess of:
    (i) For an oxidation control system or a reduction control system 
followed by incineration, 250 ppm by volume

[[Page 201]]

(dry basis) of sulfur dioxide (SO2) at zero percent excess 
air.
    (ii) For a reduction control system not followed by incineration, 
300 ppm by volume of reduced sulfur compounds and 10 ppm by volume of 
hydrogen sulfide (H2S), each calculated as ppm SO2 
by volume (dry basis) at zero percent excess air.
    (b) Each owner or operator that is subject to the provisions of this 
subpart shall comply with one of the following conditions for each 
affected fluid catalytic cracking unit catalyst regenerator:
    (1) With an add-on control device, reduce sulfur dioxide emissions 
to the atmosphere by 90 percent or maintain sulfur dioxide emissions to 
the atmosphere less than or equal to 50 ppm by volume (vppm), whichever 
is less stringent; or
    (2) Without the use of an add-on control device, maintain sulfur 
oxides emissions calculated as sulfur dioxide to the atmosphere less 
than or equal to 9.8 kg/1,000 kg coke burn-off; or
    (3) Process in the fluid catalytic cracking unit fresh feed that has 
a total sulfur content no greater than 0.30 percent by weight.
    (c) Compliance with paragraph (b)(1), (b)(2), or (b)(3) of this 
section is determined daily on a 7-day rolling average basis using the 
appropriate procedures outlined in Sec. 60.106.
    (d) A minimum of 22 valid days of data shall be obtained every 30 
rolling successive calendar days when complying with paragraph (b)(1) of 
this section.

[43 FR 10869, Mar. 15, 1978, as amended at 54 FR 34027, Aug. 17, 1989; 
55 FR 40175, Oct. 2, 1990]



Sec. 60.105  Monitoring of emissions and operations.

    (a) Continuous monitoring systems shall be installed, calibrated, 
maintained, and operated by the owner or operator subject to the 
provisions of this subpart as follows:
    (1) For fluid catalytic cracking unit catalyst regenerators subject 
to Sec. 60.102(a)(2), an instrument for continuously monitoring and 
recording the opacity of emissions into the atmosphere. The instrument 
shall be spanned at 60, 70, or 80 percent opacity.
    (2) For fluid catalytic cracking unit catalyst regenerators subject 
to Sec. 60.103(a), an instrument for continuously monitoring and 
recording the concentration by volume (dry basis) of CO emissions into 
the atmosphere, except as provided in paragraph (a)(2) (ii) of this 
section.
    (i) The span value for this instrument is 1,000 ppm CO.
    (ii) A CO continuous monitoring system need not be installed if the 
owner or operator demonstrates that the average CO emissions are less 
than 50 ppm (dry basis) and also files a written request for exemption 
to the Administrator and receives such an exemption. The demonstration 
shall consist of continuously monitoring CO emissions for 30 days using 
an instrument that shall meet the requirements of Performance 
Specification 4 of Appendix B of this part. The span value shall be 100 
ppm CO instead of 1,000 ppm, and the relative accuracy limit shall be 10 
percent of the average CO emissions or 5 ppm CO, whichever is greater. 
For instruments that are identical to Method 10 and employ the sample 
conditioning system of Method 10A, the alternative relative accuracy 
test procedure in Sec. 10.1 of Performance Specification 2 may be used 
in place of the relative accuracy test.
    (3) For fuel gas combustion devices subject to Sec. 60.104(a)(1), an 
instrument for continuously monitoring and recording the concentration 
by volume (dry basis, zero percent excess air) of SO2 
emissions into the atmosphere (except where an H2S monitor is 
installed under paragraph (a)(4) of this section). The monitor shall 
include an oxygen monitor for correcting the data for excess air.
    (i) The span values for this monitor are 50 ppm SO2 and 
10 percent oxygen (O2).
    (ii) The SO2 monitoring level equivalent to the 
H2S standard under Sec. 60.104(a)(1) shall be 20 ppm (dry 
basis, zero percent excess air).
    (iii) The performance evaluations for this SO2 monitor 
under Sec. 60.13(c) shall use Performance Specification 2. Methods 6 and 
3 shall be used for conducting the relative accuracy evaluations. Method 
6 samples shall be taken at a flow rate of approximately 2 liters/min

[[Page 202]]

for at least 30 minutes. The relative accuracy limit shall be 20 percent 
or 4 ppm, whichever is greater, and the calibration drift limit shall be 
5 percent of the established span value.
    (iv) Fuel gas combustion devices having a common source of fuel gas 
may be monitored at only one location (i.e., after one of the combustion 
devices), if monitoring at this location accurately represents the 
S2 emissions into the atmosphere from each of the combustion 
devices.
    (4) In place of the SO2 monitor in paragraph (a)(3) of 
this section, an instrument for continuously monitoring and recording 
the concentration (dry basis) of H2S in fuel gases before 
being burned in any fuel gas combustion device.
    (i) The span value for this instrument is 425 mg/dscm 
H2S.
    (ii) Fuel gas combustion devices having a common source of fuel gas 
may be monitored at only one location, if monitoring at this location 
accurately represents the concentration of H2S in the fuel 
gas being burned.
    (iii) The performance evaluations for this H2S monitor 
under Sec. 60.13(c) shall use Performance Specification 7. Method 11 
shall be used for conducting the relative accuracy evaluations.
    (5) For Claus sulfur recovery plants with oxidation control systems 
or reduction control systems followed by incineration subject to 
Sec. 60.104(a)(2)(i), an instrument for continuously monitoring and 
recording the concentration (dry basis, zero percent excess air) of 
SO2 emissions into the atmosphere. The monitor shall include 
an oxygen monitor for correcting the data for excess air.
    (i) The span values for this monitor are 500 ppm SO2 and 
10 percent O2.
    (ii) The performance evaluations for this SO2 monitor 
under Sec. 60.13(c) shall use Performance Specification 2. Methods 6 and 
3 shall be used for conducting the relative accuracy evaluations.
    (6) For Claus sulfur recovery plants with reduction control systems 
not followed by incineration subject to Sec. 60.104(a)(2)(ii), an 
instrument for continuously monitoring and recording the concentration 
of reduced sulfur and O2 emissions into the atmosphere. The 
reduced sulfur emissions shall be calculated as SO2 (dry 
basis, zero percent excess air).
    (i) The span values for this monitor are 450 ppm reduced sulfur and 
10 percent O2.
    (ii) The performance evaluations for this reduced sulfur (and 
O2) monitor under Sec. 60.13(c) shall use Performance 
Specification 5, except the calibration drift specification is 2.5 
percent of the span value rather than 5 percent. Methods 15 or 15A and 
Method 3 shall be used for conducting the relative accuracy evaluations. 
If Method 3 yields O2 concentrations below 0.25 percent 
during the performance specification test, the O2 
concentration may be assumed to be zero and the reduced sulfur CEMS need 
not include an O2 monitor.
    (7) In place of the reduced sulfur monitor under paragraph (a)(6) of 
this section, an instrument using an air or O2 dilution and 
oxidation system to convert the reduced sulfur to SO2 for 
continuously monitoring and recording the concentration (dry basis, zero 
percent excess air) of the resultant SO2. The monitor shall 
include an oxygen monitor for correcting the data for excess oxygen.
    (i) The span values for this monitor are 375 ppm SO2 and 
10 percent O2.
    (ii) For reporting purposes, the SO2 exceedance level for 
this monitor is 250 ppm (dry basis, zero percent excess air).
    (iii) The performance evaluations for this SO2 (and 
O2) monitor under Sec. 60.13(c) shall use Performance 
Specification 5. Methods 15 or 15A and Method 3 shall be used for 
conducting the relative accuracy evaluations.
    (8) An instrument for continuously monitoring and recording 
concentrations of sulfur dioxide in the gases at both the inlet and 
outlet of the sulfur dioxide control device from any fluid catalytic 
cracking unit catalyst regenerator for which the owner or operator seeks 
to comply with Sec. 60.104(b)(1). The span value of the inlet monitor 
shall be set at 125 percent of the maximum estimated hourly potential 
sulfur dioxide emission concentration entering the control device, and 
the span value of the outlet monitor shall be set at 50 percent of the 
maximum estimated

[[Page 203]]

hourly potential sulfur dioxide emission concentration entering the 
control device.
    (9) An instrument for continuously monitoring and recording 
concentrations of sulfur dioxide in the gases discharged into the 
atmosphere from any fluid catalytic cracking unit catalyst regenerator 
for which the owner or operator seeks to comply specifically with the 50 
vppm emission limit under Sec. 60.104(b)(1). The span value of the 
monitor shall be set at 50 percent of the maximum hourly potential 
sulfur dioxide emission concentration entering the control device.
    (10) An instrument for continuously monitoring and recording 
concentrations of oxygen (O2) in the gases at both the inlet 
and outlet of the sulfur dioxide control device (or the outlet only if 
specifically complying with the 50 vppm standard) from any fluid 
catalytic cracking unit catalyst regenerator for which the owner or 
operator has elected to comply with Sec. 60.104(b)(1). The span of this 
continuous monitoring system shall be set at 10 percent.
    (11) The continuous monitoring systems under paragraphs (a)(8), 
(a)(9), and (a)(10) of this section are operated and data recorded 
during all periods of operation of the affected facility including 
periods of startup, shutdown, or malfunction, except for continuous 
monitoring system breakdowns, repairs, calibration checks, and zero and 
span adjustments.
    (12) The owner or operator shall follow appendix F, Procedure 1, 
including quarterly accuracy determinations and daily calibration drift 
tests, for the continuous monitoring systems under paragraphs (a)(8), 
(a)(9), and (a)(10) of this section.
    (13) When seeking to comply with Sec. 60.104(b)(1), when emission 
data are not obtained because of continuous monitoring system 
breakdowns, repairs, calibration checks and zero and span adjustments, 
emission data will be obtained by using one of the following methods to 
provide emission data for a minimum of 18 hours per day in at least 22 
out of 30 rolling successive calendar days.
    (i) The test methods as described in Sec. 60.106(k);
    (ii) A spare continuous monitoring system; or
    (iii) Other monitoring systems as approved by the Administrator.
    (b) [Reserved]
    (c) The average coke burn-off rate (thousands of kilograms per hour) 
and hours of operation shall be recorded daily for any fluid catalytic 
cracking unit catalyst regenerator subject to Sec. 60.102, Sec. 60.103, 
or Sec. 60.104(b)(2).
    (d) For any fluid catalytic cracking unit catalyst regenerator under 
Sec. 60.102 that uses an incinerator-waste heat boiler to combust the 
exhaust gases from the catalyst regenerator, the owner or operator shall 
record daily the rate of combustion of liquid or solid fossil-fuels 
(liters/hr or kg/hr) and the hours of operation during which liquid or 
solid fossil-fuels are combusted in the incinerator-waste heat boiler.
    (e) For the purpose of reports under Sec. 60.7(c), periods of excess 
emissions that shall be determined and reported are defined as follows:
    Note: All averages, except for opacity, shall be determined as the 
arithmetic average of the applicable 1-hour averages, e.g., the rolling 
3-hour average shall be determined as the arithmetic average of three 
contiguous 1-hour averages.
    (1) Opacity. All 1-hour periods that contain two or more 6-minute 
periods during which the average opacity as measured by the continuous 
monitoring system under Sec. 60.105(a)(1) exceeds 30 percent.
    (2) Carbon monoxide. All 1-hour periods during which the average CO 
concentration as measured by the CO continuous monitoring system under 
Sec. 60.105(a)(2) exceeds 500 ppm.
    (3) Sulfur dioxide from fuel gas combustion. (i) All rolling 3-hour 
periods during which the average concentration of SO2 as 
measured by the SO2 continuous monitoring system under 
Sec. 60.105(a)(3) exceeds 20 ppm (dry basis, zero percent excess air); 
or
    (ii) All rolling 3-hour periods during which the average 
concentration of H2S as measured by the H2S 
continuous monitoring system under Sec. 60.105(a)(4) exceeds 230 mg/dscm 
(0.10 gr/dscf).
    (4) Sulfur dioxide from Claus sulfur recovery plants. (i) All 12-
hour periods during which the average concentration of SO2 as 
measured by the SO2

[[Page 204]]

continuous monitoring system under Sec. 60.105(a)(5) exceeds 250 ppm 
(dry basis, zero percent excess air); or
    (ii) All 12-hour periods during which the average concentration of 
reduced sulfur (as SO2) as measured by the reduced sulfur 
continuous monitoring system under Sec. 60.105(a)(6) exceeds 300 ppm; or
    (iii) All 12-hour periods during which the average concentration of 
SO2 as measured by the SO2 continuous monitoring 
system under Sec. 60.105(a)(7) exceeds 250 ppm (dry basis, zero percent 
excess air).

[39 FR 9315, Mar. 8, 1974, as amended at 40 FR 46259, Oct. 6, 1975; 42 
FR 32427, June 24, 1977; 42 FR 39389, Aug. 4, 1977; 43 FR 10869, Mar. 
15, 1978; 48 FR 23611, May 25, 1983; 50 FR 31701, Aug. 5, 1985; 54 FR 
34028, Aug. 17, 1989; 55 FR 40175, Oct. 2, 1990]



Sec. 60.106  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter (PM) standards in Sec. 60.102(a) as follows:
    (1) The emission rate (E) of PM shall be computed for each run using 
the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.004

where:

E=Emission rate of PM, kg/1000 kg (lb/1000 lb) of coke burn-off.
cs=Concentration of PM, g/dscm (lb/dscf).
Qsd=Volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
Rc=Coke burn-off rate, kg coke/hr (1000 lb coke/hr).
K=Conversion factor, 1.0 (kg\2\/g)/(1000 kg) [10\3\ lb/(1000 lb)].

    (2) Method 5B or 5F is to be used to determine particulate matter 
emissions and associated moisture content from affected facilities 
without wet FGD systems; only Method 5B is to be used after wet FGD 
systems. The sampling time for each run shall be at least 60 minutes and 
the sampling rate shall be at least 0.015 dscm/min (0.53 dscf/min), 
except that shorter sampling times may be approved by the Administrator 
when process variables or other factors preclude sampling for at least 
60 minutes.
    (3) The coke burn-off rate (Rc) shall be computed for 
each run using the following equation:

Rc=K1 Qr 
          (%CO2+%CO)K2 Qa-K3 
          Qr [(%CO/2)+%CO2+%O2]

where:

Rc=Coke burn-off rate, kg/hr (1000 lb/hr).
Qr=Volumetric flow rate of exhaust gas from catalyst 
          regenerator before entering the emission control system, dscm/
          min (dscf/min).
Qa=Volumetric flow rate of air to FCCU regenerator, as 
          determined from the fluid catalytic cracking unit control room 
          instrumentation, dscm/min (dscf/min).
%CO2=Carbon dioxide concentration, percent by volume (dry 
          basis).
%CO=Carbon monoxide concentration, percent by volume (dry basis).
%O2=Oxygen concentration, percent by volume (dry basis).
K1=Material balance and conversion factor, 0.2982 (kg-min)/
          (hr-dscm-%) [0.0186 (lb-min)/(hr-dscf-%)].
K2=Material balance and conversion factor, 2.088 (kg-min)/
          (hr-dscm-%)[0.1303 (lb-min)/(hr-dscf-%)].
K3=Material balance and conversion factor,
    0.0994 (kg-min)/(hr-dscm-%)
    [0.0062 (lb-min)/(hr-dscf-%)].

    (i) Method 2 shall be used to determine the volumetric flow rate 
(Qr).
    (ii) The emission correction factor, integrated sampling and 
analysis procedure of Method 3 shall be used to determine 
CO2, CO, and O2 concentrations.
    (4) Method 9 and the procedures of Sec. 60.11 shall be used to 
determine opacity.
    (c) If auxiliary liquid or solid fossil-fuels are burned in an 
incinerator-waste heat boiler, the owner or operator shall determine the 
emission rate of PM permitted in Sec. 60.102(b) as follows:
    (1) The allowable emission rate (Es) of PM shall be 
computed for each run using the following equation:

Es=1.0 + A (H/Rc) K'

where:
Es=Emission rate of PM allowed, kg/1000 kg (lb/1000 lb) of 
          coke burn-off in catalyst regenerator.
1.0=Emission standard, kg coke/1000 kg (lb coke/1000 lb).

[[Page 205]]

A=Allowable incremental rate of PM emissions, 0.18 g/million cal (0.10 
          lb/million Btu).
H=Heat input rate from solid or liquid fossil fuel, million cal/hr 
          (million Btu/hr).
Rc=Coke burn-off rate, kg coke/hr (1000 lb coke/hr).
K'=Conversion factor to units of standard, 1.0 (kg\2\/g)/(1000 kg) 
          [10\3\ lb/(1000 lb)].

    (2) Procedures subject to the approval of the Administrator shall be 
used to determine the heat input rate.
    (3) The procedure in paragraph (b)(3) of this section shall be used 
to determine the coke burn-off rate (Rc).
    (d) The owner or operator shall determine compliance with the CO 
standard in Sec. 60.103(a) by using the integrated sampling technique of 
Method 10 to determine the CO concentration (dry basis). The sampling 
time for each run shall be 60 minutes.
    (e) The owner or operator shall determine compliance with the 
H2S standard in Sec. 60.104(a)(1) as follows: Method 11 shall 
be used to determine the H2 concentration. The gases entering 
the sampling train should be at about atmospheric pressure. If the 
pressure in the refinery fuel gas lines is relatively high, a flow 
control valve may be used to reduce the pressure. If the line pressure 
is high enough to operate the sampling train without a vacuum pump, the 
pump may be eliminated from the sampling train. The sample shall be 
drawn from a point near the centroid of the fuel gas line. The sampling 
time and sample volume shall be at least 10 minutes and 0.010 dscm (0.35 
dscf). Two samples of equal sampling times shall be taken at about 1-
hour intervals. The arithmetic average of these two samples shall 
constitute a run. For most fuel gases, sampling times exceeding 20 
minutes may result in depletion of the collection solution, although 
fuel gases containing low concentrations of H2S may 
necessitate sampling for longer periods of time.
    (f) The owner or operator shall determine compliance with the 
SO2 and the H2S and reduced sulfur standards in 
Sec. 60.104(a)(2) as follows:
    (1) Method 6 shall be used to determine the SO2 
concentration. The concentration in mg/dscm (lb/dscf) obtained by Method 
6 is multiplied by 0.3754 to obtain the concentration in ppm. The 
sampling point in the duct shall be the centroid of the cross section if 
the cross-sectional area is less than 5.00 m2 (54 
ft2) or at a point no closer to the walls than 1.00 m (39 
in.) if the cross-sectional area is 5.00 m2 or more and the 
centroid is more than 1 m from the wall. The sampling time and sample 
volume shall be at least 10 minutes and 0.010 dscm (0.35 dscf) for each 
sample. Eight samples of equal sampling times shall be taken at about 
30-minute intervals. The arithmetic average of these eight samples shall 
constitute a run. Method 4 shall be used to determine the moisture 
content of the gases. The sampling point for Method 4 shall be adjacent 
to the sampling point for Method 6. The sampling time for each sample 
shall be equal to the time it takes for two Method 6 samples. The 
moisture content from this sample shall be used to correct the 
corresponding Method 6 samples for moisture. For documenting the 
oxidation efficiency of the control device for reduced sulfur compounds, 
Method 15 shall be used following the procedures of paragraph (f)(2) of 
this section.
    (2) Method 15 shall be used to determine the reduced sulfur and 
H2 S concentrations. Each run shall consist of 16 samples 
taken over a minimum of 3 hours. The sampling point shall be the same as 
that described for Method 6 in paragraph (f)(1) of this section. To 
ensure minimum residence time for the sample inside the sample lines, 
the sampling rate shall be at least 3.0 lpm (0.10 cfm). The 
SO2 equivalent for each run shall be calculated after being 
corrected for moisture and oxygen as the arithmetic average of the 
SO2 equivalent for each sample during the run. Method 4 shall 
be used to determine the moisture content of the gases as the paragraph 
(f)(1) of this section. The sampling time for each sample shall be equal 
to the time it takes for four Method 15 samples.
    (3) The oxygen concentration used to correct the emission rate for 
excess air shall be obtained by the integrated sampling and analysis 
procedure of Method 3. The samples shall be taken simultaneously with 
the SO2, reduced sulfur and H2S, or moisture 
samples. The SO2, reduced sulfur, and H2S samples 
shall be corrected to zero percent

[[Page 206]]

excess air using the equation in paragraph (h)(3) of this section.
    (g) Each performance test conducted for the purpose of determining 
compliance under Sec. 60.104(b) shall consist of all testing performed 
over a 7-day period using the applicable test methods and procedures 
specified in this section. To determine compliance, the arithmetic mean 
of the results of all the tests shall be compared with the applicable 
standard.
    (h) For the purpose of determining compliance with 
Sec. 60.104(b)(1), the following calculation procedures shall be used:
    (1) Calculate each 1-hour average concentration (dry, zero percent 
oxygen, vppm) of sulfur dioxide at both the inlet and the outlet to the 
add-on control device as specified in Sec. 60.13(h). These calculations 
are made using the emission data collected under Sec. 60.105(a).
    (2) Calculate a 7-day average (arithmetic mean) concentration of 
sulfur dioxide for the inlet and for the outlet to the add-on control 
device using all of the 1-hour average concentration values obtained 
during seven successive 24-hour periods.
    (3) Calculate the 7-day average percent reduction using the 
following equation:

Rso2 = 100(Cso2(i)-Cso2(o))/
Cso2(i)
where:

Rso2 = 7-day average sulfur dioxide emission reduction, 
percent
Cso2(i) = sulfur dioxide emission concentration determined in 
Sec. 60.106(h)(2) at the inlet to the add-on control device, vppm
Cso2(o) = sulfur dioxide emission concentration determined in 
Sec. 60.106(h)(2) at the outlet to the add-on control device, vppm
100 = conversion factor, decimal to percent

    (4) Outlet concentrations of sulfur dioxide from the add-on control 
device for compliance with the 50 vppm standard, reported on a dry, 
O2-free basis, shall be calculated using the procedures 
outlined in Sec. 60.106(h)(1) and (2) above, but for the outlet monitor 
only.
    (5) If supplemental sampling data are used for determining the 7-day 
averages under paragraph (h) of this section and such data are not 
hourly averages, then the value obtained for each supplemental sample 
shall be assumed to represent the hourly average for each hour over 
which the sample was obtained.
    (6) For the purpose of adjusting pollutant concentrations to zero 
percent oxygen, the following equation shall be used:

Cadj = Cmeas [20.9c/
(20.9-%O2)]

where:

Cadj = pollutant concentration adjusted to zero percent 
oxygen, ppm or g/dscm
Cmeas = pollutant concentration measured on a dry basis, ppm 
or g/dscm
20.9c = 20.9 percent oxygen-0.0 percent oxygen (defined 
oxygen correction basis), percent

20.9 = oxygen concentration in air, percent
%O2 = oxygen concentration measured on a dry basis, percent

    (i) For the purpose of determining compliance with 
Sec. 60.104(b)(2), the following reference methods and calculation 
procedures shall be used except as provided in paragraph (i)(12) of this 
section:
    (1) One 3-hour test shall be performed each day.
    (2) For gases released to the atmosphere from the fluid catalytic 
cracking unit catalyst regenerator:
    (i) Method 8 as modified in Sec. 60.106(i)(3) for the concentration 
of sulfur oxides calculated as sulfur dioxide and moisture content,
    (ii) Method 1 for sample and velocity traverses,
    (iii) Method 2 calculation procedures (data obtained from Methods 3 
and 8) for velocity and volumetric flow rate, and
    (iv) Method 3 for gas analysis.
    (3) Method 8 shall be modified by the insertion of a heated glass 
fiber filter between the probe and first impinger. The probe liner and 
glass fiber filter temperature shall be maintained above 160  deg.C (320 
 deg.F). The isopropanol impinger shall be eliminated. Sample recovery 
procedures described in Method 8 for container No. 1 shall be 
eliminated. The heated glass fiber filter also shall be excluded; 
however, rinsing of all connecting glassware after the heated glass 
fiber filter shall be retained and included in container No. 2. Sampled 
volume shall be at least 1 dscm.
    (4) For Method 3, the integrated sampling technique shall be used.

[[Page 207]]

    (5) Sampling time for each run shall be at least 3 hours.
    (6) All testing shall be performed at the same location. Where the 
gases discharged by the fluid catalytic cracking unit catalyst 
regenerator pass through an incinerator-waste heat boiler in which 
auxiliary or supplemental gaseous, liquid, or solid fossil fuel is 
burned, testing shall be conducted at a point between the regenerator 
outlet and the incinerator-waste heat boiler. An alternative sampling 
location after the waste heat boiler may be used if alternative coke 
burn-off rate equations, and, if requested, auxiliary/supplemental fuel 
SOX credits, have been submitted to and approved by the 
Administrator prior to sampling.
    (7) Coke burn-off rate shall be determined using the procedures 
specified under paragraph (b)(3) of this section, unless paragraph 
(i)(6) of this section applies.
    (8) Calculate the concentration of sulfur oxides as sulfur dioxide 
using equation 8-3 in Section 6.5 of Method 8 to calculate and report 
the total concentration of sulfur oxides as sulfur dioxide 
(Cso x).
    (9) Sulfur oxides emission rate calculated as sulfur dioxide shall 
be determined for each test run by the following equation:

         Eso x = CsoX Qsd/1,000

where:

Eso x = sulfur oxides emission rate calculated as sulfur 
          dioxide, kg/hr
Cso x = sulfur oxides emission concentration calculated as 
          sulfur dioxide, g/dscm
Qsd = dry volumetric stack gas flow rate corrected to 
          standard conditions, dscm/hr
1,000 = conversion factor, g to kg

    (10) Sulfur oxides emissions calculated as sulfur dioxide per 1,000 
kg coke burn-off in the fluid catalytic cracking unit catalyst 
regenerator shall be determined for each test run by the following 
equation:

           Rso x = (Eso x/Rc)

where:

Rso x = sulfur oxides emissions calculated as sulfur dioxide, 
          kg/1,000 kg coke burn-off
Eso x = sulfur oxides emission rate calculated as sulfur 
          dioxide, kg/hr
Rc = coke burn-off rate, 1,000 kg/hr

    (11) Calculate the 7-day average sulfur oxides emission rate as 
sulfur dioxide per 1,000 kg of coke burn-off by dividing the sum of the 
individual daily rates by the number of daily rates summed.
    (12) An owner or operator may, upon approval by the Administrator, 
use an alternative method for determining compliance with 
Sec. 60.104(b)(2), as provided in Sec. 60.8(b). Any requests for 
approval must include data to demonstrate to the Administrator that the 
alternative method would produce results adequate for the determination 
of compliance.
    (j) For the purpose of determining compliance with 
Sec. 60.104(b)(3), the following analytical methods and calculation 
procedures shall be used:
    (1) One fresh feed sample shall be collected once per 8-hour period.
    (2) Fresh feed samples shall be analyzed separately by using any one 
of the following applicable analytical test methods: ASTM D129-64 
(Reapproved 1978), ASTM D1552-83, ASTM D2622-87, or ASTM D1266-87. 
(These methods are incorporated by reference: see Sec. 60.17.) The 
applicable range of some of these ASTM methods is not adequate to 
measure the levels of sulfur in some fresh feed samples. Dilution of 
samples prior to analysis with verification of the dilution ratio is 
acceptable upon prior approval of the Administrator.
    (3) If a fresh feed sample cannot be collected at a single location, 
then the fresh feed sulfur content shall be determined as follows:
    (i) Individual samples shall be collected once per 8-hour period for 
each separate fresh feed stream charged directly into the riser or 
reactor of the fluid catalytic cracking unit. For each sample location 
the fresh feed volumetric flow rate at the time of collecting the fresh 
feed sample shall be measured and recorded. The same method for 
measuring volumetric flow rate shall be used at all locations.
    (ii) Each fresh feed sample shall be analyzed separately using the 
methods specified under paragraph (j)(2) of this section.
    (iii) Fresh feed sulfur content shall be calculated for each 8-hour 
period using the following equation:

[[Page 208]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.005

where:

Sf = fresh feed sulfur content expressed in percent by weight 
          of fresh feed.
n = number of separate fresh feed streams charged directly to the riser 
          or reactor of the fluid catalytic cracking unit.
Qf = total volumetric flow rate of fresh feed charged to the 
          fluid catalytic cracking unit.
Si = fresh feed sulfur content expressed in percent by weight 
          of fresh feed for the ``ith'' sampling location.
Qi = volumetric flow rate of fresh feed stream for the 
          ``ith'' sampling location.

    (4) Calculate a 7-day average (arithmetic mean) sulfur content of 
the fresh feed using all of the fresh feed sulfur content values 
obtained during seven successive 24-hour periods.
    (k) The test methods used to supplement continuous monitoring system 
data to meet the minimum data requirements in Sec. 60.104(d) will be 
used as described below or as otherwise approved by the Administrator.
    (1) Methods 6, 6B, or 8 are used. The sampling location(s) are the 
same as those specified for the monitor.
    (2) For Method 6, the minimum sampling time is 20 minutes and the 
minimum sampling volume is 0.02 dscm (0.71 dscf) for each sample. 
Samples are taken at approximately 60-minute intervals. Each sample 
represents a 1-hour average. A minimum of 18 valid samples is required 
to obtain one valid day of data.
    (3) For Method 6B, collection of a sample representing a minimum of 
18 hours is required to obtain one valid day of data.
    (4) For Method 8, the procedures as outlined in this section are 
used. The equivalent of 16 hours of sampling is required to obtain one 
valid day of data.

[39 FR 9315, Mar. 8, 1974, as amended at 43 FR 10869, Mar. 15, 1978; 51 
FR 42842, Nov. 26, 1986; 52 FR 20392, June 1, 1987; 53 FR 41333, Oct. 
21, 1988; 54 FR 34028, Aug. 17, 1989; 55 FR 40176, Oct. 2, 1990; 56 FR 
4176, Feb. 4, 1991]



Sec. 60.107  Reporting and recordkeeping requirements.

    (a) Each owner or operator subject to Sec. 60.104(b) shall notify 
the Administrator of the specific provisions of Sec. 60.104(b) with 
which the owner or operator seeks to comply. Notification shall be 
submitted with the notification of initial startup required by 
Sec. 60.7(a)(3). If an owner or operator elects at a later date to 
comply with an alternative provision of Sec. 60.104(b), then the 
Administrator shall be notified by the owner or operator in the report 
described in paragraph (c) of this section.
    (b) Each owner or operator subject to Sec. 60.104(b) shall record 
and maintain the following information:
    (1) If subject to Sec. 60.104(b)(1),
    (i) All data and calibrations from continuous monitoring systems 
located at the inlet and outlet to the control device, including the 
results of the daily drift tests and quarterly accuracy assessments 
required under appendix F, Procedure 1;
    (ii) Measurements obtained by supplemental sampling (refer to 
Sec. 60.105(a)(13) and Sec. 60.106(k)) for meeting minimum data 
requirements; and
    (iii) The written procedures for the quality control program 
required by appendix F, Procedure 1.
    (2) If subject to Sec. 60.104(b)(2), measurements obtained in the 
daily Method 8 testing, or those obtained by alternative measurement 
methods, if Sec. 60.106(i)(12) applies.
    (3) If subject to Sec. 60.104(b)(3), data obtained from the daily 
feed sulfur tests.
    (4) Each 7-day rolling average compliance determination.
    (c) Each owner or operator subject to Sec. 60.104(b) shall submit a 
report except as provided by paragraph (d) of this section. The 
following information shall be contained in the report:
    (1) Any 7-day period during which:
    (i) The average percent reduction and average concentration of 
sulfur dioxide on a dry, O2-free basis in the gases 
discharged to the atmosphere from any fluid cracking unit catalyst 
regenerator for which the owner or operator seeks to comply with 
Sec. 60.104(b)(1) is below 90 percent and above 50 vppm, as measured by 
the continuous monitoring system prescribed under Sec. 60.105(a)(8), or 
above 50 vppm, as measured by the outlet continuous monitoring system 
prescribed under

[[Page 209]]

Sec. 60.105(a)(9). The average percent reduction and average sulfur 
dioxide concentration shall be determined using the procedures specified 
under Sec. 60.106(h);
    (ii) The average emission rate of sulfur dioxide in the gases 
discharged to the atmosphere from any fluid catalytic cracking unit 
catalyst regenerator for which the owner or operator seeks to comply 
with Sec. 60.104(b)(2) exceeds 9.8 kg SOX per 1,000 kg coke 
burn-off, as measured by the daily testing prescribed under 
Sec. 60.106(i). The average emission rate shall be determined using the 
procedures specified under Sec. 60.106(i); and
    (iii) The average sulfur content of the fresh feed for which the 
owner or operator seeks to comply with Sec. 60.104(b)(3) exceeds 0.30 
percent by weight. The fresh feed sulfur content, a 7-day rolling 
average, shall be determined using the procedures specified under 
Sec. 60.106(j).
    (2) Any 30-day period in which the minimum data requirements 
specified in Sec. 60.104(d) are not obtained.
    (3) For each 7-day period during which an exceedance has occurred as 
defined in paragraphs (c)(1)(i) through (c)(1)(iii) and (c)(2) of this 
section:
    (i) The date that the exceedance occurred;
    (ii) An explanation of the exceedance;
    (iii) Whether the exceedance was concurrent with a startup, 
shutdown, or malfunction of the fluid catalytic cracking unit or control 
system; and
    (iv) A description of the corrective action taken, if any.
    (4) If subject to Sec. 60.104(b)(1),
    (i) The dates for which and brief explanations as to why fewer than 
18 valid hours of data were obtained for the inlet continuous monitoring 
system;
    (ii) The dates for which and brief explanations as to why fewer than 
18 valid hours of data were obtained for the outlet continuous 
monitoring system;
    (iii) Identification of times when hourly averages have been 
obtained based on manual sampling methods;
    (iv) Identification of the times when the pollutant concentration 
exceeded full span of the continuous monitoring system; and
    (v) Description of any modifications to the continuous monitoring 
system that could affect the ability of the continuous monitoring system 
to comply with Performance Specifications 2 or 3.
    (vi) Results of daily drift tests and quarterly accuracy assessments 
as required under appendix F, Procedure 1.
    (5) If subject to Sec. 60.104(b)(2), for each day in which a Method 
8 sample result was not obtained, the date for which and brief 
explanation as to why a Method 8 sample result was not obtained, for 
approval by the Administrator.
    (6) If subject to Sec. 60.104(b)(3), for each 8-hour shift in which 
a feed sulfur measurement was not obtained, the date for which and brief 
explanation as to why a feed sulfur measurement was not obtained, for 
approval by the Administrator.
    (d) For any periods for which sulfur dioxide or oxides emissions 
data are not available, the owner or operator of the affected facility 
shall submit a signed statement indicating if any changes were made in 
operation of the emission control system during the period of data 
unavailability which could affect the ability of the system to meet the 
applicable emission limit. Operations of the control system and affected 
facility during periods of data unavailability are to be compared with 
operation of the control system and affected facility before and 
following the period of data unavailability.
    (e) The owner or operator of an affected facility shall submit the 
reports required under this subpart to the Administrator semiannually 
for each six-month period. All semiannual reports shall be postmarked by 
the 30th day following the end of each six-month period.
    (f) The owner or operator of the affected facility shall submit a 
signed statement certifying the accuracy and completeness of the 
information contained in the report.

[54 FR 34029, Aug. 17, 1989, as amended at 55 FR 40178, Oct. 2, 1990; 64 
FR 7465, Feb. 12, 1999]



Sec. 60.108  Performance test and compliance provisions.

    (a) Section 60.8(d) shall apply to the initial performance test 
specified under

[[Page 210]]

paragraph (c) of this section, but not to the daily performance tests 
required thereafter as specified in Sec. 60.108(d). Section 60.8(f) does 
not apply when determining compliance with the standards specified under 
Sec. 60.104(b). Performance tests conducted for the purpose of 
determining compliance under Sec. 60.104(b) shall be conducted according 
to the applicable procedures specified under Sec. 60.106.
    (b) Owners or operators who seek to comply with Sec. 60.104(b)(3) 
shall meet that standard at all times, including periods of startup, 
shutdown, and malfunctions.
    (c) The initial performance test shall consist of the initial 7-day 
average calculated for compliance with Sec. 60.104(b)(1), (b)(2), or 
(b)(3).
    (d) After conducting the initial performance test prescribed under 
Sec. 60.8, the owner or operator of a fluid catalytic cracking unit 
catalyst regenerator subject to Sec. 60.104(b) shall conduct a 
performance test for each successive 24-hour period thereafter. The 
daily performance tests shall be conducted according to the appropriate 
procedures specified under Sec. 60.106. In the event that a sample 
collected under Sec. 60.106(i) or (j) is accidentally lost or conditions 
occur in which one of the samples must be discontinued because of forced 
shutdown, failure of an irreplaceable portion of the sample train, 
extreme meteorological conditions, or other circumstances, beyond the 
owner or operators' control, compliance may be determined using 
available data for the 7-day period.
    (e) Each owner or operator subject to Sec. 60.104(b) who has 
demonstrated compliance with one of the provisions of Sec. 60.104(b) but 
a later date seeks to comply with another of the provisions of 
Sec. 60.104(b) shall begin conducting daily performance tests as 
specified under paragraph (d) of this section immediately upon electing 
to become subject to one of the other provisions of Sec. 60.104(b). The 
owner or operator shall furnish the Administrator with a written 
notification of the change in the semiannual report required by 
Sec. 60.107(e).

[54 FR 34030, Aug. 17, 1989, as amended at 55 FR 40178, Oct. 2, 1990; 64 
FR 7466, Feb. 12, 1999]



Sec. 60.109  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which shall not be delegated to States:
    (1) Section 60.105(a)(13)(iii),
    (2) Section 60.106(i)(12).

[54 FR 34031, Aug. 17, 1989, as amended at 55 FR 40178, Oct. 2, 1990]



 Subpart K--Standards of Performance for Storage Vessels for Petroleum 
    Liquids for Which Construction, Reconstruction, or Modification 
        Commenced After June 11, 1973, and Prior to May 19, 1978



Sec. 60.110  Applicability and designation of affected facility.

    (a) Except as provided in Sec. 60.110(b), the affected facility to 
which this subpart applies is each storage vessel for petroleum liquids 
which has a storage capacity greater than 151,412 liters (40,000 
gallons).
    (b) This subpart does not apply to storage vessels for petroleum or 
condensate stored, processed, and/or treated at a drilling and 
production facility prior to custody transfer.
    (c) Subject to the requirements of this subpart is any facility 
under paragraph (a) of this section which:
    (1) Has a capacity greater than 151, 416 liters (40,000 gallons), 
but not exceeding 246,052 liters (65,000 gallons), and commences 
construction or modification after March 8, 1974, and prior to May 19, 
1978.
    (2) Has a capacity greater than 246,052 liters (65,000 gallons) and 
commences construction or modification after June 11, 1973, and prior to 
May 19, 1978.

[42 FR 37937, July 25, 1977, as amended at 45 FR 23379, Apr. 4, 1980]



Sec. 60.111  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.

[[Page 211]]

    (a) Storage vessel means any tank, reservoir, or container used for 
the storage of petroleum liquids, but does not include:
    (1) Pressure vessels which are designed to operate in excess of 15 
pounds per square inch gauge without emissions to the atmosphere except 
under emergency conditions,
    (2) Subsurface caverns or porous rock reservoirs, or
    (3) Underground tanks if the total volume of petroleum liquids added 
to and taken from a tank annually does not exceed twice the volume of 
the tank.
    (b) Petroleum liquids means petroleum, condensate, and any finished 
or intermediate products manufactured in a petroleum refinery but does 
not mean Nos. 2 through 6 fuel oils as specified in ASTM D396-78, gas 
turbine fuel oils Nos. 2-GT through 4-GT as specified in ASTM D2880-78, 
or diesel fuel oils Nos. 2-D and 4-D as specified in ASTM D975-78. 
(These three methods are incorporated by reference--see Sec. 60.17.)
    (c) Petroleum refinery means each facility engaged in producing 
gasoline, kerosene, distillate fuel oils, residual fuel oils, 
lubricants, or other products through distillation of petroleum or 
through redistillation, cracking, extracting, or reforming of unfinished 
petroleum derivatives.
    (d) Petroleum means the crude oil removed from the earth and the 
oils derived from tar sands, shale, and coal.
    (e) Hydrocarbon means any organic compound consisting predominantly 
of carbon and hydrogen.
    (f) Condensate means hydrocarbon liquid separated from natural gas 
which condenses due to changes in the temperature and/or pressure and 
remains liquid at standard conditions.
    (g) Custody transfer means the transfer of produced petroleum and/or 
condensate, after processing and/or treating in the producing 
operations, from storage tanks or automatic transfer facilities to 
pipelines or any other forms of transportation.
    (h) Drilling and production facility means all drilling and 
servicing equipment, wells, flow lines, separators, equipment, gathering 
lines, and auxiliary nontransportation-related equipment used in the 
production of petroleum but does not include natural gasoline plants.
    (i) True vapor pressure means the equilibrium partial pressure 
exerted by a petroleum liquid as determined in accordance with methods 
described in American Petroleum Institute Bulletin 2517, Evaporation 
Loss from External Floating-Roof Tanks, Second Edition, February 1980 
(incorporated by reference--see Sec. 60.17).
    (j) Floating roof means a storage vessel cover consisting of a 
double deck, pontoon single deck, internal floating cover or covered 
floating roof, which rests upon and is supported by the petroleum liquid 
being contained, and is equipped with a closure seal or seals to close 
the space between the roof edge and tank wall.
    (k) Vapor recovery system means a vapor gathering system capable of 
collecting all hydrocarbon vapors and gases discharged from the storage 
vessel and a vapor disposal system capable of processing such 
hydrocarbon vapors and gases so as to prevent their emission to the 
atmosphere.
    (l) Reid vapor pressure is the absolute vapor pressure of volatile 
crude oil and volatile nonviscous petroleum liquids, except liquified 
petroleum gases, as determined by ASTM D323-82 (incorporated by 
reference--see Sec. 60.17).

[39 FR 9317, Mar. 8, 1974; 39 FR 13776, Apr. 17, 1974, as amended at 39 
FR 20794, June 14, 1974; 45 FR 23379, Apr. 4, 1980; 48 FR 3737, Jan. 27, 
1983; 52 FR 11429, Apr. 8, 1987]



Sec. 60.112  Standard for volatile organic compounds (VOC).

    (a) The owner or operator of any storage vessel to which this 
subpart applies shall store petroleum liquids as follows:
    (1) If the true vapor pressure of the petroleum liquid, as stored, 
is equal to or greater than 78 mm Hg (1.5 psia) but not greater than 570 
mm Hg (11.1 psia), the storage vessel shall be equipped with a floating 
roof, a vapor recovery system, or their equivalents.
    (2) If the true vapor pressure of the petroleum liquid as stored is 
greater than 570 mm Hg (11.1 psia), the storage vessel shall be equipped 
with a vapor recovery system or its equivalent.

[39 FR 9317, Mar. 8, 1974; 39 FR 13776, Apr. 17, 1974, as amended at 45 
FR 23379, Apr. 4, 1980]

[[Page 212]]



Sec. 60.113  Monitoring of operations.

    (a) Except as provided in paragraph (d) of this section, the owner 
or operator subject to this subpart shall maintain a record of the 
petroleum liquid stored, the period of storage, and the maximum true 
vapor pressure of that liquid during the respective storage period.
    (b) Available data on the typical Reid vapor pressure and the 
maximum expected storage temperature of the stored product may be used 
to determine the maximum true vapor pressure from nomographs contained 
in API Bulletin 2517, unless the Administrator specifically requests 
that the liquid be sampled, the actual storage temperature determined, 
and the Reid vapor pressure determined from the sample(s).
    (c) The true vapor pressure of each type of crude oil with a Reid 
vapor pressure less than 13.8 kPa (2.0 psia) or whose physical 
properties preclude determination by the recommended method is to be 
determined from available data and recorded if the estimated true vapor 
pressure is greater than 6.9 kPa (1.0 psia).
    (d) The following are exempt from the requirements of this section:
    (1) Each owner or operator of each affected facility which stores 
petroleum liquids with a Reid vapor pressure of less than 6.9 kPa (1.0 
psia) provided the maximum true vapor pressure does not exceed 6.9 kPa 
(1.0 psia).
    (2) Each owner or operator of each affected facility equipped with a 
vapor recovery and return or disposal system in accordance with the 
requirements of Sec. 60.112.

[45 FR 23379, Apr. 4, 1980]



 Subpart Ka--Standards of Performance for Storage Vessels for Petroleum 
    Liquids for Which Construction, Reconstruction, or Modification 
        Commenced After May 18, 1978, and Prior to July 23, 1984



Sec. 60.110a  Applicability and designation of affected facility.

    (a) Except as provided in paragraph (b) of this section, the 
affected facility to which this subpart applies is each storage vessel 
for petroleum liquids which has a storage capacity greater than 151,416 
liters (40,000 gallons) and for which construction is commenced after 
May 18, 1978.
    (b) Each petroleum liquid storage vessel with a capacity of less 
than 1,589,873 liters (420,000 gallons) used for petroleum or condensate 
stored, processed, or treated prior to custody transfer is not an 
affected facility and, therefore, is exempt from the requirements of 
this subpart.

[45 FR 23379, Apr. 4, 1980]



Sec. 60.111a  Definitions.

    In addition to the terms and their definitions listed in the Act and 
subpart A of this part the following definitions apply in this subpart:
    (a) Storage vessel means each tank, reservoir, or container used for 
the storage of petroleum liquids, but does not include:
    (1) Pressure vessels which are designed to operate in excess of 
204.9 kPa (15 psig) without emissions to the atmosphere except under 
emergency conditions.
    (2) Subsurface caverns or porous rock reservoirs, or
    (3) Underground tanks if the total volume of petroleum liquids added 
to and taken from a tank annually does not exceed twice the volume of 
the tank.
    (b) Petroleum liquids means petroleum, condensate, and any finished 
or

[[Page 213]]

intermediate products manufactured in a petroleum refinery but does not 
mean Nos. 2 through 6 fuel oils as specified in ASTM D396-78, gas 
turbine fuel oils Nos. 2-GT through 4-GT as specified in ASTM D2880-78, 
gas turbine fuel oils Nos. 2-GT through 4-GT as specified in ASTM D2880-
78, or diesel fuel oils Nos. 2-D and 4-D as specified in ASTM D975-78. 
(These three methods are incorporated by reference--see Sec. 60.17.)
    (c) Petroleum refinery means each facility engaged in producing 
gasoline, kerosene, distillate fuel oils, residual fuel oils, 
lubricants, or other products through distillation of petroleum or 
through redistillation, cracking, extracting, or reforming of unfinished 
petroleum derivatives.
    (d) Petroleum means the crude oil removed from the earth and the 
oils derived from tar sands, shale, and coal.
    (e) Condensate means hydrocarbon liquid separated from natural gas 
which condenses due to changes in the temperature or pressure, or both, 
and remains liquid at standard conditions.
    (f) True vapor pressure means the equilibrium partial pressure 
exerted by a petroleum liquid such as determined in accordance with 
methods described in American Petroleum Institute Bulletin 2517, 
Evaporation Loss from External Floating-Roof Tanks, Second Edition, 
February 1980 (incorporated by reference--see Sec. 60.17).
    (g) Reid vapor pressure is the absolute vapor pressure of volatile 
crude oil and nonviscous petroleum liquids, except liquified petroleum 
gases, as determined by ASTM D323-82 (incorporated by reference--see 
Sec. 60.17).
    (h) Liquid-mounted seal means a foam or liquid-filled primary seal 
mounted in contact with the liquid between the tank wall and the 
floating roof continuously around the circumference of the tank.
    (i) Metallic shoe seal includes but is not limited to a metal sheet 
held vertically against the tank wall by springs or weighted levers and 
is connected by braces to the floating roof. A flexible coated fabric 
(envelope) spans the annular space between the metal sheet and the 
floating roof.
    (j) Vapor-mounted seal means a foam-filled primary seal mounted 
continuously around the circumference of the tank so there is an annular 
vapor space underneath the seal. The annular vapor space is bounded by 
the bottom of the primary seal, the tank wall, the liquid surface, and 
the floating roof.
    (k) Custody transfer means the transfer of produced petroleum and/or 
condensate, after processing and/or treating in the producing 
operations, from storage tanks or automatic transfer facilities to 
pipelines or any other forms of transportation.

[45 FR 23379, Apr. 4, 1980, as amended at 48 FR 3737, Jan. 27, 1983; 52 
FR 11429, Apr. 8, 1987]



Sec. 60.112a  Standard for volatile organic compounds (VOC).

    (a) The owner or operator of each storage vessel to which this 
subpart applies which contains a petroleum liquid which, as stored, has 
a true vapor pressure equal to or greater than 10.3 kPa (1.5 psia) but 
not greater than 76.6 kPa (11.1 psia) shall equip the storage vessel 
with one of the following:
    (1) An external floating roof, consisting of a pontoon-type or 
double-deck-type cover that rests on the surface of the liquid contents 
and is equipped with a closure device between the tank wall and the roof 
edge. Except as provided in paragraph (a)(1)(ii)(D) of this section, the 
closure device is to consist of two seals, one above the other. The 
lower seal is referred to as the primary seal and the upper seal is 
referred to as the secondary seal. The roof is to be floating on the 
liquid at all times (i.e., off the roof leg supports) except during 
initial fill and when the tank is completely emptied and subsequently 
refilled. The process of emptying and refilling when the roof is resting 
on the leg supports shall be continuous and shall be accomplished as 
rapidly as possible.
    (i) The primary seal is to be either a metallic shoe seal, a liquid-
mounted seal, or a vapor-mounted seal. Each seal is to meet the 
following requirements:
    (A) The accumulated area of gaps between the tank wall and the 
metallic shoe seal or the liquid-mounted seal shall not exceed 212 
cm2 per meter of tank diameter (10.0 in 2per ft of 
tank diameter) and the width of any portion of

[[Page 214]]

any gap shall not exceed 3.81 cm (1\1/2\ in).
    (B) The accumulated area of gaps between the tank wall and the 
vapor-mounted seal shall not exceed 21.2 cm2 per meter of 
tank diameter (1.0 in2 per ft of tank diameter) and the width 
of any portion of any gap shall not exceed 1.27 cm (\1/2\ in).
    (C) One end of the metallic shoe is to extend into the stored liquid 
and the other end is to extend a minimum vertical distance of 61 cm (24 
in) above the stored liquid surface.
    (D) There are to be no holes, tears, or other openings in the shoe, 
seal fabric, or seal envelope.
    (ii) The secondary seal is to meet the following requirements:
    (A) The secondary seal is to be installed above the primary seal so 
that it completely covers the space between the roof edge and the tank 
wall except as provided in paragraph (a)(1)(ii)(B) of this section.
    (B) The accumulated area of gaps between the tank wall and the 
secondary seal used in combination with a metallic shoe or liquid-
mounted primary seal shall not exceed 21.2 cm2per meter of 
tank diameter (1.0 in2per ft. of tank diameter) and the width 
of any portion of any gap shall not exceed 1.27 cm (\1/2\ in.). There 
shall be no gaps between the tank wall and the secondary seal used in 
combination with a vapor-mounted primary seal.
    (C) There are to be no holes, tears or other openings in the seal or 
seal fabric.
    (D) The owner or operator is exempted from the requirements for 
secondary seals and the secondary seal gap criteria when performing gap 
measurements or inspections of the primary seal.
    (iii) Each opening in the roof except for automatic bleeder vents 
and rim space vents is to provide a projection below the liquid surface. 
Each opening in the roof except for automatic bleeder vents, rim space 
vents and leg sleeves is to be equipped with a cover, seal or lid which 
is to be maintained in a closed position at all times (i.e., no visible 
gap) except when the device is in actual use or as described in pargraph 
(a)(1)(iv) of this section. Automatic bleeder vents are to be closed at 
all times when the roof is floating, except when the roof is being 
floated off or is being landed on the roof leg supports. Rim vents are 
to be set to open when the roof is being floated off the roof legs 
supports or at the manufacturer's recommended setting.
    (iv) Each emergency roof drain is to be provided with a slotted 
membrane fabric cover that covers at least 90 percent of the area of the 
opening.
    (2) A fixed roof with an internal floating type cover equipped with 
a continuous closure device between the tank wall and the cover edge. 
The cover is to be floating at all times, (i.e., off the leg supports) 
except during initial fill and when the tank is completely emptied and 
subsequently refilled. The process of emptying and refilling when the 
cover is resting on the leg supports shall be continuous and shall be 
accomplished as rapidly as possible. Each opening in the cover except 
for automatic bleeder vents and the rim space vents is to provide a 
projection below the liquid surface. Each opening in the cover except 
for automatic bleeder vents, rim space vents, stub drains and leg 
sleeves is to be equipped with a cover, seal, or lid which is to be 
maintained in a closed position at all times (i.e., no visible gap) 
except when the device is in actual use. Automatic bleeder vents are to 
be closed at all times when the cover is floating except when the cover 
is being floated off or is being landed on the leg supports. Rim vents 
are to be set to open only when the cover is being floated off the leg 
supports or at the manufacturer's recommended setting.
    (3) A vapor recovery system which collects all VOC vapors and gases 
discharged from the storage vessel, and a vapor return or disposal 
system which is designed to process such VOC vapors and gases so as to 
reduce their emission to the atmosphere by at least 95 percent by 
weight.
    (4) A system equivalent to those described in paragraphs (a)(1), 
(a)(2), or (a)(3) of this section as provided in Sec. 60.114a.
    (b) The owner or operator of each storage vessel to which this 
subpart applies which contains a petroleum liquid

[[Page 215]]

which, as stored, has a true vapor pressure greater than 76.6 kPa (11.1 
psia), shall equip the storage vessel with a vapor recovery system which 
collects all VOC vapors and gases discharged from the storage vessel, 
and a vapor return or disposal system which is designed to process such 
VOC vapors and gases so as to reduce their emission to the atmosphere by 
at least 95 percent by weight.

[45 FR 23379, Apr. 4, 1980, as amended at 45 FR 83229, Dec. 18, 1980]



Sec. 60.113a  Testing and procedures.

    (a) Except as provided in Sec. 60.8(b) compliance with the standard 
prescribed in Sec. 60.112a shall be determined as follows or in 
accordance with an equivalent procedure as provided in Sec. 60.114a.
    (1) The owner or operator of each storage vessel to which this 
subpart applies which has an external floating roof shall meet the 
following requirements:
    (i) Determine the gap areas and maximum gap widths between the 
primary seal and the tank wall and between the secondary seal and the 
tank wall according to the following frequency:
    (A) For primary seals, gap measurements shall be performed within 60 
days of the initial fill with petroleum liquid and at least once every 
five years thereafter. All primary seal inspections or gap measurements 
which require the removal or dislodging of the secondary seal shall be 
accomplished as rapidly as possible and the secondary seal shall be 
replaced as soon as possible.
    (B) For secondary seals, gap measurements shall be performed within 
60 days of the initial fill with petroleum liquid and at least once 
every year thereafter.
    (C) If any storage vessel is out of service for a period of one year 
or more, subsequent refilling with petroleum liquid shall be considered 
initial fill for the purposes of paragraphs (a)(1)(i)(A) and 
(a)(1)(i)(B) of this section.
    (D) Keep records of each gap measurement at the plant for a period 
of at least 2 years following the date of measurement. Each record shall 
identify the vessel on which the measurement was performed and shall 
contain the date of the seal gap measurement, the raw data obtained in 
the measurement process required by paragraph (a)(1)(ii) of this section 
and the calculation required by paragraph (a)(1)(iii) of this section.
    (E) If either the seal gap calculated in accord with paragraph 
(a)(1)(iii) of this section or the measured maximum seal gap exceeds the 
limitations specified by Sec. 60.112a of this subpart, a report shall be 
furnished to the Administrator within 60 days of the date of 
measurements. The report shall identify the vessel and list each reason 
why the vessel did not meet the specifications of Sec. 60.112a. The 
report shall also describe the actions necessary to bring the storage 
vessel into compliance with the specifications of Sec. 60.112a.
    (ii) Determine gap widths in the primary and secondary seals 
individually by the following procedures:
    (A) Measure seal gaps, if any, at one or more floating roof levels 
when the roof is floating off the roof leg supports.
    (B) Measure seal gaps around the entire circumference of the tank in 
each place where a \1/8\" diameter uniform probe passes freely (without 
forcing or binding against seal) between the seal and the tank wall and 
measure the circumferential distance of each such location.
    (C) The total surface area of each gap described in paragraph 
(a)(1)(ii)(B) of this section shall be determined by using probes of 
various widths to accurately measure the actual distance from the tank 
wall to the seal and multiplying each such width by its respective 
circumferential distance.
    (iii) Add the gap surface area of each gap location for the primary 
seal and the secondary seal individually. Divide the sum for each seal 
by the nominal diameter of the tank and compare each ratio to the 
appropriate ratio in the standard in Sec. 60.112a(a)(1)(i) and 
Sec. 60.112a(a)(1)(ii).
    (iv) Provide the Administrator 30 days prior notice of the gap 
measurement to afford the Administrator the opportunity to have an 
observer present.

[[Page 216]]

    (2) The owner or operator of each storage vessel to which this 
subpart applies which has a vapor recovery and return or disposal system 
shall provide the following information to the Administrator on or 
before the date on which construction of the storage vessel commences:
    (i) Emission data, if available, for a similar vapor recovery and 
return or disposal system used on the same type of storage vessel, which 
can be used to determine the efficiency of the system. A complete 
description of the emission measurement method used must be included.
    (ii) The manufacturer's design specifications and estimated emission 
reduction capability of the system.
    (iii) The operation and maintenance plan for the system.
    (iv) Any other information which will be useful to the Administrator 
in evaluating the effectiveness of the system in reducing VOC emissions.

[45 FR 23379, Apr. 4, 1980, as amended at 52 FR 11429, Apr. 8, 1987]



Sec. 60.114a  Alternative means of emission limitation.

    (a) If, in the Administrator's judgment, an alternative means of 
emission limitation will achieve a reduction in emissions at least 
equivalent to the reduction in emissions achieved by any requirement in 
Sec. 60.112a, the Administrator will publish in the Federal Register a 
notice permitting the use of the alternative means for purposes of 
compliance with that requirement.
    (b) Any notice under paragraph (a) of this section will be published 
only after notice and an opportunity for a hearing.
    (c) Any person seeking permission under this section shall submit to 
the Administrator a written application including:
    (1) An actual emissions test that uses a full-sized or scale-model 
storage vessel that accurately collects and measures all VOC emissions 
from a given control device and that accurately simulates wind and 
accounts for other emission variables such as temperature and barometric 
pressure.
    (2) An engineering evaluation that the Administrator determines is 
an accurate method of determining equivalence.
    (d) The Administrator may condition the permission on requirements 
that may be necessary to ensure operation and maintenance to achieve the 
same emissions reduction as specified in Sec. 60.112a.
    (e) The primary vapor-mounted seal in the ``Volume-Maximizing Seal'' 
manufactured by R.F.I. Services Corporation is approved as equivalent to 
the vapor-mounted seal required by Sec. 60.112a(a)(1)(i) and must meet 
the gap criteria specified in Sec. 60.112a(a)(1)(i)(B). There shall be 
no gaps between the tank wall and any secondary seal used in conjunction 
with the primary seal in the ``Volume-Maximizing Seal''.

[52 FR 11429, Apr. 8, 1987]



Sec. 60.115a  Monitoring of operations.

    (a) Except as provided in paragraph (d) of this section, the owner 
or operator subject to this subpart shall maintain a record of the 
petroleum liquid stored, the period of storage, and the maximum true 
vapor pressure of that liquid during the respective storage period.
    (b) Available data on the typical Reid vapor pressure and the 
maximum expected storage temperature of the stored product may be used 
to determine the maximum true vapor pressure from nomographs contained 
in API Bulletin 2517, unless the Administrator specifically requests 
that the liquid be sampled, the actual storage temperature determined, 
and the Reid vapor pressure determined from the sample(s).
    (c) The true vapor pressure of each type of crude oil with a Reid 
vapor pressure less than 13.8 kPa (2.0 psia) or whose physical 
properties preclude determination by the recommended method is to be 
determined from available data and recorded if the estimated true vapor 
pressure is greater than 6.9 kPa (1.0 psia).
    (d) The following are exempt from the requirements of this section:
    (1) Each owner or operator of each storage vessel storing a 
petroleum liquid with a Reid vapor pressure of less than 6.9 kPa (1.0 
psia) provided the maximum true vapor pressure does not exceed 6.9 kPa 
(1.0 psia).

[[Page 217]]

    (2) Each owner or operator of each storage vessel equipped with a 
vapor recovery and return or disposal system in accordance with the 
requirements of Sec. 60.112a (a)(3) and (b).

[45 FR 23379, Apr. 4, 1980]



Subpart Kb--Standards of Performance for Volatile Organic Liquid Storage 
     Vessels (Including Petroleum Liquid Storage Vessels) for Which 
 Construction, Reconstruction, or Modification Commenced After July 23, 
                                  1984

    Source: 52 FR 11429, Apr. 8, 1987, unless otherwise noted.



Sec. 60.110b  Applicability and designation of affected facility.

    (a) Except as provided in paragraphs (b), (c), and (d) of this 
section, the affected facility to which this subpart applies is each 
storage vessel with a capacity greater than or equal to 40 cubic meters 
(m3) that is used to store volatile organic liquids (VOL's) 
for which construction, reconstruction, or modification is commenced 
after July 23, 1984.
    (b) Except as specified in paragraphs (a) and (b) of Sec. 60.116b, 
storage vessels with design capacity less than 75 m3 are 
exempt from the General Provisions (part 60, subpart A) and from the 
provisions of this subpart.
    (c) Except as specified in paragraphs (a) and (b) of Sec. 60.116b, 
vessels either with a capacity greater than or equal to 151 m\3\ storing 
a liquid with a maximum true vapor pressure less than 3.5 kPa or with a 
capacity greater than or equal to 75 m\3\ but less than 151 m\3\ storing 
a liquid with a maximum true vapor pressure less than 15.0 kPa are 
exempt from the General Provisions (part 60, subpart A) and from the 
provisions of this subpart.
    (d) This subpart does not apply to the following:
    (1) Vessels at coke oven by-product plants.
    (2) Pressure vessels designed to operate in excess of 204.9 kPa and 
without emissions to the atmosphere.
    (3) Vessels permanently attached to mobile vehicles such as trucks, 
railcars, barges, or ships.
    (4) Vessels with a design capacity less than or equal to 1,589.874 
m3 used for petroleum or condensate stored, processed, or 
treated prior to custody transfer.
    (5) Vessels located at bulk gasoline plants.
    (6) Storage vessels located at gasoline service stations.
    (7) Vessels used to store beverage alcohol.

[52 FR 11429, Apr. 8, 1987, as amended at 54 FR 32973, Aug. 11, 1989]



Sec. 60.111b  Definitions.

    Terms used in this subpart are defined in the Act, in subpart A of 
this part, or in this subpart as follows:
    (a) Bulk gasoline plant means any gasoline distribution facility 
that has a gasoline throughput less than or equal to 75,700 liters per 
day. Gasoline throughput shall be the maximum calculated design 
throughput as may be limited by compliance with an enforceable condition 
under Federal requirement or Federal, State or local law, and 
discoverable by the Administrator and any other person.
    (b) Condensate means hydrocarbon liquid separated from natural gas 
that condenses due to changes in the temperature or pressure, or both, 
and remains liquid at standard conditions.
    (c) Custody transfer means the transfer of produced petroleum and/or 
condensate, after processing and/or treatment in the producing 
operations, from storage vessels or automatic transfer facilities to 
pipelines or any other forms of transportation.
    (d) Fill means the introduction of VOL into a storage vessel but not 
necessarily to complete capacity.
    (e) Gasoline service station means any site where gasoline is 
dispensed to motor vehicle fuel tanks from stationary storage tanks.
    (f) Maximum true vapor pressure means the equilibrium partial 
pressure exerted by the stored VOL at the temperature equal to the 
highest calendar-month average of the VOL storage temperature for VOL's 
stored above or below the ambient temperature or at the local maximum 
monthly average

[[Page 218]]

temperature as reported by the National Weather Service for VOL's stored 
at the ambient temperature, as determined:
    (1) In accordance with methods described in American Petroleum 
institute Bulletin 2517, Evaporation Loss From External Floating Roof 
Tanks, (incorporated by reference--see Sec. 60.17); or
    (2) As obtained from standard reference texts; or
    (3) As determined by ASTM Method D2879-83 (incorporated by 
reference--see Sec. 60.17);
    (4) Any other method approved by the Administrator.
    (g) Reid vapor pressure means the absolute vapor pressure of 
volatile crude oil and volatile nonviscous petroleum liquids except 
liquified petroleum gases, as determined by ASTM D323-82 (incorporated 
by reference--see Sec. 60.17).
    (h) Petroleum means the crude oil removed from the earth and the 
oils derived from tar sands, shale, and coal.
    (i) Petroleum liquids means petroleum, condensate, and any finished 
or intermediate products manufactured in a petroleum refinery.
    (j) Storage vessel means each tank, reservoir, or container used for 
the storage of volatile organic liquids but does not include:
    (1) Frames, housing, auxiliary supports, or other components that 
are not directly involved in the containment of liquids or vapors; or
    (2) Subsurface caverns or porous rock reservoirs.
    (k) Volatile organic liquid (VOL) means any organic liquid which can 
emit volatile organic compounds into the atmosphere except those VOL's 
that emit only those compounds which the Administrator has determined do 
not contribute appreciably to the formation of ozone. These compounds 
are identified in EPA statements on ozone abatement policy for SIP 
revisions (42 FR 35314, 44 FR 32042, 45 FR 32424, and 45 FR 48941).
    (l) Waste means any liquid resulting from industrial, commercial, 
mining or agricultural operations, or from community activities that is 
discarded or is being accumulated, stored, or physically, chemically, or 
biologically treated prior to being discarded or recycled.

[52 FR 11429, Apr. 8, 1987, as amended at 54 FR 32973, Aug. 11, 1989]



Sec. 60.112b  Standard for volatile organic compounds (VOC).

    (a) The owner or operator of each storage vessel either with a 
design capacity greater than or equal to 151 m\3\ containing a VOL that, 
as stored, has a maximum true vapor pressure equal to or greater than 
5.2 kPa but less than 76.6 kPa or with a design capacity greater than or 
equal to 75 m\3\ but less than 151 m\3\ containing a VOL that, as 
stored, has a maximum true vapor pressure equal to or greater than 27.6 
kPa but less than 76.6 kPa, shall equip each storage vessel with one of 
the following:
    (1) A fixed roof in combination with an internal floating roof 
meeting the following specifications:
    (i) The internal floating roof shall rest or float on the liquid 
surface (but not necessarily in complete contact with it) inside a 
storage vessel that has a fixed roof. The internal floating roof shall 
be floating on the liquid surface at all times, except during initial 
fill and during those intervals when the storage vessel is completely 
emptied or subsequently emptied and refilled. When the roof is resting 
on the leg supports, the process of filling, emptying, or refilling 
shall be continuous and shall be accomplished as rapidly as possible.
    (ii) Each internal floating roof shall be equipped with one of the 
following closure devices between the wall of the storage vessel and the 
edge of the internal floating roof:
    (A) A foam- or liquid-filled seal mounted in contact with the liquid 
(liquid-mounted seal). A liquid-mounted seal means a foam- or liquid-
filled seal mounted in contact with the liquid between the wall of the 
storage vessel and the floating roof continuously around the 
circumference of the tank.
    (B) Two seals mounted one above the other so that each forms a 
continuous closure that completely covers the space between the wall of 
the storage vessel and the edge of the internal floating roof. The lower 
seal may be

[[Page 219]]

vapor-mounted, but both must be continuous.
    (C) A mechanical shoe seal. A mechanical shoe seal is a metal sheet 
held vertically against the wall of the storage vessel by springs or 
weighted levers and is connected by braces to the floating roof. A 
flexible coated fabric (envelope) spans the annular space between the 
metal sheet and the floating roof.
    (iii) Each opening in a noncontact internal floating roof except for 
automatic bleeder vents (vacuum breaker vents) and the rim space vents 
is to provide a projection below the liquid surface.
    (iv) Each opening in the internal floating roof except for leg 
sleeves, automatic bleeder vents, rim space vents, column wells, ladder 
wells, sample wells, and stub drains is to be equipped with a cover or 
lid which is to be maintained in a closed position at all times (i.e., 
no visible gap) except when the device is in actual use. The cover or 
lid shall be equipped with a gasket. Covers on each access hatch and 
automatic gauge float well shall be bolted except when they are in use.
    (v) Automatic bleeder vents shall be equipped with a gasket and are 
to be closed at all times when the roof is floating except when the roof 
is being floated off or is being landed on the roof leg supports.
    (vi) Rim space vents shall be equipped with a gasket and are to be 
set to open only when the internal floating roof is not floating or at 
the manufacturer's recommended setting.
    (vii) Each penetration of the internal floating roof for the purpose 
of sampling shall be a sample well. The sample well shall have a slit 
fabric cover that covers at least 90 percent of the opening.
    (viii) Each penetration of the internal floating roof that allows 
for passage of a column supporting the fixed roof shall have a flexible 
fabric sleeve seal or a gasketed sliding cover.
    (ix) Each penetration of the internal floating roof that allows for 
passage of a ladder shall have a gasketed sliding cover.
    (2) An external floating roof. An external floating roof means a 
pontoon-type or double-deck type cover that rests on the liquid surface 
in a vessel with no fixed roof. Each external floating roof must meet 
the following specifications:
    (i) Each external floating roof shall be equipped with a closure 
device between the wall of the storage vessel and the roof edge. The 
closure device is to consist of two seals, one above the other. The 
lower seal is referred to as the primary seal, and the upper seal is 
referred to as the secondary seal.
    (A) The primary seal shall be either a mechanical shoe seal or a 
liquid-mounted seal. Except as provided in Sec. 60.113b(b)(4), the seal 
shall completely cover the annular space between the edge of the 
floating roof and tank wall.
    (B) The secondary seal shall completely cover the annular space 
between the external floating roof and the wall of the storage vessel in 
a continuous fashion except as allowed in Sec. 60.113b(b)(4).
    (ii) Except for automatic bleeder vents and rim space vents, each 
opening in a noncontact external floating roof shall provide a 
projection below the liquid surface. Except for automatic bleeder vents, 
rim space vents, roof drains, and leg sleeves, each opening in the roof 
is to be equipped with a gasketed cover, seal, or lid that is to be 
maintained in a closed position at all times (i.e., no visible gap) 
except when the device is in actual use. Automatic bleeder vents are to 
be closed at all times when the roof is floating except when the roof is 
being floated off or is being landed on the roof leg supports. Rim vents 
are to be set to open when the roof is being floated off the roof legs 
supports or at the manufacturer's recommended setting. Automatic bleeder 
vents and rim space vents are to be gasketed. Each emergency roof drain 
is to be provided with a slotted membrane fabric cover that covers at 
least 90 percent of the area of the opening.
    (iii) The roof shall be floating on the liquid at all times (i.e., 
off the roof leg supports) except during initial fill until the roof is 
lifted off leg supports and when the tank is completely emptied and 
subsequently refilled. The process of filling, emptying, or refilling 
when the roof is resting on the leg supports shall be continuous and 
shall be accomplished as rapidly as possible.

[[Page 220]]

    (3) A closed vent system and control device meeting the following 
specifications:
    (i) The closed vent system shall be designed to collect all VOC 
vapors and gases discharged from the storage vessel and operated with no 
detectable emissions as indicated by an instrument reading of less than 
500 ppm above background and visual inspections, as determined in part 
60, subpart VV, Sec. 60.485(b).
    (ii) The control device shall be designed and operated to reduce 
inlet VOC emissions by 95 percent or greater. If a flare is used as the 
control device, it shall meet the specifications described in the 
general control device requirements (Sec. 60.18) of the General 
Provisions.
    (4) A system equivalent to those described in paragraphs (a)(1), 
(a)(2), or (a)(3) of this section as provided in Sec. 60.114b of this 
subpart.
    (b) The owner or operator of each storage vessel with a design 
capacity greater than or equal to 75 m3 which contains a VOL 
that, as stored, has a maximum true vapor pressure greater than or equal 
to 76.6 kPa shall equip each storage vessel with one of the following:
    (1) A closed vent system and control device as specified in 
Sec. 60.112b(a)(3).
    (2) A system equivalent to that described in paragraph (b)(1) as 
provided in Sec. 60.114b of this subpart.
    (c) Site-specific standard for Merck & Co., Inc.'s Stonewall Plant 
in Elkton, Virginia. This paragraph applies only to the pharmaceutical 
manufacturing facility, commonly referred to as the Stonewall Plant, 
located at Route 340 South, in Elkton, Virginia (``site'').
    (1) For any storage vessel that otherwise would be subject to the 
control technology requirements of paragraphs (a) or (b) of this 
section, the site shall have the option of either complying directly 
with the requirements of this subpart, or reducing the site-wide total 
criteria pollutant emissions cap (total emissions cap) in accordance 
with the procedures set forth in a permit issued pursuant to 40 CFR 
52.2454. If the site chooses the option of reducing the total emissions 
cap in accordance with the procedures set forth in such permit, the 
requirements of such permit shall apply in lieu of the otherwise 
applicable requirements of this subpart for such storage vessel.
    (2) For any storage vessel at the site not subject to the 
requirements of 40 CFR 60.112b (a) or (b), the requirements of 40 CFR 
60.116b (b) and (c) and the General Provisions (subpart A of this part) 
shall not apply.

[52 FR 11429, Apr. 8, 1987, as amended at 62 FR 52641, Oct. 8, 1997]



Sec. 60.113b  Testing and procedures.

    The owner or operator of each storage vessel as specified in 
Sec. 60.112b(a) shall meet the requirements of paragraph (a), (b), or 
(c) of this section. The applicable paragraph for a particular storage 
vessel depends on the control equipment installed to meet the 
requirements of Sec. 60.112b.
    (a) After installing the control equipment required to meet 
Sec. 60.112b(a)(1) (permanently affixed roof and internal floating 
roof), each owner or operator shall:
    (1) Visually inspect the internal floating roof, the primary seal, 
and the secondary seal (if one is in service), prior to filling the 
storage vessel with VOL. If there are holes, tears, or other openings in 
the primary seal, the secondary seal, or the seal fabric or defects in 
the internal floating roof, or both, the owner or operator shall repair 
the items before filling the storage vessel.
    (2) For Vessels equipped with a liquid-mounted or mechanical shoe 
primary seal, visually inspect the internal floating roof and the 
primary seal or the secondary seal (if one is in service) through 
manholes and roof hatches on the fixed roof at least once every 12 
months after initial fill. If the internal floating roof is not resting 
on the surface of the VOL inside the storage vessel, or there is liquid 
accumulated on the roof, or the seal is detached, or there are holes or 
tears in the seal fabric, the owner or operator shall repair the items 
or empty and remove the storage vessel from service within 45 days. If a 
failure that is detected during inspections required in this paragraph 
cannot be repaired within 45 days and if the vessel cannot be

[[Page 221]]

emptied within 45 days, a 30-day extension may be requested from the 
Administrator in the inspection report required in Sec. 60.115b(a)(3). 
Such a request for an extension must document that alternate storage 
capacity is unavailable and specify a schedule of actions the company 
will take that will assure that the control equipment will be repaired 
or the vessel will be emptied as soon as possible.
    (3) For vessels equipped with a double-seal system as specified in 
Sec. 60.112b(a)(1)(ii)(B):
    (i) Visually inspect the vessel as specified in paragraph (a)(4) of 
this section at least every 5 years; or
    (ii) Visually inspect the vessel as specified in paragraph (a)(2) of 
this section.
    (4) Visually inspect the internal floating roof, the primary seal, 
the secondary seal (if one is in service), gaskets, slotted membranes 
and sleeve seals (if any) each time the storage vessel is emptied and 
degassed. If the internal floating roof has defects, the primary seal 
has holes, tears, or other openings in the seal or the seal fabric, or 
the secondary seal has holes, tears, or other openings in the seal or 
the seal fabric, or the gaskets no longer close off the liquid surfaces 
from the atmosphere, or the slotted membrane has more than 10 percent 
open area, the owner or operator shall repair the items as necessary so 
that none of the conditions specified in this paragraph exist before 
refilling the storage vessel with VOL. In no event shall inspections 
conducted in accordance with this provision occur at intervals greater 
than 10 years in the case of vessels conducting the annual visual 
inspection as specified in paragraphs (a)(2) and (a)(3)(ii) of this 
section and at intervals no greater than 5 years in the case of vessels 
specified in paragraph (a)(3)(i) of this section.
    (5) Notify the Administrator in writing at least 30 days prior to 
the filling or refilling of each storage vessel for which an inspection 
is required by paragraphs (a)(1) and (a)(4) of this section to afford 
the Administrator the opportunity to have an observer present. If the 
inspection required by paragraph (a)(4) of this section is not planned 
and the owner or operator could not have known about the inspection 30 
days in advance or refilling the tank, the owner or operator shall 
notify the Administrator at least 7 days prior to the refilling of the 
storage vessel. Notification shall be made by telephone immediately 
followed by written documentation demonstrating why the inspection was 
unplanned. Alternatively, this notification including the written 
documentation may be made in writing and sent by express mail so that it 
is received by the Administrator at least 7 days prior to the refilling.
    (b) After installing the control equipment required to meet 
Sec. 60.112b(a)(2) (external floating roof), the owner or operator 
shall:
    (1) Determine the gap areas and maximum gap widths, between the 
primary seal and the wall of the storage vessel and between the 
secondary seal and the wall of the storage vessel according to the 
following frequency.
    (i) Measurements of gaps between the tank wall and the primary seal 
(seal gaps) shall be performed during the hydrostatic testing of the 
vessel or within 60 days of the initial fill with VOL and at least once 
every 5 years thereafter.
    (ii) Measurements of gaps between the tank wall and the secondary 
seal shall be performed within 60 days of the initial fill with VOL and 
at least once per year thereafter.
    (iii) If any source ceases to store VOL for a period of 1 year or 
more, subsequent introduction of VOL into the vessel shall be considered 
an initial fill for the purposes of paragraphs (b)(1)(i) and (b)(1)(ii) 
of this section.
    (2) Determine gap widths and areas in the primary and secondary 
seals individually by the following procedures:
    (i) Measure seal gaps, if any, at one or more floating roof levels 
when the roof is floating off the roof leg supports.
    (ii) Measure seal gaps around the entire circumference of the tank 
in each place where a 0.32-cm diameter uniform probe passes freely 
(without forcing or binding against seal) between the seal and the wall 
of the storage vessel and measure the circumferential distance of each 
such location.
    (iii) The total surface area of each gap described in paragraph 
(b)(2)(ii) of

[[Page 222]]

this section shall be determined by using probes of various widths to 
measure accurately the actual distance from the tank wall to the seal 
and multiplying each such width by its respective circumferential 
distance.
    (3) Add the gap surface area of each gap location for the primary 
seal and the secondary seal individually and divide the sum for each 
seal by the nominal diameter of the tank and compare each ratio to the 
respective standards in paragraph (b)(4) of this section.
    (4) Make necessary repairs or empty the storage vessel within 45 
days of identification in any inspection for seals not meeting the 
requirements listed in (b)(4) (i) and (ii) of this section:
    (i) The accumulated area of gaps between the tank wall and the 
mechanical shoe or liquid-mounted primary seal shall not exceed 212 
Cm\2\ per meter of tank diameter, and the width of any portion of any 
gap shall not exceed 3.81 cm.
    (A) One end of the mechanical shoe is to extend into the stored 
liquid, and the other end is to extend a minimum vertical distance of 61 
cm above the stored liquid surface.
    (B) There are to be no holes, tears, or other openings in the shoe, 
seal fabric, or seal envelope.
    (ii) The secondary seal is to meet the following requirements:
    (A) The secondary seal is to be installed above the primary seal so 
that it completely covers the space between the roof edge and the tank 
wall except as provided in paragraph (b)(2)(iii) of this section.
    (B) The accumulated area of gaps between the tank wall and the 
secondary seal shall not exceed 21.2 cm2 per meter of tank 
diameter, and the width of any portion of any gap shall not exceed 1.27 
cm.
    (C) There are to be no holes, tears, or other openings in the seal 
or seal fabric.
    (iii) If a failure that is detected during inspections required in 
paragraph (b)(1) of Sec. 60.113b(b) cannot be repaired within 45 days 
and if the vessel cannot be emptied within 45 days, a 30-day extension 
may be requested from the Administrator in the inspection report 
required in Sec. 60.115b(b)(4). Such extension request must include a 
demonstration of unavailability of alternate storage capacity and a 
specification of a schedule that will assure that the control equipment 
will be repaired or the vessel will be emptied as soon as possible.
    (5) Notify the Administrator 30 days in advance of any gap 
measurements required by paragraph (b)(1) of this section to afford the 
Administrator the opportunity to have an observer present.
    (6) Visually inspect the external floating roof, the primary seal, 
secondary seal, and fittings each time the vessel is emptied and 
degassed.
    (i) If the external floating roof has defects, the primary seal has 
holes, tears, or other openings in the seal or the seal fabric, or the 
secondary seal has holes, tears, or other openings in the seal or the 
seal fabric, the owner or operator shall repair the items as necessary 
so that none of the conditions specified in this paragraph exist before 
filling or refilling the storage vessel with VOL.
    (ii) For all the inspections required by paragraph (b)(6) of this 
section, the owner or operator shall notify the Administrator in writing 
at least 30 days prior to the filling or refilling of each storage 
vessel to afford the Administrator the opportunity to inspect the 
storage vessel prior to refilling. If the inspection required by 
paragraph (b)(6) of this section is not planned and the owner or 
operator could not have known about the inspection 30 days in advance of 
refilling the tank, the owner or operator shall notify the Administrator 
at least 7 days prior to the refilling of the storage vessel. 
Notification shall be made by telephone immediately followed by written 
documentation demonstrating why the inspection was unplanned. 
Alternatively, this notification including the written documentation may 
be made in writing and sent by express mail so that it is received by 
the Administrator at least 7 days prior to the refilling.
    (c) The owner or operator of each source that is equipped with a 
closed vent system and control device as required in Sec. 60.112b (a)(3) 
or (b)(2) (other than a flare) is exempt from Sec. 60.8 of the General 
Provisions and shall meet the following requirements.

[[Page 223]]

    (1) Submit for approval by the Administrator as an attachment to the 
notification required by Sec. 60.7(a)(1) or, if the facility is exempt 
from Sec. 60.7(a)(1), as an attachment to the notification required by 
Sec. 60.7(a)(2), an operating plan containing the information listed 
below.
    (i) Documentation demonstrating that the control device will achieve 
the required control efficiency during maximum loading conditions. This 
documentation is to include a description of the gas stream which enters 
the control device, including flow and VOC content under varying liquid 
level conditions (dynamic and static) and manufacturer's design 
specifications for the control device. If the control device or the 
closed vent capture system receives vapors, gases, or liquids other than 
fuels from sources that are not designated sources under this subpart, 
the efficiency demonstration is to include consideration of all vapors, 
gases, and liquids received by the closed vent capture system and 
control device. If an enclosed combustion device with a minimum 
residence time of 0.75 seconds and a minimum temperature of 816  deg.C 
is used to meet the 95 percent requirement, documentation that those 
conditions will exist is sufficient to meet the requirements of this 
paragraph.
    (ii) A description of the parameter or parameters to be monitored to 
ensure that the control device will be operated in conformance with its 
design and an explanation of the criteria used for selection of that 
parameter (or parameters).
    (2) Operate the closed vent system and control device and monitor 
the parameters of the closed vent system and control device in 
accordance with the operating plan submitted to the Administrator in 
accordance with paragraph (c)(1) of this section, unless the plan was 
modified by the Administrator during the review process. In this case, 
the modified plan applies.
    (d) The owner or operator of each source that is equipped with a 
closed vent system and a flare to meet the requirements in Sec. 60.112b 
(a)(3) or (b)(2) shall meet the requirements as specified in the general 
control device requirements, Sec. 60.18 (e) and (f).

[52 FR 11429, Apr. 8, 1987, as amended at 54 FR 32973, Aug. 11, 1989]



Sec. 60.114b  Alternative means of emission limitation.

    (a) If, in the Administrator's judgment, an alternative means of 
emission limitation will achieve a reduction in emissions at least 
equivalent to the reduction in emissions achieved by any requirement in 
Sec. 60.112b, the Administrator will publish in the Federal Register a 
notice permitting the use of the alternative means for purposes of 
compliance with that requirement.
    (b) Any notice under paragraph (a) of this section will be published 
only after notice and an opportunity for a hearing.
    (c) Any person seeking permission under this section shall submit to 
the Administrator a written application including:
    (1) An actual emissions test that uses a full-sized or scale-model 
storage vessel that accurately collects and measures all VOC emissions 
from a given control device and that accurately simulates wind and 
accounts for other emission variables such as temperature and barometric 
pressure.
    (2) An engineering evaluation that the Administrator determines is 
an accurate method of determining equivalence.
    (d) The Administrator may condition the permission on requirements 
that may be necessary to ensure operation and maintenance to achieve the 
same emissions reduction as specified in Sec. 60.112b.



Sec. 60.115b  Reporting and recordkeeping requirements.

    The owner or operator of each storage vessel as specified in 
Sec. 60.112b(a) shall keep records and furnish reports as required by 
paragraphs (a), (b), or (c) of this section depending upon the control 
equipment installed to meet the requirements of Sec. 60.112b. The owner 
or operator shall keep copies of all reports and records required by 
this section, except for the record required by (c)(1), for at least 2 
years. The record required by (c)(1) will be kept for the life of the 
control equipment.

[[Page 224]]

    (a) After installing control equipment in accordance with 
Sec. 60.112b(a)(1) (fixed roof and internal floating roof), the owner or 
operator shall meet the following requirements.
    (1) Furnish the Administrator with a report that describes the 
control equipment and certifies that the control equipment meets the 
specifications of Sec. 60.112b(a)(1) and Sec. 60.113b(a)(1). This report 
shall be an attachment to the notification required by Sec. 60.7(a)(3).
    (2) Keep a record of each inspection performed as required by 
Sec. 60.113b (a)(1), (a)(2), (a)(3), and (a)(4). Each record shall 
identify the storage vessel on which the inspection was performed and 
shall contain the date the vessel was inspected and the observed 
condition of each component of the control equipment (seals, internal 
floating roof, and fittings).
    (3) If any of the conditions described in Sec. 60.113b(a)(2) are 
detected during the annual visual inspection required by 
Sec. 60.113b(a)(2), a report shall be furnished to the Administrator 
within 30 days of the inspection. Each report shall identify the storage 
vessel, the nature of the defects, and the date the storage vessel was 
emptied or the nature of and date the repair was made.
    (4) After each inspection required by Sec. 60.113b(a)(3) that finds 
holes or tears in the seal or seal fabric, or defects in the internal 
floating roof, or other control equipment defects listed in 
Sec. 60.113b(a)(3)(ii), a report shall be furnished to the Administrator 
within 30 days of the inspection. The report shall identify the storage 
vessel and the reason it did not meet the specifications of 
Sec. 61.112b(a)(1) or Sec. 60.113b(a)(3) and list each repair made.
    (b) After installing control equipment in accordance with 
Sec. 61.112b(a)(2) (external floating roof), the owner or operator shall 
meet the following requirements.
    (1) Furnish the Administrator with a report that describes the 
control equipment and certifies that the control equipment meets the 
specifications of Sec. 60.112b(a)(2) and Sec. 60.113b(b)(2), (b)(3), and 
(b)(4). This report shall be an attachment to the notification required 
by Sec. 60.7(a)(3).
    (2) Within 60 days of performing the seal gap measurements required 
by Sec. 60.113b(b)(1), furnish the Administrator with a report that 
contains:
    (i) The date of measurement.
    (ii) The raw data obtained in the measurement.
    (iii) The calculations described in Sec. 60.113b (b)(2) and (b)(3).
    (3) Keep a record of each gap measurement performed as required by 
Sec. 60.113b(b). Each record shall identify the storage vessel in which 
the measurement was performed and shall contain:
    (i) The date of measurement.
    (ii) The raw data obtained in the measurement.
    (iii) The calculations described in Sec. 60.113b (b)(2) and (b)(3).
    (4) After each seal gap measurement that detects gaps exceeding the 
limitations specified by Sec. 60.113b(b)(4), submit a report to the 
Administrator within 30 days of the inspection. The report will identify 
the vessel and contain the information specified in paragraph (b)(2) of 
this section and the date the vessel was emptied or the repairs made and 
date of repair.
    (c) After installing control equipment in accordance with 
Sec. 60.112b (a)(3) or (b)(1) (closed vent system and control device 
other than a flare), the owner or operator shall keep the following 
records.
    (1) A copy of the operating plan.
    (2) A record of the measured values of the parameters monitored in 
accordance with Sec. 60.113b(c)(2).
    (d) After installing a closed vent system and flare to comply with 
Sec. 60.112b, the owner or operator shall meet the following 
requirements.
    (1) A report containing the measurements required by Sec. 60.18(f) 
(1), (2), (3), (4), (5), and (6) shall be furnished to the Administrator 
as required by Sec. 60.8 of the General Provisions. This report shall be 
submitted within 6 months of the initial start-up date.
    (2) Records shall be kept of all periods of operation during which 
the flare pilot flame is absent.
    (3) Semiannual reports of all periods recorded under 
Sec. 60.115b(d)(2) in which the pilot flame was absent shall be 
furnished to the Administrator.

[[Page 225]]



Sec. 60.116b  Monitoring of operations.

    (a) The owner or operator shall keep copies of all records required 
by this section, except for the record required by paragraph (b) of this 
section, for at least 2 years. The record required by paragraph (b) of 
this section will be kept for the life of the source.
    (b) The owner or operator of each storage vessel as specified in 
Sec. 60.110b(a) shall keep readily accessible records showing the 
dimension of the storage vessel and an analysis showing the capacity of 
the storage vessel. Each storage vessel with a design capacity less than 
75 m3 is subject to no provision of this subpart other than 
those required by this paragraph.
    (c) Except as provided in paragraphs (f) and (g) of this section, 
the owner or operator of each storage vessel either with a design 
capacity greater than or equal to 151 m3 storing a liquid 
with a maximum true vapor pressure greater than or equal to 3.5 kPa or 
with a design capacity greater than or equal to 75 m3 but 
less than 151 m3 storing a liquid with a maximum true vapor 
pressure greater than or equal to 15.0 kPa shall maintain a record of 
the VOL stored, the period of storage, and the maximum true vapor 
pressure of that VOL during the respective storage period.
    (d) Except as provided in paragraph (g) of this section, the owner 
or operator of each storage vessel either with a design capacity greater 
than or equal to 151 m3 storing a liquid with a maximum true 
vapor pressure that is normally less than 5.2 kPa or with a design 
capacity greater than or equal to 75 m3 but less than 151 
m3 storing a liquid with a maximum true vapor pressure that 
is normally less than 27.6 kPa shall notify the Administrator within 30 
days when the maximum true vapor pressure of the liquid exceeds the 
respective maximum true vapor vapor pressure values for each volume 
range.
    (e) Available data on the storage temperature may be used to 
determine the maximum true vapor pressure as determined below.
    (1) For vessels operated above or below ambient temperatures, the 
maximum true vapor pressure is calculated based upon the highest 
expected calendar-month average of the storage temperature. For vessels 
operated at ambient temperatures, the maximum true vapor pressure is 
calculated based upon the maximum local monthly average ambient 
temperature as reported by the National Weather Service.
    (2) For crude oil or refined petroleum products the vapor pressure 
may be obtained by the following:
    (i) Available data on the Reid vapor pressure and the maximum 
expected storage temperature based on the highest expected calendar-
month average temperature of the stored product may be used to determine 
the maximum true vapor pressure from nomographs contained in API 
Bulletin 2517 (incorporated by reference--see Sec. 60.17), unless the 
Administrator specifically requests that the liquid be sampled, the 
actual storage temperature determined, and the Reid vapor pressure 
determined from the sample(s).
    (ii) The true vapor pressure of each type of crude oil with a Reid 
vapor pressure less than 13.8 kPa or with physical properties that 
preclude determination by the recommended method is to be determined 
from available data and recorded if the estimated maximum true vapor 
pressure is greater than 3.5 kPa.
    (3) For other liquids, the vapor pressure:
    (i) May be obtained from standard reference texts, or
    (ii) Determined by ASTM Method D2879-83 (incorporated by reference--
see Sec. 60.17); or
    (iii) Measured by an appropriate method approved by the 
Administrator; or
    (iv) Calculated by an appropriate method approved by the 
Administrator.
    (f) The owner or operator of each vessel storing a waste mixture of 
indeterminate or variable composition shall be subject to the following 
requirements.
    (1) Prior to the initial filling of the vessel, the highest maximum 
true vapor pressure for the range of anticipated liquid compositions to 
be stored will be determined using the methods described in paragraph 
(e) of this section.

[[Page 226]]

    (2) For vessels in which the vapor pressure of the anticipated 
liquid composition is above the cutoff for monitoring but below the 
cutoff for controls as defined in Sec. 60.112b(a), an initial physical 
test of the vapor pressure is required; and a physical test at least 
once every 6 months thereafter is required as determined by the 
following methods:
    (i) ASTM Method D2879-83 (incorporated by reference--see 
Sec. 60.17); or
    (ii) ASTM Method D323-82 (incorporated by reference--see 
Sec. 60.17); or
    (iii) As measured by an appropriate method as approved by the 
Administrator.
    (g) The owner or operator of each vessel equipped with a closed vent 
system and control device meeting the specifications of Sec. 60.112b is 
exempt from the requirements of paragraphs (c) and (d) of this section.



Sec. 60.117b  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to States: 
Secs. 60.111b(f)(4), 60.114b, 60.116b(e)(3)(iii), 60.116b(e)(3)(iv), and 
60.116b(f)(2)(iii).

[52 FR 11429, Apr. 8, 1987, as amended at 52 FR 22780, June 16, 1987]



     Subpart L--Standards of Performance for Secondary Lead Smelters



Sec. 60.120  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in secondary lead smelters: Pot furnaces of more 
than 250 kg (550 lb) charging capacity, blast (cupola) furnaces, and 
reverberatory furnaces.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after June 11, 1973, is subject to the 
requirements of this subpart.

[42 FR 37937, July 25, 1977]



Sec. 60.121  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Reverberatory furnace includes the following types of 
reverberatory furnaces: stationary, rotating, rocking, and tilting.
    (b) Secondary lead smelter means any facility producing lead from a 
leadbearing scrap material by smelting to the metallic form.
    (c) Lead means elemental lead or alloys in which the predominant 
component is lead.

[39 FR 9317, Mar. 8, 1974; 39 FR 13776, Apr. 17, 1974]



Sec. 60.122  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall discharge or cause the discharge 
into the atmosphere from a blast (cupola) or reverberatory furnace any 
gases which:
    (1) Contain particulate matter in excess of 50 mg/dscm (0.022 gr/
dscf).
    (2) Exhibit 20 percent opacity or greater.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall discharge or cause the discharge 
into the atmosphere from any pot furnace any gases which exhibit 10 
percent opacity or greater.

[39 FR 9317, Mar. 8, 1974, as amended at 40 FR 46259, Oct. 6, 1975]



Sec. 60.123  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in Appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.122 as follows:

[[Page 227]]

    (1) Method 5 shall be used to determine the particulate matter 
concentration during representative periods of furnace operation, 
including charging and tapping. The sampling time and sample volume for 
each run shall be at least 60 minutes and 0.90 dscm (31.8 dscf).
    (2) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6667, Feb. 14, 1989]



   Subpart M--Standards of Performance for Secondary Brass and Bronze 
                            Production Plants



Sec. 60.130  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in secondary brass or bronze production plants: 
Reverberatory and electric furnaces of 1,000 kg (2205 lb) or greater 
production capacity and blast (cupola) furnaces of 250 kg/h (550 lb/h) 
or greater production capacity. Furnaces from which molten brass or 
bronze are cast into the shape of finished products, such as foundry 
furnaces, are not considered to be affected facilities.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after June 11, 1973, is subject to the 
requirements of this subpart.

[42 FR 37937, July 25, 1977, as amended at 49 FR 43618, Oct. 30, 1984]



Sec. 60.131  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Brass or bronze means any metal alloy containing copper as its 
predominant constituent, and lesser amounts of zinc, tin, lead, or other 
metals.
    (b) Reverberatory furnace includes the following types of 
reverberatory furnaces: Stationary, rotating, rocking, and tilting.
    (c) Electric furnace means any furnace which uses electricity to 
produce over 50 percent of the heat required in the production of 
refined brass or bronze.
    (d) Blast furnace means any furnace used to recover metal from slag.

[39 FR 9318, Mar. 8, 1974]



Sec. 60.132  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall discharge or cause the discharge 
into the atmosphere from a reverberatory furnace any gases which:
    (1) Contain particulate matter in excess of 50 mg/dscm (0.022 gr/
dscf).
    (2) Exhibit 20 percent opacity or greater.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall discharge or cause the discharge 
into the atmosphere from any blast (cupola) or electric furnace any 
gases which exhibit 10 percent opacity or greater.

[39 FR 9318, Mar. 8, 1974, as amended at 40 FR 46259, Oct. 6, 1975]



Sec. 60.133  Test methods and procedures.

    (a) In conducting performance tests required in Sec. 60.8, the owner 
or operator shall use as reference methods and procedures the test 
methods in Appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.132 as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration during representative periods of charging and refining, 
but not during pouring of the heat. The sampling time and sample volume 
for each run shall be at least 120 minutes and 1.80 dscm (63.6 dscf).
    (2) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6667, Feb. 14, 1989]

[[Page 228]]



  Subpart N--Standards of Performance for Primary Emissions from Basic 
 Oxygen Process Furnaces for Which Construction is Commenced After June 
                                11, 1973



Sec. 60.140  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each basic oxygen process furnace.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after June 11, 1973, is subject to the 
requirements of this subpart.

[42 FR 37937, July 25, 1977]



Sec. 60.141  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Basic oxygen process furnace (BOPF) means any furnace with a 
refractory lining in which molten steel is produced by charging scrap 
metal, molten iron, and flux materials or alloy additions into a vessel 
and introducing a high volume of oxygen-rich gas. Open hearth, blast, 
and reverberatory furnaces are not included in this definition.
    (b) Primary emissions means particulate matter emissions from the 
BOPF generated during the steel production cycle and captured by the 
BOPF primary control system.
    (c) Primary oxygen blow means the period in the steel production 
cycle of a BOPF during which a high volume of oxygen-rich gas is 
introduced to the bath of molten iron by means of a lance inserted from 
the top of the vessel or through tuyeres in the bottom or through the 
bottom and sides of the vessel. This definition does not include any 
additional or secondary oxygen blows made after the primary blow or the 
introduction of nitrogen or other inert gas through tuyeres in the 
bottom or bottom and sides of the vessel.
    (d) Steel production cycle means the operations conducted within the 
BOPF steelmaking facility that are required to produce each batch of 
steel and includes the following operations: scrap charging, preheating 
(when used), hot metal charging, primary oxygen blowing, sampling 
(vessel turndown and turnup), additional oxygen blowing (when used), 
tapping, and deslagging. This definition applies to an affected facility 
constructed, modified, or reconstructed after January 20, 1983. For an 
affected facility constructed, modified, or reconstructed after June 11, 
1973, but on or before January 20, 1983, steel production cycle means 
the operations conducted within the BOPF steelmaking facility that are 
required to produce each batch of steel and includes the following 
operations: scrap charging, preheating (when used), hot metal charging, 
primary oxygen blowing, sampling (vessel turndown and turnup), 
additional oxygen blowing (when used), and tapping.

[39 FR 9318, Mar. 8, 1974, as amended at 51 FR 160, Jan. 2, 1986]



Sec. 60.142  Standard for particulate matter.

    (a) Except as provided under paragraph (b) of this section, on and 
after the date on which the performance test required to be conducted by 
Sec. 60.8 is completed, no owner or operator subject to the provisions 
of this subpart shall discharge or cause the discharge into the 
atmosphere from any affected facility any gases which:
    (1) Contain particulate matter in excess of 50 mg/dscm (0.022 gr/
dscf).
    (2) Exit from a control device and exhibit 10 percent opacity or 
greater, except that an opacity of greater than 10 percent but less than 
20 percent may occur once per steel production cycle.
    (b) For affected facilities constructed, modified, or reconstructed 
after January 20, 1983, the following limits shall apply:
    (1) On or after the date on which the performance test under 
Sec. 60.8 is required to be completed, no owner or operator of an 
affected facility for which open hooding is the method for controlling 
primary emissions shall cause to be discharged to the atmosphere any 
gases that:
    (i) Contain particulate matter in excess of 50 mg/dscm (0.022 gr/
dscf), as measured for the primary oxygen blow.

[[Page 229]]

    (ii) Exit from a control device not used solely for the collection 
of secondary emissions, as defined in Sec. 60.141a, and exhibit 10 
percent opacity or greater, except that an opacity greater than 10 
percent but less than 20 percent may occur once per steel production 
cycle.
    (2) On or after the date on which the performance test required by 
Sec. 60.8 is completed, no owner or operator of an affected facility for 
which closed hooding is the method for controlling primary emissions 
shall cause to be discharged into the atmosphere any gases that:
    (i) Contain particulate matter in excess of 68 mg/dscm (0.030 gr/
dscf), as measured for the primary oxygen blow.
    (ii) Exit from a control device not used solely for the collection 
of secondary emissions, as defined in Sec. 60.141a, and exhibit 10 
percent opacity or greater, except that an opacity greater than 10 
percent but less than 20 percent may occur once per steel production 
cycle.
    (c) On and after the date on which the performance test required by 
Sec. 60.8 is completed, each owner or operator of an affected facility 
subject to paragraph (b) of this section shall operate the primary gas 
cleaning system during any reblow in a manner identical to operation 
during the primary oxygen blow.

[39 FR 9318, Mar. 8, 1974, as amended at 43 FR 15602, Apr. 13, 1978; 51 
FR 161, Jan. 2, 1986]



Sec. 60.143  Monitoring of operations.

    (a) The owner or operator of an affected facility shall maintain a 
single time-measuring instrument which shall be used in recording daily 
the time and duration of each steel production cycle, and the time and 
duration of any diversion of exhaust gases from the main stack servicing 
the BOPF.
    (b) The owner or operator of any affected facility that uses venturi 
scrubber emission control equipment shall install, calibrate, maintain, 
and continuously operate monitoring devices as follows:
    (1) A monitoring device for the continuous measurement of the 
pressure loss through the venturi constriction of the control equipment. 
The monitoring device is to be certified by the manufacturer to be 
accurate within plus-minus250 Pa (plus-minus1 inch 
water).
    (2) A monitoring device for the continual measurement of the water 
supply pressure to the control equipment. The monitoring device is to be 
certified by the manufacturer to be accurate within 5 
percent of the design water supply pressure. The monitoring device's 
pressure sensor or pressure tap must be located close to the water 
discharge point. The Administrator must be consulted for approval in 
advance of selecting alternative locations for the pressure sensor or 
tap.
    (3) All monitoring devices shall be synchronized each day with the 
time-measuring instrument used under paragraph (a) of this section. The 
chart recorder error directly after synchronization shall not exceed 
0.08 cm (\1/32\ inch).
    (4) All monitoring devices shall use chart recorders which are 
operated at a minimum chart speed of 3.8 cm/hr (1.5 in/hr).
    (5) All monitoring devices are to be recalibrated annually, and at 
other times as the Administrator may require, in accordance with the 
procedures under Sec. 60.13(b).
    (c) Any owner or operator subject to the requirements of paragraph 
(b) of this section shall report to the Administrator, on a semiannual 
basis, all measurements over any 3-hour period that average more than 10 
percent below the average levels maintained during the most recent 
performance test conducted under Sec. 60.8 in which the affected 
facility demonstrated compliance with the mass standards under 
Sec. 60.142(a)(1), (b)(1)(i) or (b)(2)(i). The accuracy of the 
respective measurements, not to exceed the values specified in 
paragraphs (b)(1) and (b)(2) of this section, may be taken into 
consideration when determining the measurement results that must be 
reported.

[43 FR 15602, Apr. 13, 1978, as amended at 51 FR 161, Jan. 2, 1986; 54 
FR 6667, Feb. 14, 1989]



Sec. 60.144  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in Appendix A of this part or other methods

[[Page 230]]

and procedures as specified in this section, except as provided in 
Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.142 as follows:
    (1) The time-measuring instrument of Sec. 60.143 shall be used to 
document the time and duration of each steel production cycle and each 
diversion period during each run.
    (2) Method 5 shall be used to determine the particulate matter 
concentration. The sampling time and sample volume for each run shall be 
at least 60 minutes and 1.50 dscm (53 dscf). Sampling shall be 
discontinued during periods of diversions.
    (i) For affected facilities that commenced construction, 
modification, or reconstruction on or before January 20, 1983, the 
sampling for each run shall continue for an integral number of steel 
production cycles. A cycle shall start at the beginning of either the 
scrap preheat or the oxygen blow and shall terminate immediately before 
tapping.
    (ii) For affected facilities that commenced construction, 
modification, or reconstruction after January 20, 1983, the sampling for 
each run shall continue for an integral number of primary oxygen blows.
    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity. Observations taken during a diversion period shall 
not be used in determining compliance with the opacity standard. Opacity 
observations taken at 15-second intervals immediately before and after a 
diversion of exhaust gases from the stack may be considered to be 
consecutive for the purpose of computing an average opacity for a 6-
minute period.
    (c) To comply with Sec. 60.143(c), the owner or operator shall use 
the monitoring devices of Sec. 60.143(b) (1) and (2) during the 
particulate runs to determine the 3-hour averages of the required 
measurements.

[54 FR 6667, Feb. 14, 1989]



Subpart Na--Standards of Performance for Secondary Emissions from Basic 
    Oxygen Process Steelmaking Facilities for Which Construction is 
                    Commenced After January 20, 1983

    Source: 51 FR 161, Jan. 2, 1986, unless otherwise noted.



Sec. 60.140a  Applicability and designation of affected facilities.

    (a) The provisions of this subpart apply to the following affected 
facilities in an iron and steel plant: top-blown BOPF's and hot metal 
transfer stations and skimming stations used with bottom-blown or top-
blown BOPF's.
    (b) This subpart applies to any facility identified in paragraph (a) 
of this section that commences construction, modification, or 
reconstruction after January 20, 1983.
    (c) Any BOPF subject to the provisions of this subpart is subject to 
those provisions of subpart N of this part applicable to affected 
facilities commencing construction, modification or reconstruction after 
January 20, 1983.



Sec. 60.141a  Definitions.

    All terms in this subpart not defined below are given the same 
meaning as in the Clean Air Act as amended or in subpart A of this part.
    Basic oxygen process furnace (BOPF) means any furnace with a 
refractory lining in which molten steel is produced by charging scrap 
metal, molten iron, and flux materials or alloy additions into a vessel 
and by introducing a high volume of oxygen-rich gas. Open hearth, blast, 
and reverberatory furnaces are not included in this definition.
    Bottom-blown furnace means any BOPF in which oxygen and other 
combustion gases are introduced to the bath of molten iron through 
tuyeres in the bottom of the vessel or through tuyeres in the bottom and 
sides of the vessel.

[[Page 231]]

    Fume suppression system means the equipment comprising any system 
used to inhibit the generation of emissions from steelmaking facilities 
with an inert gas, flame, or steam blanket applied to the surface of 
molten iron or steel.
    Hot metal transfer station means the facility where molten iron is 
emptied from the railroad torpedo car or hot metal car to the shop 
ladle. This includes the transfer of molten iron from the torpedo car or 
hot metal car to a mixer (or other intermediate vessel) and from a mixer 
(or other intermediate vessel) to the ladle. This facility is also known 
as the reladling station or ladle transfer station.
    Primary emission control system means the combination of equipment 
used for the capture and collection of primary emissions (e.g., an open 
hood capture system used in conjunction with a particulate matter 
cleaning device such as an electrostatic precipitator or a closed hood 
capture system used in conjunction with a particulate matter cleaning 
device such as a scrubber).
    Primary emissions means particulate matter emissions from the BOPF 
generated during the steel production cycle which are captured by, and 
do not thereafter escape from, the BOPF primary control system.
    Primary oxygen blow means the period in the steel production cycle 
of a BOPF during which a high volume of oxygen-rich gas is introduced to 
the bath of molten iron by means of a lance inserted from the top of the 
vessel. This definition does not include any additional, or secondary, 
oxygen blows made after the primary blow.
    Secondary emission control system means the combination of equipment 
used for the capture and collection of secondary emissions (e.g.,
    (1) An open hood system for the capture and collection of primary 
and secondary emissions from the BOPF, with local hooding ducted to a 
secondary emission collection device such as a baghouse for the capture 
and collection of emissions from the hot metal transfer and skimming 
station; or
    (2) An open hood system for the capture and collection of primary 
and secondary emissions from the furnace, plus a furnace enclosure with 
local hooding ducted to a secondary emission collection device, such as 
a baghouse, for additional capture and collection of secondary emissions 
from the furnace, with local hooding ducted to a secondary emission 
collection device, such as a baghouse, for the capture and collection of 
emissions from hot metal transfer and skimming station; or
    (3) A furnace enclosure with local hooding ducted to a secondary 
emission collection device such as a baghouse for the capture and 
collection of secondary emissions from a BOPF controlled by a closed 
hood primary emission control system, with local hooding ducted to a 
secondary emission collection device, such as a baghouse, for the 
capture and collection of emissions from hot metal transfer and skimming 
stations).
    Secondary emissions means particulate matter emissions that are not 
captured by the BOPF primary control system, including emissions from 
hot metal transfer and skimming stations. This definition also includes 
particulate matter emissions that escape from openings in the primary 
emission control system, such as from lance hole openings, gaps or tears 
in the ductwork of the primary emission control system, or leaks in 
hoods.
    Skimming station means the facility where slag is mechanically raked 
from the top of the bath of molten iron.
    Steel production cycle means the operations conducted within the 
BOPF steelmaking facility that are required to produce each batch of 
steel, including the following operations: scrap charging, preheating 
(when used), hot metal charging, primary oxygen blowing, sampling 
(vessel turndown and turnup), additional oxygen blowing (when used), 
tapping, and deslagging. Hot metal transfer and skimming operations for 
the next steel production cycle are also included when the hot metal 
transfer station or skimming station is an affected facility.
    Top-blown furnace means any BOPF in which oxygen is introduced to 
the bath of molten iron by means of an oxygen lance inserted from the 
top of the vessel.

[[Page 232]]



Sec. 60.142a  Standards for particulate matter.

    (a) Except as provided under paragraphs (b) and (c) of this section, 
on and after the date on which the performance test under Sec. 60.8 is 
required to be completed, no owner or operator subject to the provisions 
of this subpart shall cause to be discharged into the atmosphere from 
any affected facility any secondary emissions that:
    (1) Exit from the BOPF shop roof monitor (or other building 
openings) and exhibit greater than 10 percent opacity during the steel 
production cycle of any top-blown BOPF or during hot metal transfer or 
skimming operations for any bottom-blown BOPF; except that an opacity 
greater than 10 percent but less than 20 percent may occur once per 
steel production cycle.
    (2) Exit from a control device used solely for the collection of 
secondary emissions from a top-blown BOPF or from hot metal transfer or 
skimming for a top-blown or a bottom-blown BOPF and contain particulate 
matter in excess of 23 mg/dscm (0.010 gr/dscf).
    (3) Exit from a control device used solely for the collecton of 
secondary emissions from a top-blown BOPF or from hot metal transfer or 
skimming for a top-blown or a bottom-blown BOPF and exhibit more than 5 
percent opacity.
    (b) A fume suppression system used to control secondary emissions 
from an affected facility is not subject to paragraphs (a)(2) and (a)(3) 
of this section.
    (c) A control device used to collect both primary and secondary 
emissions from a BOPF is not subject to paragraphs (a)(2) and (a)(3) of 
this section.



Sec. 60.143a  Monitoring of operations.

    (a) Each owner or operator of an affected facility shall install, 
calibrate, operate, and maintain a monitoring device that continually 
measures and records for each steel production cycle the various rates 
or levels of exhaust ventilation at each phase of the cycle through each 
duct of the secondary emission capture system. The monitoring device or 
devices are to be placed at locations near each capture point of the 
secondary emission capture system to monitor the exhaust ventilation 
rates or levels adequately, or in alternative locations approved in 
advance by the Administrator.
    (b) If a chart recorder is used, the owner or operator shall use 
chart recorders that are operated at a minimum chart speed of 3.8 cm/hr 
(1.5 in./hr).
    (c) All monitoring devices are to be certified by the manufacturer 
to be accurate to within 10 percent compared to EPA 
Reference Method 2. The owner or operator shall recalibrate and check 
the device(s) annually and at other times as the Administrator may 
require, in accordance with the written instructions of the manufacturer 
and by comparing the device against EPA Reference Method 2.
    (d) Each owner or operator subject to the requirements of paragraph 
(a) of this section shall report on a semiannual basis all measurements 
of exhaust ventilation rates or levels over any 3-hour period that 
average more than 10 percent below the average rates or levels of 
exhaust ventilation maintained during the most recent performance test 
conducted under Sec. 60.8 in which the affected facility demonstrated 
compliance with the standard under Sec. 60.142a(a)(2). The accuracy of 
the respective measurements, not to exceed the values specified in 
paragraph (c) of this section, may be considered when determining the 
measurement results that must be reported.
    (e) If a scrubber primary emission control device is used to collect 
secondary emissions, the owner or operator shall report on a semiannual 
basis all measurements of exhaust ventilation rate over any 3-hour 
period that average more than 10 percent below the average levels 
maintained during the most recent performance test conducted under 
Sec. 60.8 in which the affected facility demonstrated compliance with 
the standard under Sec. 60.142(a)(1).



Sec. 60.144a  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in Appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).

[[Page 233]]

    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.142a as follows:
    (1) Start and end times of each steel production cycle during each 
run shall be recorded (see Sec. 60.145a (c) and (d) for the definitions 
of start and end times of a cycle).
    (2) Method 5 shall be used to determine the particulate matter 
concentration. Sampling shall be conducted only during the steel 
production cycle and for a sufficient number of steel production cycles 
to obtain a total sample volume of at least 5.67 dscm (200 dscf) for 
each run.
    (3) Method 9 and the procedures of Sec. 60.11 shall be used to 
determine opacity, except sections 2.4 and 2.5 of Method 9 shall be 
replaced with the following instructions for recording observations and 
reducing data:
    (i) Section 2.4. Opacity observations shall be recorded to the 
nearest 5 percent at 15-second intervals. During the initial performance 
test conducted pursuant to Sec. 60.8, observations shall be made and 
recorded in this manner for a minimum of three steel production cycles. 
During any subsequent compliance test, observations may be made for any 
number of steel production cycles, although, where conditions permit, 
observations will generally be made for a minimum of three steel 
production cycles.
    (ii) Section 2.5. Opacity shall be determined as an average of 12 
consecutive observations recorded at 15-second intervals. For each steel 
production cycle, divide the observations recorded into sets of 12 
consecutive observations. Sets need not be consecutive in time, and in 
no case shall two sets overlap. For each set of 12 observations, 
calculate the average by summing the opacity of 12 consecutive 
observations and dividing this sum by 12.
    (c) In complying with the requirements of Sec. 60.143a(c), the owner 
or operator shall conduct an initial test as follows:
    (1) For devices that monitor and record the exhaust ventilation 
rate, compare velocity readings recorded by the monitoring device 
against the velocity readings obtained by Method 2. Take Method 2 
readings at a point or points that would properly characterize the 
monitoring device's performance and that would adequately reflect the 
various rates of exhaust ventilation. Obtain readings at sufficient 
intervals to obtain 12 pairs of readings for each duct of the secondary 
emission capture system. Compare the averages of the two sets to 
determine whether the monitoring device velocity is within 
10 percent of the Method 2 average.
    (2) For devices that monitor the level of exhaust ventilation and 
record only step changes when a set point rate is reached, compare step 
changes recorded by the monitoring device against the velocity readings 
obtained by Method 2. Take Method 2 readings at a point or points that 
would properly characterize the performance of the monitoring device and 
that would adequately reflect the various rates of exhaust ventilation. 
Obtain readings at sufficient intervals to obtain 12 pairs of readings 
for each duct of the secondary emission capture system. Compare the 
averages of the two sets to determine whether the monitoring device step 
change is within 10 percent of the setpoint rate.
    (d) To comply with Sec. 60.143a (d) or (e), the owner or operator 
shall use the monitoring device of Sec. 60.143a(a) to determine the 
exhaust ventilation rates or levels during the particulate matter runs 
and to determine a 3-hour average.

[51 FR 161, Jan. 2, 1986, as amended at 54 FR 6667, Feb. 14, 1989]



Sec. 60.145a  Compliance provisions.

    (a) When determining compliance with mass and visible emission 
limits specified in Sec. 60.142a(a) (2) and (3), the owner or operator 
of a BOPF shop that normally operates two furnaces with overlapping 
cycles may elect to operate only one furnace. If an owner or operator 
chooses to shut down one furnace, he shall be allowed a reasonable time 
period to adjust his production schedule before the compliance tests are 
conducted. The owner or operator of an affected facility may also elect 
to suspend shop operations not subject to this subpart during compliance 
testing.
    (b) During compliance testing for mass and visible emission 
standards, if an owner or operator elects to shut

[[Page 234]]

down one furnace in a shop that normally operates two furnaces with 
overlapping cycles, the owner or operator shall operate the secondary 
emission control system for the furnace being tested at exhaust 
ventilation rates or levels for each duct of the secondary emission 
control system that are appropriate for single-furnace operation. 
Following the compliance test, the owner or operator shall operate the 
secondary emission control system at exhaust ventilation rates or levels 
for each duct of the system that are no lower than 90 percent of the 
exhaust ventilation values established during the most recent compliance 
test.
    (c) For the purpose of determining compliance with visible and mass 
emission standards, a steel production cycle begins when the scrap or 
hot metal is charged to the vessel (whichever operation occurs first) 
and terminates 3 minutes after slag is emptied from the vessel into the 
slag pot. Consecutive steel production cycles are not required for the 
purpose of determining compliance. Where a hot metal transfer or 
skimming station is an affected facility, the steel production cycle 
also includes the hot metal transfer or skimming operation for the next 
steel production cycle for the affected vessel. Visible emission 
observations for both hot metal transfer and skimming operations begin 
with the start of the operation and terminate 3 minutes after completion 
of the operation.
    (d) For the purpose of determining compliance with visible emission 
standards specified in Sec. 60.142a(a) (1) and (3), the starting and 
stopping times of regulated process operations shall be determined and 
the starting and stopping times of visible emissions data sets shall be 
determined accordingly.
    (e) To determine compliance with Sec. 60.142a(a)(1), select the data 
sets yielding the highest and second highest 3-minute average opacities 
for each steel production cycle. Compliance is achieved if the highest 
3-minute average for each cycle observed is less than 20 percent and the 
second highest 3-minute average is 10 percent or less.
    (f) To determine compliance with Sec. 60.142(a)(2), determine the 
concentration of particulate matter in exhaust gases exiting the 
secondary emission collection device with Reference Method 5. Compliance 
is achieved if the concentration of particulate matter does not exceed 
23 mg/dscm (0.010 gr/dscf).
    (g) To determine compliance with Sec. 60.142a(a)(3), construct 
consecutive 3-minute averages for each steel production cycle. 
Compliance is achieved if no 3-minute average is more than 5 percent.



     Subpart O--Standards of Performance for Sewage Treatment Plants



Sec. 60.150  Applicability and designation of affected facility.

    (a) The affected facility is each incinerator that combusts wastes 
containing more than 10 percent sewage sludge (dry basis) produced by 
municipal sewage treatment plants, or each incinerator that charges more 
than 1000 kg (2205 lb) per day municipal sewage sludge (dry basis).
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after June 11, 1973, is subject to the 
requirements of this subpart.

[42 FR 58521, Nov. 10, 1977]



Sec. 60.151  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.

[39 FR 9319, Mar. 8, 1974]



Sec. 60.152  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator of any 
sewage sludge incinerator subject to the provisions of this subpart 
shall discharge or cause the discharge into the atmosphere of:
    (1) Particulate matter at a rate in excess of 0.65 g/kg dry sludge 
input (1.30 lb/ton dry sludge input).
    (2) Any gases which exhibit 20 percent opacity or greater.

[39 FR 9319, Mar. 8, 1974, as amended at 40 FR 46259, Oct. 6, 1975]

[[Page 235]]



Sec. 60.153  Monitoring of operations.

    (a) The owner or operator of any sludge incinerator subject to the 
provisions of this subpart shall:
    (1) Install, calibrate, maintain, and operate a flow measuring 
device which can be used to determine either the mass or volume of 
sludge charged to the incinerator. The flow measuring device shall be 
certified by the manufacturer to have an accuracy of 5 
percent over its operating range. Except as provided in paragraph (d) of 
this section, the flow measuring device shall be operated continuously 
and data recorded during all periods of operation of the incinerator.
    (2) Provide access to the sludge charged so that a well-mixed 
representative grab sample of the sludge can be obtained.
    (3) Install, calibrate, maintain, and operate a weighing device for 
determining the mass of any municipal solid waste charged to the 
incinerator when sewage sludge and municipal solid waste are incinerated 
together. The weighing device shall have an accuracy of 
plus-minus5 percent over its operating range.
    (b) The owner or operator of any multiple hearth, fluidized bed, or 
electric sludge incinerator subject to the provisions of this subpart 
shall comply with the requirements of paragraph (a) of this section and:
    (1) For incinerators equipped with a wet scrubbing device, install, 
calibrate, maintain and operate a monitoring device that continuously 
measures and records the pressure drop of the gas flow through the wet 
scrubbing device. Where a combination of wet scrubbers is used in 
series, the pressure drop of the gas flow through the combined system 
shall be continuously monitored. The device used to monitor scrubber 
pressure drop shall be certified by the manufacturer to be accurate 
within 250 pascals (1 inch water gauge) and 
shall be calibrated on an annual basis in accordance with the 
manufacturer's instructions.
    (2) Install, calibrate, maintain and operate a monitoring device 
that continuously measures and records the oxygen content of the 
incinerator exhaust gas. The oxygen monitor shall be located upstream of 
any rabble shaft cooling air inlet into the incinerator exhaust gas 
stream, fan, ambient air recirculation damper, or any other source of 
dilution air. The oxygen monitoring device shall be certified by the 
manufacturer to have a relative accurancy of 5 percent over 
its operating range and shall be calibrated according to method(s) 
prescribed by the manufacturer at least once each 24-hour operating 
period.
    (3) Install, calibrate, maintain and operate temperature measuring 
devices at every hearth in multiple hearth furnaces; in the bed and 
outlet of fluidized bed incinerators; and in the drying, combustion, and 
cooling zones of electric incinerators. For multiple hearth furnaces, a 
minimum of one thermocouple shall be installed in each hearth in the 
cooling and drying zones, and a minimum of two thermocouples shall be 
installed in each hearth in the combustion zone. For electric 
incinerators, a minimum of one thermocouple shall be installed in the 
drying zone and one in the cooling zone, and a minimum of two 
thermocouples shall be installed in the combustion zone. Each 
temperature measuring device shall be certified by the manufacturer to 
have an accuracy of 5 percent over its operating range. 
Except as provided in paragraph (d) of this section, the temperature 
monitoring devices shall be operated continuously and data recorded 
during all periods of operation of the incinerator.
    (4) Install, calibrate, maintain and operate a device for measuring 
the fuel flow to the incinerator. The flow measuring device shall be 
certified by the manufacturer to have an accuracy of 5 
percent over its operating range. Except as provided in paragraph (d) of 
the section, the fuel flow measuring device shall be operated 
continuously and data recorded during all periods of operation of the 
incinerator.
    (5) Except as provided in paragraph (d) of this section, collect and 
analyze a grab sample of the sludge fed to the incinerator once per day. 
The dry sludge content and the volatile solids content of the sample 
shall be determined in accordance with the method specified under 
Sec. 60.154(c)(2), except that the determination of volatile solids, 
step (3)(b) of the method, may not be deleted.

[[Page 236]]

    (c) The owner or operator of any multiple hearth, fluidized bed, or 
electric sludge incinerator subject to the provisions of this subpart 
shall retain the following information and make it available for 
inspection by the Administrator for a minimum of 2 years:
    (1) For incinerators equipped with a wet scrubbing device, a record 
of the measured pressure drop of the gas flow through the wet scrubbing 
device, as required by paragraph (b)(1) of this section.
    (2) A record of the measured oxygen content of the incinerator 
exhaust gas, as required by paragraph (b)(2) of this section.
    (3) A record of the rate of sludge charged to the incinerator, the 
measured temperatures of the incinerator, the fuel flow to the 
incinerator, and the total solids and volatile solids content of the 
sludge charged to the incinerator, as required by paragraphs (a)(1), 
(b)(3), (b)(4), and (b)(5) of this section.
    (d) The owner or operator of any multiple hearth, fluidized bed, or 
electric sludge incinerator subject to the provisions of this subpart 
from which the particulate matter emission rate measured during the 
performance test required under Sec. 60.154(d) is less than or equal to 
0.38 g/kg of dry sludge input (0.75 lb/ton) shall be required to comply 
with the requirements in paragraphs (a), (b), and (c) of this section 
during all periods of this incinerator following the performance test 
except that:
    (1) Continuous operation of the monitoring devices and data 
recorders in paragraphs (a)(1), (b)(3), and (b)(4) of this section shall 
not be required.
    (2) Daily sampling and analysis of sludge feed in paragraph (b)(5) 
of this section shall not be required.
    (3) Recordkeeping specified in paragraph (c)(3) of this section 
shall not be required.
    (e) The owner or operator of any sludge incinerator other than a 
multiple hearth, fluidized bed, or electric incinerator or any sludge 
incinerator equipped with a control device other than a wet scrubber 
shall submit to the Administrator for approval a plan for monitoring and 
recording incinerator and control device operation parameters. The plan 
shall be submitted to the Administrator:
    (1) No later than 90 days after October 6, 1988, for sources which 
have provided notification of commencement of construction prior to 
October 6, 1988.
    (2) No later than 90 days after the notification of commencement of 
construction, for sources which provide notification of commencement of 
construction on or after October 6, 1988.
    (3) At least 90 days prior to the date on which the new control 
device becomes operative, for sources switching to a control device 
other than a wet scrubber.

[36 FR 24877, Dec. 23, 1971, as amended at 53 FR 39416, Oct. 6, 1988]



Sec. 60.154  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in Appendix A of this part or other methods and procedures as 
specified in this section, except as provided for in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter emission standards in Sec. 60.152 as follows:
    (1) The emission rate (E) of particulate matter for each run shall 
be computed using the following equation:

E=K(cs Qsd)/S

where:
E=emission rate of particulate matter, g/kg (lb/ton) of dry sludge 
          input.
cs=concentration of particulate matter, g/dscm (g/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
S=charging rate of dry sludge during the run, kg/hr (lb/hr).
K=conversion factor, 1.0 g/g [4.409 lb2/(g-ton)].

    (2) Method 5 shall be used to determine the particulate matter 
concentration (cs) and the volumetric flow rate 
(Qsd) of the effluent gas. The sampling time and sample 
volume for each run shall be at least 60 minutes and 0.90 dscm (31.8 
dscf).
    (3) The dry sludge charging rate (S) for each run shall be computed 
using either of the following equations:

S=Km Sm Rdm/
S=Kv Sv Rdv/
where:
S=charging rate of dry sludge, kg/hr (lb/hr).
Sm=total mass of sludge charged, kg (lb).
Rdm=average mass of dry sludge per unit mass of sludge 
          charged, mg/mg (lb/lb).

[[Page 237]]

=duration of run, min.
Km=conversion factor, 60 min/hr.
Sv=total volume of sludge charged, m\3\ (gal).
Rdv=average mass of dry sludge per unit volume of sludge 
          charged, mg/liter (lb/ft\3\).
Kv=conversion factor, 60 x 10-3 (liter-kg-min)/
          (m\3\-mg-hr) [8.021 (ft\3\-min)/(gal-hr)].

    (4) the flow measuring device of Sec. 60.153(a)(1) shall be used to 
determine the total mass (Sm) or volume (Sv) of 
sludge charged to the incinerator during each run. If the flow measuring 
device is on a time rate basis, readings shall be taken and recorded at 
5-minute intervals during the run and the total charge of sludge shall 
be computed using the following equations, as applicable:
[GRAPHIC] [TIFF OMITTED] TC16NO91.006

where:
Qmi=average mass flow rate calculated by averaging the flow 
rates at the beginning and end of each interval ``i'', kg/min (lb/min).
Qvi=average volume flow rate calculated by averaging the flow 
          rates at the beginning and end of each interval ``i'', m\3\/
          min (gal/min).
i=duration of interval ``i'', min.

    (5) Samples of the sludge charged to the incinerator shall be 
collected in nonporous jars at the beginning of each run and at 
approximately 1-hour intervals thereafter until the test ends, and ``209 
F. Method for Solid and Semisolid Samples'' (incorporated by reference--
see Sec. 60.17) shall be used to determine dry sludge content of each 
sample (total solids residue), except that:
    (i) Evaporating dishes shall be ignited to at least 103  deg.C 
rather than the 550  deg.C specified in step 3(a)(1).
    (ii) Determination of volatile residue, step 3(b) may be deleted.
    (iii) The quantity of dry sludge per unit sludge charged shall be 
determined in terms of mg/liter (lb/ft\3\) or mg/mg (lb/lb).
    (iv) The average dry sludge content shall be the arithmetic average 
of all the samples taken during the run.
    (6) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (c) [Reserved]
    (d) The owner or operator of any sludge incinerator subject to the 
provisions of this subpart shall conduct a performance test during which 
the monitoring and recording devices required under Sec. 60.153(a)(1), 
(b)(1), (b)(2), (b)(3), and (b)(4) are installed and operating and for 
which the sampling and analysis procedures required under 
Sec. 60.153(b)(5) are performed. The owner or operator shall provide the 
Administrator at least 30 days prior notice of the performance test to 
afford the Administrator the opportunity to have an observer present.
    (1) For incinerators that commenced construction or modification on 
or before April 18, 1986, the performance test shall be conducted within 
360 days of the effective date of these regulations unless the 
monitoring and recording devices required under Sec. 60.153(a)(1), 
(b)(1), (b)(2), (b)(3), and (b)(4) were installed and operating and the 
sampling and analysis procedures required under Sec. 60.153(b)(5) were 
performed during the most recent performance test and a record of the 
measurements taken during the performance test is available.
    (2) For incinerators that commence construction or modification 
after April 18, 1986, the date of the performance test shall be 
determined by the requirements in Sec. 60.8.

[54 FR 6668, Feb. 14, 1989, as amended at 54 FR 27015, June 27, 1989; 59 
FR 5108, Feb. 3, 1994]



Sec. 60.155  Reporting.

    (a) The owner or operator of any multiple hearth, fluidized bed, or 
electric sludge incinerator subject to the provisions of this subpart 
shall submit to the Administrator semi-annually a report in writing 
which contains the following:
    (1) A record of average scrubber pressure drop measurements for each 
period of 15 minutes duration or more during which the pressure drop of 
the scrubber was less than, by a percentage specified below, the average 
scrubber pressure drop measured during the most recent performance test. 
The percent reduction in scrubber pressure

[[Page 238]]

drop for which a report is required shall be determined as follows:
    (i) For incinerators that achieved an average particulate matter 
emission rate of 0.38 kg/Mg (0.75 lb/ton) dry sludge input or less 
during the most recent performance test, a scrubber pressure drop 
reduction of more than 30 percent from the average scrubber pressure 
drop recorded during the most recent performance test shall be reported.
    (ii) For incinerators that achieved an average particulate matter 
emission rate of greater than 0.38 kg/Mg (0.75 lb/ton) dry sludge input 
during the most recent performance test, a percent reduction in pressure 
drop greater than that calculated according to the following equation 
shall be reported:

P=-111E+72.15
where P=Percent reduction in pressure drop, and
E=Average particulate matter emissions (kg/megagram)

    (2) A record of average oxygen content in the incinerator exhaust 
gas for each period of 1-hour duration or more that the oxygen content 
of the incinerator exhaust gas exceeds the average oxygen content 
measured during the most recent performance test by more than 3 percent.
    (b) The owner or operator of any multiple hearth, fluidized bed, or 
electric sludge incinerator from which the average particulate matter 
emission rate measured during the performance test required under 
Sec. 60.154(d) exceeds 0.38 g/kg of dry sludge input (0.75 lb/ton of dry 
sludge input) shall include in the report for each calendar day that a 
decrease in scrubber pressure drop or increase in oxygen content of 
exhaust gas is reported a record of the following:
    (1) Scrubber pressure drop averaged over each 1-hour incinerator 
operating period.
    (2) Oxygen content in the incinerator exhaust averaged over each 1-
hour incinerator operating period.
    (3) Temperatures of every hearth in multiple hearth incinerators; of 
the bed and outlet of fluidized bed incinerators; and of the drying, 
combustion, and cooling zones of electric incinerators averaged over 
each 1-hour incinerator operating period.
    (4) Rate of sludge charged to the incinerator averaged over each 1-
hour incinerator operating period.
    (5) Incinerator fuel use averaged over each 8-hour incinerator 
operating period.
    (6) Moisture and volatile solids content of the daily grab sample of 
sludge charged to the incinerator.
    (c) The owner or operator of any sludge incinerator other than a 
multiple hearth, fluidized bed, or electric incinerator or any sludge 
incinerator equipped with a control device other than a wet scrubber 
shall include in the semi-annual report a record of control device 
operation measurements, as specified in the plan approved under 
Sec. 60.153(e).

[53 FR 39417, Oct. 6, 1988]



Sec. 60.156  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to States: 
Sec. 60.153(e).

[53 FR 39418, Oct. 6, 1988]



     Subpart P--Standards of Performance for Primary Copper Smelters

    Source: 41 FR 2338, Jan. 15, 1976, unless otherwise noted.



Sec. 60.160  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in primary copper smelters: Dryer, roaster, smelting 
furnace, and copper converter.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 16, 1974, is subject to the 
requirements of this subpart.

[42 FR 37937, July 25, 1977]



Sec. 60.161  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning

[[Page 239]]

given them in the Act and in subpart A of this part.
    (a) Primary copper smelter means any installation or any 
intermediate process engaged in the production of copper from copper 
sulfide ore concentrates through the use of pyrometallurgical 
techniques.
    (b) Dryer means any facility in which a copper sulfide ore 
concentrate charge is heated in the presence of air to eliminate a 
portion of the moisture from the charge, provided less than 5 percent of 
the sulfur contained in the charge is eliminated in the facility.
    (c) Roaster means any facility in which a copper sulfide ore 
concentrate charge is heated in the presence of air to eliminate a 
significant portion (5 percent or more) of the sulfur contained in the 
charge.
    (d) Calcine means the solid materials produced by a roaster.
    (e) Smelting means processing techniques for the melting of a copper 
sulfide ore concentrate or calcine charge leading to the formation of 
separate layers of molten slag, molten copper, and/or copper matte.
    (f) Smelting furnace means any vessel in which the smelting of 
copper sulfide ore concentrates or calcines is performed and in which 
the heat necessary for smelting is provided by an electric current, 
rapid oxidation of a portion of the sulfur contained in the concentrate 
as it passes through an oxidizing atmosphere, or the combustion of a 
fossil fuel.
    (g) Copper converter means any vessel to which copper matte is 
charged and oxidized to copper.
    (h) Sulfuric acid plant means any facility producing sulfuric acid 
by the contact process.
    (i) Fossil fuel means natural gas, petroleum, coal, and any form of 
solid, liquid, or gaseous fuel derived from such materials for the 
purpose of creating useful heat.
    (j) Reverberatory smelting furnace means any vessel in which the 
smelting of copper sulfide ore concentrates or calcines is performed and 
in which the heat necessary for smelting is provided primarily by 
combustion of a fossil fuel.
    (k) Total smelter charge means the weight (dry basis) of all copper 
sulfide ore concentrates processed at a primary copper smelter, plus the 
weight of all other solid materials introduced into the roasters and 
smelting furnaces at a primary copper smelter, except calcine, over a 
one-month period.
    (l) High level of volatile impurities means a total smelter charge 
containing more than 0.2 weight percent arsenic, 0.1 weight percent 
antimony, 4.5 weight percent lead or 5.5 weight percent zinc, on a dry 
basis.



Sec. 60.162  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any dryer any gases which contain particulate matter in 
excess of 50 mg/dscm (0.022 gr/dscf).



Sec. 60.163  Standard for sulfur dioxide.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any roaster, smelting furnace, or copper converter any 
gases which contain sulfur dioxide in excess of 0.065 percent by volume, 
except as provided in paragraphs (b) and (c) of this section.
    (b) Reverberatory smelting furnaces shall be exempted from paragraph 
(a) of this section during periods when the total smelter charge at the 
primary copper smelter contains a high level of volatile impurities.
    (c) A change in the fuel combusted in a reverberatory smelting 
furnace shall not be considered a modification under this part.



Sec. 60.164  Standard for visible emissions.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any dryer any visible emissions which exhibit greater 
than 20 percent opacity.
    (b) On and after the date on which the performance test required to 
be

[[Page 240]]

conducted by Sec. 60.8 is completed, no owner or operator subject to the 
provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility that uses a sulfuric acid plant to 
comply with the standard set forth in Sec. 60.163, any visible emissions 
which exhibit greater than 20 percent opacity.



Sec. 60.165  Monitoring of operations.

    (a) The owner or operator of any primary copper smelter subject to 
Sec. 60.163 (b) shall keep a monthly record of the total smelter charge 
and the weight percent (dry basis) of arsenic, antimony, lead and zinc 
contained in this charge. The analytical methods and procedures employed 
to determine the weight of the total smelter charge and the weight 
percent of arsenic, antimony, lead and zinc shall be approved by the 
Administrator and shall be accurate to within plus or minus ten percent.
    (b) The owner or operator of any primary copper smelter subject to 
the provisions of this subpart shall install and operate:
    (1) A continuous monitoring system to monitor and record the opacity 
of gases discharged into the atmosphere from any dryer. The span of this 
system shall be set at 80 to 100 percent opacity.
    (2) A continuous monitoring system to monitor and record sulfur 
dioxide emissions discharged into the atmosphere from any roaster, 
smelting furnace or copper converter subject to Sec. 60.163 (a). The 
span of this system shall be set at a sulfur dioxide concentration of 
0.20 percent by volume.
    (i) The continuous monitoring system performance evaluation required 
under Sec. 60.13(c) shall be completed prior to the initial performance 
test required under Sec. 60.8.
    (ii) For the purpose of the continuous monitoring system performance 
evaluation required under Sec. 60.13(c) the reference method referred to 
under the Relative Accuracy Test Procedure in Performance Specification 
2 of appendix B to this part shall be Method 6. For the performance 
evaluation, each concentration measurement shall be of one hour 
duration. The pollutant gas used to prepare the calibration gas mixtures 
required under Performance Specification 2 of appendix B, and for 
calibration checks under Sec. 60.13 (d), shall be sulfur dioxide.
    (c) Six-hour average sulfur dioxide concentrations shall be 
calculated and recorded daily for the four consecutive 6-hour periods of 
each operating day. Each six-hour average shall be determined as the 
arithmetic mean of the appropriate six contiguous one-hour average 
sulfur dioxide concentrations provided by the continuous monitoring 
system installed under paragraph (b) of this section.
    (d) For the purpose of reports required under Sec. 60.7(c), periods 
of excess emissions that shall be reported are defined as follows:
    (1) Opacity. Any six-minute period during which the average opacity, 
as measured by the continuous monitoring system installed under 
paragraph (b) of this section, exceeds the standard under 
Sec. 60.164(a).
    (2) Sulfur dioxide. All six-hour periods during which the average 
emissions of sulfur dioxide, as measured by the continuous monitoring 
system installed under Sec. 60.163, exceed the level of the standard. 
The Administrator will not consider emissions in excess of the level of 
the standard for less than or equal to 1.5 percent of the six-hour 
periods during the quarter as indicative of a potential violation of 
Sec. 60.11(d) provided the affected facility, including air pollution 
control equipment, is maintained and operated in a manner consistent 
with good air pollution control practice for minimizing emissions during 
these periods. Emissions in excess of the level of the standard during 
periods of startup, shutdown, and malfunction are not to be included 
within the 1.5 percent.

[41 FR 2338, Jan. 15, 1976; 41 FR 8346, Feb. 26, 1976, as amended at 42 
FR 57126, Nov. 1, 1977; 48 FR 23611, May 25, 1983; 54 FR 6668, Feb. 14, 
1989]



Sec. 60.166  Test methods and procedures.

    (a) In conducting performance tests required in Sec. 60.8, the owner 
or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).

[[Page 241]]

    (b) The owner or operator shall determine compliance with the 
particulate matter, sulfur dioxide (SO2) and visible emission 
standards in Secs. 60.162, 60.163, and 60.164 as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration. The sampling time and sample volume for each run shall be 
at least 60 minutes and 0.85 dscm (30 dscf).
    (2) The continuous monitoring system of Sec. 60.165(b)(2) shall be 
used to determine the SO2 concentrations on a dry basis. The 
sampling time for each run shall be 6 hours, and the average 
SO2 concentration shall be computed for the 6-hour period as 
in Sec. 60.165(c). The monitoring system drift during the run may not 
exceed 2 percent of the span value.
    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6668, Feb. 14, 1989]



      Subpart Q--Standards of Performance for Primary Zinc Smelters

    Source: 41 FR 2340, Jan. 15, 1976, unless otherwise noted.



Sec. 60.170  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in primary zinc smelters: roaster and sintering 
machine.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 16, 1974, is subject to the 
requirements of this subpart.

[42 FR 37937, July 25, 1977]



Sec. 60.171  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Primary zinc smelter means any installation engaged in the 
production, or any intermediate process in the production, of zinc or 
zinc oxide from zinc sulfide ore concentrates through the use of 
pyrometallurgical techniques.
    (b) Roaster means any facility in which a zinc sulfide ore 
concentrate charge is heated in the presence of air to eliminate a 
significant portion (more than 10 percent) of the sulfur contained in 
the charge.
    (c) Sintering machine means any furnace in which calcines are heated 
in the presence of air to agglomerate the calcines into a hard porous 
mass called sinter.
    (d) Sulfuric acid plant means any facility producing sulfuric acid 
by the contact process.



Sec. 60.172  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any sintering machine any gases which contain 
particulate matter in excess of 50 mg/dscm (0.022 gr/dscf).



Sec. 60.173  Standard for sulfur dioxide.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any roaster any gases which contain sulfur dioxide in 
excess of 0.065 percent by volume.
    (b) Any sintering machine which eliminates more than 10 percent of 
the sulfur initially contained in the zinc sulfide ore concentrates will 
be considered as a roaster under paragraph (a) of this section.



Sec. 60.174  Standard for visible emissions.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any sintering machine any visible emissions which 
exhibit greater than 20 percent opacity.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility that uses a sulfuric acid plant to 
comply with the

[[Page 242]]

standard set forth in Sec. 60.173, any visible emissions which exhibit 
greater than 20 percent opacity.



Sec. 60.175  Monitoring of operations.

    (a) The owner or operator of any primary zinc smelter subject to the 
provisions of this subpart shall install and operate:
    (1) A continuous monitoring system to monitor and record the opacity 
of gases discharged into the atmosphere from any sintering machine. The 
span of this system shall be set at 80 to 100 percent opacity.
    (2) A continuous monitoring system to monitor and record sulfur 
dioxide emissions discharged into the atmosphere from any roaster 
subject to Sec. 60.173. The span of this system shall be set at a sulfur 
dioxide concentration of 0.20 percent by volume.
    (i) The continuous monitoring system performance evaluation required 
under Sec. 60.13(c) shall be completed prior to the initial performance 
test required under Sec. 60.8.
    (ii) For the purpose of the continuous monitoring system performance 
evaluation required under Sec. 60.13(c), the reference method referred 
to under the Relative Accuracy Test Procedure in Performance 
Specification 2 of appendix B to this part shall be Method 6. For the 
performance evaluation, each concentration measurement shall be of 1 
hour duration. The pollutant gas used to prepare the calibration gas 
mixtures required under Performance Specification 2 of appendix B, and 
for calibration checks under Sec. 60.13(d), shall be sulfur dioxide.
    (b) Two-hour average sulfur dioxide concentrations shall be 
calculated and recorded daily for the 12 consecutive 2-hour periods of 
each operating day. Each 2-hour average shall be determined as the 
arithmetic mean of the appropriate two contiguous 1-hour average sulfur 
dioxide concentrations provided by the continuous monitoring system 
installed under paragraph (a) of this section.
    (c) For the purpose of reports required under Sec. 60.7(c), periods 
of excess emissions that shall be reported are defined as follows:
    (1) Opacity. Any 6-minute period during which the average opacity, 
as measured by the continuous monitoring system installed under 
paragraph (a) of this section, exceeds the standard under 
Sec. 60.174(a).
    (2) Sulfur dioxide. Any 2-hour period, as described in paragraph (b) 
of this section, during which the average emissions of sulfur dioxide, 
as measured by the continuous monitoring system installed under 
paragraph (a) of this section, exceeds the standard under Sec. 60.173.

[41 FR 2340, Jan. 15, 1976, as amended at 48 FR 23611, May 25, 1983; 54 
FR 6668, Feb. 14, 1989]



Sec. 60.176  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter, sulfur dioxide (SO2), and visible 
emission standards in Secs. 60.172, 60.173, and 60.174 as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration. The sampling time and sample volume for each run shall be 
at least 60 minutes and 0.85 dscm (30 dscf).
    (2) The continuous monitoring system of Sec. 60.175(a)(2) shall be 
used to determine the SO2 concentrations on a dry basis. The 
sampling time for each run shall be 2 hours, and the average 
SO2 concentration for the 2-hour period shall be computed as 
in Sec. 60.175(b). The monitoring system drift during the run may not 
exceed 2 percent of the span value.
    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6669, Feb. 14, 1989]



      Subpart R--Standards of Performance for Primary Lead Smelters

    Source: 41 FR 2340, Jan. 15, 1976, unless otherwise noted.

[[Page 243]]



Sec. 60.180  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in primary lead smelters: sintering machine, 
sintering machine discharge end, blast furnace, dross reverberatory 
furnace, electric smelting furnace, and converter.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 16, 1974, is subject to the 
requirements of this subpart.

[42 FR 37937, July 25, 1977]



Sec. 60.181  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Primary lead smelter means any installation or any intermediate 
process engaged in the production of lead from lead sulfide ore 
concentrates through the use of pyrometallurgical techniques.
    (b) Sintering machine means any furnace in which a lead sulfide ore 
concentrate charge is heated in the presence of air to eliminate sulfur 
contained in the charge and to agglomerate the charge into a hard porous 
mass called sinter.
    (c) Sinter bed means the lead sulfide ore concentrate charge within 
a sintering machine.
    (d) Sintering machine discharge end means any apparatus which 
receives sinter as it is discharged from the conveying grate of a 
sintering machine.
    (e) Blast furnace means any reduction furnace to which sinter is 
charged and which forms separate layers of molten slag and lead bullion.
    (f) Dross reverberatory furnace means any furnace used for the 
removal or refining of impurities from lead bullion.
    (g) Electric smelting furnace means any furnace in which the heat 
necessary for smelting of the lead sulfide ore concentrate charge is 
generated by passing an electric current through a portion of the molten 
mass in the furnace.
    (h) Converter means any vessel to which lead concentrate or bullion 
is charged and refined.
    (i) Sulfuric acid plant means any facility producing sulfuric acid 
by the contact process.



Sec. 60.182  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any blast furnace, dross reverberatory furnace, or 
sintering machine discharge end any gases which contain particulate 
matter in excess of 50 mg/dscm (0.022 gr/dscf).
    (b) [Reserved]



Sec. 60.183  Standard for sulfur dioxide.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any sintering machine, electric smelting furnace, or 
converter gases which contain sulfur dioxide in excess of 0.065 percent 
by volume.
    (b) [Reserved]



Sec. 60.184  Standard for visible emissions.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any blast furnace, dross reverberatory furnace, or 
sintering machine discharge end any visible emissions which exhibit 
greater than 20 percent opacity.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility that uses a sulfuric acid plant to 
comply with the standard set forth in Sec. 60.183, any visible emissions 
which exhibit greater than 20 percent opacity.

[[Page 244]]



Sec. 60.185  Monitoring of operations.

    (a) The owner or operator of any primary lead smelter subject to the 
provisions of this subpart shall install and operate:
    (1) A continuous monitoring system to monitor and record the opacity 
of gases discharged into the atmosphere from any blast furnace, dross 
reverberatory furnace, or sintering machine discharge end. The span of 
this system shall be set at 80 to 100 percent opacity.
    (2) A continuous monitoring system to monitor and record sulfur 
dioxide emissions discharged into the atmosphere from any sintering 
machine, electric furnace or converter subject to Sec. 60.183. The span 
of this system shall be set at a sulfur dioxide concentration of 0.20 
percent by volume.
    (i) The continuous monitoring system performance evaluation required 
under Sec. 60.13(c) shall be completed prior to the initial performance 
test required under Sec. 60.8.
    (ii) For the purpose of the continuous monitoring system performance 
evaluation required under Sec. 60.13(c), the reference method referred 
to under the Relative Accuracy Test Procedure in Performance 
Specification 2 of appendix B to this part shall be Method 6. For the 
performance evaluation, each concentration measurement shall be of one 
hour duration. The pollutant gases used to prepare the calibration gas 
mixtures required under Performance Specification 2 of appendix B, and 
for calibration checks under Sec. 60.13(d), shall be sulfur dioxide.
    (b) Two-hour average sulfur dioxide concentrations shall be 
calculated and recorded daily for the twelve consecutive two-hour 
periods of each operating day. Each two-hour average shall be determined 
as the arithmetic mean of the appropriate two contiguous one-hour 
average sulfur dioxide concentrations provided by the continuous 
monitoring system installed under paragraph (a) of this section.
    (c) For the purpose of reports required under Sec. 60.7(c), periods 
of excess emissions that shall be reported are defined as follows:
    (1) Opacity. Any six-minute period during which the average opacity, 
as measured by the continuous monitoring system installed under 
paragraph (a) of this section, exceeds the standard under 
Sec. 60.184(a).
    (2) Sulfur dioxide. Any two-hour period, as described in paragraph 
(b) of this section, during which the average emissions of sulfur 
dioxide, as measured by the continuous monitoring system installed under 
paragraph (a) of this section, exceeds the standard under Sec. 60.183.

[41 FR 2340, Jan. 15, 1976, as amended at 48 FR 23611, May 25, 1983; 54 
FR 6668, Feb. 14, 1989]



Sec. 60.186  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter, sulfur dioxide (SO2), and visible 
emission standards in Secs. 60.182, 60.183, and 60.184 as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration. The sampling time and sample volume for each run shall be 
at least 60 minutes and 0.85 dscm (30 dscf).
    (2) The continuous monitoring system of Sec. 60.185(a)(2) shall be 
used to determine the SO2 concentrations on a dry basis. The 
sampling time for each run shall be 2 hours, and the average 
SO2 concentration for the 2-hour period shall be computed as 
in Sec. 60.185(b). The monitoring system drift during the run may not 
exceed 2 percent of the span value.
    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6669, Feb. 14, 1989]



   Subpart S--Standards of Performance for Primary Aluminum Reduction 
                                 Plants

    Source: 45 FR 44207, June 30, 1980, unless otherwise noted.



Sec. 60.190  Applicability and designation of affected facility.

    (a) The affected facilities in primary aluminum reduction plants to 
which

[[Page 245]]

this subpart applies are potroom groups and anode bake plants.
    (b) Except as provided in paragraph (c) of this section, any 
affected facility under paragraph (a) of this section that commences 
construction or modification after October 23, 1974, is subject to the 
requirements of this subpart.
    (c) An owner or operator of an affected facility under paragraph (a) 
of this section may elect to comply with the requirements of this 
subpart or the requirements of subpart LL of part 63 of this chapter.

[42 FR 37937, July 25, 1977, as amended at 45 FR 44206, June 30, 1980; 
62 FR 52399, Oct. 7, 1997]



Sec. 60.191  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    Aluminum equivalent means an amount of aluminum which can be 
produced from a Mg of anodes produced by an anode bake plant as 
determined by Sec. 60.195(g).
    Anode bake plant means a facility which produces carbon anodes for 
use in a primary aluminum reduction plant.
    Potroom means a building unit which houses a group of electrolytic 
cells in which aluminum is produced.
    Potroom group means an uncontrolled potroom, a potroom which is 
controlled individually, or a group of potrooms or potroom segments 
ducted to a common control system.
    Primary aluminum reduction plant means any facility manufacturing 
aluminum by electrolytic reduction.
    Primary control system means an air pollution control system 
designed to remove gaseous and particulate flourides from exhaust gases 
which are captured at the cell.
    Roof monitor means that portion of the roof of a potroom where gases 
not captured at the cell exit from the potroom.
    Total fluorides means elemental fluorine and all fluoride compounds 
as measured by reference methods specified in Sec. 60.195 or by 
equivalent or alternative methods (see Sec. 60.8(b)).



Sec. 60.192  Standard for fluorides.

    (a) On and after the date on which the initial performance test 
required to be conducted by Sec. 60.8 is completed, no owner or operator 
subject to the provisions of this subpart shall cause to be discharged 
into the atmosphere from any affected facility any gases containing 
total fluorides, as measured according to Sec. 60.8 above, in excess of:
    (1) 1.0 kg/Mg (2.0 lb/ton) of aluminum produced for potroom groups 
at Soderberg plants: except that emissions between 1.0 kg/Mg and 1.3 kg/
Mg (2.6 lb/ton) will be considered in compliance if the owner or 
operator demonstrates that exemplary operation and maintenance 
procedures were used with respect to the emission control system and 
that proper control equipment was operating at the affected facility 
during the performance tests;
    (2) 0.95 kg/Mg (1.9 lb/ton) of aluminum produced for potroom groups 
at prebake plants; except that emissions between 0.95 kg/Mg and 1.25 kg/
Mg (2.5 lb/ton) will be considered in compliance if the owner or 
operator demonstrates that exemplary operation and maintenance 
procedures were used with respect to the emission control system and 
that proper control equipment was operating at the affected facility 
during the performance test; and
    (3) 0.05 kg/Mg (0.1 lb/ton) of aluminum equivalent for anode bake 
plants.
    (b) Within 30 days of any performance test which reveals emissions 
which fall between the 1.0 kg/Mg and 1.3 kg/Mg levels in paragraph 
(a)(1) of this section or between the 0.95 kg/Mg and 1.25 kg/Mg levels 
in paragraph (a)(2) of this section, the owner or operator shall submit 
a report indicating whether all necessary control devices were on-line 
and operating properly during the performance test, describing the 
operating and maintenance procedures followed, and setting forth any 
explanation for the excess emissions, to the Director of the Enforcement 
Division of the appropriate EPA Regional Office.



Sec. 60.193  Standard for visible emissions.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no

[[Page 246]]

owner or operator subject to the provisions of this subpart shall cause 
to be discharged into the atmosphere:
    (1) From any potroom group any gases which exhibit 10 percent 
opacity or greater, or
    (2) From any anode bake plant any gases which exhibit 20 percent 
opacity or greater.



Sec. 60.194  Monitoring of operations.

    (a) The owner or operator of any affected facility subject to the 
provisions of this subpart shall install, calibrate, maintain, and 
operate monitoring devices which can be used to determine daily the 
weight of aluminum and anode produced. The weighing devices shall have 
an accuracy of plus-minus 5 percent over their operating 
range.
    (b) The owner or operator of any affected facility shall maintain a 
record of daily production rates of aluminum and anodes, raw material 
feed rates, and cell or potline voltages.
    (c) Following the initial performance test as required under 
Sec. 60.8(a), an owner or operator shall conduct a performance test at 
least once each month during the life of the affected facility, except 
when malfunctions prevent representative sampling, as provided under 
Sec. 60.8(c). The owner or operator shall give the Administrator at 
least 15 days advance notice of each test. The Administrator may require 
additional testing under section 114 of the Clean Air Act.
    (d) An owner or operator may petition the Administrator to establish 
an alternative testing requirement that requires testing less frequently 
than once each month for a primary control system or an anode bake 
plant. If the owner or operator show that emissions from the primary 
control system or the anode bake plant have low variability during day-
to-day operations, the Administrator may establish such an alternative 
testing requirement. The alternative testing requirement shall include a 
testing schedule and, in the case of a primary control system, the 
method to be used to determine primary control system emissions for the 
purpose of performance tests. The Administrator shall publish the 
alternative testing requirement in the Federal Register.
    (1) Alternative testing requirements are established for Anaconda 
Aluminum Company's Sebree plant in Henderson, Kentucky: The anode bake 
plant and primary control system are to be tested once a year rather 
than once a month.
    (2) Alternative testing requirements are established for Alumax of 
South Carolina's Mt. Holly Plant in Mt. Holly, South Carolina: The anode 
bake plant and primary control system are to be tested once a year 
rather than once a month.

[45 FR 44207, June 30, 1980, as amended at 54 FR 6669, Feb. 14, 1989]



Sec. 60.195  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the total 
fluorides and visible emission standards in Secs. 60.192 and 60.193 as 
follows:
    (1) The emission rate (Ep) of total fluorides from 
potroom groups shall be computed for each run using the following 
equation:

Ep=[(Cs Qsd)1+(Cs 
          Qsd)2]/(P K)
where:
Ep=emission rate of total fluorides from a potroom group, kg/
          Mg (lb/ton).
Cs=concentration of total fluorides, mg/dscm (mg/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
P=aluminum production rate, Mg/hr (ton/hr).
K=conversion factor, 106 mg/kg (453,600 mg/lb).
1=subscript for primary control system effluent gas.
2=subscript for secondary control system or roof monitor effluent gas.

    (2) The emission rate (Eb) of total fluorides from anode 
bake plants shall be computed for each run using the following equation:

Eb=(Cs Qsd)/(PeK)

where:
Eb=emission rate of total fluorides, kg/Mg (lb/ton) of 
          aluminum equivalent.
Cs=concentration of total fluorides, mg/dscm (mg/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).

[[Page 247]]

Pe=aluminum equivalent for anode production rate, Mg/hr (ton/
          hr).
K=conversion factor, 106 mg/kg (453,600 mg/lb).

    (3) Methods 13A or 13B shall be used for ducts or stacks, and Method 
14 for roof monitors not employing stacks or pollutant collection 
systems, to determine the total fluorides concentration (Cs) 
and volumetric flow rate (Qsd) of the effluent gas. The 
sampling time and sample volume for each run shall be at least 8 hours 
and 6.80 dscm (240 dscf) for potroom groups and at least 4 hours and 
3.40 dscm (120 dscf) for anode bake plants.
    (4) The monitoring devices of Sec. 60.194(a) shall be used to 
determine the daily weight of aluminum and anode produced.
    (i) The aluminum production rate (P) shall be determined by dividing 
720 hours into the weight of aluminum tapped from the affected facility 
during a period of 30 days before and including the final run of a 
performance test.
    (ii) The aluminum equivalent production rate (Pe) for 
anodes shall be determined as 2 times the average weight of anode 
produced during a representative oven cycle divided by the cycle time. 
An owner or operator may establish a multiplication factor other than 2 
by submitting production records of the amount of aluminum produced and 
the concurrent weight of anodes consumed by the potrooms.
    (5) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6669, Feb. 14, 1989]



    Subpart T--Standards of Performance for the Phosphate Fertilizer 
              Industry: Wet-Process Phosphoric Acid Plants



Sec. 60.200  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each wet-process phosphoric acid plant having a design capacity 
of more than 15 tons of equivalent P2O5 feed per 
calendar day. For the purpose of this subpart, the affected facility 
includes any combination of: reactors, filters, evaporators, and hot 
wells.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 22, 1974, is subject to the 
requirements of this subpart.

[42 FR 37937, July 25, 1977, as amended at 48 FR 7129, Feb. 17, 1983]



Sec. 60.201  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Wet-process phosphoric acid plant means any facility 
manufacturing phosphoric acid by reacting phosphate rock and acid.
    (b) Total fluorides means elemental fluorine and all fluoride 
compounds as measured by reference methods specified in Sec. 60.204, or 
equivalent or alternative methods.
    (c) Equivalent P2 O5 feed means the quantity 
of phosphorus, expressed as phosphorous pentoxide, fed to the process.

[40 FR 33154, Aug. 6, 1975]



Sec. 60.202  Standard for fluorides.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain total 
fluorides in excess of 10.0 g/metric ton of equivalent 
P2O5 feed (0.020 lb/ton).

[40 FR 33154, Aug. 6, 1975]



Sec. 60.203  Monitoring of operations.

    (a) The owner or operator of any wet-process phosphoric acid plant 
subject to the provisions of this subpart shall install, calibrate, 
maintain, and operate a monitoring device which can be used to determine 
the mass flow of phosphorus-bearing feed material to the process. The 
monitoring device shall have an accuracy of plus-minus5 
percent over its operating range.
    (b) The owner or operator of any wet-process phosphoric acid plant 
shall maintain a daily record of equivalent P2O5 
feed by first determining the total

[[Page 248]]

mass rate in metric ton/hr of phosphorus bearing feed using a monitoring 
device for measuring mass flowrate which meets the requirements of 
paragraph (a) of this section and then by proceeding according to 
Sec. 60.204(b)(3).
    (c) The owner or operator of any wet-process phosphoric acid subject 
to the provisions of this part shall install, calibrate, maintain, and 
operate a monitoring device which continuously measures and permanently 
records the total pressure drop across the process scrubbing system. The 
monitoring device shall have an accuracy of plus-minus5 
percent over its operating range.

[40 FR 3154, Aug. 6, 1975, as amended at 54 FR 6669, Feb. 14, 1989]



Sec. 60.204  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the total 
fluorides standard in Sec. 60.202 as follows:
    (1) The emission rate (E) of total fluorides shall be computed for 
each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.007

where:
E=emission rate of total fluorides, g/metric ton (lb/ton) of equivalent 
          P2O5 feed.
Csi=concentration of total fluorides from emission point 
          ``i,'' mg/dscm (mg/dscf).
Qsdi=volumetric flow rate of effluent gas from emission point 
          ``i,'' dscm/hr (dscf/hr).
N=number of emission points associated with the affected facility.
P=equivalent P2O5 feed rate, metric ton/hr (ton/
          hr).
K=conversion factor, 1000 mg/g (453,600 mg/lb).

    (2) Method 13A or 13B shall be used to determine the total fluorides 
concentration (Csi) and volumetric flow rate 
(Qsdi) of the effluent gas from each of the emission points. 
The sampling time and sample volume for each run shall be at least 60 
minutes and 0.85 dscm (30 dscf).
    (3) The equivalent P2O5 feed rate (P) shall be 
computed for each run using the following equation:

P=Mp Rp
where:
Mp=total mass flow rate of phosphorus-bearing feed, metric 
          ton/hr (ton/hr).
Rp=P2O5 content, decimal fraction.

    (i) The accountability system of Sec. 60.203(a) shall be used to 
determine the mass flow rate (Mp) of the phosphorus-bearing 
feed.
    (ii) The Association of Official Analytical Chemists (AOAC) Method 9 
(incorporated by reference--see Sec. 60.17) shall be used to determine 
the P2O5 content (Rp) of the feed.

[54 FR 6669, Feb. 14, 1989]



    Subpart U--Standards of Performance for the Phosphate Fertilizer 
                  Industry: Superphosphoric Acid Plants



Sec. 60.210  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each superphosphoric acid plant having a design capacity of 
more than 15 tons of equivalent P2O5 feed per 
calendar day. For the purpose of this subpart, the affected facility 
includes any combination of: evaporators, hot wells, acid sumps, and 
cooling tanks.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 22, 1974, is subject to the 
requirements of this subpart.

[42 FR 37937, July 25, 1977, as amended at 48 FR 7129, Feb. 17, 1983]



Sec. 60.211  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Superphosphoric acid plant means any facility which concentrates 
wet-process phosphoric acid to 66 percent or greater 
P2O5 content by weight for eventual consumption as 
a fertilizer.
    (b) Total fluorides means elemental fluorine and all fluoride 
compounds as measured by reference methods specified in Sec. 60.214, or 
equivalent or alternative methods.

[[Page 249]]

    (c) Equivalent P2 O5 feed means the quantity 
of phosphorus, expressed as phosphorous pentoxide, fed to the process.

[40 FR 33155, Aug. 6, 1975]



Sec. 60.212  Standard for fluorides.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain total 
fluorides in excess of 5.0 g/metric ton of equivalent 
P2O5 feed (0.010 lb/ton).

[40 FR 33155, Aug. 6, 1975]



Sec. 60.213  Monitoring of operations.

    (a) The owner or operator of any superphosphoric acid plant subject 
to the provisions of this subpart shall install, calibrate, maintain, 
and operate a flow monitoring device which can be used to determine the 
mass flow of phosphorus-bearing feed material to the process. The flow 
monitoring device shall have an accuracy of plus-minus5 
percent over its operating range.
    (b) The owner or operator of any superphosphoric acid plant shall 
maintain a daily record of equivalent P2O5 feed by 
first determining the total mass rate in metric ton/hr of phosphorus-
bearing feed using a flow monitoring device meeting the requirements of 
paragraph (a) of this section and then by proceeding according to 
Sec. 60.214(b)(3).
    (c) The owner or operator of any superphosphoric acid plant subject 
to the provisions of this part shall install, calibrate, maintain, and 
operate a monitoring device which continuously measures and permanently 
records the total pressure drop across the process scrubbing system. The 
monitoring device shall have an accuracy of plus-minus5 
percent over its operating range.

[40 FR 33155, Aug. 6, 1975, as amended at 54 FR 6670, Feb. 14, 1989]



Sec. 60.214  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the total 
fluorides standard in Sec. 60.212 as follows:
    (1) The emission rate (E) of total fluorides shall be computed for 
each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.008

where:
E=emission rate of total fluorides, g/metric ton (lb/ton) of equivalent 
          P2O5 feed.
Csi=concentration of total fluorides from emission point 
          ``i,'' mg/dscm (mg/dscf).
Qsdi=volumetric flow rate of effluent gas from emission point 
          ``i,'' dscm/hr (dscf/hr).
N=number of emission points associated with the affected facility.
P=equivalent P2O5 feed rate, metric ton/hr (ton/
          hr).
K=conversion factor, 1000 mg/g (453,600 mg/lb).

    (2) Method 13A or 13B shall be used to determine the total fluorides 
concentration (Csi) and volumetric flow rate 
(Qsdi) of the effluent gas from each of the emission points. 
The sampling time and sample volume for each run shall be at least 60 
minutes and 0.85 dscm (30 dscf).
    (3) The equivalent P2O5 feed rate (P) shall be 
computed for each run using the following equation:

P=Mp Rp
where:
Mp=total mass flow rate of phosphorus-bearing feed, metric 
          ton/hr (ton/hr).
Rp=P2O5 content, decimal fraction.

    (i) The accountability system of Sec. 60.213(a) shall be used to 
determine the mass flow rate (Mp) of the phosphorus-bearing 
feed.
    (ii) The Association of Official Analytical Chemists (AOAC) Method 9 
(incorporated by reference--see Sec. 60.17) shall be used to determine 
the P2O5 content (Rp) of the feed.

[54 FR 6670, Feb. 14, 1989]

[[Page 250]]



    Subpart V--Standards of Performance for the Phosphate Fertilizer 
                  Industry: Diammonium Phosphate Plants



Sec. 60.220  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each granular diammonium phosphate plant having a design 
capacity of more than 15 tons of equivalent P2O5 
feed per calendar day. For the purpose of this subpart, the affected 
facility includes any combination of: reactors, granulators, dryers, 
coolers, screens, and mills.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 22, 1974, is subject to the 
requirements of this subpart.

[42 FR 37938, July 25, 1977, as amended at 48 FR 7129, Feb. 17, 1983]



Sec. 60.221  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Granular diammonium phosphate plant means any plant 
manufacturing granular diammonium phosphate by reacting phosphoric acid 
with ammonia.
    (b) Total fluorides means elemental fluorine and all fluoride 
compounds as measured by reference methods specified in Sec. 60.224, or 
equivalent or alternative methods.
    (c) Equivalent P2O5 feed means the quantity of 
phosphorus, expressed as phosphorus pentoxide, fed to the process.

[40 FR 33155, Aug. 6, 1975]



Sec. 60.222  Standard for fluorides.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain total 
fluorides in excess of 30 g/metric ton of equivalent 
P2O5 feed (0.060 lb/ton).

[40 FR 33155, Aug. 6, 1975]



Sec. 60.223  Monitoring of operations.

    (a) The owner or operator of any granular diammonium phosphate plant 
subject to the provisions of this subpart shall install, calibrate, 
maintain, and operate a flow monitoring device which can be used to 
determine the mass flow of phosphorus-bearing feed material to the 
process. The flow monitoring device shall have an accuracy of 
plus-minus5 percent over its operating range.
    (b) The owner or operator of any granular diammonium phosphate plant 
shall maintain a daily record of equivalent P2O5 
feed by first determining the total mass rate in metric ton/hr of 
phosphorus-bearing feed using a flow monitoring device meeting the 
requirements of paragraph (a) of this section and then by proceeding 
according to Sec. 60.224(b)(3).
    (c) The owner or operator of any granular diammonium phosphate plant 
subject to the provisions of this part shall install, calibrate, 
maintain, and operate a monitoring device which continuously measures 
and permanently records the total pressure drop across the scrubbing 
system. The monitoring device shall have an accuracy of 
plus-minus5 percent over its operating range.

[40 FR 33155, Aug. 6, 1975, as amended at 54 FR 6670, Feb. 14, 1989]



Sec. 60.224  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the total 
fluorides standard in Sec. 60.222 as follows:
    (1) The emission rate (E) of total fluorides shall be computed for 
each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.009

where:
E=emission rate of total fluorides, g/metric ton (lb/ton) of equivalent 
          P2O5 feed.
Csi=concentration of total fluorides from emission point 
          ``i,'' mg/dscm (mg/dscf).
Qsdi=volumetric flow rate of effluent gas from emission point 
          ``i,'' dscm/hr (dscf/hr).

[[Page 251]]

N=number of emission points associated with the affected facility.
P=equivalent P2O5 feed rate, metric ton/hr (ton/
          hr).
K=conversion factor, 1000 mg/g (453,600 mg/lb).

    (2) Method 13A or 13B shall be used to determine the total fluorides 
concentration (Csi) and volumetric flow rate 
(Qsdi) of the effluent gas from each of the emission points. 
The sampling time and sample volume for each run shall be at least 60 
minutes and 0.85 dscm (30 dscf).
    (3) The equivalent P2O5 feed rate (P) shall be 
computed for each run using the following equation:

P=Mp Rp
where:
Mp=total mass flow rate of phosphorus-bearing feed, metric 
          ton/hr (ton/hr).
Rp=P2O5 content, decimal fraction.

    (i) The accountability system of Sec. 60.223(a) shall be used to 
determine the mass flow rate (Mp) of the phosphorus-bearing 
feed.
    (ii) The Association of Official Analytical Chemists (AOAC) Method 9 
(incorported by reference--see Sec. 60.17) shall be used to determine 
the P2O5 content (Rp) of the feed.

[54 FR 6670, Feb. 14, 1989]



    Subpart W--Standards of Performance for the Phosphate Fertilizer 
                 Industry: Triple Superphosphate Plants



Sec. 60.230  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each triple superphosphate plant having a design capacity of 
more than 15 tons of equivalent P2O5 feed per 
calendar day. For the purpose of this subpart, the affected facility 
includes any combination of: mixers, curing belts (dens), reactors, 
granulators, dryers, cookers, screens, mills, and facilities which store 
run-of-pile triple superphosphate.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 22, 1974, is subject to the 
requirements of this subpart.

[42 FR 37938, July 25, 1977, as amended at 48 FR 7129, Feb. 17, 1983]



Sec. 60.231  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Triple superphosphate plant means any facility manufacturing 
triple superphosphate by reacting phosphate rock with phosphoric acid. A 
run-of-pile triple superphosphate plant includes curing and storing.
    (b) Run-of-pile triple superphosphate means any triple 
superphosphate that has not been processed in a granulator and is 
composed of particles at least 25 percent by weight of which (when not 
caked) will pass through a 16 mesh screen.
    (c) Total fluorides means elemental fluorine and all fluoride 
compounds as measured by reference methods specified in Sec. 60.234, or 
equivalent or alternative methods.
    (d) Equivalent P2O5 feed means the quantity of 
phosphorus, expressed as phosphorus pentoxide, fed to the process.

[40 FR 33156, Aug. 6, 1975]



Sec. 60.232  Standard for fluorides.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain total 
fluorides in excess of 100 g/metric ton of equivalent 
P2O5 feed (0.20 lb/ton).

[40 FR 33156, Aug. 6, 1975]



Sec. 60.233  Monitoring of operations.

    (a) The owner or operator of any triple superphosphate plant subject 
to the provisions of this subpart shall install, calibrate, maintain, 
and operate a flow monitoring device which can be used to determine the 
mass flow of phosphorus-bearing feed material to the process. The flow 
monitoring device shall have an accuracy of plus-minus5 
percent over its operating range.
    (b) The owner or operator of any triple superphosphate plant shall 
maintain a daily record of equivalent P2O5 feed by 
first determining the total

[[Page 252]]

mass rate in metric ton/hr of phosphorus-bearing feed using a flow 
monitoring device meeting the requirements of paragraph (a) of this 
section and then by proceeding according to Sec. 60.234(b)(3).
    (c) The owner or operator of any triple superphosphate plant subject 
to the provisions of this part shall install, calibrate, maintain, and 
operate a monitoring device which continuously measures and permanently 
records the total pressure drop across the process scrubbing system. The 
monitoring device shall have an accuracy of plus-minus5 
percent over its operating range.

[40 FR 33156, Aug. 6, 1975, as amended at 54 FR 6670, Feb. 14, 1989]



Sec. 60.234  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the total 
fluorides standards in Sec. 60.232 as follows:
    (1) The emission rate (E) of total fluorides shall be computed for 
each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.010

where:
E=emission rate of total fluorides, g/metric ton (lb/ton) of equivalent 
          P2O5 feed.
Csi=concentration of total fluorides from emission point 
          ``i,'' mg/dscm (mg/dscf).
Qsdi=volumetric flow rate of effluent gas from emission point 
          ``i,'' dscm/hr (dscf/hr).
N=number of emission points in the affected facility.
P=equivalent P2O5 feed rate, metric ton/hr (ton/
          hr).
K=conversion factor, 1000 mg/g (453,600 mg/lb).

    (2) Method 13A or 13b shall be used to determine the total fluorides 
concentration (Csi) and volumetric flow rate 
(Qsdi) of the effluent gas from each of the emission points. 
The sampling time and sample volume for each run shall be at least 60 
minutes and 0.85 dscm (30 dscf).
    (3) The equivalent P2O5 feed rate (P) shall be 
computed for each run using the following equation:

P = Mp Rp
where:
Mp total mass flow rate of phosphorus-bearing feed, metric 
          ton/hr (ton/hr).
Rp=P2O5 content, decimal fraction.

    (i) The accountability system of Sec. 60.233(a) shall be used to 
determine the mass flow rate (Mp) of the phosphorus-bearing 
feed.
    (ii) The Association of Official Analytical Chemists (AOAC) Method 9 
(incorporated by reference--see Sec. 60.17) shall be used to determine 
the P2O5 content (Rp) of the feed.

[54 FR 6670, Feb. 14, 1989; 54 FR 21344, May 17, 1989]



    Subpart X--Standards of Performance for the Phosphate Fertilizer 
       Industry: Granular Triple Superphosphate Storage Facilities



Sec. 60.240  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each granular triple superphosphate storage facility. For the 
purpose of this subpart, the affected facility includes any combination 
of: Storage or curing piles, conveyors, elevators, screens and mills.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 22, 1974, is subject to the 
requirements of this subpart.

[42 FR 37938, July 25, 1977]



Sec. 60.241  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Granular triple superphosphate storage facility means any 
facility curing or storing fresh granular triple superphosphate.
    (b) Total fluorides means elemental fluorine and all fluoride 
compounds as measured by reference methods specified in Sec. 60.244, or 
equivalent or alternative methods.

[[Page 253]]

    (c) Equivalent P2O5 stored means the quantity 
of phosphorus, expressed as phosphorus pentoxide, being cured or stored 
in the affected facility.
    (d) Fresh granular triple superphosphate means granular triple 
superphosphate produced within the preceding 72 hours.

[40 FR 33156, Aug. 6, 1975, as amended at 62 FR 18280, Apr. 15, 1997]



Sec. 60.242  Standard for fluorides.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain total 
fluorides in excess of 0.25 g/hr/metric ton of equivalent 
P2O5 stored (5.0  x  10-4 lb/hr/ton of 
equivalent P2O5 stored).
    (b) No owner or operator subject to the provisions of this subpart 
shall ship fresh granular triple superphosphate from an affected 
facility.

[40 FR 33156, Aug. 6, 1975, as amended at 62 FR 18280, Apr. 15, 1997]



Sec. 60.243  Monitoring of operations.

    (a) The owner or operator of any granular triple superphosphate 
storage facility subject to the provisions of this subpart shall 
maintain an accurate account of triple superphosphate in storage to 
permit the determination of the amount of equivalent 
P2O5 stored.
    (b) The owner or operator of any granular triple superphosphate 
storage facility subject to the provisions of this subpart shall 
maintain a daily record of total equivalent P2O5 
stored by multiplying the percentage P2O5 content, 
as determined by Sec. 60.244(c)(3), times the total mass of granular 
triple superphosphate stored.
    (c) The owner or operator of any granular triple superphosphate 
storage facility subject to the provisions of this subpart shall 
install, calibrate, maintain, and operate a monitoring device which 
continuously measures and permanently records the total pressure drop 
across any process scrubbing system. The monitoring device shall have an 
accuracy of  5 percent over its operating range.
    (d) The owner or operator of any granular triple superphosphate 
storage facility subject to the provisions of this subpart shall develop 
for approval by the Administrator a site-specific methodology including 
sufficient recordkeeping for the purposes of demonstrating compliance 
with Sec. 60.242 (b).

[40 FR 33156, Aug. 6, 1975, as amended at 54 FR 6671, Feb. 14, 1989; 62 
FR 18280, Apr. 15, 1997]



Sec. 60.244  Test methods and procedures.

    (a) The owner or operator shall conduct performance tests required 
in Sec. 60.8 only when the following quantities of product are being 
cured or stored in the facility.
    (1) Total granular triple superphosphate is at least 10 percent of 
the building capacity, and
    (2) Fresh granular triple superphosphate is at least 6 percent of 
the total amount of triple superphosphate, or
    (3) If the provision in paragraph (a)(2) of this section exceeds 
production capabilities for fresh granular triple superphosphate, fresh 
granular triple superphosphate is equal to at least 5 days maximum 
production.
    (b) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (c) The owner or operator shall determine compliance with the total 
fluorides standard in Sec. 60.242 as follows:
    (1) The emission rate (E) of total fluorides shall be computed for 
each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.011

where:
E=emission rate of total fluorides, g/hr/metric ton (lb/hr/ton) of 
          equivalent P2O5 stored.
Csi=concentration of total fluorides from emission point 
          ``i,'' mg/dscm (mg/dscf).
Qsdi=volumetric flow rate of effluent gas from emission point 
          ``i,'' dscm/hr (dscf/hr).
N=number of emission points in the affected facility.
P=equivalent P2O5 stored, metric tons (tons).

[[Page 254]]

K=conversion factor, 1000 mg/g (453,600 mg/lb).

    (2) Method 13A or 13B shall be used to determine the total fluorides 
concentration (Csi) and volumetric flow rate 
(Qsdi) of the effluent gas from each of the emission points. 
The sampling time and sample volume for each run shall be at least 60 
minutes and 0.85 dscm (30 dscf).
    (3) The equivalent P2O5 feed rate (P) shall be 
computed for each run using the following equation:

P=Mp Rp
where:
Mp=amount of product in storage, metric ton (ton).
Rp=P2O5 content of product in storage, 
          weight fraction.

    (i) The accountability system of Sec. 60.243(a) shall be used to 
determine the amount of product (Mp) in storage.
    (ii) The Association of Official Analytical Chemists (AOAC) Method 9 
(incorporated by reference--see Sec. 60.17) shall be used to determine 
the P2O5 content (Rp) of the product in 
storage.

[54 FR 6671, Feb. 14, 1989, as amended at 62 FR 18280, Apr. 15, 1997]



     Subpart Y--Standards of Performance for Coal Preparation Plants



Sec. 60.250  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to any of the 
following affected facilities in coal preparation plants which process 
more than 200 tons per day: Thermal dryers, pneumatic coal-cleaning 
equipment (air tables), coal processing and conveying equipment 
(including breakers and crushers), coal storage systems, and coal 
transfer and loading systems.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October 24, 1974, is subject to the 
requirements of this subpart.

[42 FR 37938, July 25, 1977; 42 FR 44812, Sept. 7, 1977]



Sec. 60.251  Definitions.

    As used in this subpart, all terms not defined herein have the 
meaning given them in the Act and in subpart A of this part.
    (a) Coal preparation plant means any facility (excluding underground 
mining operations) which prepares coal by one or more of the following 
processes: breaking, crushing, screening, wet or dry cleaning, and 
thermal drying.
    (b) Bituminous coal means solid fossil fuel classified as bituminous 
coal by ASTM Designation D388-77 (incorporated by reference--see 
Sec. 60.17).
    (c) Coal means all solid fossil fuels classified as anthracite, 
bituminous, subbituminous, or lignite by ASTM Designation D388-77 
(incorporated by reference--see Sec. 60.17).
    (d) Cyclonic flow means a spiraling movement of exhaust gases within 
a duct or stack.
    (e) Thermal dryer means any facility in which the moisture content 
of bituminous coal is reduced by contact with a heated gas stream which 
is exhausted to the atmosphere.
    (f) Pneumatic coal-cleaning equipment means any facility which 
classifies bituminous coal by size or separates bituminous coal from 
refuse by application of air stream(s).
    (g) Coal processing and conveying equipment means any machinery used 
to reduce the size of coal or to separate coal from refuse, and the 
equipment used to convey coal to or remove coal and refuse from the 
machinery. This includes, but is not limited to, breakers, crushers, 
screens, and conveyor belts.
    (h) Coal storage system means any facility used to store coal except 
for open storage piles.
    (i) Transfer and loading system means any facility used to transfer 
and load coal for shipment.

[41 FR 2234, Jan. 15, 1976, as amended at 48 FR 3738, Jan. 27, 1983]



Sec. 60.252  Standards for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, an owner or operator subject to 
the provisions of this subpart shall not cause to be discharged into the 
atmosphere from any thermal dryer gases which:
    (1) Contain particulate matter in excess of 0.070 g/dscm (0.031 gr/
dscf).

[[Page 255]]

    (2) Exhibit 20 percent opacity or greater.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, an owner or operator subject to 
the provisions of this subpart shall not cause to be discharged into the 
atmosphere from any pneumatic coal cleaning equipment, gases which:
    (1) Contain particulate matter in excess of 0.040 g/dscm (0.018 gr/
dscf).
    (2) Exhibit 10 percent opacity or greater.
    (c) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, an owner or operator subject to 
the provisions of this subpart shall not cause to be discharged into the 
atmosphere from any coal processing and conveying equipment, coal 
storage system, or coal transfer and loading system processing coal, 
gases which exhibit 20 percent opacity or greater.

[41 FR 2234, Jan. 15, 1976]



Sec. 60.253  Monitoring of operations.

    (a) The owner or operator of any thermal dryer shall install, 
calibrate, maintain, and continuously operate monitoring devices as 
follows:
    (1) A monitoring device for the measurement of the temperature of 
the gas stream at the exit of the thermal dryer on a continuous basis. 
The monitoring device is to be certified by the manufacturer to be 
accurate within plus-minus3  deg.Fahrenheit.
    (2) For affected facilities that use venturi scrubber emission 
control equipment:
    (i) A monitoring device for the continuous measurement of the 
pressure loss through the venturi constriction of the control equipment. 
The monitoring device is to be certified by the manufacturer to be 
accurate within plus-minus1 inch water gage.
    (ii) A monitoring device for the continuous measurement of the water 
supply pressure to the control equipment. The monitoring device is to be 
certified by the manufacturer to be accurate within 
plus-minus5 percent of design water supply pressure. The 
pressure sensor or tap must be located close to the water discharge 
point. The Administrator may be consulted for approval of alternative 
locations.
    (b) All monitoring devices under paragraph (a) of this section are 
to be recalibrated annually in accordance with procedures under 
Sec. 60.13(b).

[41 FR 2234, Jan. 15, 1976, as amended at 54 FR 6671, Feb. 14, 1989]



Sec. 60.254  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particular matter standards in Sec. 60.252 as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration. The sampling time and sample volume for each run shall be 
at least 60 minutes and 0.85 dscm (30 dscf). Sampling shall begin no 
less than 30 minutes after startup and shall terminate before shutdown 
procedures begin.
    (2) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6671, Feb. 14, 1989]



Subpart Z--Standards of Performance for Ferroalloy Production Facilities

    Source: 41 FR 18501, May 4, 1976, unless otherwise noted.



Sec. 60.260  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities: Electric submerged arc furnaces which produce 
silicon metal, ferrosilicon, calcium silicon, silicomanganese zirconium, 
ferrochrome silicon, silvery iron, high-carbon ferrochrome, charge 
chrome, standard ferromanganese, silicomanganese, ferromanganese 
silicon, or calcium carbide; and dust-handling equipment.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after October

[[Page 256]]

21, 1974, is subject to the requirements of this subpart.

[42 FR 37938, July 25, 1977]



Sec. 60.261  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Electric submerged arc furnace means any furnace wherein 
electrical energy is converted to heat energy by transmission of current 
between electrodes partially submerged in the furnace charge.
    (b) Furnace charge means any material introduced into the electric 
submerged arc furnace, and may consist of, but is not limited to, ores, 
slag, carbonaceous material, and limestone.
    (c) Product change means any change in the composition of the 
furnace charge that would cause the electric submerged arc furnace to 
become subject to a different mass standard applicable under this 
subpart.
    (d) Slag means the more or less completely fused and vitrified 
matter separated during the reduction of a metal from its ore.
    (e) Tapping means the removal of slag or product from the electric 
submerged arc furnace under normal operating conditions such as removal 
of metal under normal pressure and movement by gravity down the spout 
into the ladle.
    (f) Tapping period means the time duration from initiation of the 
process of opening the tap hole until plugging of the tap hole is 
complete.
    (g) Furnace cycle means the time period from completion of a furnace 
product tap to the completion of the next consecutive product tap.
    (h) Tapping station means that general area where molten product or 
slag is removed from the electric submerged arc furnace.
    (i) Blowing tap means any tap in which an evolution of gas forces or 
projects jets of flame or metal sparks beyond the ladle, runner, or 
collection hood.
    (j) Furnace power input means the resistive electrical power 
consumption of an electric submerged arc furnace as measured in 
kilowatts.
    (k) Dust-handling equipment means any equipment used to handle 
particulate matter collected by the air pollution control device (and 
located at or near such device) serving any electric submerged arc 
furnace subject to this subpart.
    (l) Control device means the air pollution control equipment used to 
remove particulate matter generated by an electric submerged arc furnace 
from an effluent gas stream.
    (m) Capture system means the equipment (including hoods, ducts, 
fans, dampers, etc.) used to capture or transport particulate matter 
generated by an affected electric submerged arc furnace to the control 
device.
    (n) Standard ferromanganese means that alloy as defined by ASTM 
Designation A99-76 (incorporated by reference--see Sec. 60.17).
    (o) Silicomanganese means that alloy as defined by ASTM Designation 
A483-64 (Reapproved 1974) (incorporated by reference--see Sec. 60.17).
    (p) Calcium carbide means material containing 70 to 85 percent 
calcium carbide by weight.
    (q) High-carbon ferrochrome means that alloy as defined by ASTM 
Designation A101-73 (incorporated by reference--see Sec. 60.17) grades 
HC1 through HC6.
    (r) Charge chrome means that alloy containing 52 to 70 percent by 
weight chromium, 5 to 8 percent by weight carbon, and 3 to 6 percent by 
weight silicon.
    (s) Silvery iron means any ferrosilicon, as defined by ASTM 
Designation A100-69 (Reapproved 1974) (incorporated by reference--see 
Sec. 60.17), which contains less than 30 percent silicon.
    (t) Ferrochrome silicon means that alloy as defined by ASTM 
Designation A482-76 (incorporated by reference--see Sec. 60.17).
    (u) Silicomanganese zirconium means that alloy containing 60 to 65 
percent by weight silicon, 1.5 to 2.5 percent by weight calcium, 5 to 7 
percent by weight zirconium, 0.75 to 1.25 percent by weight aluminum, 5 
to 7 percent by weight manganese, and 2 to 3 percent by weight barium.
    (v) Calcium silicon means that alloy as defined by ASTM Designation 
A495-

[[Page 257]]

76 (incorporated by reference--see Sec. 60.17).
    (w) Ferrosilicon means that alloy as defined by ASTM Designation 
A100-69 (Reapproved 1974) (incorporated by reference--see Sec. 60.17) 
grades A, B, C, D, and E, which contains 50 or more percent by weight 
silicon.
    (x) Silicon metal means any silicon alloy containing more than 96 
percent silicon by weight.
    (y) Ferromanganese silicon means that alloy containing 63 to 66 
percent by weight manganese, 28 to 32 percent by weight silicon, and a 
maximum of 0.08 percent by weight carbon.

[41 FR 18501, May 4, 1976; 41 FR 20659, May 20, 1976, as amended at 48 
FR 3738, Jan. 27, 1983]



Sec. 60.262  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any electric submerged arc furnace any gases which:
    (1) Exit from a control device and contain particulate matter in 
excess of 0.45 kg/MW-hr (0.99 lb/MW-hr) while silicon metal, 
ferrosilicon, calcium silicon, or silicomanganese zirconium is being 
produced.
    (2) Exit from a control device and contain particulate matter in 
excess of 0.23 kg/MW-hr (0.51 lb/MW-hr) while highcarbon ferrochrome, 
charge chrome, standard ferromanganese, silicomanganese, calcium 
carbide, ferrochrome silicon, ferromanganese silicon, or silvery iron is 
being produced.
    (3) Exit from a control device and exhibit 15 percent opacity or 
greater.
    (4) Exit from an electric submerged arc furnace and escape the 
capture system and are visible without the aid of instruments. The 
requirements under this subparagraph apply only during periods when flow 
rates are being established under Sec. 60.265(d).
    (5) Escape the capture system at the tapping station and are visible 
without the aid of instruments for more than 40 percent of each tapping 
period. There are no limitations on visible emissions under this 
subparagraph when a blowing tap occurs. The requirements under this 
subparagraph apply only during periods when flow rates are being 
established under Sec. 60.265(d).
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any dust-handling equipment any gases which exhibit 10 
percent opacity or greater.



Sec. 60.263  Standard for carbon monoxide.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged in to the 
atmosphere from any electric submerged arc furnace any gases which 
contain, on a dry basis, 20 or greater volume percent of carbon 
monoxide. Combustion of such gases under conditions acceptable to the 
Administrator constitutes compliance with this section. Acceptable 
conditions include, but are not limited to, flaring of gases or use of 
gases as fuel for other processes.



Sec. 60.264  Emission monitoring.

    (a) The owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain and operate a continuous monitoring 
system for measurement of the opacity of emissions discharged into the 
atmosphere from the control device(s).
    (b) For the purpose of reports required under Sec. 60.7(c), the 
owner or operator shall report as excess emissions all six-minute 
periods in which the average opacity is 15 percent or greater.
    (c) The owner or operator subject to the provisions of this subpart 
shall submit a written report of any product change to the 
Administrator. Reports of product changes must be postmarked not later 
than 30 days after implementation of the product change.



Sec. 60.265  Monitoring of operations.

    (a) The owner or operator of any electric submerged arc furnace 
subject to the provisions of this subpart shall maintain daily records 
of the following information:

[[Page 258]]

    (1) Product being produced.
    (2) Description of constituents of furnace charge, including the 
quantity, by weight.
    (3) Time and duration of each tapping period and the identification 
of material tapped (slag or product.)
    (4) All furnace power input data obtained under paragraph (b) of 
this section.
    (5) All flow rate data obtained under paragraph (c) of this section 
or all fan motor power consumption and pressure drop data obtained under 
paragraph (e) of this section.
    (b) The owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain, and operate a device to measure and 
continuously record the furnace power input. The furnace power input may 
be measured at the output or input side of the transformer. The device 
must have an accuracy of plus-minus5 percent over its 
operating range.
    (c) The owner or operator subject to the provisions of this subpart 
shall install, calibrate, and maintain a monitoring device that 
continuously measures and records the volumetric flow rate through each 
separately ducted hood of the capture system, except as provided under 
paragraph (e) of this section. The owner or operator of an electric 
submerged arc furnace that is equipped with a water cooled cover which 
is designed to contain and prevent escape of the generated gas and 
particulate matter shall monitor only the volumetric flow rate through 
the capture system for control of emissions from the tapping station. 
The owner or operator may install the monitoring device(s) in any 
appropriate location in the exhaust duct such that reproducible flow 
rate monitoring will result. The flow rate monitoring device must have 
an accuracy of plus-minus10 percent over its normal operating 
range and must be calibrated according to the manufacturer's 
instructions. The Administrator may require the owner or operator to 
demonstrate the accuracy of the monitoring device relative to Methods 1 
and 2 of appendix A to this part.
    (d) When performance tests are conducted under the provisions of 
Sec. 60.8 of this part to demonstrate compliance with the standards 
under Secs. 60.262(a) (4) and (5), the volumetric flow rate through each 
separately ducted hood of the capture system must be determined using 
the monitoring device required under paragraph (c) of this section. The 
volumetric flow rates must be determined for furnace power input levels 
at 50 and 100 percent of the nominal rated capacity of the electric 
submerged arc furnace. At all times the electric submerged arc furnace 
is operated, the owner or operator shall maintain the volumetric flow 
rate at or above the appropriate levels for that furnace power input 
level determined during the most recent performance test. If emissions 
due to tapping are captured and ducted separately from emissions of the 
electric submerged arc furnace, during each tapping period the owner or 
operator shall maintain the exhaust flow rates through the capture 
system over the tapping station at or above the levels established 
during the most recent performance test. Operation at lower flow rates 
may be considered by the Administrator to be unacceptable operation and 
maintenance of the affected facility. The owner or operator may request 
that these flow rates be reestablished by conducting new performance 
tests under Sec. 60.8 of this part.
    (e) The owner or operator may as an alternative to paragraph (c) of 
this section determine the volumetric flow rate through each fan of the 
capture system from the fan power consumption, pressure drop across the 
fan and the fan performance curve. Only data specific to the operation 
of the affected electric submerged arc furnace are acceptable for 
demonstration of compliance with the requirements of this paragraph. The 
owner or operator shall maintain on file a permanent record of the fan 
performance curve (prepared for a specific temperature) and shall:
    (1) Install, calibrate, maintain, and operate a device to 
continuously measure and record the power consumption of the fan motor 
(measured in kilowatts), and
    (2) Install, calibrate, maintain, and operate a device to 
continuously measure and record the pressure drop across the fan. The 
fan power consumption and pressure drop measurements must be 
synchronized to allow real time

[[Page 259]]

comparisions of the data. The monitoring devices must have an accuracy 
of plus-minus5 percent over their normal operating ranges.
    (f) The volumetric flow rate through each fan of the capture system 
must be determined from the fan power consumption, fan pressure drop, 
and fan performance curve specified under paragraph (e) of this section, 
during any performance test required under Sec. 60.8 to demonstrate 
compliance with the standards under Secs. 60.262(a)(4) and (5). The 
owner or operator shall determine the volumetric flow rate at a 
representative temperature for furnace power input levels of 50 and 100 
percent of the nominal rated capacity of the electric submerged arc 
furnace. At all times the electric submerged arc furnace is operated, 
the owner or operator shall maintain the fan power consumption and fan 
pressure drop at levels such that the volumetric flow rate is at or 
above the levels established during the most recent performance test for 
that furnace power input level. If emissions due to tapping are captured 
and ducted separately from emissions of the electric submerged arc 
furnace, during each tapping period the owner or operator shall maintain 
the fan power consumption and fan pressure drop at levels such that the 
volumetric flow rate is at or above the levels established during the 
most recent performance test. Operation at lower flow rates may be 
considered by the Administrator to be unacceptable operation and 
maintenance of the affected facility. The owner or operator may request 
that these flow rates be reestablished by conducting new performance 
tests under Sec. 60.8. The Administrator may require the owner or 
operator to verify the fan performance curve by monitoring necessary fan 
operating parameters and determining the gas volume moved relative to 
Methods 1 and 2 of appendix A to this part.
    (g) All monitoring devices required under paragraphs (c) and (e) of 
this section are to be checked for calibration annually in accordance 
with the procedures under Sec. 60.13(b).



Sec. 60.266  Test methods and procedures.

    (a) During any performance test required in Sec. 60.8, the owner or 
operator shall not allow gaseous diluents to be added to the effluent 
gas stream after the fabric in an open pressurized fabric filter 
collector unless the total gas volume flow from the collector is 
accurately determined and considered in the determination of emissions.
    (b) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (c) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.262 as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.012

where:
E=emission rate of particulate matter, kg/MW-hr (1b/MW-hr).
n=total number of exhaust streams at which emissions is quantified.
csi=concentration of particulate matter from exhaust stream 
          ``i'', g/dscm (g/dscf).
Qsdi=volumetric flow rate of effluent gas from exhaust stream 
          ``i'', dscm/hr (dscf/hr).
P=average furnace power input, MW.
K=conversion factor, 1000 g/kg (453.6 g/lb).

    (2) Method 5 shall be used to determine the particulate matter 
concentration (csi) and volumetric flow rate 
(Qsdi) of the effluent gas, except that the heating systems 
specified in sections 2.1.2 and 2.1.6 are not to be used when the carbon 
monoxide content of the gas stream exceeds 10 percent by volume, dry 
basis. If a flare is used to comply with Sec. 60.263, the sampling site 
shall be upstream of the flare. The sampling time shall include an 
integral number of furnace cycles.
    (i) When sampling emissions from open electric submerged arc 
furnaces with wet scrubber control devices, sealed electric submerged 
arc furnaces, or semienclosed electric arc furnaces, the sampling time 
and sample volume for each run shall be at least 60 minutes and 1.80 
dscm (63.6 dscf).
    (ii) When sampling emissions from other types of installations, the 
sampling time and sample volume for each

[[Page 260]]

run shall be at least 200 minutes and 5.70 dscm (200 dscf).
    (3) The measurement device of Sec. 60.265(b) shall be used to 
determine the average furnace power input (P) during each run.
    (4) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (5) The emission rate correction factor, integrated sampling 
procedure of Method 3B shall be used to determine the CO concentration. 
The sample shall be taken simultaneously with each particulate matter 
sample.
    (d) During the particulate matter run, the maximum open hood area 
(in hoods with segmented or otherwise moveable sides) under which the 
process is expected to be operated and remain in compliance with all 
standards shall be recorded. Any future operation of the hooding system 
with open areas in excess of the maximum is not permitted.
    (e) To comply with Sec. 60.265 (d) or (f), the owner or operator 
shall use the monitoring devices in Sec. 60.265 (c) or (e) to make the 
required measurements as determined during the performance test.

[54 FR 6671, Feb. 14, 1989; 54 FR 21344, May 17, 1989, as amended at 55 
FR 5212, Feb. 14, 1990]



  Subpart AA--Standards of Performance for Steel Plants: Electric Arc 
Furnaces Constructed After October 21, 1974, and On or Before August 17, 
                                  1983



Sec. 60.270  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in steel plants that produce carbon, alloy, or 
specialty steels: electric arc furnaces and dust-handling systems.
    (b) The provisions of this subpart apply to each affected facility 
identified in paragraph (a) of this section that commenced construction, 
modification, or reconstruction after October 21, 1974, and on or before 
August 17, 1983.

[49 FR 43843, Oct. 31, 1984]



Sec. 60.271  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Electric arc furnace (EAF) means a furnace that produces molten 
steel and heats the charge materials with electric arcs from carbon 
electrodes. Furnaces that continuously feed direct-reduced iron ore 
pellets as the primary source of iron are not affected facilities within 
the scope of this definition.
    (b) Dust-handling equipment means any equipment used to handle 
particulate matter collected by the control device and located at or 
near the control device for an EAF subject to this subpart.
    (c) Control device means the air pollution control equipment used to 
remove particulate matter generated by an EAF(s) from the effluent gas 
stream.
    (d) Capture system means the equipment (including ducts, hoods, 
fans, dampers, etc.) used to capture or transport particulate matter 
generated by an EAF to the air pollution control device.
    (e) Charge means the addition of iron and steel scrap or other 
materials into the top of an electric arc furnace.
    (f) Charging period means the time period commencing at the moment 
an EAF starts to open and ending either three minutes after the EAF roof 
is returned to its closed position or six minutes after commencement of 
opening of the roof, whichever is longer.
    (g) Tap means the pouring of molten steel from an EAF.
    (h) Tapping period means the time period commencing at the moment an 
EAF begins to pour molten steel and ending either three minutes after 
steel ceases to flow from an EAF, or six minutes after steel begins to 
flow, whichever is longer.
    (i) Meltdown and refining means that phase of the steel production 
cycle when charge material is melted and undesirable elements are 
removed from the metal.
    (j) Meltdown and refining period means the time period commencing at 
the termination of the initial charging period

[[Page 261]]

and ending at the initiation of the tapping period, excluding any 
intermediate charging periods and times when power to the EAF is off.
    (k) Shop opacity means the arithmetic average of 24 or more opacity 
observations of emissions from the shop taken in accordance with Method 
9 of appendix A of this part for the applicable time periods.
    (l) Heat time means the period commencing when scrap is charged to 
an empty EAF and terminating when the EAF tap is completed.
    (m) Shop means the building which houses one or more EAF's.
    (n) Direct shell evacuation system means any system that maintains a 
negative pressure within the EAF above the slag or metal and ducts these 
emissions to the control device.

[40 FR 43852, Sept. 23, 1975, as amended at 49 FR 43843, Oct. 31, 1984; 
64 FR 10109, Mar. 2, 1999]



Sec. 60.272  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from an electric arc furnace any gases which:
    (1) Exit from a control device and contain particulate matter in 
excess of 12 mg/dscm (0.0052 gr/dscf).
    (2) Exit from a control device and exhibit three percent opacity or 
greater.
    (3) Exit from a shop and, due solely to operations of any EAF(s), 
exhibit 6 percent opacity or greater except:
    (i) Shop opacity less than 20 percent may occur during charging 
periods.
    (ii) Shop opacity less than 40 percent may occur during tapping 
periods.
    (iii) The shop opacity standards under paragraph (a)(3) of this 
section shall apply only during periods when the monitoring parameter 
limits specified in Sec. 60.274(b) are being established according to 
Sec. 60.274(c) and (g), unless the owner or operator elects to perform 
daily shop opacity observations in lieu of furnace static pressure 
monitoring as provided for under Sec. 60.273(d).
    (iv) Where the capture system is operated such that the roof of the 
shop is closed during the charge and the tap, and emissions to the 
atmosphere are prevented until the roof is opened after completion of 
the charge or tap, the shop opacity standards under paragraph (a)(3) of 
this section shall apply when the roof is opened and shall continue to 
apply for the length of time defined by the charging and/or tapping 
periods.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from dust-handling equipment any gases which exhibit 10 
percent opacity or greater.

[40 FR 43852, Sept. 23, 1975, as amended at 49 FR 43843, Oct. 31, 1984; 
64 FR 10109, Mar. 2, 1999]



Sec. 60.273  Emission monitoring.

    (a) A continuous monitoring system for the measurement of the 
opacity of emissions discharged into the atmosphere from the control 
device(s) shall be installed, calibrated, maintained, and operated by 
the owner or operator subject to the provisions of this subpart.
    (b) For the purpose of reports under Sec. 60.7(c), all six-minute 
periods during which the average opacity is three percent or greater 
shall indicate a period of excess emission, and shall be reported to the 
Administrator semi-annually.
    (c) A continuous monitoring system is not required on any modular, 
multiple-stack, negative-pressure or positive-pressure fabric filter if 
observations of the opacity of the visible emissions from the control 
device are performed by a certified visible emission observer as 
follows: Visible emission observations shall be conducted at least once 
per day when the furnace is operating in the melting and refining 
period. These observations shall be taken in accordance with Method 9, 
and, for at least three 6-minute periods, the opacity shall be recorded 
for any point(s) where visible emissions are observed. Where it is 
possible to determine that a number of visible emission sites relate to 
only one incident of the visible emission, only one set of

[[Page 262]]

three 6-minute observations will be required. In this case, Method 9 
observations must be made for the site of highest opacity that directly 
relates to the cause (or location) of visible emissions observed during 
a single incident. Records shall be maintained of any 6-minute average 
that is in excess of the emission limit specified in Sec. 60.272(a) of 
this subpart.
    (d) A furnace static pressure monitoring device is not required on 
any EAF equipped with a DEC system if observations of shop opacity are 
performed by a certified visible emission observer as follows: Shop 
opacity observations shall be conducted at least once per day when the 
furnace is operating in the meltdown and refining period. Shop opacity 
shall be determined as the arithmetic average of 24 or more consecutive 
15-second opacity observations of emissions from the shop taken in 
accordance with Method 9. Shop opacity shall be recorded for any 
point(s) where visible emissions are observed in proximity to an 
affected EAF. Where it is possible to determine that a number of visible 
emission sites relate to only one incident of visible emissions, only 
one observation of shop opacity will be required. In this case, the shop 
opacity observations must be made for the site of highest opacity that 
directly relates to the cause (or location) of visible emissions 
observed during a single incident.

[40 FR 43852, Sept. 23, 1975, as amended at 49 FR 43843, Oct. 31, 1984; 
54 FR 6672. Feb. 14, 1989; 64 FR 10109, Mar. 2, 1999]



Sec. 60.274  Monitoring of operations.

    (a) The owner or operator subject to the provisions of this subpart 
shall maintain records daily of the following information:
    (1) Time and duration of each charge;
    (2) Time and duration of each tap;
    (3) All flow rate data obtained under paragraph (b) of this section, 
or equivalent obtained under paragraph (d) of this section; and
    (4) All pressure data obtained under paragraph (e) of this section.
    (b) Except as provided under paragraph (d) of this section, the 
owner or operator subject to the provisions of this subpart shall check 
and record on a once-per-shift basis furnace static pressure (if a DEC 
system is in use, and a furnace static pressure gauge is installed 
according to paragraph (f) of this section) and either: check and record 
the control system fan motor amperes and damper positions on a once-per-
shift basis; install, calibrate, and maintain a monitoring device that 
continuously records the volumetric flow rate through each separately 
ducted hood; or install, calibrate, and maintain a monitoring device 
that continuously records the volumetric flow rate at the control device 
inlet and check and record damper positions on a once-per-shift basis. 
The monitoring device(s) may be installed in any appropriate location in 
the exhaust duct such that reproducible flow rate monitoring will 
result. The flow rate monitoring device(s) shall have an accuracy of 
10 percent over its normal operating range and shall be 
calibrated according to the manufacturer's instructions. The 
Administrator may require the owner or operator to demonstrate the 
accuracy of the monitoring device(s) relative to Methods 1 and 2 of 
appendix A of this part.
    (c) When the owner or operator of an EAF is required to demonstrate 
compliance with the standards under Sec. 60.272(a)(3) and at any other 
time the Administrator may require that (under section 114 of the Act, 
as amended) either: the control system fan motor amperes and all damper 
positions; the volumetric flow rate through each separately ducted hood; 
or the volumetric flow rate at the control device inlet and all damper 
positions shall be determined during all periods in which a hood is 
operated for the purpose of capturing emissions from the EAF subject to 
paragraph (b)(1) or (b)(2) of this section. The owner or operator may 
petition the Administrator for reestablishment of these parameters 
whenever the owner or operator can demonstrate to the Administrator's 
satisfaction that the EAF operating conditions upon which the parameters 
were previously established are no longer applicable. The values of 
these parameters as determined during the most recent demonstration of 
compliance shall be maintained at the appropriate level for each 
applicable period. Operation at

[[Page 263]]

other than baseline values may be subject to the requirements of 
Sec. 60.276(a).
    (d) The owner or operator may petition the Administrator to approve 
any alternative method that will provide a continuous record of 
operation of each emission capture system.
    (e) The owner or operator shall perform monthly operational status 
inspections of the equipment that is important to the performance of the 
total capture system (i.e., pressure sensors, dampers, and damper 
switches). This inspection shall include observations of the physical 
appearance of the equipment (e.g., presence of hole in ductwork or 
hoods, flow constrictions caused by dents or accumulated dust in 
ductwork, and fan erosion). Any deficiencies shall be noted and proper 
maintenance performed.
    (f) Except as provided for under Sec. 60.273(d), where emissions 
during any phase of the heat time are controlled by use of a direct 
shell evacuation system, the owner or operator shall install, calibrate, 
and maintain a monitoring device that continuously records the pressure 
in the free space inside the EAF. The pressure shall be recorded as 15-
minute integrated averages. The monitoring device may be installed in 
any appropriate location in the EAF or DEC duct prior to the 
introduction of ambient air such that reproducible results will be 
obtained. The pressure monitoring device shall have an accuracy of 
5 mm of water gauge over its normal operating range and 
shall be calibrated according to the manufacturer's instructions.
    (g) Except as provided for under Sec. 60.273(d), when the owner or 
operator of an EAF is required to demonstrate compliance with the 
standard under Sec. 60.272(a)(3) and at any other time the Administrator 
may require (under section 114 of the Act, as amended), the pressure in 
the free space inside the furnace shall be determined during the 
meltdown and refining period(s) using the monitoring device under 
paragraph (f) of this section. The owner or operator may petition the 
Administrator for reestablishment of the 15-minute integrated average 
pressure whenever the owner or operator can demonstrate to the 
Administrator's satisfaction that the EAF operating conditions upon 
which the pressures were previously established are no longer 
applicable. The pressure determined during the most recent demonstration 
of compliance shall be maintained at all times the EAF is operating in a 
meltdown and refining period. Operation at higher pressures may be 
considered by the Administrator to be unacceptable operation and 
maintenance of the affected facility.
    (h) Where the capture system is designed and operated such that all 
emissions are captured and ducted to a control device, the owner or 
operator shall not be subject to the requirements of this section.
    (i) During any performance test required under Sec. 60.8, and for 
any report thereof required by Sec. 60.275(c) of this subpart or to 
determine compliance with Sec. 60.272(a)(3) of this subpart, the owner 
or operator shall monitor the following information for all heats 
covered by the test:
    (1) Charge weights and materials, and tap weights and materials;
    (2) Heat times, including start and stop times, and a log of process 
operation, including periods of no operation during testing and the 
pressure inside the furnace where direct-shell evacuation systems are 
used;
    (3) Control device operation log; and
    (4) Continuous monitor or Reference Method 9 data.

[40 FR 43852, Sept. 23, 1975, as amended at 49 FR 43843, Oct. 31, 1984; 
64 FR 10110, Mar. 2, 1999]



Sec. 60.275  Test methods and procedures.

    (a) During performance tests required in Sec. 60.8, the owner or 
operator shall not add gaseous diluent to the effluent gas after the 
fabric in any pressurized fabric collector, unless the amount of 
dilution is separately determined and considered in the determination of 
emissions.
    (b) When emissions from any EAF(s) are combined with emissions from 
facilities not subject to the provisions of this subpart but controlled 
by a common capture system and control device, the owner or operator 
shall use either or both of the following procedures during a 
performance test (see also Sec. 60.276(b)):

[[Page 264]]

    (1) Determine compliance using the combined emissions.
    (2) Use a method that is acceptable to the Administrator and that 
compensates for the emissions from the facilities not subject to the 
provisions of this subpart.
    (c) When emissions from any EAF(s) are combined with emissions from 
facilities not subject to the provisions of this subpart, the owner or 
operator shall use either or both of the following procedures to 
demonstrate compliance with Sec. 60.272(a)(3):
    (1) Determine compliance using the combined emissions.
    (2) Shut down operation of facilities not subject to the provisions 
of this subpart during the performance test.
    (d) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (e) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.272 as follows:
    (1) Method 5 shall be used for negative-pressure fabric filters and 
other types of control devices and Method 5D shall be used for positive-
pressure fabric filters to determine the particular matter concentration 
and, if applicable, the volumetric flow rate of the effluent gas. The 
sampling time and sample volume for each run shall be at least 4 hours 
and 4.5 dscm (160 dscf) and, when a single EAF is sampled, the sampling 
time shall include an integral number of heats.
    (2) When more then one control device serves the EAF(s) being 
tested, the concentration of particulate matter shall be determined 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.013

where:
cst=average concentration of particulate matter, mg/dscm (gr/
          dscf).
csi=concentration of particulate matter from control device 
          ``i'', mg/dscm (gr/dscf).
n=total number of control devices tested.
Qsdi=volumetric flow rate of stack gas from control device 
          ``i'', dscm/hr (dscf/hr).

    (3) Method 9 and the procedures of Sec. 60.11 shall be used to 
determine opacity.
    (4) To demonstrate compliance with Sec. 60.272(a) (1), (2), and (3), 
the test runs shall be conducted concurrently, unless inclement weather 
interferes.
    (f) To comply with Sec. 60.274 (c), (f), (g), and (i), the owner or 
operator shall obtain the information in these paragraphs during the 
particulate matter runs.
    (g) Where emissions from any EAF(s) are combined with emissions from 
facilities not subject to the provisions of this subpart but controlled 
by a common capture system and control device, the owner or operator may 
use any of the following procedures during a performance test:
    (1) Base compliance on control of the combined emissions.
    (2) Utilize a method acceptable to the Administrator which 
compensates for the emissions from the facilities not subject to the 
provisions of this subpart.
    (3) Any combination of the criteria of paragraphs (g)(1) and (g)(2) 
of this section.
    (h) Where emissions from any EAF(s) are combined with emissions from 
facilities not subject to the provisions of this subpart, the owner or 
operator may use any of the following procedures for demonstrating 
compliance with Sec. 60.272(a)(3):
    (1) Base compliance on control of the combined emissions.
    (2) Shut down operation of facilities not subject to the provisions 
of this subpart.
    (3) Any combination of the criteria of paragraphs (h)(1) and (h)(2) 
of this section.
    (i) Visible emissions observations of modular, multiple-stack, 
negative-pressure or positive-pressure fabric filters shall occur at 
least once per day of operation. The observations shall occur when the 
furnace is operating in the melting and refining period. These 
observations shall be taken in accordance with Method 9, and, for at 
least three 6-minute periods, the opacity shall be recorded for any 
point(s) where visible emissions are observed. Where it is possible to 
determine that a number of visible emission sites relate to only

[[Page 265]]

one incident of the visible emissions, only one set of three 6-minute 
observations will be required. In the case, Reference Method 9 
observations must be made for the site of highest opacity that directly 
relates to the cause (or location) of visible emissions observed during 
a single incident. Records shall be maintained of any 6-minute average 
that is in excess of the emission limit specified in Sec. 60.272(a) of 
this subpart.
    (j) Unless the presence of inclement weather makes concurrent 
testing infeasible, the owner or operator shall conduct concurrently the 
performance tests required under Sec. 60.8 to demonstrate compliance 
with Sec. 60.272(a) (1), (2), and (3) of this subpart.

[40 FR 43852, Sept. 23, 1975, as amended at 49 FR 43844, Oct. 31, 1984; 
54 FR 6672, Feb. 14, 1989; 54 FR 21344, May 17, 1989]



Sec. 60.276  Recordkeeping and reporting requirements.

    (a) Operation at a furnace static pressure that exceeds the value 
established under Sec. 60.274(f) and either operation of control system 
fan motor amperes at valves exceeding plus-minus15 percent of 
the value established under Sec. 60.274(c) or operation at flow rates 
lower than those established under Sec. 60.274(c) may be considered by 
the Administrator to be unacceptable operation and maintenance of the 
affected facility. Operation at such values shall be reported to 
Administrator semiannually.
    (b) When the owner or operator of an EAF is required to demonstrate 
compliance with the standard under Sec. 60.275 (b)(2) or a combination 
of (b)(1) and (b)(2), the owner or operator shall obtain approval from 
the Administrator of the procedure(s) that will be used to determine 
compliance. Notification of the procedure(s) to be used must be 
postmarked 30 days prior to the performance test.
    (c) For the purpose of this subpart, the owner or operator shall 
conduct the demonstration of compliance with Sec. 60.272(a) of this 
subpart and furnish the Administrator a written report of the results of 
the test. This report shall include the following information:
    (1) Facility name and address;
    (2) Plant representative;
    (3) Make and model of process, control device, and continuous 
monitoring equipment;
    (4) Flow diagram of process and emission capture equipment including 
other equipment or process(es) ducted to the same control device;
    (5) Rated (design) capacity of process equipment;
    (6) Those data required under Sec. 60.274(i) of this subpart;
    (i) List of charge and tap weights and materials;
    (ii) Heat times and process log;
    (iii) Control device operation log; and
    (iv) Continuous monitor or Reference Method 9 data.
    (7) Test dates and test times;
    (8) Test company;
    (9) Test company representative;
    (10) Test observers from outside agency;
    (11) Description of test methodology used, including any deviation 
from standard reference methods
    (12) Schematic of sampling location;
    (13) Number of sampling points;
    (14) Description of sampling equipment;
    (15) Listing of sampling equipment calibrations and procedures;
    (16) Field and laboratory data sheets;
    (17) Description of sample recovery procedures;
    (18) Sampling equipment leak check results;
    (19) Description of quality assurance procedures;
    (20) Description of analytical procedures;
    (21) Notation of sample blank corrections; and
    (22) Sample emission calculations.
    (d) The owner or operator shall maintain records of all shop opacity 
observations made in accordance with Sec. 60.273(d). All shop opacity 
observations in excess of the emission limit specified in 
Sec. 60.272(a)(3) of this subpart shall indicate a period of excess 
emission, and shall be reported to the Administrator semi-annually, 
according to Sec. 60.7(c).

[49 FR 43844, Oct. 31, 1984, as amended at 54 FR 6672, Feb. 14, 1989; 64 
FR 10110, Mar. 2, 1999]

[[Page 266]]



  Subpart AAa--Standards of Performance for Steel Plants: Electric Arc 
  Furnaces and Argon-Oxygen Decarburization Vessels Constructed After 
                             August 17, 1983

    Source: 49 FR 43845, Oct. 31, 1984, unless otherwise noted.



Sec. 60.270a  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in steel plants that produce carbon, alloy, or 
specialty steels: electric arc furnaces, argon-oxygen decarburization 
vessels, and dust-handling systems.
    (b) The provisions of this subpart apply to each affected facility 
identified in paragraph (a) of this section that commences construction, 
modification, or reconstruction after August 17, 1983.



Sec. 60.271a  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    Argon-oxygen decarburization vessel (AOD vessel) means any closed-
bottom, refractory-lined converter vessel with submerged tuyeres through 
which gaseous mixtures containing argon and oxygen or nitrogen may be 
blown into molten steel for further refining.
    Capture system means the equipment (including ducts, hoods, fans, 
dampers, etc.) used to capture or transport particulate matter generated 
by an electric arc furnace or AOD vessel to the air pollution control 
device.
    Charge means the addition of iron and steel scrap or other materials 
into the top of an electric arc furnace or the addition of molten steel 
or other materials into the top of an AOD vessel.
    Control device means the air pollution control equipment used to 
remove particulate matter from the effluent gas stream generated by an 
electric arc furnace or AOD vessel.
    Direct-shell evacuation control system (DEC system) means a system 
that maintains a negative pressure within the electric arc furnace above 
the slag or metal and ducts emissions to the control device.
    Dust-handling system means equipment used to handle particulate 
matter collected by the control device for an electric arc furnace or 
AOD vessel subject to this subpart. For the purposes of this subpart, 
the dust-handling system shall consist of the control device dust 
hoppers, the dust-conveying equipment, any central dust storage 
equipment, the dust-treating equipment (e.g., pug mill, pelletizer), 
dust transfer equipment (from storage to truck), and any secondary 
control devices used with the dust transfer equipment.
    Electric arc furnace (EAF) means a furnace that produces molten 
steel and heats the charge materials with electric arcs from carbon 
electrodes. For the purposes of this subpart, an EAF shall consist of 
the furnace shell and roof and the transformer. Furnaces that 
continuously feed direct-reduced iron ore pellets as the primary source 
of iron are not affected facilities within the scope of this definition.
    Heat cycle means the period beginning when scrap is charged to an 
empty EAF and ending when the EAF tap is completed or beginning when 
molten steel is charged to an empty AOD vessel and ending when the AOD 
vessel tap is completed.
    Meltdown and refining period means the time period commencing at the 
termination of the initial charging period and ending at the initiation 
of the tapping period, excluding any intermediate charging periods and 
times when power to the EAF is off.
    Melting means that phase of steel production cycle during which the 
iron and steel scrap is heated to the molten state.
    Negative-pressure fabric filter means a fabric filter with the fans 
on the downstream side of the filter bags.
    Positive-pressure fabric filter means a fabric filter with the fans 
on the upstream side of the filter bags.
    Refining means that phase of the steel production cycle during which 
undesirable elements are removed from the molten steel and alloys are 
added to reach the final metal chemistry.

[[Page 267]]

    Shop means the building which houses one or more EAF's or AOD 
vessels.
    Shop opacity means the arithmetic average of 24 observations of the 
opacity of emissions from the shop taken in accordance with Method 9 of 
appendix A of this part.
    Tap means the pouring of molten steel from an EAF or AOD vessel.
    Tapping period means the time period commencing at the moment an EAF 
begins to pour molten steel and ending either three minutes after steel 
ceases to flow from an EAF, or six minutes after steel begins to flow, 
whichever is longer.

[49 FR 43845, Oct. 31, 1984, as amended at 64 FR 10110, Mar. 2, 1999]



Sec. 60.272a  Standard for particulate matter.

    (a) On and after the date of which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from an EAF or an AOD vessel any gases which:
    (1) Exit from a control device and contain particulate matter in 
excess of 12 mg/dscm (0.0052 gr/dscf);
    (2) Exit from a control device and exhibit 3 percent opacity or 
greater; and
    (3) Exit from a shop and, due solely to the operations of any 
affected EAF(s) or AOD vessel(s), exhibit 6 percent opacity or greater.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from the dust-handling system any gases that exhibit 10 
percent opacity or greater.



Sec. 60.273a  Emission monitoring.

    (a) Except as provided under paragraphs (b) and (c) of this section, 
a continuous monitoring system for the measurement of the opacity of 
emissions discharged into the atmosphere from the control device(s) 
shall be installed, calibrated, maintained, and operated by the owner or 
operator subject to the provisions of this subpart.
    (b) No continuous monitoring system shall be required on any control 
device serving the dust-handling system.
    (c) A continuous monitoring system for the measurement of opacity is 
not required on modular, multiple-stack, negative-pressure or positive-
pressure fabric filters if observations of the opacity of the visible 
emissions from the control device are performed by a certified visible 
emission observer as follows: Visible emission observations are 
conducted at least once per day when the furnace is operating in the 
melting and refining period. These observations shall be taken in 
accordance with Method 9, and, for at least three 6-minute periods, the 
opacity shall be recorded for any point(s) where visible emissions are 
observed. Where it is possible to determine that a number of visible 
emission sites relate to only one incident of the visible emissions, 
only one set of three 6-minute observations will be required. In this 
case, Method 9 observations must be made for the site of highest opacity 
that directly relates to the cause (or location) of visible emissions 
observed during a single incident. Records shall be maintained of any 6-
minute average that is in excess of the emission limit specified in 
Sec. 60.272a(a) of this subpart.
    (d) A furnace static pressure monitoring device is not required on 
any EAF equipped with a DEC system if observations of shop opacity are 
performed by a certified visible emission observer as follows: Shop 
opacity observations shall be conducted at least once per day when the 
furnace is operating in the meltdown and refining period. Shop opacity 
shall be determined as the arithmetic average of 24 consecutive 15-
second opacity observations of emissions from the shop taken in 
accordance with Method 9. Shop opacity shall be recorded for any 
point(s) where visible emissions are observed. Where it is possible to 
determine that a number of visible emission sites relate to only one 
incident of visible emissions, only one observation of shop opacity will 
be required. In this case, the shop opacity observations must be made 
for the site of highest opacity that directly relates to the cause (or 
location)

[[Page 268]]

of visible emissions observed during a single incident.

[49 FR 43845, Oct. 31, 1984, as amended at 54 FR 6672, Feb. 14, 1989; 64 
FR 10111, Mar. 2, 1999]



Sec. 60.274a  Monitoring of operations.

    (a) The owner or operator subject to the provisions of this subpart 
shall maintain records of the following information:
    (1) All data obtained under paragraph (b) of this section; and
    (2) All monthly operational status inspections performed under 
paragraph (c) of this section.
    (b) Except as provided under paragraph (d) of this section, the 
owner or operator subject to the provisions of this subpart shall check 
and record on a once-per-shift basis the furnace static pressure (if DEC 
system is in use, and a furnace static pressure gauge is installed 
according to paragraph (f) of this section) and either: check and record 
the control system fan motor amperes and damper position on a once-per-
shift basis; install, calibrate, and maintain a monitoring device that 
continuously records the volumetric flow rate through each separately 
ducted hood; or install, calibrate, and maintain a monitoring device 
that continuously records the volumetric flow rate at the control device 
inlet and check and record damper positions on a once-per-shift basis. 
The monitoring device(s) may be installed in any appropriate location in 
the exhaust duct such that reproducible flow rate monitoring will 
result. The flow rate monitoring device(s) shall have an accuracy of 
10 percent over its normal operating range and shall be 
calibrated according to the manufacturer's instructions. The 
Administrator may require the owner or operator to demonstrate the 
accuracy of the monitoring device(s) relative to Methods 1 and 2 of 
appendix A of this part.
    (c) When the owner or operator of an affected facility is required 
to demonstrate compliance with the standards under Sec. 60.272a(a)(3) 
and at any other time the Administrator may require that (under section 
114 of the Act, as amended) either: the control system fan motor amperes 
and all damper positions; the volumetric flow rate through each 
separately ducted hood; or the volumetric flow rate at the control 
device inlet and all damper positions shall be determined during all 
periods in which a hood is operated for the purpose of capturing 
emissions from the affected facility subject to paragraph (b)(1) or 
(b)(2) of this section. The owner or operator may petition the 
Administrator for reestablishment of these parameters whenever the owner 
or operator can demonstrate to the Administrator's satisfaction that the 
affected facility operating conditions upon which the parameters were 
previously established are no longer applicable. The values of these 
parameters as determined during the most recent demonstration of 
compliance shall be maintained at the appropriate level for each 
applicable period. Operation at other than baseline values may be 
subject to the requirements of Sec. 60.276a(c).
    (d) The owner or operator shall perform monthly operational status 
inspections of the equipment that is important to the performance of the 
total capture system (i.e., pressure sensors, dampers, and damper 
switches). This inspection shall include observations of the physical 
appearance of the equipment (e.g., presence of holes in ductwork or 
hoods, flow constrictions caused by dents or accumulated dust in 
ductwork, and fan erosion). Any deficiencies shall be noted and proper 
maintenance performed.
    (e) The owner or operator may petition the Administrator to approve 
any alternative to monthly operational status inspections that will 
provide a continuous record of the operation of each emission capture 
system.
    (f) Except as provided for under Sec. 60.273a(d), if emissions 
during any phase of the heat time are controlled by the use of a DEC 
system, the owner or operator shall install, calibrate, and maintain a 
monitoring device that allows the pressure in the free space inside the 
EAF to be monitored. The monitoring device may be installed in any 
appropriate location in the EAF or DEC duct prior to the introduction of 
ambient air such that reproducible results will be obtained. The 
pressure monitoring device shall have an accuracy of 5 mm of 
water gauge over its normal operating range and shall be

[[Page 269]]

calibrated according to the manufacturer's instructions.
    (g) Except as provided for under Sec. 60.273a(d), when the owner or 
operator of an EAF controlled by a DEC is required to demonstrate 
compliance with the standard under Sec. 60.272a(a)(3), and at any other 
time the Administrator may require (under section 114 of the Clean Air 
Act, as amended), the pressure in the free space inside the furnace 
shall be determined during the meltdown and refining period(s) using the 
monitoring device required under paragraph (f) of this section. The 
owner or operator may petition the Administrator for reestablishment of 
the pressure whenever the owner or operator can demonstrate to the 
Administrator's satisfaction that the EAF operating conditions upon 
which the pressures were previously established are no longer 
applicable. The pressure determined during the most recent demonstration 
of compliance shall be maintained at all times when the EAF is operating 
in a meltdown and refining period. Operation at higher pressures may be 
considered by the Administrator to be unacceptable operation and 
maintenance of the affected facility.
    (h) During any performance test required under Sec. 60.8, and for 
any report thereof required by Sec. 60.275a(d) of this subpart, or to 
determine compliance with Sec. 60.272a(a)(3) of this subpart, the owner 
or operator shall monitor the following information for all heats 
covered by the test:
    (1) Charge weights and materials, and tap weights and materials;
    (2) Heat times, including start and stop times, and a log of process 
operation, including periods of no operation during testing and the 
pressure inside an EAF when direct-shell evacuation control systems are 
used;
    (3) Control device operation log; and
    (4) Continuous monitor or Reference Method 9 data.

[49 FR 43845, Oct. 31, 1984, as amended at 64 FR 10111, Mar. 2, 1999]



Sec. 60.275a  Test methods and procedures.

    (a) During performance tests required in Sec. 60.8, the owner or 
operator shall not add gaseous diluents to the effluent gas stream after 
the fabric in any pressurized fabric filter collector, unless the amount 
of dilution is separately determined and considered in the determination 
of emissions.
    (b) When emissions from any EAF(s) or AOD vessel(s) are combined 
with emissions from facilities not subject to the provisions of this 
subpart but controlled by a common capture system and control device, 
the owner or operator shall use either or both of the following 
procedures during a performance test (see also Sec. 60.276a(e)):
    (1) Determine compliance using the combined emissions.
    (2) Use a method that is acceptable to the Administrator and that 
compensates for the emissions from the facilities not subject to the 
provisions of this subpart.
    (c) When emission from any EAF(s) or AOD vessel(s) are combined with 
emissions from facilities not subject to the provisions of this subpart, 
the owner or operator shall demonstrate compliance with 
Sec. 60.272(a)(3) based on emissions from only the affected 
facility(ies).
    (d) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (e) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.272a as follows:
    (1) Method 5 shall be used for negative-pressure fabric filters and 
other types of control devices and Method 5D shall be used for positive-
pressure fabric filters to determine the particulate matter 
concentration and volumetric flow rate of the effluent gas. The sampling 
time and sample volume for each run shall be at least 4 hours and 4.50 
dscm (160 dscf) and, when a single EAF or AOD vessel is sampled, the 
sampling time shall include an integral number of heats.
    (2) When more than one control device serves the EAF(s) being 
tested, the concentration of particulate matter shall be determined 
using the following equation:

[[Page 270]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.014

where:
cst=average concentration of particulate matter, mg/dscm (gr/
          dscf).
csi=concentration of particulate matter from control device 
          ``i'', mg/dscm (gr/dscf).
n=total number of control devices tested.
Qsdi=volumetric flow rate of stack gas from control device 
          ``i'', dscm/hr (dscf/hr).

    (3) Method 9 and the procedures of Sec. 60.11 shall be used to 
determine opacity.
    (4) To demonstrate compliance with Sec. 60.272a(a) (1), (2), and 
(3), the test runs shall be conducted concurrently, unless inclement 
weather interferes.
    (f) To comply with Sec. 60.274a (c), (f), (g), and (h), the owner or 
operator shall obtain the information required in these paragraphs 
during the particulate matter runs.
    (g) Any control device subject to the provisions of the subpart 
shall be designed and constructed to allow measurement of emissions 
using applicable test methods and procedures.
    (h) Where emissions from any EAF(s) or AOD vessel(s) are combined 
with emissions from facilities not subject to the provisions of this 
subpart but controlled by a common capture system and control device, 
the owner or operator may use any of the following procedures during a 
performance test:
    (1) Base compliance on control of the combined emissions;
    (2) Utilize a method acceptable to the Administrator that 
compensates for the emissions from the facilities not subject to the 
provisions of this subpart, or;
    (3) Any combination of the criteria of paragraphs (h)(1) and (h)(2) 
of this section.
    (i) Where emissions from any EAF(s) or AOD vessel(s) are combined 
with emissions from facilities not subject to the provisions of this 
subpart, determinations of compliance with Sec. 60.272a(a)(3) will only 
be based upon emissions originating from the affected facility(ies).
    (j) Unless the presence of inclement weather makes concurrent 
testing infeasible, the owner or operator shall conduct concurrently the 
performance tests required under Sec. 60.8 to demonstrate compliance 
with Sec. 60.272a(a) (1), (2), and (3) of this subpart.

[49 FR 43845, Oct. 31, 1984, as amended at 54 FR 6673, Feb. 14, 1989; 54 
FR 21344, May 17, 1989]



Sec. 60.276a  Recordkeeping and reporting requirements.

    (a) Records of the measurements required in Sec. 60.274a must be 
retained for at least 2 years following the date of the measurement.
    (b) Each owner or operator shall submit a written report of 
exceedances of the control device opacity to the Administrator semi-
annually. For the purposes of these reports, exceedances are defined as 
all 6-minute periods during which the average opacity is 3 percent or 
greater.
    (c) Operation at a furnace static pressure that exceeds the value 
established under Sec. 60.274a(g) and either operation of control system 
fan motor amperes at values exceeding 15 percent of the 
value established under Sec. 60.274a(c) or operation at flow rates lower 
than those established under Sec. 60.274a(c) may be considered by the 
Administrator to be unacceptable operation and maintenance of the 
affected facility. Operation at such values shall be reported to the 
Administrator semiannually.
    (d) The requirements of this section remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternative 
means of compliance surveillance adopted by such State. In that event, 
affected sources within the State will be relieved of the obligation to 
comply with this section, provided that they comply with the 
requirements established by the State.
    (e) When the owner or operator of an EAF or AOD is required to 
demonstrate compliance with the standard under Sec. 60.275 (b)(2) or a 
combination of (b)(1) and (b)(2) the owner or operator shall obtain 
approval from the Administrator of the procedure(s) that will be used to 
determine compliance. Notification of the procedure(s) to be used must 
be postmarked 30 days prior to the performance test.
    (f) For the purpose of this subpart, the owner or operator shall 
conduct

[[Page 271]]

the demonstration of compliance with Sec. 60.272a(a) of this subpart and 
furnish the Administrator a written report of the results of the test. 
This report shall include the following information:
    (1) Facility name and address;
    (2) Plant representative;
    (3) Make and model of process, control device, and continuous 
monitoring equipment;
    (4) Flow diagram of process and emission capture equipment including 
other equipment or process(es) ducted to the same control device;
    (5) Rated (design) capacity of process equipment;
    (6) Those data required under Sec. 60.274a(h) of this subpart;
    (i) List of charge and tap weights and materials;
    (ii) Heat times and process log;
    (iii) Control device operation log; and
    (iv) Continuous monitor or Reference Method 9 data.
    (7) Test dates and test times;
    (8) Test company;
    (9) Test company representative;
    (10) Test observers from outside agency;
    (11) Description of test methodology used, including any deviation 
from standard reference methods;
    (12) Schematic of sampling location;
    (13) Number of sampling points;
    (14) Description of sampling equipment;
    (15) Listing of sampling equipment calibrations and procedures;
    (16) Field and laboratory data sheets;
    (17) Description of sample recovery procedures;
    (18) Sampling equipment leak check results;
    (19) Description of quality assurance procedures;
    (20) Description of analytical procedures;
    (21) Notation of sample blank corrections; and
    (22) Sample emission calculations.
    (g) The owner or operator shall maintain records of all shop opacity 
observations made in accordance with Sec. 60.273a(d). All shop opacity 
observations in excess of the emission limit specified in 
Sec. 60.272a(a)(3) of this subpart shall indicate a period of excess 
emission, and shall be reported to the administrator semi-annually, 
according to Sec. 60.7(c).

[49 FR 43845, Oct. 31, 1984, as amended at 54 FR 6673, Feb. 14, 1989; 64 
FR 10111, Mar. 2, 1999]



        Subpart BB--Standards of Performance for Kraft Pulp Mills



Sec. 60.280  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in kraft pulp mills: Digester system, brown stock 
washer system, multiple-effect evaporator system, recovery furnace, 
smelt dissolving tank, lime kiln, and condensate stripper system. In 
pulp mills where kraft pulping is combined with neutral sulfite 
semichemical pulping, the provisions of this subpart are applicable when 
any portion of the material charged to an affected facility is produced 
by the kraft pulping operation.
    (b) Except as noted in Sec. 60.283(a)(1)(iv), any facility under 
paragraph (a) of this section that commences construction or 
modification after September 24, 1976, is subject to the requirements of 
this subpart.

[51 FR 18544, May 20, 1986]



Sec. 60.281  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
same meaning given them in the Act and in subpart A.
    (a) Kraft pulp mill means any stationary source which produces pulp 
from wood by cooking (digesting) wood chips in a water solution of 
sodium hydroxide and sodium sulfide (white liquor) at high temperature 
and pressure. Regeneration of the cooking chemicals through a recovery 
process is also considered part of the kraft pulp mill.
    (b) Neutral sulfite semichemical pulping operation means any 
operation in which pulp is produced from wood by cooking (digesting) 
wood chips in a solution of sodium sulfite and sodium bicarbonate, 
followed by mechanical defibrating (grinding).
    (c) Total reduced sulfur (TRS) means the sum of the sulfur compounds 
hydrogen sulfide, methyl mercaptan, dimethyl sulfide, and dimethyl 
disulfide,

[[Page 272]]

that are released during the kraft pulping operation and measured by 
Reference Method 16.
    (d) Digester system means each continuous digester or each batch 
digester used for the cooking of wood in white liquor, and associated 
flash tank(s), below tank(s), chip steamer(s), and condenser(s).
    (e) Brown stock washer system means brown stock washers and 
associated knotters, vacuum pumps, and filtrate tanks used to wash the 
pulp following the digestion system. Diffusion washers are excluded from 
this definition.
    (f) Multiple-effect evaporator system means the multiple-effect 
evaporators and associated condenser(s) and hotwell(s) used to 
concentrate the spent cooking liquid that is separated from the pulp 
(black liquor).
    (g) Black liquor oxidation system means the vessels used to oxidize, 
with air or oxygen, the black liquor, and associated storage tank(s).
    (h) Recovery furnace means either a straight kraft recovery furnace 
or a cross recovery furnace, and includes the direct-contact evaporator 
for a direct-contact furnace.
    (i) Straight kraft recovery furnace means a furnace used to recover 
chemicals consisting primarily of sodium and sulfur compounds by burning 
black liquor which on a quarterly basis contains 7 weight percent or 
less of the total pulp solids from the neutral sulfite semichemical 
process or has green liquor sulfidity of 28 percent or less.
    (j) Cross recovery furnace means a furnace used to recover chemicals 
consisting primarily of sodium and sulfur compounds by burning black 
liquor which on a quarterly basis contains more than 7 weight percent of 
the total pulp solids from the neutral sulfite semichemical process and 
has a green liquor sulfidity of more than 28 percent.
    (k) Black liquor solids means the dry weight of the solids which 
enter the recovery furnace in the black liquor.
    (l) Green liquor sulfidity means the sulfidity of the liquor which 
leaves the smelt dissolving tank.
    (m) Smelt dissolving tank means a vessel used for dissolving the 
smelt collected from the recovery furnace.
    (n) Lime kiln means a unit used to calcine lime mud, which consists 
primarily of calcium carbonate, into quicklime, which is calcium oxide.
    (o) Condensate stripper system means a column, and associated 
condensers, used to strip, with air or steam, TRS compounds from 
condensate streams from various processes within a kraft pulp mill.

[43 FR 7572, Feb. 23, 1978, as amended at 51 FR 18544, May 20, 1986]



Sec. 60.282  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere:
    (1) From any recovery furnace any gases which:
    (i) Contain particulate matter in excess of 0.10 g/dscm (0.044 gr/
dscf) corrected to 8 percent oxygen.
    (ii) Exhibit 35 percent opacity or greater.
    (2) From any smelt dissolving tank any gases which contain 
particulate matter in excess of 0.1 g/kg black liquor solids (dry 
weight)[0.2 lb/ton black liquor solids (dry weight)].
    (3) From any lime kiln any gases which contain particulate matter in 
excess of:
    (i) 0.15 g/dscm (0.067 gr/dscf) corrected to 10 percent oxygen, when 
gaseous fossil fuel is burned.
    (ii) 0.30 g/dscm (0.13 gr/dscf) corrected to 10 percent oxygen, when 
liquid fossil fuel is burned.

[43 FR 7572, Feb. 23, 1978]



Sec. 60.283  Standard for total reduced sulfur (TRS).

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere:
    (1) From any digester system, brown stock washer system, multiple-
effect evaporator system, or condensate stripper system any gases which 
contain TRS in excess of 5 ppm by volume on a dry basis, corrected to 10 
percent

[[Page 273]]

oxygen, unless the following conditions are met:
    (i) The gases are combusted in a lime kiln subject to the provisions 
of paragraph (a)(5) of this section; or
    (ii) The gases are combusted in a recovery furnace subject to the 
provisions of paragraphs (a)(2) or (a)(3) of this section; or
    (iii) The gases are combusted with other waste gases in an 
incinerator or other device, or combusted in a lime kiln or recovery 
furnace not subject to the provisions of this subpart, and are subjected 
to a minimum temperature of 1200  deg.F. for at least 0.5 second; or
    (iv) It has been demonstrated to the Administrator's satisfaction by 
the owner or operator that incinerating the exhaust gases from a new, 
modified, or reconstructed brown stock washer system is technologically 
or economically unfeasible. Any exempt system will become subject to the 
provisions of this subpart if the facility is changed so that the gases 
can be incinerated.
    (v) The gases from the digester system, brown stock washer system, 
or condensate stripper system are controlled by a means other than 
combustion. In this case, this system shall not discharge any gases to 
the atmosphere which contain TRS in excess of 5 ppm by volume on a dry 
basis, corrected to the actual oxygen content of the untreated gas 
stream.
    (vi) The uncontrolled exhaust gases from a new, modified, or 
reconstructed digester system contain TRS less than 0.005 g/kg ADP (0.01 
lb/ton ADP).
    (2) From any straight kraft recovery furnace any gases which contain 
TRS in excess of 5 ppm by volume on a dry basis, corrected to 8 percent 
oxygen.
    (3) From any cross recovery furnace any gases which contain TRS in 
excess of 25 ppm by volume on a dry basis, corrected to 8 percent 
oxygen.
    (4) From any smelt dissolving tank any gases which contain TRS in 
excess of 0.016 g/kg black liquor solids as H2S (0.033 lb/ton 
black liquor solids as H2S).
    (5) From any lime kiln any gases which contain TRS in excess of 8 
ppm by volume on a dry basis, corrected to 10 percent oxygen.

[43 FR 7572, Feb. 23, 1978, as amended at 50 FR 6317, Feb. 14, 1985; 51 
FR 18544, May 20, 1986]



Sec. 60.284  Monitoring of emissions and operations.

    (a) Any owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain, and operate the following continuous 
monitoring systems:
    (1) A continuous monitoring system to monitor and record the opacity 
of the gases discharged into the atmosphere from any recovery furnace. 
The span of this system shall be set at 70 percent opacity.
    (2) Continuous monitoring systems to monitor and record the 
concentration of TRS emissions on a dry basis and the percent of oxygen 
by volume on a dry basis in the gases discharged into the atmosphere 
from any lime kiln, recovery furnace, digester system, brown stock 
washer system, multiple-effect evaporator system, or condensate stripper 
system, except where the provisions of Sec. 60.283(a)(1) (iii) or (iv) 
apply. These systems shall be located downstream of the control 
device(s) and the spans of these continuous monitoring system(s) shall 
be set:
    (i) At a TRS concentration of 30 ppm for the TRS continuous 
monitoring system, except that for any cross recovery furnace the span 
shall be set at 50 ppm.
    (ii) At 20 percent oxygen for the continuous oxygen monitoring 
system.
    (b) Any owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain, and operate the following continuous 
monitoring devices:
    (1) For any incinerator, a monitoring device which measures and 
records the combustion temperature at the point of incineration of 
effluent gases which are emitted from any digester system, brown stock 
washer system, multiple-effect evaporator system, black liquor oxidation 
system, or condensate stripper system where the provisions of 
Sec. 60.283(a)(1)(iii) apply. The monitoring

[[Page 274]]

device is to be certified by the manufacturer to be accurate within 
1 percent of the temperature being measured.
    (2) For any lime kiln or smelt dissolving tank using a scrubber 
emission control device:
    (i) A monitoring device for the continuous measurement of the 
pressure loss of the gas stream through the control equipment. The 
monitoring device is to be certified by the manufacturer to be accurate 
to within a gage pressure of plus-minus500 pascals (ca. 
plus-minus2 inches water gage pressure).
    (ii) A monitoring device for the continuous measurement of the 
scrubbing liquid supply pressure to the control equipment. The 
monitoring device is to be certified by the manufacturer to be accurate 
within plus-minus15 percent of design scrubbing liquid supply 
pressure. The pressure sensor or tap is to be located close to the 
scrubber liquid discharge point. The Administrator may be consulted for 
approval of alternative locations.
    (c) Any owner or operator subject to the provisions of this subpart 
shall, except where the provisions of Sec. 60.283 (a)(1)(iv) or (a)(4) 
apply.
    (1) Calculate and record on a daily basis 12-hour average TRS 
concentrations for the two consecutive periods of each operating day. 
Each 12-hour average shall be determined as the arithmetic mean of the 
appropriate 12 contiguous 1-hour average total reduced sulfur 
concentrations provided by each continuous monitoring system installed 
under paragraph (a)(2) of this section.
    (2) Calculate and record on a daily basis 12-hour average oxygen 
concentrations for the two consecutive periods of each operating day for 
the recovery furnace and lime kiln. These 12-hour averages shall 
correspond to the 12-hour average TRS concentrations under paragraph 
(c)(1) of this section and shall be determined as an arithmetic mean of 
the appropriate 12 contiguous 1-hour average oxygen concentrations 
provided by each continuous monitoring system installed under paragraph 
(a)(2) of this section.
    (3) Correct all 12-hour average TRS concentrations to 10 volume 
percent oxygen, except that all 12-hour average TRS concentration from a 
recovery furnace shall be corrected to 8 volume percent using the 
following equation:

Ccorr=Cmeas x (21-X/21-Y)
where:

Ccorr=the concentration corrected for oxygen.
Cmeas=the concentration uncorrected for oxygen.
X=the volumetric oxygen concentration in percentage to be corrected to 
          (8 percent for recovery furnaces and 10 percent for lime 
          kilns, incinerators, or other devices).
Y=the measured 12-hour average volumetric oxygen concentration.

    (4) Record once per shift measurements obtained from the continuous 
monitoring devices installed under paragraph (b)(2) of this section.
    (d) For the purpose of reports required under Sec. 60.7(c), any 
owner or operator subject to the provisions of this subpart shall report 
semiannually periods of excess emissions as follows:
    (1) For emissions from any recovery furnace periods of excess 
emissions are:
    (i) All 12-hour averages of TRS concentrations above 5 ppm by volume 
for straight kraft recovery furnaces and above 25 ppm by volume for 
cross recovery furnaces.
    (ii) All 6-minute average opacities that exceed 35 percent.
    (2) For emissions from any lime kiln, periods of excess emissions 
are all 12-hour average TRS concentration above 8 ppm by volume.
    (3) For emissions from any digester system, brown stock washer 
system, multiple-effect evaporator system, or condensate stripper system 
periods of excess emissions are:
    (i) All 12-hour average TRS concentrations above 5 ppm by volume 
unless the provisions of Sec. 60.283(a)(1) (i), (ii), or (iv) apply; or
    (ii) All periods in excess of 5 minutes and their duration during 
which the combustion temperature at the point of incineration is less 
than 1200  deg.F, where the provisions of Sec. 60.283(a)(1)(iii) apply.
    (e) The Administrator will not consider periods of excess emissions 
reported under paragraph (d) of this section to be indicative of a 
violation of Sec. 60.11(d) provided that:
    (1) The percent of the total number of possible contiguous periods 
of excess

[[Page 275]]

emissions in a quarter (excluding periods of startup, shutdown, or 
malfunction and periods when the facility is not operating) during which 
excess emissions occur does not exceed:
    (i) One percent for TRS emissions from recovery furnaces.
    (ii) Six percent for average opacities from recovery furnaces.
    (2) The Administrator determines that the affected facility, 
including air pollution control equipment, is maintained and operated in 
a manner which is consistent with good air pollution control practice 
for minimizing emissions during periods of excess emissions.

[43 FR 7572, Feb. 23, 1978, as amended at 51 FR 18545, May 20, 1986]



Sec. 60.285  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures in 
this section, except as provided in Sec. 60.8(b). Acceptable alternative 
methods and procedures are given in paragraph (f) of this section.
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.282(a) (1) and (3) as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration. The sampling time and sample volume for each run shall be 
at least 60 minutes and 0.90 dscm (31.8 dscf). Water shall be used as 
the cleanup solvent instead of acetone in the sample recovery procedure. 
The particulate concentration shall be corrected to the appropriate 
oxygen concentration according to Sec. 60.284(c)(3).
    (2) The emission rate correction factor, integrated sampling and 
analysis procedure of Method 3B shall be used to determine the oxygen 
concentration. The gas sample shall be taken at the same time and at the 
same traverse points as the particulate sample.
    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (c) The owner or operator shall determine compliance with the 
particular matter standard in Sec. 60.282(a)(2) as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:

E=cs Qsd/BLS
where:
E=emission rate of particulate matter, g/kg (lb/ton) of BLS.
cs=concentration --of --particulate --matter, g/dsm (lb/
          dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
BLS=black liquor solids (dry weight) feed rate, kg/hr (ton/hr).

    (2) Method 5 shall be used to determine the particulate matter 
concentration (cs) and the volumetric flow rate 
(Qsd) of the effluent gas. The sampling time and sample 
volume shall be at least 60 minutes and 0.90 dscm (31.8 dscf). Water 
shall be used instead of acetone in the sample recovery.
    (3) Process data shall be used to determine the black liquor solids 
(BLS) feed rate on a dry weight basis.
    (d) The owner or operator shall determine compliance with the TRS 
standards in Sec. 60.283, except Sec. 60.283(a)(1)(vi) and (4), as 
follows:
    (1) Method 16 shall be used to determine the TRS concentration. The 
TRS concentration shall be corrected to the appropriate oxygen 
concentration using the procedure in Sec. 60.284(c)(3). The sampling 
time shall be at least 3 hours, but no longer than 6 hours.
    (2) The emission rate correction factor, integrated sampling and 
analysis procedure of Method 3B shall be used to determine the oxygen 
concentration. The sample shall be taken over the same time period as 
the TRS samples.
    (3) When determining whether a furnace is a straight kraft recovery 
furnace or a cross recovery furnace, TAPPI Method T.624 (incorporated by 
reference--see Sec. 60.17) shall be used to determine sodium sulfide, 
sodium hydroxide, and sodium carbonate. These determinations shall be 
made 3 times daily from the green liquor, and the daily average values 
shall be converted to sodium oxide (Na20) and substituted 
into the following equation to determine the green liquor sulfidity:

GLS = 100 CNa2S/
          (CNA2S+CNa2H+CNa2CO3 )
Where:

GLS=green liquor sulfidity, percent.
CNa2S=concentration of Na2S as Na2O, 
          mg/liter (gr/gal).

[[Page 276]]

CNaOH=concentration of NaOH as Na2O, mg/liter (gr/
          gal).
CNa2CO3=concentration of Na2CO3 as 
          Na2O, mg/liter (gr/gal).

    (e) The owner or operator shall determine compliance with the TRS 
standards in Sec. 60.283(a)(1)(vi) and (4) as follows:
    (1) The emission rate (E) of TRS shall be computed for each run 
using the following equation:

E=CTRS F Qsd/P
where:
E=emission rate of TRS, g/kg (lb/ton) of BLS or ADP.
CTRS=average combined concentration of TRS, ppm.
F=conversion factor, 0.001417 g H2S/m\3\ ppm
    (0.08844 x 10-\6\ lb H2S/ft\3\ ppm).
Qsd=volumetric flow rate of stack gas, dscm/hr (dscf/hr).
P=black liquor solids feed or pulp production rate, kg/hr (ton/hr).

    (2) Method 16 shall be used to determine the TRS concentration 
(CTRS).
    (3) Method 2 shall be used to determine the volumetric flow rate 
(Qsd) of the effluent gas.
    (4) Process data shall be used to determine the black liquor feed 
rate or the pulp production rate (P).
    (f) The owner or operator may use the following as alternatives to 
the reference methods and procedures specified in this section:
    (1) For Method 5, Method 17 may be used if a constant value of 0.009 
g/dscm (0.004 gr/dscf) is added to the results of Method 17 and the 
stack temperature is no greater than 205  deg.C (400  deg.F).
    (2) For Method 16, Method 16A or 16B may be used if the sampling 
time is 60 minutes.

[54 FR 6673, Feb. 14, 1989; 54 FR 21344, May 17, 1989, as amended at 55 
FR 5212, Feb. 14, 1990]



   Subpart CC--Standards of Performance for Glass Manufacturing Plants



Sec. 60.290  Applicability and designation of affected facility.

    (a) Each glass melting furnace is an affected facility to which the 
provisions of this subpart apply.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after June 15, 1979, is subject to the 
requirements of this subpart.
    (c) This subpart does not apply to hand glass melting furnaces, 
glass melting furnaces designed to produce less than 4,550 kilograms of 
glass per day and all-electric melters.

[45 FR 66751, Oct. 7, 1980]



Sec. 60.291  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part, unless 
otherwise required by the context.
    All-electric melter means a glass melting furnace in which all the 
heat required for melting is provided by electric current from 
electrodes submerged in the molten glass, although some fossil fuel may 
be charged to the furnace as raw material only.
    Borosilicate recipe means glass product composition of the following 
approximate ranges of weight proportions: 60 to 80 percent silicon 
dioxide, 4 to 10 percent total R2O (e.g., Na2O and 
K2O), 5 to 35 percent boric oxides, and 0 to 13 percent other 
oxides.
    Container glass means glass made of soda-lime recipe, clear or 
colored, which is pressed and/or blown into bottles, jars, ampoules, and 
other products listed in Standard Industrial Classification 3221 (SIC 
3221).
    Experimental furnace means a glass melting furnace with the sole 
purpose of operating to evaluate glass melting processes, technologies, 
or glass products. An experimental furnace does not produce glass that 
is sold (except for further research and development purposes) or that 
is used as a raw material for nonexperimental furnaces.
    Flat glass means glass made of soda-lime recipe and produced into 
continuous flat sheets and other products listed in SIC 3211.
    Flow channels means appendages used for conditioning and 
distributing molten glass to forming apparatuses and are a permanently 
separate source of emissions such that no mixing of emissions occurs 
with emissions from the melter cooling system prior to their being 
vented to the atmosphere.
    Glass melting furnace means a unit comprising a refractory vessel in 
which raw materials are charged, melted at

[[Page 277]]

high temperature, refined, and conditioned to produce molten glass. The 
unit includes foundations, superstructure and retaining walls, raw 
material charger systems, heat exchangers, melter cooling system, 
exhaust system, refractory brick work, fuel supply and electrical 
boosting equipment, integral control systems and instrumentation, and 
appendaees for conditioning and distributing molten glass to forming 
apparatuses. The forming apparatuses, including the float bath used in 
flat glass manufacturing and flow channels in wool fiberglass and 
textile fiberglass manufacturing, are not considered part of the glass 
melting furnace.
    Glass produced means the weight of the glass pulled from the glass 
melting furnace.
    Hand glass melting furnace means a glass melting furnace where the 
molten glass is removed from the furnace by a glassworker using a 
blowpipe or a pontil.
    Lead recipe means glass product composition of the following ranges 
of weight proportions: 50 to 60 percent silicon dioxide, 18 to 35 
percent lead oxides, 5 to 20 percent total R2O (e.g., 
Na2M and K2O), 0 to 8 percent total 
R2O3 (e.g., Al2O3), 0 to 15 
percent total RO (e.g., CaO, MgO), other than lead oxide, and 5 to 10 
percent other oxides.
    Pressed and blown glass means glass which is pressed, blown, or 
both, including textile fiberglass, noncontinuous flat glass, 
noncontainer glass, and other products listed in SIC 3229. It is 
separated into:
    (1) Glass of borosilicate recipe.
    (2) Glass of soda-lime and lead recipes.
    (3) Glass of opal, fluoride, and other recipes.
    Rebricking means cold replacement of damaged or worn refractory 
parts of the glass melting furnace. Rebricking includes replacement of 
the refractories comprising the bottom, sidewalls, or roof of the 
melting vessel; replacement of refractory work in the heat exchanger; 
replacment of refractory portions of the glass conditioning and 
distribution system.
    Soda-lime recipe means glass product composition of the following 
ranges of weight proportions: 60 to 75 percent silicon dioxide, 10 to 17 
percent total R2O (e.g., Na2O and K2O), 
8 to 20 percent total RO but not to include any PbO (e.g., CaO, and 
MgO), 0 to 8 percent total R2O3 (e.g., 
Al2O3), and 1 to 5 percent other oxides.
    Textile fiberglass means fibrous glass in the form of continuous 
strands having uniform thickness.
    With modified-processes means using any technique designed to 
minimize emissions without the use of add-on pollution controls.
    Wool fiberglass means fibrous glass of random texture, including 
fiberglass insulation, and other products listed in SIC 3296.

[45 FR 66751, Oct. 7, 1980, as amended at 49 FR 41035, Oct. 19, 1984]



Sec. 60.292  Standards for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator of a glass 
melting furnace subject to the provisions of this subpart shall cause to 
be discharged into the atmosphere--
    (1) From any glass melting furnace fired exclusively with either a 
gaseous fuel or a liquid fuel, particulate matter at emission rates 
exceeding those specified in Table CC-1, Column 2 and Column 3, 
respectively, or
    (2) From any glass melting furnace, fired simultaneously with 
gaseous and liquid fuels, particulate matter at emission rates exceeding 
STD as specified by the following equation:

STD=X [1.3(Y)+(Z)]
Where:

STD=Particulate matter emission limit, g of particulate/kg of glass 
          produced.
X=Emission rate specified in Table CC-1 for furnaces fired with gaseous 
          fuel (Column 2).
Y=Decimal fraction of liquid fuel heating value to total (gaseous and 
          liquid) fuel heating value fired in the glass melting furnaces 
          as determined in Sec. 60.296(b). (joules/joules).
Z=(1-Y).
    (b) Conversion of a glass melting furnace to the use of liquid fuel 
is not considered a modification for the purposes of Sec. 60.14.
    (c) Rebricking and the cost of rebricking is not considered a 
reconstruction for the purposes of Sec. 60.15.

[[Page 278]]

    (d) An owner or operator of an experimental furnace is not subject 
to the requirements of this section.
    (e) During routine maintenance of add-on pollution controls, an 
owner or operator of a glass melting furnace subject to the provisions 
of paragraph (a) of this section is exempt from the provisions of 
paragraph (a) of this section if:
    (1) Routine maintenance in each calendar year does not exceed 6 
days;
    (2) Routine maintenance is conducted in a manner consistent with 
good air pollution control practices for minimizing emissions; and
    (3) A report is submitted to the Administrator 10 days before the 
start of the routine maintenance (if 10 days cannot be provided, the 
report must be submitted as soon as practicable) and the report contains 
an explanation of the schedule of the maintenance.

                       Table CC-1--Emission Rates
                 [g of particulate/kg of glass produced]
------------------------------------------------------------------------
                                                   Col. 2--    Col. 3--
                                                    Furnace     Furnace
   Col. 1--Glass manufacturing plant industry     fired with  fired with
                     segment                        gaseous     liquid
                                                     fuel        fuel
------------------------------------------------------------------------
Container glass.................................      0.1         0.13
Pressed and blown glass
  (a) Borosilicate Recipes......................      0.5         0.65
  (b) Soda-Lime and Lead Recipes................      0.1         0.13
  (c) Other-Than Borosilicate, Soda-Lime, and         0.25        0.325
   Lead Recipes (including opal, fluoride, and
   other recipes)...............................
Wool fiberglass.................................      0.25        0.325
Flat glass......................................      0.225       0.225
------------------------------------------------------------------------


[45 FR 66751, Oct. 7, 1980, as amended at 49 FR 41035, Oct. 19, 1984; 54 
FR 6674, Feb. 14, 1989]



Sec. 60.293  Standards for particulate matter from glass melting furnace with modified-processes.

    (a) An owner or operator of a glass melting furnaces with modified-
processes is not subject to the provisions of Sec. 60.292 if the 
affected facility complies with the provisions of this section.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator of a glass 
melting furnace with modified-processes subject to the provisions of 
this subpart shall cause to be discharged into the atmosphere from the 
affected facility:
    (1) Particulate matter at emission rates exceeding 0.5 gram of 
particulate per kilogram of glass produced (g/kg) as measured according 
to paragraph (e) of this section for container glass, flat glass, and 
pressed and blown glass with a soda-lime recipe melting furnaces.
    (2) Particulate matter at emission rates exceeding 1.0 g/kg as 
measured according to paragraph (e) of this section for pressed and 
blown glass with a borosilicate recipe melting furnace.
    (3) Particulate matter at emission rates exceeding 0.5 g/kg as 
measured according to paragraph (e) of this section for textile 
fiberglass and wool fiberglass melting furnaces.
    (c) The owner or operator of an affected facility that is subject to 
emission limits specified under paragraph (b) of this section shall:
    (1) Install, calibrate, maintain, and operate a continuous 
monitoring system for the measurement of the opacity of emissions 
discharged into the atmosphere from the affected facility.
    (2) During the performance test required to be conducted by 
Sec. 60.8, conduct continuous opacity monitoring during each test run.
    (3) Calculate 6-minute opacity averages from 24 or more data points 
equally spaced over each 6-minute period during the test runs.
    (4) Determine, based on the 6-minute opacity averages, the opacity 
value corresponding to the 99 percent upper confidence level of a normal 
distribution of average opacity values.
    (5) For the purposes of Sec. 60.7, report to the Administrator as 
excess emissions all of the 6-minute periods during which the average 
opacity, as measured by the continuous monitoring system installed under 
paragraph (c)(1) of this section, exceeds the opacity value 
corresponding to the 99 percent upper confidence level determined under 
paragraph (c)(4) of this section.
    (d)(1) After receipt and consideration of written application, the 
Administrator may approve alternative continuous monitoring systems for 
the measurement of one or more process or operating parameters that is 
or are demonstrated to enable accurate and representative monitoring of 
an emission limit specified in paragraph (b)(1) of this section.

[[Page 279]]

    (2) After the Administrator approves an alternative continuous 
monitoring system for an affected facility, the requirements of 
paragraphs (c) (1) through (5) of this section will not apply for that 
affected facility.
    (3) An owner or operator may redetermine the opacity value 
corresponding to the 99 percent upper confidence level as described in 
paragraph (c)(4) of this section if the owner or operator:
    (i) Conducts continuous opacity monitoring during each test run of a 
performance test that demonstrates compliance with an emission limit of 
paragraph (b) of this section,
    (ii) Recalculates the 6-minute opacity averages as described in 
paragraph (c)(3) of this section, and
    (iii) Uses the redetermined opacity value corresponding to the 99 
percent upper confidence level for the purposes of paragraph (c)(5) of 
this section.
    (e) Test methods and procedures as specified in Sec. 60.296 shall be 
used to determine compliance with this section except that to determine 
compliance for any glass melting furnace using modified processes and 
fired with either a gaseous fuel or a liquid fuel containing less than 
0.50 weight percent sulfur, Method 5 shall be used with the probe and 
filter holder heating system in the sampling train set to provide a gas 
temperature of 12014  deg.C.

[49 FR 41036, Oct. 19, 1984, as amended at 64 FR 7466, Feb. 12, 1999]



Secs. 60.294-60.295  [Reserved]



Sec. 60.296  Test methods and procedures.

    (a) If a glass melting furnace with modified processes is changed to 
one without modified processes or if a glass melting furnace without 
modified processes is changed to one with modified processes, the owner 
or operator shall notify the Administrator at least 60 days before the 
change is scheduled to occur.
    (b) When gaseous and liquid fuels are fired simultaneously in a 
glass melting furnace, the owner or operator shall determine the 
applicable standard under Sec. 60.292(a)(2) as follows:
    (1) The ratio (Y) of liquid fuel heating value to total (gaseous and 
liquid) fuel heating value fired in the glass melting furnaces shall be 
computed for each run using the following equation:

Y=(Hl L)/(Hl L+Hg G)
where:
Y=decimal fraction of liquid fuel heating value to total fuel heating 
          value.
Hl=gross calorific value of liquid fuel, J/kg.
Hg=gross calorific value of gaseous fuel, J/kg.
L=liquid flow rate, kg/hr.
G=gaseous flow rate, kg/hr.

    (2) Suitable methods shall be used to determine the rates (L and G) 
of fuels burned during each test period and a material balance over the 
glass melting furnace shall be used to confirm the rates.
    (3) American Society of Testing and Materials (ASTM) Method D 240-76 
(liquid fuels) and D 1826-77 (gaseous fuels) (incorporated by 
reference--see Sec. 60.17), as applicable, shall be used to determine 
the gross calorific values.
    (c) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (d) The owner or operator shall determine compliance with the 
particulate matter standards in Secs. 60.292 and 60.293 as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:
E=(cs Qsd-A)/P
where:
E=emission rate of particulate matter, g/kg.
cs=concentration of particulate matter, g/dsm.
Qsd=volumetric flow rate, dscm/hr.
A=zero production rate correction
=227 g/hr for container glass, pressed and blown (soda-lime and lead) 
          glass, and pressed and blown (other than borosilicate, soda-
          lime, and lead) glass.
=454 g/hr for pressed and blown (borosilicate) glass, wool fiberglass, 
          and flat glass.
P=glass production rate, kg/hr.

    (2) Method 5 shall be used to determine the particulate matter 
concentration (cs) and volumetric flow rate (Qsd) 
of the effluent gas. The sampling time and sample volume for each run 
shall be at least 60 minutes and 0.90 dscm (31.8 dscf). The probe and 
filter holder heating system may be set to provide a gas temperature no 
greater than 17714  deg.C (35025  deg.F), except 
under the conditions specified in Sec. 60.293(e).

[[Page 280]]

    (3) Direct measurement or material balance using good engineering 
practice shall be used to determine the amount of glass pulled during 
the performance test. The rate of glass produced is defined as the 
weight of glass pulled from the affected facility during the performance 
test divided by the number of hours taken to perform the performance 
test.
    (4) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.

[54 FR 6674, Feb. 14, 1989; 54 FR 21344, May 17, 1989]



        Subpart DD--Standards of Performance for Grain Elevators

    Source: 43 FR 34347, Aug. 3, 1978, unless otherwise noted.



Sec. 60.300  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to each affected facility 
at any grain terminal elevator or any grain storage elevator, except as 
provided under Sec. 60.304(b). The affected facilities are each truck 
unloading station, truck loading station, barge and ship unloading 
station, barge and ship loading station, railcar loading station, 
railcar unloading station, grain dryer, and all grain handling 
operations.
    (b) Any facility under paragraph (a) of this section which commences 
construction, modification, or reconstruction after August 3, 1978, is 
subject to the requirements of this part.

[43 FR 34347, Aug. 3, 1978, as amended at 52 FR 42434, Nov. 5, 1988]



Sec. 60.301  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the act and in subpart A of this part.
    (a) Grain means corn, wheat, sorghum, rice, rye, oats, barley, and 
soybeans.
    (b) Grain elevator means any plant or installation at which grain is 
unloaded, handled, cleaned, dried, stored, or loaded.
    (c) Grain terminal elevator means any grain elevator which has a 
permanent storage capacity of more than 88,100 m3(ca. 2.5 
million U.S. bushels), except those located at animal food 
manufacturers, pet food manufacturers, cereal manufacturers, breweries, 
and livestock feedlots.
    (d) Permanent storage capacity means grain storage capacity which is 
inside a building, bin, or silo.
    (e) Railcar means railroad hopper car or boxcar.
    (f) Grain storage elevator means any grain elevator located at any 
wheat flour mill, wet corn mill, dry corn mill (human consumption), rice 
mill, or soybean oil extraction plant which has a permanent grain 
storage capacity of 35,200 m3(ca. 1 million bushels).
    (g) Process emission means the particulate matter which is collected 
by a capture system.
    (h) Fugitive emission means the particulate matter which is not 
collected by a capture system and is released directly into the 
atmosphere from an affected facility at a grain elevator.
    (i) Capture system means the equipment such as sheds, hoods, ducts, 
fans, dampers, etc. used to collect particulate matter generated by an 
affected facility at a grain elevator.
    (j) Grain unloading station means that portion of a grain elevator 
where the grain is transferred from a truck, railcar, barge, or ship to 
a receiving hopper.
    (k) Grain loading station means that portion of a grain elevator 
where the grain is transferred from the elevator to a truck, railcar, 
barge, or ship.
    (l) Grain handling operations include bucket elevators or legs 
(excluding legs used to unload barges or ships), scale hoppers and surge 
bins (garners), turn heads, scalpers, cleaners, trippers, and the 
headhouse and other such structures.
    (m) Column dryer means any equipment used to reduce the moisture 
content of grain in which the grain flows from the top to the bottom in 
one or more continuous packed columns between two perforated metal 
sheets.
    (n) Rack dryer means any equipment used to reduce the moisture 
content of grain in which the grain flows from the top to the bottom in 
a cascading flow around rows of baffles (racks).
    (o) Unloading leg means a device which includes a bucket-type 
elevator

[[Page 281]]

which is used to remove grain from a barge or ship.



Sec. 60.302  Standard for particulate matter.

    (a) On and after the 60th day of achieving the maximum production 
rate at which the affected facility will be operated, but no later than 
180 days after initial startup, no owner or operator subject to the 
provisions of this subpart shall cause to be discharged into the 
atmosphere any gases which exhibit greater than 0 percent opacity from 
any:
    (1) Column dryer with column plate perforation exceeding 2.4 mm 
diameter (ca. 0.094 inch).
    (2) Rack dryer in which exhaust gases pass through a screen filter 
coarser than 50 mesh.
    (b) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility except a grain dryer any process 
emission which:
    (1) Contains particulate matter in excess of 0.023 g/dscm (ca. 0.01 
gr/dscf).
    (2) Exhibits greater than 0 percent opacity.
    (c) On and after the 60th day of achieving the maximum production 
rate at which the affected facility will be operated, but no later than 
180 days after initial startup, no owner or operator subject to the 
provisions of this subpart shall cause to be discharged into the 
atmosphere any fugitive emission from:
    (1) Any individual truck unloading station, railcar unloading 
station, or railcar loading station, which exhibits greater than 5 
percent opacity.
    (2) Any grain handling operation which exhibits greater than 0 
percent opacity.
    (3) Any truck loading station which exhibits greater than 10 percent 
opacity.
    (4) Any barge or ship loading station which exhibits greater than 20 
percent opacity.
    (d) The owner or operator of any barge or ship unloading station 
shall operate as follows:
    (1) The unloading leg shall be enclosed from the top (including the 
receiving hopper) to the center line of the bottom pulley and 
ventilation to a control device shall be maintained on both sides of the 
leg and the grain receiving hopper.
    (2) The total rate of air ventilated shall be at least 32.1 actual 
cubic meters per cubic meter of grain handling capacity (ca. 40 
ft3/bu).
    (3) Rather than meet the requirements of paragraphs (d)(1) and (2) 
of this section the owner or operator may use other methods of emission 
control if it is demonstrated to the Administrator's satisfaction that 
they would reduce emissions of particulate matter to the same level or 
less.



Sec. 60.303  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b). 
Acceptable alternative methods and procedures are given in paragraph (c) 
of this section.
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.302 as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration and the volumetric flow rate of the effluent gas. The 
sampling time and sample volume for each run shall be at least 60 
minutes and 1.70 dscm (60 dscf). The probe and filter holder shall be 
operated without heaters.
    (2) Method 2 shall be used to determine the ventilation volumetric 
flow rate.
    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (c) The owner or operator may use the following as alternatives to 
the reference methods and procedures specified in this section:
    (1) For Method 5, Method 17 may be used.

[54 FR 6674, Feb. 14, 1989]



Sec. 60.304  Modifications.

    (a) The factor 6.5 shall be used in place of ``annual asset 
guidelines repair

[[Page 282]]

allowance percentage,'' to determine whether a capital expenditure as 
defined by Sec. 60.2 has been made to an existing facility.
    (b) The following physical changes or changes in the method of 
operation shall not by themselves be considered a modification of any 
existing facility:
    (1) The addition of gravity loadout spouts to existing grain storage 
or grain transfer bins.
    (2) The installation of automatic grain weighing scales.
    (3) Replacement of motor and drive units driving existing grain 
handling equipment.
    (4) The installation of permanent storage capacity with no increase 
in hourly grain handling capacity.



   Subpart EE--Standards of Performance for Surface Coating of Metal 
                                Furniture

    Source: 47 FR 49287, Oct. 29, 1982, unless otherwise noted.



Sec. 60.310  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each metal furniture surface coating operation in which organic 
coatings are applied.
    (b) This subpart applies to each affected facility identified in 
paragraph (a) of this section on which construction, modification, or 
reconstruction is commenced after November 28, 1980.
    (c) Any owner or operator of a metal furniture surface coating 
operation that uses less than 3,842 liters of coating (as applied) per 
year and keeps purchase or inventory records or other data necessary to 
substantiate annual coating usage shall be exempt from all other 
provisions of this subpart. These records shall be maintained at the 
source for a period of at least 2 years.

[47 FR 49287, Oct. 29, 1982, as amended at 50 FR 18248, Apr. 30, 1985]



Sec. 60.311  Definitions and symbols.

    (a) All terms used in this subpart not defined below are given the 
meaning in the Act and in subpart A of this part.
    Bake oven means a device which uses heat to dry or cure coatings.
    Dip coating means a method of applying coatings in which the part is 
submerged in a tank filled with the coatings.
    Electrodeposition (EDP) means a method of applying coatings in which 
the part is submerged in a tank filled with the coatings and in which an 
electrical potential is used to enhance deposition of the coatings on 
the part.
    Electrostatic spray application means a spray application method 
that uses an electrical potential to increase the transfer efficiency of 
the coatings.
    Flash-off area means the portion of a surface coating operation 
between the coating application area and bake oven.
    Flow coating means a method of applying coatings in which the part 
is carried through a chamber containing numerous nozzles which direct 
unatomized streams of coatings from many different angles onto the 
surface of the part.
    Organic coating means any coating used in a surface coating 
operation, including dilution solvents, from which volatile organic 
compound emissions occur during the application or the curing process. 
For the purpose of this regulation, powder coatings are not included in 
this definition.
    Powder coating means any surface coating which is applied as a dry 
powder and is fused into a continuous coating film through the use of 
heat.
    Spray application means a method of applying coatings by atomizing 
and directing the atomized spray toward the part to be coated.
    Surface coating operation means the system on a metal furniture 
surface coating line used to apply and dry or cure an organic coating on 
the surface of the metal furniture part or product. The surface coating 
operation may be a prime coat or a top coat operation and includes the 
coating application station(s), flash-off area, and curing oven.
    Transfer efficiency means the ratio of the amount of coating solids 
deposited onto the surface of a part or product to the total amount of 
coating solids used.
    VOC content means the proportion of a coating that is volatile 
organic compounds (VOC's), expressed as kilograms of VOC's per liter of 
coating solids.

[[Page 283]]

    VOC emissions means the mass of volatile organic compounds (VOC's), 
expressed as kilograms of VOC's per liter of applied coating solids, 
emitted from a metal furniture surface coating operation.
    (b) All symbols used in this subpart not defined below are given the 
meaning in the Act and in subpart A of this part.

Ca=the VOC concentration in each gas stream leaving the 
          control device and entering the atmosphere (parts per million 
          by volume, as carbon)
Cb=the VOC concentration in each gas stream entering the 
          control device (parts per million by volume, as carbon)
Cf=the VOC concentration in each gas stream emitted directly 
          to the atmosphere (parts per million by volume, as carbon)
Dc=density of each coating, as received (kilograms per liter)
Dd=density of each diluent VOC-solvent (kilograms per liter)
Dr=density of VOC-solvent recovered by an emission control 
          device (kilograms per liter)
E=VOC destruction efficiency of the control device (fraction)
F=the proportion of total VOC's emitted by an affected facility that 
          enters the control device (fraction)
G=the volume-weighted average mass of VOC's in coatings consumed in a 
calendar month per unit volume of coating solids applied (kilograms per 
liter)
Lc=the volume of each coating consumed, as received (liters)
Ld=the volume of each diluent VOC-solvent added to coatings 
(liters)
Lr=the volume of VOC-solvent recovered by an emission control 
device (liters)
Ls=the volume of coating solids consumed (liters)
Md=the mass of diluent VOC-solvent consumed (kilograms)
Mo=the mass of VOC's in coatings consumed, as received 
(kilograms)
Mr=the mass of VOC's recovered by an emission control device 
(kilograms)
N=the volume weighted average mass of VOC emissions to the atmosphere 
per unit volume of coating solids applied (kilograms per liter)
Qa=the volumetric flow rate of each gas stream leaving the 
control device and entering the atmosphere (dry standard cubic meters 
per hour)
Qb=the volumetric flow rate of each gas stream entering the 
control device (dry standard cubic meters per hour)
Qf=the volumetric flow rate of each gas stream emitted 
directly to the atmosphere (dry standard cubic meters per hour)
R=the overall VOC emission reduction achieved for an affected facility 
(fraction)
T=the transfer efficiency (fraction)
Vs=the proportion of solids in each coating (or input 
stream), as received (fraction by volume)
Wo=the proportion of VOC's in each coating (or input stream), 
as received (fraction by weight)



Sec. 60.312  Standard for volatile organic compounds (VOC).

    (a) On and after the date on which the initial performance test 
required to be conducted by Sec. 60.8(a) is completed, no owner or 
operator subject to the provisions of this subpart shall cause the 
discharge into the atmosphere of VOC emissions from any metal furniture 
surface coating operation in excess of 0.90 kilogram of VOC per liter of 
coating solids applied.



Sec. 60.313  Performance tests and compliance provisions.

    (a) Section 60.8(d) and (f) do not apply to the performance test 
procedures required by this subpart.
    (b) The owner or operator of an affected facility shall conduct an 
initial performance test as required under Sec. 60.8(a) and thereafter a 
performance test each calendar month for each affected facility 
according to the procedures in this section.
    (c) The owner or operator shall use the following procedures for 
determining monthly volume-weighted average emissions of VOC's in 
kilograms per liter of coating solids applied (G).
    (1) An owner or operator shall use the following procedures for any 
affected facility which does not use a capture system and control device 
to comply with the emissions limit specified under Sec. 60.312. The 
owner or operator shall determine the composition of the coatings by 
formulation data supplied by the manufacturer of the coating or by an 
analysis of each coating, as received, using Reference Method 24. The 
Administrator may require the owner or operator who uses formulation 
data supplied by the manufacturer of the coating to determine the VOC 
content of coatings using Reference Method 24. The owner or operator 
shall determine the volume of coating and the mass of VOC-solvent used 
for thinning purposes from company records on a monthly

[[Page 284]]

basis. If a common coating distribution system serves more than one 
affected facility or serves both affected and existing facilities, the 
owner or operator shall estimate the volume of coating used at each 
facility by using the average dry weight of coating and the surface area 
coated by each affected and existing facility or by other procedures 
acceptable to the Administrator.
    (i) Calculate the volume-weighted average of the total mass of VOC's 
consumed per unit volume of coating solids applied (G) during each 
calendar month for each affected facility, except as provided under 
Sec. 60.313(c)(2) and (c)(3). Each monthly calculation is considered a 
performance test. Except as provided in paragraph (c)(1)(iv) of this 
section, the volume-weighted average of the total mass of VOC's consumed 
per unit volume of coating solids applied (G) each calendar month will 
be determined by the following procedures.
    (A) Calculate the mass of VOC's used (Mo+Md) 
during each calendar month for each affected facility by the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.015

(LdjDdj will be 0 if no VOC solvent is 
added to the coatings, as received.)

Where: n is the number of different coatings used during the calendar 
month and m is the number of different diluent VOC-solvents used during 
the calendar month.

    (B) Calculate the total volume of coating solids used 
(Ls) in each calendar month for each affected facility by the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.016

Where: n is the number of different coatings used during the calendar 
month.

Select the appropriate transfer efficiency from Table 1. If the owner or 
operator can demonstrate to the satisfaction of the Administrator that 
other transfer efficiencies other than those shown are appropriate, the 
Administrator will approve their use on a case-by-case basis. Transfer 
efficiency values for application methods not listed below shall be 
determined by the Administrator on a case-by-case basis. An owner or 
operator must submit sufficient data for the Administrator to judge the 
accuracy of the transfer efficiency claims.

                     Table 1--Transfer Efficiencies
------------------------------------------------------------------------
                                                               Transfer
                     Application methods                      efficiency
                                                                  (T)
------------------------------------------------------------------------
Air atomized spray..........................................        0.25
Airless spray...............................................         .25
Manual electrostatic spray..................................         .60
Nonrotational automatic electrostatic spray.................         .70
Rotating head electrostatic spray (manual and automatic)....         .80
Dip coat and flow coat......................................         .90
Electrodeposition...........................................         .95
------------------------------------------------------------------------


Where more than one application method is used within a single surface 
coating operation, the owner or operator shall determine the composition 
and volume of each coating applied by each method through a means 
acceptable to the Administrator and compute the weighted average 
transfer efficiency by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.017

Where n is the number of coatings used and p is the number of 
application methods used.

    (C) Calculate the volume-weighted average mass of VOC's consumed per 
unit volume of coating solids applied (G) during the calendar month for 
each affected facility by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.018

    (ii) Calculate the volume-weighted average of VOC emissions to the 
atmosphere (N) during the calendar month for each affected facility by 
the following equation:

N=G
    (iii) Where the volume-weighted average mass of VOC discharged to 
the atmosphere per unit volume of coating solids applied (N) is less 
than or equal

[[Page 285]]

to 0.90 kilogram per liter, the affected facility is in compliance.
    (iv) If each individual coating used by an affected facility has a 
VOC content, as received, which when divided by the lowest transfer 
efficiency at which the coating is applied, results in a value equal to 
or less than 0.90 kilogram per liter, the affected facility is in 
compliance provided no VOC's are added to the coatings during 
distribution or application.
    (2) An owner or operator shall use the following procedures for any 
affected facility that uses a capture system and a control device that 
destroys VOC's (e.g., incinerator) to comply with the emission limit 
specified under Sec. 60.312.
    (i) Determine the overall reduction efficiency (R) for the capture 
system and control device. For the initial performance test the overall 
reduction efficiency (R) shall be determined as prescribed in (c)(2)(i) 
(A), (B), and (C) of this section. In subsequent months, the owner or 
operator may use the most recently determined overall reduction 
efficiency (R) for the performance test providing control device and 
capture system operating conditions have not changed. The procedure in, 
(c)(2)(i) (A), (B), and (C), of this section, shall be repeated when 
directed by the Administrator or when the owner or operator elects to 
operate the control device or capture system at conditions different 
from the initial performance test.
    (A) Determine the fraction (F) of total VOC's emitted by an affected 
facility that enters the control device using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.010

Where
n is the number of gas streams entering the control device and
m is the number of gas streams emitted directly to the atmosphere.

    (B) Determine the destruction efficiency of the control device (E) 
using values of the volumetric flow rate of each of the gas streams and 
the VOC content (as carbon) of each of the gas streams in and out of the 
device by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.011

Where:
n is the number of gas streams entering the control device, and
m is the number of gas streams leaving the contol device and entering 
          the atmosphere.

    (C) Determine overall reduction efficiency (R) using the following 
equation:
R=EF
    (ii) Calculate the volume-weighted average of the total mass of 
VOC's per unit volume of coating solids applied (G) during each calendar 
month for each affected facility using equations in paragraphs (c)(1)(i) 
(A), (B), and (C) of this section.
    (iii) Calculate the volume-weighted average of VOC emissions to the 
atmosphere (N) during each calendar month by the following equation:
N=G(1-R)
    (iv) If the volume-weighted average mass of VOC's emitted to the 
atmosphere for each calendar month (N) is less than or equal to 0.90 
kilogram per liter of coating solids applied, the affected facility is 
in compliance. Each monthly calculation is a performance test.
    (3) An owner or operator shall use the following procedure for any 
affected facility which uses a control device that recovers the VOC's 
(e.g., carbon adsorber) to comply with the applicable emission limit 
specified under Sec. 60.312.
    (i) Calculate the total mass of VOC's consumed 
(Mo+Md) and the volume-weighted average of the 
total mass of VOC's per unit volume of coating solids applied (G) during 
each calendar month for each affected facility using equations in 
paragraph (c)(1)(i) (A), (B), and (C) of this section.
    (ii) Calculate the total mass of VOC's recovered (Mr) 
during each calendar month using the following equation:

Mr=Lr Dr

    (iii) Calculate overall reduction efficiency of the control 
device (R) for each calendar month for each affected facility using the 
following equation:

[[Page 286]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.019

    (iv) Calculate the volume-weighted average mass of VOC's emitted to 
the atmosphere (N) for each calendar month for each affected facility 
using equation in paragraph (c)(2)(iii) of this section.
    (v) If the weighted average mass of VOC's emitted to the atmosphere 
for each calendar month (N) is less than or equal to 0.90 kilogram per 
liter of coating solids applied, the affected facility is in compliance. 
Each monthly calculation is a performance test.



Sec. 60.314  Monitoring of emissions and operations.

    (a) The owner or operator of an affected facility which uses a 
capture system and an incinerator to comply with the emission limits 
specified under Sec. 60.312 shall install, calibrate, maintain, and 
operate temperature measurement devices according to the following 
procedures:
    (1) Where thermal incineration is used, a temperature measurement 
device shall be installed in the firebox. Where catalytic incineration 
is used, a temperature measurement device shall be installed in the gas 
stream immediately before and after the catalyst bed.
    (2) Each temperature measurement device shall be installed, 
calibrated, and maintained according to the manufacturer's 
specifications. The device shall have an accuracy of the greater of 0.75 
percent of the temperature being measured expressed in degrees Celsius 
or plus-minus2.5  deg.C.
    (3) Each temperature measurement device shall be equipped with a 
recording device so that a permanent continuous record is produced.
    (b) The owner or operator of an affected facility which uses a 
capture system and a solvent recovery system to comply with the emission 
limits specified under Sec. 60.312 shall install the equipment necessary 
to determine the total volume of VOC-solvent recovered daily.



Sec. 60.315  Reporting and recordkeeping requirements.

    (a) The reporting requirements of Sec. 60.8(a) apply only to the 
initial performance test. Each owner or operator subject to the 
provisions of this subpart shall include the following data in the 
report of the initial performance test required under Sec. 60.8(a):
    (1) Except as provided in paragraph (a)(2) of this section, the 
volume-weighted average mass of VOC's emitted to the atmosphere per 
volume of applied coating solids (N) for a period of one calendar month 
from each affected facility.
    (2) For each affected facility where compliance is determined under 
the provisions of Sec. 60.313(c)(1)(iv), a list of the coatings used 
during a period of one calendar month, the VOC content of each coating 
calculated from data determined using Reference Method 24 or supplied by 
the manufacturer of the coating, and the minimum transfer efficiency of 
any coating application equipment used during the month.
    (3) For each affected facility where compliance is achieved through 
the use of an incineration system, the following additional information 
will be reported:
    (i) The proportion of total VOC's emitted that enters the control 
device (F),
    (ii) The VOC reduction efficiency of the control device (E),
    (iii) The average combustion temperature (or the average temperature 
upstream and downstream of the catalyst bed), and
    (iv) A description of the method used to establish the amount of 
VOC's captured and sent to the incinerator.
    (4) For each affected facility where compliance is achieved through 
the use of a solvent recovery system, the following additional 
information will be reported:
    (i) The volume of VOC-solvent recovered (Lr), and
    (ii) The overall VOC emission reduction achieved (R).
    (b) Following the initial performance test, the owner or operator of 
an affected facility shall identify, record, and submit a written report 
to the Administrator every calendar quarter of each instance in which 
the volume-

[[Page 287]]

weighted average of the total mass of VOC's emitted to the atmosphere 
per volume of applied coating solids (N) is greater than the limit 
specified under Sec. 60.312. If no such instances have occurred during a 
particular quarter, a report stating this shall be submitted to the 
Administrator semiannually.
    (c) Following the initial performance test, the owner or operator of 
an affected facility shall identify, record, and submit at the frequency 
specified in Sec. 60.7(c) the following:
    (1) Where compliance with Sec. 60.312 is achieved through the use of 
thermal incineration, each 3-hour period when metal furniture is being 
coated during which the average temperature of the device was more than 
28  deg.C below the average temperature of the device during the most 
recent performance test at which destruction efficiency was determined 
as specified under Sec. 60.313.
    (2) Where compliance with Sec. 60.312 is achieved through the use of 
catalytic incineration, each 3-hour period when metal furniture is being 
coated during which the average temperature of the device immediately 
before the catalyst bed is more than 28  deg.C below the average 
temperature of the device immediately before the catalyst bed during the 
most recent performance test at which destruction efficiency was 
determined as specified under Sec. 60.313. Additionally, when metal 
furniture is being coated, all 3-hour periods during which the average 
temperature difference across the catalyst bed is less than 80 percent 
of the average temperature difference across the catalyst bed during the 
most recent performance test at which destruction efficiency was 
determined as specified under Sec. 60.313 will be recorded.
    (3) For thermal and catalytic incinerators, if no such periods as 
described in paragraphs (c)(1) and (c)(2) of this section occur, the 
owner or operator shall state this in the report.
    (d) Each owner or operator subject to the provisions of this subpart 
shall maintain at the source, for a period of at least 2 years, records 
of all data and calculations used to determine VOC emissions from each 
affected facility. Where compliance is achieved through the use of 
thermal incineration, each owner or operator shall maintain, at the 
source, daily records of the incinerator combustion chamber temperature. 
If catalytic incineration is used, the owner or operator shall maintain 
at the source daily records of the gas temperature, both upstream and 
downstream of the incinerator catalyst bed. Where compliance is achieved 
through the use of a solvent recovery system, the owner or operator 
shall maintain at the source daily records of the amount of solvent 
recovered by the system for each affected facility.

[47 FR 49287, Oct. 29, 1982, as amended at 55 FR 51383, Dec. 13, 1990]



Sec. 60.316  Test methods and procedures.

    (a) The reference methods in appendix A to this part except as 
provided under Sec. 60.8(b) shall be used to determine compliance with 
Sec. 60.312 as follows:
    (1) Method 24, or coating manufacturer's formulation data, for use 
in the determination of VOC content of each batch of coating as applied 
to the surface of the metal parts. In case of an inconsistency between 
the Method 24 results and the formulation data, the Method 24 results 
will govern.
    (2) Method 25 for the measurement of VOC concentration.
    (3) Method 1 for sample and velocity traverses.
    (4) Method 2 for velocity and volumetric flow rate.
    (5) Method 3 for gas analysis.
    (6) Method 4 for stack gas moisture.
    (b) For Method 24, the coating sample must be at least a 1 liter 
sample in a 1 liter container taken at a point where the sample will be 
representative of the coating material as applied to the surface of the 
metal part.
    (c) For Method 25, the minimum sampling time for each of 3 runs is 
60 minutes and the minimum sample volume is 0.003 dry standard cubic 
meters except that shorter sampling times or smaller volumes, when 
necessitated by process variables or other factors, may be approved by 
the Administrator.
    (d) The Administrator will approve testing of representative stacks 
on a case-by-case basis if the owner or operator can demonstrate to the 
satisfaction of the Administrator that testing of representative stacks 
yields results

[[Page 288]]

comparable to those that would be obtained by testing all stacks.

Subpart FF  [Reserved]



    Subpart GG--Standards of Performance for Stationary Gas Turbines



Sec. 60.330  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities: All stationary gas turbines with a heat input at 
peak load equal to or greater than 10.7 gigajoules per hour, based on 
the lower heating value of the fuel fired.
    (b) Any facility under paragraph (a) of this section which commences 
construction, modification, or reconstruction after October 3, 1977, is 
subject to the requirements of this part except as provided in 
paragraphs (e) and (j) of Sec. 60.332.

[44 FR 52798, Sept. 10, 1979, as amended at 52 FR 42434, Nov. 5, 1987]



Sec. 60.331  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Stationary gas turbine means any simple cycle gas turbine, 
regenerative cycle gas turbine or any gas turbine portion of a combined 
cycle steam/electric generating system that is not self propelled. It 
may, however, be mounted on a vehicle for portability.
    (b) Simple cycle gas turbine means any stationary gas turbine which 
does not recover heat from the gas turbine exhaust gases to preheat the 
inlet combustion air to the gas turbine, or which does not recover heat 
from the gas turbine exhaust gases to heat water or generate steam.
    (c) Regenerative cycle gas turbine means any stationary gas turbine 
which recovers heat from the gas turbine exhaust gases to preheat the 
inlet combustion air to the gas turbine.
    (d) Combined cycle gas turbine means any stationary gas turbine 
which recovers heat from the gas turbine exhaust gases to heat water or 
generate steam.
    (e) Emergency gas turbine means any stationary gas turbine which 
operates as a mechanical or electrical power source only when the 
primary power source for a facility has been rendered inoperable by an 
emergency situation.
    (f) Ice fog means an atmospheric suspension of highly reflective ice 
crystals.
    (g) ISO standard day conditions means 288 degrees Kelvin, 60 percent 
relative humidity and 101.3 kilopascals pressure.
    (h) Efficiency means the gas turbine manufacturer's rated heat rate 
at peak load in terms of heat input per unit of power output based on 
the lower heating value of the fuel.
    (i) Peak load means 100 percent of the manufacturer's design 
capacity of the gas turbine at ISO standard day conditions.
    (j) Base load means the load level at which a gas turbine is 
normally operated.
    (k) Fire-fighting turbine means any stationary gas turbine that is 
used solely to pump water for extinguishing fires.
    (l) Turbines employed in oil/gas production or oil/gas 
transportation means any stationary gas turbine used to provide power to 
extract crude oil/natural gas from the earth or to move crude oil/
natural gas, or products refined from these substances through 
pipelines.
    (m) A Metropolitan Statistical Area or MSA as defined by the 
Department of Commerce.
    (n) Offshore platform gas turbines means any stationary gas turbine 
located on a platform in an ocean.
    (o) Garrison facility means any permanent military installation.
    (p) Gas turbine model means a group of gas turbines having the same 
nominal air flow, combuster inlet pressure, combuster inlet temperature, 
firing temperature, turbine inlet temperature and turbine inlet 
pressure.
    (q) Electric utility stationary gas turbine means any stationary gas 
turbine constructed for the purpose of supplying more than one-third of 
its potential electric output capacity to any utility power distribution 
system for sale.
    (r) Emergency fuel is a fuel fired by a gas turbine only during 
circumstances,

[[Page 289]]

such as natural gas supply curtailment or breakdown of delivery system, 
that make it impossible to fire natural gas in the gas turbine.
    (s) Regenerative cycle gas turbine means any stationary gas turbine 
that recovers thermal energy from the exhaust gases and utilizes the 
thermal energy to preheat air prior to entering the combustor.

[44 FR 52798, Sept. 10, 1979, as amended at 47 FR 3770, Jan. 27, 1982]



Sec. 60.332  Standard for nitrogen oxides.

    (a) On and after the date of the performance test required by 
Sec. 60.8 is completed, every owner or operator subject to the 
provisions of this subpart as specified in paragraphs (b), (c), and (d) 
of this section shall comply with one of the following, except as 
provided in paragraphs (e), (f), (g), (h), (i), (j), (k), and (l) of 
this section.
    (1) No owner or operator subject to the provisions of this subpart 
shall cause to be discharged into the atmosphere from any stationary gas 
turbine, any gases which contain nitrogen oxides in excess of:
[GRAPHIC] [TIFF OMITTED] TC16NO91.020

where:

STD=allowable NOx emissions (percent by volume at 15 percent 
          oxygen and on a dry basis).
Y=manufacturer's rated heat rate at manufacturer's rated load 
          (kilojoules per watt hour) or, actual measured heat rate based 
          on lower heating value of fuel as measured at actual peak load 
          for the facility. The value of Y shall not exceed 14.4 
          kilojoules per watt hour.
F=NOx emission allowance for fuel-bound nitrogen as defined 
          in paragraph (a)(3) of this section.

    (2) No owner or operator subject to the provisions of this subpart 
shall cause to be discharged into the atmosphere from any stationary gas 
turbine, any gases which contain nitrogen oxides in excess of:
[GRAPHIC] [TIFF OMITTED] TC16NO91.021

where:

STD=allowable NOx emissions (percent by volume at 15 percent 
          oxygen and on a dry basis).
Y=manufacturer's rated heat rate at manufacturer's rated peak load 
          (kilojoules per watt hour), or actual measured heat rate based 
          on lower heating value of fuel as measured at actual peak load 
          for the facility. The value of Y shall not exceed 14.4 
          kilojoules per watt hour.
F=NOx emission allowance for fuel-bound nitrogen as defined 
          in paragraph (a)(3) of this section.

    (3) F shall be defined according to the nitrogen content of the fuel 
as follows:

------------------------------------------------------------------------
                                                      F (NOx percent by
      Fuel-bound nitrogen (percent by weight)              volume)
------------------------------------------------------------------------
N0.015............................................                     0
0.015< N0.1.......................................               0.04(N)
0.1< N0.25........................................   0.004+0.0067(N-0.1)
N>0.25............................................                 0.005
------------------------------------------------------------------------

where:

N=the nitrogen content of the fuel (percent by weight).
or:


Manufacturers may develop custom fuel-bound nitrogen allowances for each 
gas turbine model they manufacture. These fuel-bound nitrogen allowances 
shall be substantiated with data and must be approved for use by the 
Administrator before the initial performance test required by Sec. 60.8. 
Notices of approval of custom fuel-bound nitrogen allowances will be 
published in the Federal Register.
    (b) Electric utility stationary gas turbines with a heat input at 
peak load greater than 107.2 gigajoules per hour (100 million Btu/hour) 
based on the lower heating value of the fuel fired shall comply with the 
provisions of paragraph (a)(1) of this section.
    (c) Stationary gas turbines with a heat input at peak load equal to 
or greater than 10.7 gigajoules per hour (10 million Btu/hour) but less 
than or equal to 107.2 gigajoules per hour (100 million Btu/hour) based 
on the lower heating value of the fuel fired, shall comply with the 
provisions of paragraph (a)(2) of this section.
    (d) Stationary gas turbines with a manufacturer's rated base load at 
ISO conditions of 30 megawatts or less except as provided in 
Sec. 60.332(b) shall comply with paragraph (a)(2) of this section.

[[Page 290]]

    (e) Stationary gas turbines with a heat input at peak load equal to 
or greater than 10.7 gigajoules per hour (10 million Btu/hour) but less 
than or equal to 107.2 gigajoules per hour (100 million Btu/hour) based 
on the lower heating value of the fuel fired and that have commenced 
construction prior to October 3, 1982 are exempt from paragraph (a) of 
this section.
    (f) Stationary gas turbines using water or steam injection for 
control of NOx emissions are exempt from paragraph (a) when 
ice fog is deemed a traffic hazard by the owner or operator of the gas 
turbine.
    (g) Emergency gas turbines, military gas turbines for use in other 
than a garrison facility, military gas turbines installed for use as 
military training facilities, and fire fighting gas turbines are exempt 
from paragraph (a) of this section.
    (h) Stationary gas turbines engaged by manufacturers in research and 
development of equipment for both gas turbine emission control 
techniques and gas turbine efficiency improvements are exempt from 
paragraph (a) on a case-by-case basis as determined by the 
Administrator.
    (i) Exemptions from the requirements of paragraph (a) of this 
section will be granted on a case-by-case basis as determined by the 
Administrator in specific geographical areas where mandatory water 
restrictions are required by governmental agencies because of drought 
conditions. These exemptions will be allowed only while the mandatory 
water restrictions are in effect.
    (j) Stationary gas turbines with a heat input at peak load greater 
than 107.2 gigajoules per hour that commenced construction, 
modification, or reconstruction between the dates of October 3, 1977, 
and January 27, 1982, and were required in the September 10, 1979, 
Federal Register (44 FR 52792) to comply with paragraph (a)(1) of this 
section, except electric utility stationary gas turbines, are exempt 
from paragraph (a) of this section.
    (k) Stationary gas turbines with a heat input greater than or equal 
to 10.7 gigajoules per hour (10 million Btu/hour) when fired with 
natural gas are exempt from paragraph (a)(2) of this section when being 
fired with an emergency fuel.
    (l) Regenerative cycle gas turbines with a heat input less than or 
equal to 107.2 gigajoules per hour (100 million Btu/hour) are exempt 
from paragraph (a) of this section.

[44 FR 52798, Sept. 10, 1979, as amended at 47 FR 3770, Jan. 27, 1982]



Sec. 60.333  Standard for sulfur dioxide.

    On and after the date on which the performance test required to be 
conducted by Sec. 60.8 is completed, every owner or operator subject to 
the provision of this subpart shall comply with one or the other of the 
following conditions:
    (a) No owner or operator subject to the provisions of this subpart 
shall cause to be discharged into the atmosphere from any stationary gas 
turbine any gases which contain sulfur dioxide in excess of 0.015 
percent by volume at 15 percent oxygen and on a dry basis.
    (b) No owner or operator subject to the provisions of this subpart 
shall burn in any stationary gas turbine any fuel which contains sulfur 
in excess of 0.8 percent by weight.

[44 FR 52798, Sept. 10, 1979]



Sec. 60.334  Monitoring of operations.

    (a) The owner or operator of any stationary gas turbine subject to 
the provisions of this subpart and using water injection to control 
NOx emissions shall install and operate a continuous 
monitoring system to monitor and record the fuel consumption and the 
ratio of water to fuel being fired in the turbine. This system shall be 
accurate to within plus-minus5.0 percent and shall be 
approved by the Administrator.
    (b) The owner or operator of any stationary gas turbine subject to 
the provisions of this subpart shall monitor sulfur content and nitrogen 
content of the fuel being fired in the turbine. The frequency of 
determination of these values shall be as follows:
    (1) If the turbine is supplied its fuel from a bulk storage tank, 
the values shall be determined on each occasion that fuel is transferred 
to the storage tank from any other source.
    (2) If the turbine is supplied its fuel without intermediate bulk 
storage the

[[Page 291]]

values shall be determined and recorded daily. Owners, operators or fuel 
vendors may develop custom schedules for determination of the values 
based on the design and operation of the affected facility and the 
characteristics of the fuel supply. These custom schedules shall be 
substantiated with data and must be approved by the Administrator before 
they can be used to comply with paragraph (b) of this section.
    (c) For the purpose of reports required under Sec. 60.7(c), periods 
of excess emissions that shall be reported are defined as follows:
    (1) Nitrogen oxides. Any one-hour period during which the average 
water-to-fuel ratio, as measured by the continuous monitoring system, 
falls below the water-to-fuel ratio determined to demonstrate compliance 
with Sec. 60.332 by the performance test required in Sec. 60.8 or any 
period during which the fuel-bound nitrogen of the fuel is greater than 
the maximum nitrogen content allowed by the fuel-bound nitrogen 
allowance used during the performance test required in Sec. 60.8. Each 
report shall include the average water-to-fuel ratio, average fuel 
consumption, ambient conditions, gas turbine load, and nitrogen content 
of the fuel during the period of excess emissions, and the graphs or 
figures developed under Sec. 60.335(a).
    (2) Sulfur dioxide. Any daily period during which the sulfur content 
of the fuel being fired in the gas turbine exceeds 0.8 percent.
    (3) Ice fog. Each period during which an exemption provided in 
Sec. 60.332(g) is in effect shall be reported in writing to the 
Administrator quarterly. For each period the ambient conditions existing 
during the period, the date and time the air pollution control system 
was deactivated, and the date and time the air pollution control system 
was reactivated shall be reported. All quarterly reports shall be 
postmarked by the 30th day following the end of each calendar quarter.
    (4) Emergency fuel. Each period during which an exemption provided 
in Sec. 60.332(k) is in effect shall be included in the report required 
in Sec. 60.7(c). For each period, the type, reasons, and duration of the 
firing of the emergency fuel shall be reported.

[44 FR 52798, Sept. 10, 1979, as amended at 47 FR 3770, Jan. 27, 1982]



Sec. 60.335  Test methods and procedures.

    (a) To compute the nitrogen oxides emissions, the owner or operator 
shall use analytical methods and procedures that are accurate to within 
5 percent and are approved by the Administrator to determine the 
nitrogen content of the fuel being fired.
    (b) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided for in Sec. 60.8(b). 
Acceptable alternative methods and procedures are given in paragraph (f) 
of this section.
    (c) The owner or operator shall determine compliance with the 
nitrogen oxides and sulfur dioxide standards in Secs. 60.332 and 
60.333(a) as follows:
    (1) The nitrogen oxides emission rate (NOx) shall be 
computed for each run using the following equation:

NOx=(NOxo) (Pr/Po) 
          0.5 e19(Ho--0.00633) (288 deg.K/
          Ta) 1.53

where:
NOx=emission rate of NOx at 15 percent 
          O2 and ISO standard ambient conditions, volume 
          percent.
NOxo=observed NOx concentration, ppm by volume.
Pr=reference combustor inlet absolute pressure at 101.3 
          kilopascals ambient pressure, mm Hg.
Po=observed combustor inlet absolute pressure at test, mm Hg.
Ho=observed humidity of ambient air, g H2O/g air.
e=transcendental constant, 2.718.
Ta=ambient temperature,  deg.K.

    (2) The monitoring device of Sec. 60.334(a) shall be used to 
determine the fuel consumption and the water-to-fuel ratio necessary to 
comply with Sec. 60.332 at 30, 50, 75, and 100 percent of peak load or 
at four points in the normal operating range of the gas turbine, 
including the minimum point in the range and peak load. All loads shall 
be corrected to ISO conditions using the appropriate equations supplied 
by the manufacturer.

[[Page 292]]

    (3) Method 20 shall be used to determine the nitrogen oxides, sulfur 
dioxide, and oxygen concentrations. The span values shall be 300 ppm of 
nitrogen oxide and 21 percent oxygen. The NOx emissions shall 
be determined at each of the load conditions specified in paragraph 
(c)(2) of this section.
    (d) The owner or operator shall determine compliance with the sulfur 
content standard in Sec. 60.333(b) as follows: ASTM D 2880-71 shall be 
used to determine the sulfur content of liquid fuels and ASTM D 1072-80, 
D 3031-81, D 4084-82, or D 3246-81 shall be used for the sulfur content 
of gaseous fuels (incorporated by reference--see Sec. 60.17). The 
applicable ranges of some ASTM methods mentioned above are not adequate 
to measure the levels of sulfur in some fuel gases. Dilution of samples 
before analysis (with verification of the dilution ratio) may be used, 
subject to the approval of the Administrator.
    (e) To meet the requirements of Sec. 60.334(b), the owner or 
operator shall use the methods specified in paragraphs (a) and (d) of 
this section to determine the nitrogen and sulfur contents of the fuel 
being burned. The analysis may be performed by the owner or operator, a 
service contractor retained by the owner or operator, the fuel vendor, 
or any other qualified agency.
    (f) The owner or operator may use the following as alternatives to 
the reference methods and procedures specified in this section:
    (1) Instead of using the equation in paragraph (b)(1) of this 
section, manufacturers may develop ambient condition correction factors 
to adjust the nitrogen oxides emission level measured by the performance 
test as provided in Sec. 60.8 to ISO standard day conditions. These 
factors are developed for each gas turbine model they manufacture in 
terms of combustion inlet pressure, ambient air pressure, ambient air 
humidity, and ambient air temperature. They shall be substantiated with 
data and must be approved for use by the Administrator before the 
initial performance test required by Sec. 60.8. Notices of approval of 
custom ambient condition correction factors will be published in the 
Federal Register.

[54 FR 6675, Feb. 14, 1989, as amended at 54 FR 27016, June 27, 1989],



   Subpart HH--Standards of Performance for Lime Manufacturing Plants

    Source: 49 FR 18080, Apr. 26, 1984, unless otherwise noted.



Sec. 60.340  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to each rotary 
lime kiln used in the manufacture of lime.
    (b) The provisions of this subpart are not applicable to facilities 
used in the manufacture of lime at kraft pulp mills.
    (c) Any facility under paragraph (a) of this section that commences 
construction or modification after May 3, 1977, is subject to the 
requirements of this subpart.



Sec. 60.341  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
same meaning given them in the Act and in the General Provisions.
    (a) Lime manufacturing plant means any plant which uses a rotary 
lime kiln to produce lime product from limestone by calcination.
    (b) Lime product means the product of the calcination process 
including, but not limited to, calcitic lime, dolomitic lime, and dead-
burned dolomite.
    (c) Positive-pressure fabric filter means a fabric filter with the 
fans on the upstream side of the filter bags.
    (d) Rotary lime kiln means a unit with an inclined rotating drum 
that is used to produce a lime product from limestone by calcination.
    (e) Stone feed means limestone feedstock and millscale or other iron 
oxide additives that become part of the product.



Sec. 60.342  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no

[[Page 293]]

owner or operator subject to the provisions of this subpart shall cause 
to be discharged into the atmosphere from any rotary lime kiln any gases 
which:
    (1) Contain particulate matter in excess of 0.30 kilogram per 
megagram (0.60 lb/ton) of stone feed.
    (2) Exhibit greater than 15 percent opacity when exiting from a dry 
emission control device.



Sec. 60.343  Monitoring of emissions and operations.

    (a) The owner or operator of a facility that is subject to the 
provisions of this subpart shall install, calibrate, maintain, and 
operate a continuous monitoring system, except as provided in paragraphs 
(b) and (c) of this section, to monitor and record the opacity of a 
representative portion of the gases discharged into the atmosphere from 
any rotary lime kiln. The span of this system shall be set at 40 percent 
opacity.
    (b) The owner or operator of any rotary lime kiln having a control 
device with a multiple stack exhaust or a roof monitor may, in lieu of 
the continuous opacity monitoring requirement of Sec. 60.343(a), monitor 
visible emissions at least once per day of operation by using a 
certified visible emissions observer who, for each site where visible 
emissions are observed, will perform three Method 9 tests and record the 
results. Visible emission observations shall occur during normal 
operation of the rotary lime kiln at least once per day. For at least 
three 6-minute periods, the opacity shall be recorded for any point(s) 
where visible emissions are observed, and the corresponding feed rate of 
the kiln shall also be recorded. Records shall be maintained of any 6-
minute average that is in excess of the emissions specified in 
Sec. 60.342(a) of this subpart.
    (c) The owner or operator of any rotary lime kiln using a wet 
scrubbing emission control device subject to the provisions of this 
subpart shall not be required to monitor the opacity of the gases 
discharged as required in paragraph (a) of this section, but shall 
install, calibrate, maintain, operate, and record the resultant 
information from the following continuous monitoring devices:
    (1) A monitoring device for the continuous measurement of the 
pressure loss of the gas stream through the scrubber. The monitoring 
device must be accurate within 250 pascals (one inch of 
water).
    (2) A monitoring device for continuous measurement of the scrubbing 
liquid supply pressure to the control device. The monitoring device must 
be accurate within 5 percent of the design scrubbing liquid 
supply pressure.
    (d) For the purpose of conducting a performance test under 
Sec. 60.8, the owner or operator of any lime manufacturing plant subject 
to the provisions of this subpart shall install, calibrate, maintain, 
and operate a device for measuring the mass rate of stone feed to any 
affected rotary lime kiln. The measuring device used must be accurate to 
within 5 percent of the mass rate over its operating range.
    (e) For the purpose of reports required under Sec. 60.7(c), periods 
of excess emissions that shall be reported are defined as all 6-minute 
periods during which the average opacity of the visible emissions from 
any lime kiln subject to paragraph (a) of this subpart is greater than 
15 percent or, in the case of wet scrubbers, any period in which the 
scrubber pressure drop is greater than 30 percent below the rate 
established during the performance test. If visible emission 
observations are made according to paragraph (b) of this section, 
reports of excess emissions shall be submitted semiannually.

[49 FR 18080, Apr. 26, 1984, as amended at 52 FR 4773, Feb. 17, 1987; 54 
FR 6675, Feb. 14, 1989]



Sec. 60.344  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.342(a) as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:

E=(cs Qsd)/PK)


[[Page 294]]


where:
E=emission rate of particulate matter, kg/Mg (1b/ton) of stone feed.
cs=concentration of particulate matter,     g/dscm (g/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
P=stone feed rate, Mg/hr (ton/hr).
K=conversion factor, 1000 g/kg (453.6 g/lb).

    (2) Method 5 shall be used at negative-pressure fabric filters and 
other types of control devices and Method 5D shall be used as positive-
pressure fabric filters to determine the particulate matter 
concentration (cs) and the volumetric flow rate 
(Qsd) of the effluent gas. The sampling time and sample 
volume for each run shall be at least 60 minutes and 0.90 dscm (31.8 
dscf).
    (3) The monitoring device of Sec. 60.343(d) shall be used to 
determine the stone feed rate (P) for each run.
    (4) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (c) During the particulate matter run, the owner or operator shall 
use the monitoring devices in Sec. 60.343(c)(1) and (2) to determine the 
average pressure loss of the gas stream through the scrubber and the 
average scrubbing liquid supply pressure.

[54 FR 6675, Feb. 14, 1989]



Subpart KK--Standards of Performance for Lead-Acid Battery Manufacturing 
                                 Plants

    Source: 47 FR 16573, Apr. 16, 1982, unless otherwise noted.



Sec. 60.370  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the affected 
facilities listed in paragraph (b) of this section at any lead-acid 
battery manufacturing plant that produces or has the design capacity to 
produce in one day (24 hours) batteries containing an amount of lead 
equal to or greater than 5.9 Mg (6.5 tons).
    (b) The provisions of this subpart are applicable to the following 
affected facilities used in the manufacture of lead-acid storage 
batteries:
    (1) Grid casting facility.
    (2) Paste mixing facility.
    (3) Three-process operation facility.
    (4) Lead oxide manufacturing facility.
    (5) Lead reclamation facility.
    (6) Other lead-emitting operations.
    (c) Any facility under paragraph (b) of this section the 
construction or modification of which is commenced after January 14, 
1980, is subject to the requirements of this subpart.



Sec. 60.371  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    (a) Grid casting facility means the facility which includes all lead 
melting pots and machines used for casting the grid used in battery 
manufacturing.
    (b) Lead-acid battery manufacturing plant means any plant that 
produces a storage battery using lead and lead compounds for the plates 
and sulfuric acid for the electrolyte.
    (c) Lead oxide manufacturing facility means a facility that produces 
lead oxide from lead, including product recovery.
    (d) Lead reclamation facility means the facility that remelts lead 
scrap and casts it into lead ingots for use in the battery manufacturing 
process, and which is not a furnace affected under subpart L of this 
part.
    (e) Other lead-emitting operation means any lead-acid battery 
manufacturing plant operation from which lead emissions are collected 
and ducted to the atmosphere and which is not part of a grid casting, 
lead oxide manufacturing, lead reclamation, paste mixing, or three-
process operation facility, or a furnace affected under subpart L of 
this part.
    (f) Paste mixing facility means the facility including lead oxide 
storage, conveying, weighing, metering, and charging operations; paste 
blending, handling, and cooling operations; and plate pasting, takeoff, 
cooling, and drying operations.
    (g) Three-process operation facility means the facility including 
those processes involved with plate stacking, burning or strap casting, 
and assembly of elements into the battery case.

[[Page 295]]



Sec. 60.372  Standards for lead.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere:
    (1) From any grid casting facility any gases that contain lead in 
excess of 0.40 milligram of lead per dry standard cubic meter of exhaust 
(0.000176 gr/dscf).
    (2) From any paste mixing facility any gases that contain in excess 
of 1.00 milligram of lead per dry standard cubic meter of exhaust 
(0.00044 gr/dscf).
    (3) From any three-process operation facility any gases that contain 
in excess of 1.00 milligram of lead per dry standard cubic meter of 
exhaust (0.00044 gr/dscf).
    (4) From any lead oxide manufacturing facility any gases that 
contain in excess of 5.0 milligrams of lead per kilogram of lead feed 
(0.010 lb/ton).
    (5) From any lead reclamation facility any gases that contain in 
excess of 4.50 milligrams of lead per dry standard cubic meter of 
exhaust (0.00198 gr/dscf).
    (6) From any other lead-emitting operation any gases that contain in 
excess of 1.00 milligram per dry standard cubic meter of exhaust 
(0.00044 gr/dscf).
    (7) From any affected facility other than a lead reclamation 
facility any gases with greater than 0 percent opacity (measured 
according to Method 9 and rounded to the nearest whole percentage).
    (8) From any lead reclamation facility any gases with greater than 5 
percent opacity (measured according to Method 9 and rounded to the 
nearest whole percentage).
    (b) When two or more facilities at the same plant (except the lead 
oxide manufacturing facility) are ducted to a common control device, an 
equivalent standard for the total exhaust from the commonly controlled 
facilities shall be determined as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.012

Where:
Se=is the equivalent standard for the total exhaust stream.
Sa=is the actual standard for each exhaust stream ducted to 
          the control device.
N=is the total number of exhaust streams ducted to the control device.
Qsda=is the dry standard volumetric flow rate of the effluent 
          gas stream from each facility ducted to the control device.
QsdT=is the total dry standard volumetric flow rate of all 
          effluent gas streams ducted to the control device.



Sec. 60.373  Monitoring of emissions and operations.

    The owner or operator of any lead-acid battery manufacturing 
facility subject to the provisions of this subpart and controlled by a 
scrubbing system(s) shall install, calibrate, maintain, and operate a 
monitoring device(s) that measures and records the pressure drop across 
the scrubbing system(s) at least once every 15 minutes. The monitoring 
device shall have an accuracy of plus-minus5 percent over its 
operating range.



Sec. 60.374  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the lead 
standards in Sec. 60.372, except Sec. 60.372(a)(4), as follows:
    (1) Method 12 shall be used to determine the lead concentration and, 
if applicable, the volumetric flow rate (Qsda) of the 
effluent gas. The sampling time and sample volume for each run shall be 
at least 60 minutes and 0.85 dscm (30 dscf).
    (2) When different operations in a three-process operation facility 
are ducted to separate control devices, the lead emission concentration 
(C) from the facility shall be determined as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.022

where:
C=concentration of lead emissions for the entire facility, mg/dscm (gr/
          dscf).

[[Page 296]]

Ca=concentration of lead emissions from facility ``a'', mg/
          dscm (gr/dscf).
Qsda=volumetric flow rate of effluent gas from facility 
          ``a'', dscm/hr (dscf/hr).
N=total number of control devices to which separate operations in the 
          facility are ducted.

    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity. The opacity numbers shall be rounded off to the 
nearest whole percentage.
    (c) The owner or operator shall determine compliance with the lead 
standard in Sec. 60.372(a)(4) as follows:
    (1) The emission rate (E) from lead oxide manufacturing facility 
shall be computed for each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.023

where:
E=emission rate of lead, mg/kg (lb/ton) of lead charged.
CPbi=concentration of lead from emission point ``i,'' mg/
          dscm.
Qsdi=volumetric flow rate of effluent gas from emission point 
          ``i,'' dscm/hr (sdcf/hr).
M=number of emission points in the affected facility.
P=lead feed rate to the facility, kg/hr (ton/hr).
K=conversion factor, 1.0 mg/mg (453,600 mg/lb).

    (2) Method 12 shall be used to determine the lead concentration 
(CPb) and the volumetric flow rate (Qsd) of the 
effluent gas. The sampling time and sample volume for each run shall be 
at least 60 minutes and 0.85 dscm (30 dscf).
    (3) The average lead feed rate (P) shall be determined for each run 
using the following equation:

P=N W/

where:
N=number of lead pigs (ingots) charged.
W=average mass of a pig, kg (ton).
=duration of run, hr.

[54 FR 6675, Feb. 14, 1989]



  Subpart LL--Standards of Performance for Metallic Mineral Processing 
                                 Plants

    Source: 49 FR 6464, Feb. 21, 1984, unless otherwise noted.



Sec. 60.380  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities in metallic mineral processing plants: Each crusher 
and screen in open-pit mines; each crusher, screen, bucket elevator, 
conveyor belt transfer point, thermal dryer, product packaging station, 
storage bin, enclosed storage area, truck loading station, truck 
unloading station, railcar loading station, and railcar unloading 
station at the mill or concentrator with the following exceptions. All 
facilities located in underground mines are exempted from the provisions 
of this subpart. At uranium ore processing plants, all facilities 
subsequent to and including the beneficiation of uranium ore are 
exempted from the provisions of this subpart.
    (b) An affected facility under paragraph (a) of this section that 
commences construction or modification after August 24, 1982, is subject 
to the requirements of this part.



Sec. 60.381  Definitions.

    All terms used in this subpart, but not specifically defined in this 
section, shall have the meaning given them in the Act and in subpart A 
of this part.
    Bucket elevator means a conveying device for metallic minerals 
consisting of a head and foot assembly that supports and drives an 
endless single or double strand chain or belt to which buckets are 
attached.
    Capture system means the equipment used to capture and transport 
particulate matter generated by one or more affected facilities to a 
control device.
    Control device means the air pollution control equipment used to 
reduce particulate matter emissions released to the atmosphere from one 
or more affected facilities at a metallic mineral processing plant.
    Conveyor belt transfer point means a point in the conveying 
operation where the metallic mineral or metallic mineral concentrate is 
transferred to or from a conveyor belt except where the metallic mineral 
is being transferred to a stockpile.

[[Page 297]]

    Crusher means a machine used to crush any metallic mineral and 
includes feeders or conveyors located immediately below the crushing 
surfaces. Crushers include, but are not limited to, the following types: 
jaw, gyratory, cone, and hammermill.
    Enclosed storage area means any area covered by a roof under which 
metallic minerals are stored prior to further processing or loading.
    Metallic mineral concentrate means a material containing metallic 
compounds in concentrations higher than naturally occurring in ore but 
requiring additional processing if pure metal is to be isolated. A 
metallic mineral concentrate contains at least one of the following 
metals in any of its oxidation states and at a concentration that 
contributes to the concentrate's commercial value: Aluminum, copper, 
gold, iron, lead, molybdenum, silver, titanium, tungsten, uranium, zinc, 
and zirconium. This definition shall not be construed as requiring that 
material containing metallic compounds be refined to a pure metal in 
order for the material to be considered a metallic mineral concentrate 
to be covered by the standards.
    Metallic mineral processing plant means any combination of equipment 
that produces metallic mineral concentrates from ore. Metallic mineral 
processing commences with the mining of ore and includes all operations 
either up to and including the loading of wet or dry concentrates or 
solutions of metallic minerals for transfer to facilities at non-
adjacent locations that will subsequently process metallic concentrates 
into purified metals (or other products), or up to and including all 
material transfer and storage operations that precede the operations 
that produce refined metals (or other products) from metallic mineral 
concentrates at facilities adjacent to the metallic mineral processing 
plant. This definition shall not be construed as requiring that mining 
of ore be conducted in order for the combination of equipment to be 
considered a metallic mineral processing plant. (See also the definition 
of metallic mineral concentrate.)
    Process fugitive emissions means particulate matter emissions from 
an affected facility that are not collected by a capture system.
    Product packaging station means the equipment used to fill 
containers with metallic compounds or metallic mineral concentrates.
    Railcar loading station means that portion of a metallic mineral 
processing plant where metallic minerals or metallic mineral 
concentrates are loaded by a conveying system into railcars.
    Railcar unloading station means that portion of a metallic mineral 
processing plant where metallic ore is unloaded from a railcar into a 
hopper, screen, or crusher.
    Screen means a device for separating material according to size by 
passing undersize material through one or more mesh surfaces (screens) 
in series and retaining oversize material on the mesh surfaces 
(screens).
    Stack emissions means the particulate matter captured and released 
to the atmosphere through a stack, chimney, or flue.
    Storage bin means a facility for storage (including surge bins and 
hoppers) or metallic minerals prior to further processing or loading.
    Surface moisture means water that is not chemically bound to a 
metallic mineral or metallic mineral concentrate.
    Thermal dryer means a unit in which the surface moisture content of 
a metallic mineral or a metallic mineral concentrate is reduced by 
direct or indirect contact with a heated gas stream.
    Truck loading station means that portion of a metallic mineral 
processing plant where metallic minerals or metallic mineral 
concentrates are loaded by a conveying system into trucks.
    Truck unloading station means that portion of a metallic mineral 
processing plant where metallic ore is unloaded from a truck into a 
hopper, screen, or crusher.



Sec. 60.382  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be

[[Page 298]]

discharged into the atmosphere from an affected facility any stack 
emissions that:
    (1) Contain particulate matter in excess of 0.05 grams per dry 
standard cubic meter.
    (2) Exhibit greater than 7 percent opacity, unless the stack 
emissions are discharged from an affected facility using a wet scrubbing 
emission control device.
    (b) On and after the sixtieth day after achieving the maximum 
production rate at which the affected facility will be operated, but not 
later than 180 days after initial startup, no owner or operator subject 
to the provisions of this subpart shall cause to be discharged into the 
atmosphere from an affected facility any process fugitive emissions that 
exhibit greater than 10 percent opacity.



Sec. 60.383  Reconstruction.

    (a) The cost of replacement of ore-contact surfaces on processing 
equipment shall not be considered in calculating either the ``fixed 
capital cost of the new components'' or the ``fixed capital cost that 
would be required to construct a comparable new facility'' under 
Sec. 60.15. Ore-contact surfaces are: Crushing surfaces; screen meshes, 
bars, and plates; conveyor belts; elevator buckets; and pan feeders.
    (b) Under Sec. 60.15, the ``fixed capital cost of the new 
components'' includes the fixed capital cost of all depreciable 
components (except components specified in paragraph (a) of this 
section) that are or will be replaced pursuant to all continuous 
programs of component replacement commenced within any 2-year period 
following August 24, 1982.



Sec. 60.384  Monitoring of operations.

    (a) The owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain, and operate a monitoring device for 
the continuous measurement of the change in pressure of the gas stream 
through the scrubber for any affected facility using a wet scrubbing 
emission control device. The monitoring device must be certified by the 
manufacturer to be accurate within 250 pascals 
(1 inch water) gauge pressure and must be calibrated on an 
annual basis in accordance with manufacturer's instructions.
    (b) The owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain, and operate a monitoring device for 
the continuous measurement of the scrubbing liquid flow rate to a wet 
scrubber for any affected facility using any type of wet scrubbing 
emission control device. The monitoring device must be certified by the 
manufacturer to be accurate within 5 percent of design 
scrubbing liquid flow rate and must be calibrated on at least an annual 
basis in accordance with manufacturer's instructions.



Sec. 60.385  Recordkeeping and reporting requirements.

    (a) The owner or operator subject to the provisions of this subpart 
shall conduct a performance test and submit to the Administrator a 
written report of the results of the test as specified in Sec. 60.8(a).
    (b) During the initial performance test of a wet scrubber, and at 
least weekly thereafter, the owner or operator shall record the 
measurements of both the change in pressure of the gas stream across the 
scrubber and the scrubbing liquid flow rate.
    (c) After the initial performance test of a wet scrubber, the owner 
or operator shall submit semiannual reports to the Administrator of 
occurrences when the measurements of the scrubber pressure loss (or 
gain) and liquid flow rate differ by more than 30 percent 
from the average obtained during the most recent performance test.
    (d) The reports required under paragraph (c) shall be postmarked 
within 30 days following the end of the second and fourth calendar 
quarters.
    (e) The requirements of this subsection remain in force until and 
unless the Agency, in delegating enforcement authority to a State under 
section 111(c) of the Act, approves reporting requirements or an 
alternative means of compliance surveillance adopted by such States. In 
that event, affected sources within the State will be relieved of the 
obligation to comply with this subsection, provided that

[[Page 299]]

they comply with requirements established by the State.

[49 FR 6464, Feb. 21, 1984, as amended at 54 FR 6676, Feb. 14, 1989]



Sec. 60.386  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine complance with the 
particulate matter standards Sec. 60.382 as follows:
    (1) Method 5 or 17 shall be used to determine the particulate matter 
concentration. The sample volume for each run shall be at least 1.70 
dscm (60 dscf). The sampling probe and filter holder of Method 5 may be 
operated without heaters if the gas stream being sampled is at ambient 
temperature. For gas streams above ambient temperature, the Method 5 
sampling train shall be operated with a probe and filter temperature 
slightly above the effluent temperature (up to a maximum filter 
temperature of 121 deg.C (250  deg.F)) in order to prevent water 
condensation on the filter.
    (2) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity from stack emissions and process fugitive emissions. 
The observer shall read opacity only when emissions are clearly 
identified as emanating solely from the affected facility being 
observed.
    (c) To comply with Sec. 60.385(c), the owner or operator shall use 
the monitoring devices in Sec. 60.3284(a) and (b) to determine the 
pressure loss of the gas stream through the scrubber and scrubbing 
liquid flow rate at any time during each particulate matter run, and the 
average of the three determinations shall be computed.

[54 FR 6676, Feb. 14, 1989]



Subpart MM--Standards of Performance for Automobile and Light Duty Truck 
                       Surface Coating Operations

    Source: 45 FR 85415, Dec. 24, 1980, unless otherwise noted.



Sec. 60.390  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to the following affected 
facilities in an automobile or light-duty truck assembly plant: each 
prime coat operation, each guide coat operation, and each topcoat 
operation.
    (b) Exempted from the provisions of this subpart are operations used 
to coat plastic body components or all-plastic automobile or light-duty 
truck bodies on separate coating lines. The attachment of plastic body 
parts to a metal body before the body is coated does not cause the metal 
body coating operation to be exempted.
    (c) The provisions of this subpart apply to any affected facility 
identified in paragraph (a) of this section that begins construction, 
reconstruction, or modification after October 5, 1979.



Sec. 60.391  Definitions.

    (a) All terms used in this subpart that are not defined below have 
the meaning given to them in the Act and in subpart A of this part.
    Applied coating solids means the volume of dried or cured coating 
solids which is deposited and remains on the surface of the automobile 
or light-duty truck body.
    Automobile means a motor vehicle capable of carrying no more than 12 
passengers.
    Automobile and light-duty truck body means the exterior surface of 
an automobile or light-duty truck including hoods, fenders, cargo boxes, 
doors, and grill opening panels.
    Bake oven means a device that uses heat to dry or cure coatings.
    Electrodeposition (EDP) means a method of applying a prime coat by 
which the automobile or light-duty truck body is submerged in a tank 
filled with coating material and an electrical field is used to effect 
the deposition of the coating material on the body.
    Electrostatic spray application means a spray application method 
that uses an electrical potential to increase the transfer efficiency of 
the coating solids. Electrostatic spray application can be used for 
prime coat, guide coat, or topcoat operations.

[[Page 300]]

    Flash-off area means the structure on automobile and light-duty 
truck assembly lines between the coating application system (dip tank or 
spray booth) and the bake oven.
    Guide coat operation means the guide coat spray booth, flash-off 
area and bake oven(s) which are used to apply and dry or cure a surface 
coating between the prime coat and topcoat operation on the components 
of automobile and light-duty truck bodies.
    Light-duty truck means any motor vehicle rated at 3,850 kilograms 
gross vehicle weight or less, designed mainly to transport property.
    Plastic body means an automobile or light-duty truck body 
constructed of synthetic organic material.
    Plastic body component means any component of an automobile or 
light-duty truck exterior surface constructed of synthetic organic 
material.
    Prime coat operation means the prime coat spray booth or dip tank, 
flash-off area, and bake oven(s) which are used to apply and dry or cure 
the initial coating on components of automobile or light-duty truck 
bodies.
    Purge or line purge means the coating material expelled from the 
spray system when clearing it.
    Solids Turnover Ratio (RT) means the ratio of total 
volume of coating solids that is added to the EDP system in a calendar 
month divided by the total volume design capacity of the EDP system.
    Solvent-borne means a coating which contains five percent or less 
water by weight in its volatile fraction.
    Spray application means a method of applying coatings by atomizing 
the coating material and directing the atomized material toward the part 
to be coated. Spray applications can be used for prime coat, guide coat, 
and topcoat operations.
    Spray booth means a structure housing automatic or manual spray 
application equipment where prime coat, guide coat, or topcoat is 
applied to components of automobile or light-duty truck bodies.
    Surface coating operation means any prime coat, guide coat, or 
topcoat operation on an automobile or light-duty truck surface coating 
line.
    Topcoat operation means the topcoat spray booth, flash-off area, and 
bake oven(s) which are used to apply and dry or cure the final 
coating(s) on components of automobile and light-duty truck bodies.
    Transfer efficiency means the ratio of the amount of coating solids 
transferred onto the surface of a part or product to the total amount of 
coating solids used.
    VOC content means all volatile organic compounds that are in a 
coating expressed as kilograms of VOC per liter of coating solids.
    Volume Design Capacity of EDP System (LE) means the total liquid 
volume that is contained in the EDP system (tank, pumps, recirculating 
lines, filters, etc.) at its designed liquid operating level.
    Waterborne or water reducible means a coating which contains more 
than five weight percent water in its volatile fraction.
    (b) The nomenclature used in this subpart has the following 
meanings:

Caj=concentration of VOC (as carbon) in the effluent gas 
flowing through stack (j) leaving the control device (parts per million 
by volume),
Cbi=concentration of VOC (as carbon) in the effluent gas 
flowing through stack (i) entering the control device (parts per million 
by volume),
Cfk=concentration of VOC (as carbon) in the effluent gas 
flowing through exhaust stack (k) not entering the control device (parts 
per million by volume),
Dci=density of each coating (i) as received (kilograms per 
liter),
Ddj=density of each type VOC dilution solvent (j) added to 
the coatings, as received (kilograms per liter),
Dr=density of VOC recovered from an affected facility 
(kilograms per liter),
E=VOC destruction efficiency of the control device,
F=fraction of total VOC which is emitted by an affected facility that 
enters the control device,
G=volume weighted average mass of VOC per volume of applied solids 
(kilograms per liter),
Lci=volume of each coating (i) consumed, as received 
(liters),
Lcill=volume of each coating (i) consumed by each application 
method (l), as received liters),
Ldj=volume of each type VOC dilution solvent (j) added to the 
coatings, as received (liters),

[[Page 301]]

Lr=volume of VOC recovered from an affected facility 
(liters),
Ls=volume of solids in coatings consumed (liters),
LE=the total volume of the EDP system (liters),
Md=total mass of VOC in dilution solvent (kilograms),
M0=total mass of VOC in coatings as received (kilograms),
Mr=total mass of VOC recovered from an affected facility 
(kilograms),
N=volume weighted average mass of VOC per volume of applied coating 
solids after the control device
[GRAPHIC] [TIFF OMITTED] TC16NO91.024

Qaj=volumetric flow rate of the effluent gas flowing through 
stack (j) leaving the control device (dry standard cubic meters per 
hour),
Qbi=volumetric flow rate of the effluent gas flowing through 
stack (i) entering the control device (dry standard cubic meters per 
hour),
Qfk=volumetric flow rate of the effluent gas flowing through 
exhaust stack (k) not entering the control device (dry standard cubic 
meters per hour),
T=overall transfer efficiency,
Tl=transfer efficiency for application method (l),
Vsi=proportion of solids by volume in each coating (i) as 
received
[GRAPHIC] [TIFF OMITTED] TC16NO91.025

Woi=proportion of VOC by weight in each coating (i), as 
received
[GRAPHIC] [TIFF OMITTED] TC16NO91.026


[45 FR 85415, Dec. 24, 1980, as amended at 59 FR 51386, Oct. 11, 1994]



Sec. 60.392  Standards for volatile organic compounds

    On and after the date on which the initial performance test required 
by Sec. 60.8 is completed, no owner or operator subject to the 
provisions of this subpart shall discharge or cause the discharge into 
the atmosphere from any affected facility VOC emissions in excess of:
    (a) Prime Coat Operation. (1) For each EDP prime coat operation:
    (i) 0.17 kilogram of VOC per liter of applied coating solids when 
RT is 0.16 or greater.
    (ii) 0.17 x 350 (0.160-RT) kg of VOC per liter 
of applied coating solids when RT is greater than or equal to 
0.040 and less than 0.160.
    (iii) When RT is less than 0.040, there is no emission 
limit.
    (2) For each nonelectrodeposition prime coat operation: 0.17 
kilogram of VOC per liter of applied coating solids.
    (b) 1.40 kilograms of VOC per liter of applied coating solids from 
each guide coat operation.
    (c) 1.47 kilograms of VOC per liter of applied coating solids from 
each topcoat operation.

[45 FR 85415, Dec. 24, 1980, as amended at 59 FR 51386, Oct. 11, 1994]



Sec. 60.393  Performance test and compliance provisions.

    (a) Section 60.8 (d) and (f) do not apply to the performance test 
procedures required by this section.
    (b) The owner or operator of an affected facility shall conduct an 
initial performance test in accordance with Sec. 60.8(a) and thereafter 
for each calendar month for each affected facility according to the 
procedures in this section.
    (c) The owner or operator shall use the following procedures for 
determining the monthly volume weighted average mass of VOC emitted per 
volume of applied coating solids.
    (1) The owner or operator shall use the following procedures for 
each affected facility which does not use a capture system and a control 
device to comply with the applicable emission limit specified under 
Sec. 60.392.
    (i) Calculate the volume weighted average mass of VOC per volume of 
applied coating solids for each calendar month for each affected 
facility. The owner or operator shall determine the composition of the 
coatings by formulation data supplied by the manufacturer of the coating 
or from data determined by an analysis of each coating, as received, by 
Reference Method 24. The Administrator may require the owner or operator 
who uses formulation data supplied by the manufacturer of the coating to 
determine data used in the calculation of the VOC content

[[Page 302]]

of coatings by Reference Method 24 or an equivalent or alternative 
method. The owner or operator shall determine from company records on a 
monthly basis the volume of coating consumed, as received, and the mass 
of solvent used for thinning purposes. The volume weighted average of 
the total mass of VOC per volume of coating solids used each calendar 
month will be determined by the following procedures.
    (A) Calculate the mass of VOC used in each calendar month for each 
affected facility by the following equation where ``n'' is the total 
number of coatings used and ``m'' is the total number of VOC solvents 
used:
[GRAPHIC] [TIFF OMITTED] TC16NO91.027


[LdjDdj will be zero if no VOC solvent is 
added to the coatings, as received].
    (B) Calculate the total volume of coating solids used in each 
calendar month for each affected facility by the following equation 
where ``n'' is the total number of coatings used:
[GRAPHIC] [TIFF OMITTED] TC16NO91.028

    (C) Select the appropriate transfer efficiency (T) from the 
following tables for each surface coating operation:

------------------------------------------------------------------------
                                                               Transfer
                     Application method                       efficiency
------------------------------------------------------------------------
Air Atomized Spray (waterborne coating).....................        0.39
Air Atomized Spray (solvent-borne coating)..................        0.50
Manual Electrostatic Spray..................................        0.75
Automatic Electrostatic Spray...............................        0.95
Electrodeposition...........................................        1.00
------------------------------------------------------------------------


The values in the table above represent an overall system efficiency 
which includes a total capture of purge. If a spray system uses line 
purging after each vehicle and does not collect any of the purge 
material, the following table shall be used:

------------------------------------------------------------------------
                                                               Transfer
                     Application method                       efficiency
------------------------------------------------------------------------
Air Atomized Spray (waterborne coating).....................        0.30
Air Atomized Spray (solvent-borne coating)..................        0.40
Manual Electrostatic Spray..................................        0.62
Automatic Electrostatic Spray...............................        0.75
------------------------------------------------------------------------


If the owner or operator can justify to the Administrator's satisfaction 
that other values for transfer efficiencies are appropriate, the 
Administrator will approve their use on a case-by-case basis.
    (1) When more than one application method (l) is used on an 
individual surface coating operation, the owner or operator shall 
perform an analysis to determine an average transfer efficiency by the 
following equation where ``n'' is the total number of coatings used and 
``p'' is the total number of application methods:
[GRAPHIC] [TIFF OMITTED] TC16NO91.029

    (D) Calculate the volume weighted average mass of VOC per volume of 
applied coating solids (G) during each calendar month for each affected 
facility by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.030

    (E) For each EDP prime coat operation, calculate the turnover ratio 
(RT) by the following equation:
[GRAPHIC] [TIFF OMITTED] TR11OC94.000


Then calculate or select the appropriate limit according to 
Sec. 60.392(a).
    (ii) If the volume weighted average mass of VOC per volume of 
applied coating solids (G), calculated on a calendar month basis, is 
less than or equal to the applicable emission limit specified in 
Sec. 60.392, the affected facility is in

[[Page 303]]

compliance. Each monthly calculation is a performance test for the 
purpose of this subpart.
    (2) The owner or operator shall use the following procedures for 
each affected facility which uses a capture system and a control device 
that destroys VOC (e.g., incinerator) to comply with the applicable 
emission limit specified under Sec. 60.392.
    (i) Calculate the volume weighted average mass of VOC per volume of 
applied coating solids (G) during each calendar month for each affected 
facility as described under Sec. 60.393(c)(1)(i).
    (ii) Calculate the volume weighted average mass of VOC per volume of 
applied solids emitted after the control device, by the following 
equation: N=G[1-FE]
    (A) Determine the fraction of total VOC which is emitted by an 
affected facility that enters the control device by using the following 
equation where ``n'' is the total number of stacks entering the control 
device and ``p'' is the total number of stacks not connected to the 
control device:
[GRAPHIC] [TIFF OMITTED] TC01JN92.013


If the owner can justify to the Administrator's satisfaction that 
another method will give comparable results, the Administrator will 
approve its use on a case-by-case basis.
    (1) In subsequent months, the owner or operator shall use the most 
recently determined capture fraction for the performance test.
    (B) Determines the destruction efficiency of the control device 
using values of the volumetric flow rate of the gas streams and the VOC 
content (as carbon) of each of the gas streams in and out of the device 
by the following equation where ``n'' is the total number of stacks 
entering the control device and ``m'' is the total number of stacks 
leaving the control device:
[GRAPHIC] [TIFF OMITTED] TC01JN92.014

    (1) In subsequent months, the owner or operator shall use the most 
recently determined VOC destruction efficiency for the performance test.
    (C) If an emission control device controls the emissions from more 
than one affected facility, the owner or operator shall measure the VOC 
concentration (Cbi) in the effluent gas entering the control 
device (in parts per million by volume) and the volumetric flow rate 
(Qbi) of the effluent gas (in dry standard cubic meters per 
hour) entering the device through each stack. The destruction or removal 
efficiency determined using these data shall be applied to each affected 
facility served by the control device.
    (iii) If the volume weighted average mass of VOC per volume of 
applied solids emitted after the control device (N) calculated on a 
calendar month basis is less than or equal to the applicable emission 
limit specified in Sec. 60.392, the affected facility is in compliance. 
Each monthly calculation is a performance test for the purposes of this 
subpart.
    (3) The owner or operator shall use the following procedures for 
each affected facility which uses a capture system and a control device 
that recovers the VOC (e.g., carbon adsorber) to comply with the 
applicable emission limit specified under Sec. 60.392.
    (i) Calculate the mass of VOC (Mo+Md) used 
during each calendar month for each affected facility as described under 
Sec. 60.393(c)(1)(i).
    (ii) Calculate the total volume of coating solids (Ls) 
used in each calendar month for each affected facility as described 
under Sec. 60.393(c)(1)(i).
    (iii) Calculate the mass of VOC recovered (Mr) each 
calendar month for each affected facility by the following equation: 
Mr=Lr Dr
    (iv) Calculate the volume weighted average mass of VOC per 
volume of applied coating solids emitted after the

[[Page 304]]

control device during a calendar month by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.031

    (v) If the volume weighted average mass of VOC per volume of applied 
solids emitted after the control device (N) calculated on a calendar 
month basis is less than or equal to the applicable emission limit 
specified in Sec. 60.392, the affected facility is in compliance. Each 
monthly calculation is a performance test for the purposes of this 
subpart.

[45 FR 85415, Dec. 24, 1980, as amended at 59 FR 51387, Oct. 11, 1994]



Sec. 60.394  Monitoring of emissions and operations.

    The owner or operator of an affected facility which uses an 
incinerator to comply with the emission limits specified under 
Sec. 60.392 shall install, calibrate, maintain, and operate temperature 
measurement devices as prescribed below:
    (a) Where thermal incineration is used, a temperature measurement 
device shall be installed in the firebox. Where catalytic incineration 
is used, a temperature measurement device shall be installed in the gas 
stream immediately before and after the catalyst bed.
    (b) Each temperature measurement device shall be installed, 
calibrated, and maintained according to accepted practice and the 
manufacturer's specifications. The device shall have an accuracy of the 
greater of plus-minus0.75 percent of the temperature being 
measured expressed in degrees Celsius or plus-minus2.5 
deg.C.
    (c) Each temperature measurement device shall be equipped with a 
recording device so that a permanent record is produced.



Sec. 60.395  Reporting and recordkeeping requirements.

    (a) Each owner or operator of an affected facility shall include the 
data outlined in paragraphs (a)(1) and (2) in the initial compliance 
report required by Sec. 60.8.
    (1) The owner or operator shall report the volume weighted average 
mass of VOC per volume of applied coating solids for each affected 
facility.
    (2) Where compliance is achieved through the use of incineration, 
the owner or operator shall include the following additional data in the 
control device initial performance test requried by Sec. 60.8(a) or 
subsequent performance tests at which destruction efficiency is 
determined: the combustion temperature (or the gas temperature upstream 
and downstream of the catalyst bed), the total mass of VOC per volume of 
applied coating solids before and after the incinerator, capture 
efficiency, the destruction efficiency of the incinerator used to attain 
compliance with the applicable emission limit specified in Sec. 60.392 
and a description of the method used to establish the fraction of VOC 
captured and sent to the control device.
    (b) Following the initial performance test, the owner or operator of 
an affected facility shall identify, record, and submit a written report 
to the Administrator every calendar quarter of each instance in which 
the volume-weighted average of the total mass of VOC's emitted to the 
atmosphere per volume of applied coating solids (N) is greater than the 
limit specified under Sec. 60.392. If no such instances have occurred 
during a particular quarter, a report stating this shall be submitted to 
the Administrator semiannually. Where compliance is achieved through the 
use of a capture system and control device, the volume-weighted average 
after the control device should be reported.
    (c) Where compliance with Sec. 60.392 is achieved through the use of 
incineration, the owner or operator shall continuously record the 
incinerator combustion temperature during coating operations for thermal 
incineration or the gas temperature upstream and downstream of the 
incinerator catalyst bed during coating operations for catalytic 
incineration. The owner or operator shall submit a written report at the 
frequency specified in Sec. 60.7(c) and as defined below.
    (1) For thermal incinerators, every three-hour period shall be 
reported during which the average temperature measured is more than 28 
deg.C less than the average temperature during the

[[Page 305]]

most recent control device performance test at which the destruction 
efficiency was determined as specified under Sec. 60.393.
    (2) For catalytic incinerators, every three-hour period shall be 
reported during which the average temperature immediately before the 
catalyst bed, when the coating system is operational, is more than 28 
deg.C less than the average temperature immediately before the catalyst 
bed during the most recent control device performance test at which 
destruction efficiency was determined as specified under Sec. 60.393. In 
addition, every three-hour period shall be reported each quarter during 
which the average temperature difference across the catalyst bed when 
the coating system is operational is less than 80 percent of the average 
temperature difference of the device during the most recent control 
device performance test at which destruction efficiency was determined 
as specified under Sec. 60.393.
    (3) For thermal and catalytic incinerators, if no such periods 
occur, the owner or operator shall submit a negative report.
    (d) The owner or operator shall notify the Administrator 30 days in 
advance of any test by Reference Method 25.

[45 FR 85415, Dec. 24, 1980, as amended at 55 FR 51383, Dec. 13, 1990]



Sec. 60.396  Reference methods and procedures.

    (a) The reference methods in appendix A to this part, except as 
provided in Sec. 60.8 shall be used to conduct performance tests.
    (1) Reference Method 24 or an equivalent or alternative method 
approved by the Administrator shall be used for the determination of the 
data used in the calculation of the VOC content of the coatings used for 
each affected facility. Manufacturers' formulation data is approved by 
the Administrator as an alternative method to Method 24. In the event of 
dispute, Reference Method 24 shall be the referee method.
    (2) Reference Method 25 or an equivalent or alternative method 
approved by the Administrator shall be used for the determination of the 
VOC concentration in the effluent gas entering and leaving the emission 
control device for each stack equipped with an emission control device 
and in the effluent gas leaving each stack not equipped with a control 
device.
    (3) The following methods shall be used to determine the volumetric 
flow rate in the effluent gas in a stack:
    (i) Method 1 for sample and velocity traverses,
    (ii) Method 2 for velocity and volumetric flow rate,
    (iii) Method 3 for gas analysis, and
    (iv) Method 4 for stack gas moisture.
    (b) For Reference Method 24, the coating sample must be a 1-liter 
sample taken in a 1-liter container.
    (c) For Reference Method 25, the sampling time for each of three 
runs must be at least one hour. The minimum sample volume must be 0.003 
dscm except that shorter sampling times or smaller volumes, when 
necessitated by process variables or other factors, may be approved by 
the Administrator. The Administrator will approve the sampling of 
representative stacks on a case-by-case basis if the owner or operator 
can demonstrate to the satisfaction of the Administrator that the 
testing of representative stacks would yield results comparable to those 
that would be obtained by testing all stacks.



Sec. 60.397  Modifications.

    The following physical or operational changes are not, by 
themselves, considered modifications of existing facilities:
    (a) Changes as a result of model year changeovers or switches to 
larger cars.
    (b) Changes in the application of the coatings to increase coating 
film thickness.



Sec. 60.398  Innovative technology      waivers.

    (a) General Motors Corporation, Wentzville, Missouri, automobile 
assembly plant. (1) Pursuant to section 111(j) of the Clean Air Act, 42 
U.S.C. 7411(j), each topcoat operation at General Motors Corporation 
automobile assembly plant located in Wentzville, Missouri, shall comply 
with the following conditions:
    (i) The General Motors Corporation shall obtain the necessary 
permits as

[[Page 306]]

required by section 173 of the Clean Air Act, as amended August 1977, to 
operate the Wentzville assembly plant.
    (ii) Commencing on February 4, 1983, and continuing to December 31, 
1986, or until the base coat/clear coat topcoat system that can achieve 
the standard specified in 40 CFR 60.392(c) (Dec. 24, 1980) is 
demonstrated to the Administrator's satisfaction the General Motors 
Corporation shall limit the discharge of VOC emissions to the atmosphere 
from each topcoat operation at the Wentzville, Missouri, assembly plant, 
to either:
    (A) 1.9 kilograms of VOC per liter of applied coating solids from 
base coat/clear coat topcoats, and 1.47 kilograms of VOC per liter of 
applied coating solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (a)(1)(ii) of this section, and continuing 
thereafter, emissions of VOC from each topcoat operations shall not 
exceed 1.47 kilograms of VOC per liter of applied coating solids as 
specified in 40 CFR 60.392(c) (Dec. 24, 1980).
    (iv) Each topcoat operation shall comply with the provisions of 
Secs. 60.393, 60.394, 60.395, 60.396, and 60.397. Separate calculations 
shall be made for base coat/clear coat coatings and all other topcoat 
coatings when necessary to demonstrate compliance with the emission 
limits in paragraph (a)(1)(ii)(A) of this section.
    (v) A technology development report shall be sent to EPA Region VII, 
324 East 11th Street, Kansas City, MO 64106, postmarked before 60 days 
after the promulgation of this waiver and annually thereafter while this 
waiver is in effect. The technology development report shall summarize 
the base coat/clear coat development work including the results of 
exposure and endurance tests of the various coatings being evaluated. 
The report shall include an updated schedule of attainment of 40 CFR 
60.392(c) (Dec. 24, 1980) based on the most current information.
    (2) This waiver shall be a federally promulgated standard of 
performance. As such, it shall be unlawful for General Motors 
Corporation to operate a topcoat operation in violation of the 
requirements established in this waiver. Violation of the terms and 
conditions of this waiver shall subject the General Motors Corporation 
to enforcement under section 113 (b) and (c), 42 U.S.C. 7412 (b) and 
(c), and section 120, 42 U.S.C. 7420, of the Act as well as possible 
citizen enforcement under section 304 of the Act, 42 U.S.C. 7604.
    (b) General Motors Corporation, Detroit, Michigan, Automobile 
Assembly plant. (1) Pursuant to section 111(j) of the Clean Air Act, 42 
U.S.C. 7411(j), each topcoat operation at General Motors Corporation's 
automobile assembly plant located in Detroit, MI, shall comply with the 
following conditions:
    (i) The General Motors Corporation shall obtain the necessary 
permits as required by section 173 of the Clean Air Act, as amended 
August 1977, to operate the Detroit assembly plant.
    (ii) Commencing on February 4, 1983, and continuing to December 31, 
1986, or until the base coat/clear coat topcoat system that can achieve 
the standard specified in 40 CFR 60.392(c) (Dec. 24, 1980), is 
demonstrated to the Administrator's satisfaction, the General Motors 
Corporation shall limit the discharge of VOC emissions to the atmosphere 
from each topcoat operation at the Detroit, MI, assembly plant, to 
either:
    (A) 1.9 kilograms of VOC per liter of applied coating solids from 
base coat/clear coat topcoats, and 1.47 kilograms of VOC per liter of 
applied coating solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (b)(ii) of this section, and continuing 
thereafter, emissions of VOC from each topcoat operation shall not 
exceed 1.47 kilograms of VOC per liter of applied coating solids as 
specified in 40 CFR 60.392(c) (December 24, 1980).
    (iv) Each topcoat operation shall comply with the provisions of 
Secs. 60.393, 60.394, 60.395, 60.396, and 60.397. Separate calculations 
shall be made for base coat/clear coat coatings and all other topcoat 
coatings when necessary to

[[Page 307]]

demonstrate compliance with the emission limits in paragraph 
(b)(1)(ii)(A) of this section.
    (v) A technology development report shall be sent to EPA Region V, 
230 South Dearborn Street, Chicago, IL 60604, postmarked before 60 days 
after the promulgation of this waiver and annually thereafter while this 
waiver is in effect. The technology development report shall summarize 
the base coat/clear coat development work including the results of 
exposure and endurance tests of the various coatings being evaluated. 
The report shall include an updated schedule of attainment of 40 CFR 
60.392(c) (Dec. 24, 1980) based on the most current information.
    (2) This waiver shall be a federally promulgated standard of 
performance. As such, it shall be unlawful for General Motors 
Corporation to operate a topcoat operation in violation of the 
requirements established in this waiver. Violation of the terms and 
conditions of this waiver shall subject the General Motors Corporation 
to enforcement under section 113 (b) and (c), 42 U.S.C. 7412 (b) and 
(c), and section 120, 42 U.S.C. 7420, of the Act as well as possible 
citizen enforcement under section 304 of the Act, 42 U.S.C. 7604.
    (c) General Motors Corporation, Orion Township, MI, automobile 
assembly plant. (1) Pursuant to section 111(j) of the Clean Air Act, 42 
U.S.C. 7411(j), each topcoat operation at General Motors Corporation 
automobile assembly plant located in Orion Township, MI, shall comply 
with the following conditions:
    (i) The General Motors Corporation shall obtain the necessary 
permits as required by section 173 of the Clean Air Act, as amended 
August 1977, to operate the Orion Township assembly plant.
    (ii) Commencing on February 4, 1983, and continuing to December 31, 
1986, or until the base coat/clear coat topcoat system that can achieve 
the standard specified in 40 CFR 60.392(c) (Dec. 24, 1980) is 
demonstrated to the Administrator's satisfaction, the General Motors 
Corporation shall limit the discharge of VOC emissions to the atmosphere 
from each topcoat operation at the Orion Township, MI, assembly plant, 
to either:
    (A) 1.9 kilograms of VOC per liter of applied coating solids from 
base coat/clear coat topcoats, and 1.47 kilograms of VOC per liter of 
applied coating solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (c)(l)(ii) of this section and continuing 
thereafter, emissions of VOC from each topcoat operation shall not 
exceed 1.47 kilograms of VOC per liter of applied coating solids as 
specified in 40 CFR 60.392(c) (Dec. 24, 1980).
    (iv) Each topcoat operation shall comply with the provisions of 
Secs. 60.393, 60.394, 60.395, 60.396, and 60.397. Separate calculations 
shall be made for base coat/clear coat coatings and all other topcoat 
coatings when necessary to demonstrate compliance with the emission 
limits in paragraph (c)(l) (ii)(A) of this section.
    (v) A technology development report shall be sent to EPA Region V, 
230 South Dearborn Street, Chicago, IL 60604, postmarked before 60 days 
after the promulgation of this waiver and annually thereafter while this 
waiver is in effect. The technology development report shall summarize 
the base coat/clear coat development work including the results of 
exposure and endurance tests of the various coatings being evaluated. 
The report shall include an updated schedule of attainment of 40 CFR 
60.392(c) (December 24, 1980) based on the most current information.
    (2) This waiver shall be a federally promulgated standard of 
performance. As such, it shall be unlawful for General Motors 
Corporation to operate a topcoat operation in violation of the 
requirements established in this waiver. Violation of the terms and 
conditions of this waiver shall subject the General Motors Corporation 
to enforcement under section 113 (b) and (c), 42 U.S.C. 7412 (b) and 
(c), and section 120, 42 U.S.C. 7420, of the Act as well as possible 
citizen enforcement under section 304 of the Act, 42 U.S.C. 7604.
    (d) Honda of America Manufacturing, Incorporated (Honda), 
Marysville, Ohio, automobile assembly plant. (1) Pursuant to section 
111(j) of the Clean Air Act, 42

[[Page 308]]

U.S.C. 7411(j), each topcoat operation at Honda's automobile assembly 
plant located in Marysville, OH, shall comply with the following 
conditions:
    (i) Honda shall obtain the necessary permits as required by section 
173 of the Clean Air Act, as amended August 1977, to operate the 
Marysville assembly plant.
    (ii) Commencing on February 4, 1983, and continuing for 4 years or 
to December 31, 1986, whichever is sooner, or until the base coat/clear 
coat topcoat system that can achieve the standard specified in 40 CFR 
60.392(c) (Dec. 24, 1980) is demonstrated to the Administrator's 
satisfaction, Honda shall limit the discharge of VOC emissions to the 
atmosphere from each topcoat operation at Marysville, OH, assembly 
plant, to either:
    (A) 3.1 kilograms of VOC per liter of applied coating solids from 
base coat/clear coat topcoats, and 1.47 kilograms of VOC per liter of 
applied coating solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (d)(1)(ii) of this section and continuing 
thereafter, emissions of VOC from each topcoat operation shall not 
exceed 1.47 kilograms of VOC per liter of applied coating solids as 
specified in 40 CFR 60.392(c) (December 24, 1980).
    (iv) Each topcoat operation shall comply with the provisions of 
Secs. 60.393, 60.394, 60.395, 60.396, and 60.397. Separate calculations 
shall be made for base coat/clear coat coatings and all other topcoat 
coatings when necessary to demonstrate compliance with the emission 
limits in paragraph (d)(1)(ii)(A) of this section.
    (v) A technology development report shall be sent to EPA Region V, 
230 South Dearborn Street, Chicago, IL 60604, postmarked before 60 days 
after the promulgation of this waiver and annually thereafter while this 
waiver is in effect. The technology development report shall summarize 
the base coat/clear coat development work including the results of 
exposure and endurance tests of the various coatings being evaluated. 
The report shall include an updated schedule of attainment of 40 CFR 
60.392(c) (Dec. 24, 1980) based on the most current information.
    (2) This waiver shall be a federally promulgated standard of 
performance. As such, it shall be unlawful for Honda to operate a 
topcoat operation in violation of the requirements established in this 
waiver. Violation of the terms and conditions of this waiver shall 
subject Honda to enforcement under section 113(b) and (c), 42 U.S.C. 
7412(b) and (c), and section 120, 42 U.S.C. 7420, of the Act as well as 
possible citizen enforcement under section 304 of the Act, 42 U.S.C. 
7604.
    (e) Nissan Motor Manufacturing Corporation, U.S.A. (Nissan), Smyrna, 
TN, light-duty truck assembly plant. (1) Pursuant to section 111(j) of 
the Clean Air Act, 42 U.S.C. 7411(j), each topcoat operation at Nissan's 
light-duty truck assembly plant located in Smyrna, Tennessee, shall 
comply with the following conditions:
    (i) Nissan shall obtain the necessary permits as required by section 
173 of the Clean Air Act, as amended August 1977, to operate the Smyrna 
assembly plant.
    (ii) Commencing on February 4, 1983, and continuing for 4 years or 
to December 31, 1986, whichever is sooner, or until the base coat/clear 
coat topcoat system that can achieve the standard specified in 40 CFR 
60.392(c) (Dec. 24, 1980), is demonstrated to the Administrator's 
satisfaction, Nissan shall limit the discharge of VOC emissions to the 
atmosphere from each topcoat operation at the Smyrna, TN, assembly 
plant, to either:
    (A) 2.3 kilograms of VOC per liter of applied coating solids from 
base coat/clear coat topcoats, and 1.47 kilograms of VOC per liter of 
applied coating solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (e)(1)(ii) of this section and continuing 
thereafter, emissions of VOC from each topcoat operation shall not 
exceed 1.47 kilograms of VOC per liter of applied coating solids as 
specified in 40 CFR 60.392(c) (Dec. 24, 1980).

[[Page 309]]


Each topcoat operation shall comply with the provisions of Secs. 60.393, 
60.394, 60.395, 60.396, and 60.397. Separate calculations shall be made 
for base coat/clear coat coatings and all other topcoat coatings when 
necessary to demonstrate compliance with the emission limits in 
paragraph (e)(1)(ii)(A) of this section.
    (f) Chrysler Corporation, Sterling Heights, MI, automobile assembly 
plant. (1) Pursuant to section 111(j) of the Clean Air Act, 42 U.S.C. 
7411(j), each topcoat operation at Chrysler Corporation's automobile 
assembly plant located in Sterling Heights, MI, shall comply with the 
following conditions:
    (i) The Chrysler Corporation shall obtain the necessary permits as 
required under Parts C and D of the Clean Air Act, as amended August 
1977, to operate the Sterling Heights assembly plant.
    (ii) Commencing on September 9, 1985, and continuing to December 31, 
1986, or until the basecoat/clearcoat (BC/CC) topcoat system that can 
achieve the standard specified under Sec. 60.392(c) of this subpart is 
demonstrated to the Administrator's satisfaction, whichever is sooner, 
the Chrysler Corporation shall limit the discharge of VOC emissions to 
the atmosphere from each topcoat operation at the Sterling Heights, MI 
assembly plant, to either:
    (A) 1.7 kilograms of VOC per liter of applied coating solids from 
BC/CC topcoats, and 1.47 kilograms of VOC per liter of applied coating 
solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (f)(1)(ii) and continuing thereafter, emissions 
of VOC's from each topcoat operation shall not exceed 1.47 kilograms of 
VOC per liter of applied coating solids as specified under 
Sec. 60.392(c) of this subpart.
    (iv) Each topcoat operation shall comply with the provisions of 
Secs. 60.393, 60.394, 60.395, 60.396, and 60.397. Separate calculations 
shall be made for BC/CC coatings and all other topcoat coatings when 
necessary to demonstrate compliance with the emission limits specified 
under paragraph (f)(1)(ii)(A) of this section.
    (v) A technology development report shall be sent to EPA Region V, 
230 South Dearborn Street, Chicago, IL 60604, postmarked before 60 days 
after the promulgation of this waiver and annually thereafter while this 
waiver is in effect. A copy of this report shall be sent to Director, 
Emission Standards and Engineering Division, U.S. Environmental 
Protection Agency, MD-13, Research Triangle Park, NC 27711. The 
technology development report shall summarize the BC/CC development work 
including the results of exposure and endurance tests of the various 
coatings being evaluated. The report shall include an updated schedule 
of attainment of Sec. 60.392(c) of this subpart, based on the most 
current information.
    (2) This waiver shall be a federally promulgated standard of 
performance. As such, it shall be unlawful for the Chrysler Corporation 
to operate a topcoat operation in violation of the requirements 
established in this waiver. Violation of the terms and conditions of 
this waiver shall subject the Chrysler Corporation to enforcement under 
sections 113 (b) and (c) of the Act (42 U.S.C. 7412 (b) and (c)) and 
under section 120 of the Act (42 U.S.C. 7420), as well as possible 
citizen enforcement under section 304 of the Act (42 U.S.C. 7604).
    (3) This waiver shall not be construed to constrain the State of 
Michigan from imposing upon the Chrysler Corporation any emission 
reduction requirement at Chrysler's Sterling Heights automobile assembly 
plant necessary for the maintenance of reasonable further progress or 
the attainment of the national ambient air quality standard for ozone or 
the maintenance of the national ambient air quality standard for ozone. 
Furthermore, this waiver shall not be construed as granting any 
exemptions from the applicability, enforcement, or other provisions of 
any other standards that apply or may apply to topcoat operations or any 
other operations at this automobile assembly plant.
    (g) Ford Motor Company, Hapeville, GA, automotive assemply plant. 
(1) Pursuant to section 111(j) of the Clean Air

[[Page 310]]

Act, 42 U.S.C. 7411(j), each topcoat operation at Ford Motor Company's 
automobile assembly plant located in Hapeville, GA, shall comply with 
the following conditions:
    (i) The Ford Motor Company shall obtain the necessary permits as 
required under parts C and D of the Clean Air Act, as amended August 
1977, to operate the Hapeville assembly plant.
    (ii) Commencing on September 9, 1985, and continuing to December 31, 
1986, or until the basecoat/clearcoat (BC/CC) topcoat system that can 
achieve the standard specified under Sec. 60.392(c) of this subpart is 
demonstrated to the Administrator's satisfaction, whichever is sooner, 
the Ford Motor Company shall limit the discharge of VOC emissions to the 
atmosphere from each topcoat operation at the Hapeville, GA, assembly 
plant, to either:
    (A) 2.6 kilograms of VOC per liter of applied coating solids from 
BC/CC topcoats, and 1.47 kilograms of VOC per liter of applied coating 
solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (g)(1)(ii) and continuing thereafter, emissions 
of VOC's from each topcoat operation shall not exceed 1.47 kilograms of 
VOC per liter of applied coating solids as specified under 
Sec. 60.392(c) of this subpart.
    (iv) Each topcoat operation shall comply with the provisions of 
Secs. 60.393, 60.394, 60.395, 60.396, and 60.397. Separate calculations 
shall be made for BC/CC coatings and all other topcoat coatings when 
necessary to demonstrate compliance with the emission limits specified 
under paragraph (g)(1)(ii)(A) of this section.
    (v) A technology development report shall be sent to EPA Region IV, 
345 Courtland Street, NE., Atlanta, GA 30365, postmarked before 60 days 
after the promulgation of this waiver and annually thereafter while this 
waiver is in effect. A copy of this report shall be sent to Director, 
Emission Standards and Engineering Division, U.S. Environmental 
Protection Agency, MD-13, Research Triangle Park, NC 27711. The 
technology development report shall summarize the BC/CC development work 
including the results of exposure and endurance tests of the various 
coatings being evaluated. The report shall include an updated schedule 
of attainment of Sec. 60.392(c) of this subpart, based on the most 
current information.
    (2) This waiver shall be a federally promulgated standard of 
performance. As such, it shall be unlawful for the Ford Motor Company to 
operate a topcoat operation in violation of the requirements established 
in this waiver. Violation of the terms and conditions of this waiver 
shall subject the Ford Motor Company to enforcement under section 113 
(b) and (c) and the Act (42 U.S.C. 7412 (b) and (c)) and under section 
120 of the Act (42 U.S.C. 7420), as well as possible citizen enforcement 
under section 304 of the Act (42 U.S.C. 7604).
    (3) This waiver shall not be construed to constrain the State of 
Georgia from imposing upon the Ford Motor Corporation any emission 
reduction requirement at Ford's Hapeville automobile assembly plant 
necessary for the maintenance of reasonable further progress or the 
attainment of the national ambient air quality standard for ozone or the 
maintenance of the national ambient air quality standard for ozone. 
Furthermore, this waiver shall not be construed as granting any 
exemptions from the applicability, enforcement, or other provisions of 
any other standards that apply or may apply to topcoat operations or any 
other operations at this automobile assembly plant.
    (h) Ford Motor Company, St. Paul, MN, light-duty truck assembly 
plant. (1) Pursuant to section 111(j) of the Clean Air Act, 42 U.S.C. 
7411(j), each topcoat operation at Ford Motor Company's automobile 
assembly plant located in St. Paul, MN, shall comply with the following 
conditions:
    (i) The Ford Motor Company shall obtain the necessary permits as 
required under parts C and D of the Clean Air Act, as amended August 
1977, to operate the St. Paul assembly plant.
    (ii) Commencing on September 9, 1985, and continuing to December 31, 
1986, or until the basecoat/clearcoat

[[Page 311]]

(BC/CC) topcoat system that can achieve the standard specified under 
Sec. 60.392(c) of this subpart, is demonstrated to the Administrator's 
satisfaction, whichever is sooner, the Ford Motor Company shall limit 
the discharge of VOC emissions to the atmosphere from each topcoat 
operation at the St. Paul, MN, assembly plant, to either:
    (A) 2.0 kilograms of VOC per liter of applied coating solids from 
BC/CC topcoats, and 1.47 kilograms of VOC per liter of applied coating 
solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (h)(1)(ii) and continuing thereafter, emissions 
of VOC's from each topcoat operation shall not exceed 1.47 kilograms of 
VOC per liter of applied coating solids as specified under 
Sec. 60.392(c) of this subpart.
    (iv) Each topcoat operation shall comply with the provisions of 
Secs. 60.393, 60.394, 60.395, 60.396, and 60.397. Separate calculations 
shall be made for BC/CC coatings and all other topcoat coatings when 
necessary to demonstrate compliance with the emission limits specified 
under paragraph (h)(1)(ii)(A) of this section.
    (v) A technology development report shall be sent to EPA Region V, 
230 South Dearborn Street, Chicago, IL 60604, postmarked before 60 days 
after the promulgation of this waiver and annually thereafter while this 
waiver is in effect. A copy of this report shall be sent to Director, 
Emission Standards and Engineering Division, U.S. Environmental 
Protection Agency, MD-13, Research Triangle Park, NC 27711. The 
technology development report shall summarize the BC/CC development work 
including the results of exposure and endurance tests of the various 
coatings being evaluated. The report shall include an updated schedule 
of attainment of Sec. 60.392(c) of this subpart, based on the most 
current information.
    (2) This waiver shall be a federally promulgated standard of 
performance. As such, it shall be unlawful for the Ford Motor Company to 
operate a topcoat operation in violation of the requirements established 
in this waiver. Violation of the terms and conditions of this wavier 
shall subject the Ford Motor Company to enforcement under section 113 
(b) and (c) of the Act (42 U.S.C. 7412 (b) and (c)) and under section 
120 of the Act (42 U.S.C. 7420), as well as possible citizen enforcement 
under section 304 of the Act (42 U.S.C. 7604).
    (3) This waiver shall not be construed to constrain the State of 
Minnesota from imposing upon the Ford Motor Corporation any emission 
reduction requirements at Ford's St. Paul light-duty truck assembly 
plant necessary for the maintenance of reasonable further progress or 
the attainment of the national ambient air quality standard for ozone or 
the maintenance of the national ambient air quality standard for ozone. 
Furthermore, this waiver shall not be construed as granting any 
exemptions from the applicability, enforcement, or other provisions of 
any other standards that apply or may apply to topcoat operations or any 
other operations at this light-duty truck assembly plant.
    (i) Ford Motor Company, Hazelwood, MO, passenger van assembly plant. 
(1) Pursuant to section 111(j) of the Clean Air Act, 42 U.S.C. 7411(j), 
each topcoat operation at Ford Motor Company's passenger van assembly 
plant located in Hazelwood, MO, shall comply with the following 
conditions:
    (i) The Ford Motor Company shall obtain the necessary permits as 
required under parts C and D of the Clean Air Act, as amended August 
1977, to operate the Hazelwood assembly plant.
    (ii) Commencing on September 9, 1985, and continuing to December 31, 
1986, or until the basecoat/clearcoat (BC/CC) topcoat system that can 
achieve the standard specified under Sec. 60.392(c) of this subpart is 
demonstrated to the Administrator's satisfaction, whichever is sooner, 
the Ford Motor Company shall limit the discharge of VOC emissions to the 
atmosphere from each topcoat operation at the Hazelwood, MO, assembly 
plant, to either:
    (A) 2.5 kilograms of VOC per liter of applied coating solids from 
BC/CC topcoats, and 1.47 kilograms of VOC per

[[Page 312]]

liter of applied coating solids from all other topcoat coatings; or
    (B) 1.47 kilograms of VOC per liter of applied coating solids from 
all topcoat coatings.
    (iii) Commencing on the day after the expiration of the period 
described in paragraph (i)(1)(ii) and continuing thereafter, emissions 
of VOC's from each topcoat operation shall not exceed 1.47 kilograms of 
VOC per liter of applied coating solids as specified under 
Sec. 60.392(c) of this subpart.
    (iv) Each topcoat operation shall comply with the provisions of 
Secs. 60.393, 60.394, 60.395, 60.396, and 60.397. Separate calculations 
shall be made for BC/CC coatings and all other topcoat coatings when 
necessary to demonstrate compliance with the emission limits specified 
under paragraph (i)(1)(ii)(A) of this section.
    (v) A technology development report shall be sent to EPA Region VII, 
726 Minnesota Avenue, Kansas City, KS 61101, postmarked before 60 days 
after the promulgation of this waiver and annually thereafter while this 
waiver is in effect. A copy of this report shall be sent to Director, 
Emission Standards and Engineering Division, U.S. Environmental 
Protection Agency, MD-13, Research Triangle Park, NC 27711. The 
technology development report shall summarize the BC/CC development work 
including the results of exposure and endurance tests of the various 
coatings being evaluated. The report shall include an updated schedule 
of attainment of Sec. 60.392(c) of this subpart, based on the most 
current information.
    (2) This waiver shall be a federally promulgated standard of 
performance. As such, it shall be unlawful for the Ford Motor Company to 
operate a topcoat operation in violation of the requirements established 
in this waiver. Violation of the terms and conditions of this waiver 
shall subject the Ford Motor Company to enforcement under section 113 
(b) and (c) of the Act (42 U.S.C. 7412 (b) and (c)) and under section 
120 of the Act (42 U.S.C. 7420), as well as possible citizen enforcement 
under section 304 of the Act (42 U.S.C. 7604).
    (3) This waiver shall not be construed to constrain the State of 
Missouri from imposing upon the Ford Motor Corporation any emission 
reduction at Ford's Hazelwood passenger van assembly plant necessary for 
the maintenance of reasonable further progresss or the attainment of the 
national ambient air quality standards for ozone or the maintenance of 
the national ambient air quality standard for ozone. Furthermore, this 
waiver shall not be construed as granting any exemptions from the 
applicability, enforcement, or other provisions of any other standards 
that apply or may apply to topcoat operations or any other operations at 
this passenger van assembly plant.

[48 FR 5454, Feb. 4, 1983, as amended at 50 FR 36834, Sept. 9, 1985]



     Subpart NN--Standards of Performance for Phosphate Rock Plants

    Source: 47 FR 16589, Apr. 16, 1982, unless otherwise noted.



Sec. 60.400  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities used in phosphate rock plants which have a maximum 
plant production capacity greater than 3.6 megagrams per hour (4 tons/
hr): dryers, calciners, grinders, and ground rock handling and storage 
facilities, except those facilities producing or preparing phosphate 
rock solely for consumption in elemental phosphorus production.
    (b) Any facility under paragraph (a) of this section which commences 
construction, modification, or reconstruction after September 21, 1979, 
is subject to the requirements of this part.



Sec. 60.401  Definitions.

    (a) Phosphate rock plant means any plant which produces or prepares 
phosphate rock product by any or all of the following processes: Mining, 
beneficiation, crushing, screening, cleaning, drying, calcining, and 
grinding.
    (b) Phosphate rock feed means all material entering the process unit 
including, moisture and extraneous material as well as the following ore 
minerals:

[[Page 313]]

Fluorapatite, hydroxylapatite, chlorapatite, and carbonateapatite.
    (c) Dryer means a unit in which the moisture content of phosphate 
rock is reduced by contact with a heated gas stream.
    (d) Calciner means a unit in which the moisture and organic matter 
of phosphate rock is reduced within a combustion chamber.
    (e) Grinder means a unit which is used to pulverize dry phosphate 
rock to the final product size used in the manufacture of phosphate 
fertilizer and does not include crushing devices used in mining.
    (f) Ground phosphate rock handling and storage system means a system 
which is used for the conveyance and storage of ground phosphate rock 
from grinders at phosphate rock plants.
    (g) Beneficiation means the process of washing the rock to remove 
impurities or to separate size fractions.



Sec. 60.402  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere:
    (1) From any phosphate rock dryer any gases which:
    (i) Contain particulate matter in excess of 0.030 kilogram per 
megagram of phosphate rock feed (0.06 lb/ton), or
    (ii) Exhibit greater than 10-percent opacity.
    (2) From any phosphate rock calciner processing unbeneficiated rock 
or blends of beneficiated and unbeneficiated rock, any gases which:
    (i) Contains particulate matter in excess of 0.12 kilogram per 
megagram of phosphate rock feed (0.23 lb/ton), or
    (ii) Exhibit greater than 10-percent opacity.
    (3) From any phosphate rock calciner processing beneficiated rock 
any gases which:
    (i) Contain particulate matter in excess of 0.055 kilogram per 
megagram of phosphate rock feed (0.11 lb/ton), or
    (ii) Exhibit greater than 10-percent opacity.
    (4) From any phosphate rock grinder any gases which:
    (i) Contain particulate matter in excess of 0.006 kilogram per 
megagram of phosphate rock feed (0.012 lb/ton), or
    (ii) Exhibit greater than zero-percent opacity.
    (5) From any ground phosphate rock handling and storage system any 
gases which exhibit greater than zero-percent opacity.



Sec. 60.403  Monitoring of emissions and operations.

    (a) Any owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain, and operate a continuous monitoring 
system, except as provided in paragraphs (b) and (c) of this section, to 
monitor and record the opacity of the gases discharged into the 
atmosphere from any phosphate rock dryer, calciner, or grinder. The span 
of this system shall be set at 40-percent opacity.
    (b) For ground phosphate rock storage and handling systems, 
continuous monitoring systems for measuring opacity are not required.
    (c) The owner or operator of any affected phosphate rock facility 
using a wet scrubbing emission control device shall not be subject to 
the requirements in paragraph (a) of this section, but shall install, 
calibrate, maintain, and operate the following continuous monitoring 
devices:
    (1) A monitoring device for the continuous measurement of the 
pressure loss of the gas stream through the scrubber. The monitoring 
device must be certified by the manufacturer to be accurate within 
plus-minus250 pascals (plus-minus1 inch water) 
gauge pressure.
    (2) A monitoring device for the continuous measurement of the 
scrubbing liquid supply pressure to the control device. The monitoring 
device must be accurate within plus-minus5 percent of design 
scrubbing liquid supply pressure.
    (d) For the purpose of conducting a performance test under 
Sec. 60.8, the owner or operator of any phosphate rock plant subject to 
the provisions of this subpart shall install, calibrate, maintain, and 
operate a device for measuring the phosphate rock feed to any affected 
dryer, calciner, or grinder. The measuring device used must be accurate 
to within plus-minus5 percent of the mass rate over its 
operating range.

[[Page 314]]

    (e) For the purpose of reports required under Sec. 60.7(c), periods 
of excess emissions that shall be reported are defined as all 6-minute 
periods during which the average opacity of the plume from any phosphate 
rock dryer, calciner, or grinder subject to paragraph (a) of this 
section exceeds the applicable opacity limit.
    (f) Any owner or operator subject to the requirements under 
paragraph (c) of this section shall report on a frequency specified in 
Sec. 60.7(c) all measurement results that are less than 90 percent of 
the average levels maintained during the most recent performance test 
conducted under Sec. 60.8 in which the affected facility demonstrated 
compliance with the standard under Sec. 60.402.

[47 FR 16589, Apr. 16, 1982, as amended at 64 FR 7466, Feb. 12, 1999]



Sec. 60.404  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided for in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.402 as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:

E=(cs Qsd)/(P K)
where:
E=emission rate of particulate matter, kg/Mg (lb/ton) of phosphate rock 
          feed.
cs=concentration of particulate matter, g/dscm (g/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
P=phosphate rock feed rate, Mg/hr (ton/hr).
K=conversion factor, 1000 g/kg (453.6 g/lb).

    (2) Method 5 shall be used to determine the particulate matter 
concentration (cs) and volumetric flow rate (Qsd) 
of the effluent gas. The sampling time and sample volume for each run 
shall be at least 60 minutes and 0.85 dscm (30 dscf).
    (3) The device of Sec. 60.403(d) shall be used to determine the 
phosphate rock feed rate (P) for each run.
    (4) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (c) To comply with Sec. 60.403(f), if applicable, the owner or 
operator shall use the monitoring devices in Sec. 60.403(c) (1) and (2) 
to determine the average pressure loss of the gas stream through the 
scrubber and the average scrubbing supply pressure during the 
particulate matter runs.

[54 FR 6676, Feb. 14, 1989; 54 FR 21344, May 17, 1989]



  Subpart PP--Standards of Performance for Ammonium Sulfate Manufacture

    Source: 45 FR 74850, Nov. 12, 1980, unless otherwise noted.



Sec. 60.420  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each ammonium sulfate dryer within an ammonium sulfate 
manufacturing plant in the caprolactam by-product, synthetic, and coke 
oven by-product sectors of the ammonium sulfate industry.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after February 4, 1980, is subject to the 
requirements of this subpart.



Sec. 60.421  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A.
    Ammonium sulfate dryer means a unit or vessel into which ammonium 
sulfate is charged for the purpose of reducing the moisture content of 
the product using a heated gas stream. The unit includes foundations, 
superstructure, material charger systems, exhaust systems, and integral 
control systems and instrumentation.
    Ammonium sulfate feed material streams means the sulfuric acid feed 
stream to the reactor/crystallizer for synthetic and coke oven by-
product ammonium sulfate manufacturing plants; and means the total or 
combined feed streams (the oximation ammonium sulfate stream and the 
rearrangement

[[Page 315]]

reaction ammonium sulfate stream) to the crystallizer stage, prior to 
any recycle streams.
    Ammonium sulfate manufacturing plant means any plant which produces 
ammonium sulfate.
    Caprolactam by-product ammonium sulfate manufacturing plant means 
any plant which produces ammonium sulfate as a by-product from process 
streams generated during caprolactam manufacture.
    Coke oven by-product ammonium sulfate manufacturing plant means any 
plant which produces ammonium sulfate by reacting sulfuric acid with 
ammonia recovered as a by-product from the manufacture of coke.
    Synthetic ammonium sulfate manufacturing plant means any plant which 
produces ammonium sulfate by direct combination of ammonia and sulfuric 
acid.



Sec. 60.422  Standards for particulate matter.

    On or after the date on which the performance test required to be 
conducted by Sec. 60.8 is completed, no owner or operator of an ammonium 
sulfate dryer subject to the provisions of this subpart shall cause to 
be discharged into the atmosphere, from any ammonium sulfate dryer, 
particulate matter at an emission rate exceeding 0.15 kilogram of 
particulate per megagram of ammonium sulfate produced (0.30 pound of 
particulate per ton of ammonium sulfate produced) and exhaust gases with 
greater than 15 percent opacity.



Sec. 60.423  Monitoring of operations.

    (a) The owner or operator of any ammonium sulfate manufacturing 
plant subject to the provisions of this subpart shall install, 
calibrate, maintain, and operate flow monitoring devices which can be 
used to determine the mass flow of ammonium sulfate feed material 
streams to the process. The flow monitoring device shall have an 
accuracy of plus-minus 5 percent over its range. However, if 
the plant uses weigh scales of the same accuracy to directly measure 
production rate of ammonium sulfate, the use of flow monitoring devices 
is not required.
    (b) The owner or operator of any ammonium sulfate manufacturing 
plant subject to the provisions of this subpart shall install, 
calibrate, maintain, and operate a monitoring device which continuously 
measures and permanently records the total pressure drop across the 
emission control system. The monitoring device shall have an accuracy of 
plus-minus 5 percent over its operating range.



Sec. 60.424  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.422 as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:

E=(cs Qsd)/(PK)

where:
E=emission rate of particulate matter, kg/Mg (lb/ton) of ammonium 
          sulfate produced.
cs=concentration of particulate matter, g/dscm (g/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
P=production rate of ammonium sulfate, Mg/hr (ton/hr).
K=conversion factor, 1000 g/kg (453.6 g/lb).

    (2) Method 5 shall be used to determine the particulate matter 
concentration (cs) and volumetric flow rate (Qsd) 
of the effluent gas. The sampling time and sample volume for each run 
shall be at least 60 minutes and 1.50 dscm (53 dscf).
    (3) Direct measurement using product weigh scales or computed from 
material balance shall be used to determine the rate (P) of the ammonium 
sulfate production. If production rate is determined by material 
balance, the following equations shall be used:
    (i) For synthetic and coke oven by-product ammonium sulfate plants:

P=ABCK\1/4\

where:
A=sulfuric aid flow rate to the reactor/crystallizer averaged over the 
          time-period taken to conduct the run, liter/min.

[[Page 316]]

B=acid density (a function of acid strength and temperature), g/cc.
C=acid strength, decimal fraction.
K\1/4\=conversion factor, 0.0808 (Mg-min-cc)/(g-hr-liter) [0.0891 (ton-
          min-cc)/(g-hr-liter)].

    (ii) For caprolactam by-product ammonium sulfate plants:

P=DEFK"

where:
D=total combined feed stream flow rate to the ammonium crystallizer 
          before the point where any recycle streams enter the stream 
          averaged over the time-period taken to conduct the test run, 
          liter/min.
E=density of the process stream solution, g/liter.
F=percent mass of ammonium sulfate in the process solution, decimal 
          fraction.
K"=conversion factor, 6.0 x 10-5 (Mg-min)/(g-hr) [6.614 x 
          10-5 (ton-min)/(g-hr)].

    (3) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine the opacity.

[54 FR 6676, Feb. 14, 1989]



  Subpart QQ--Standards of Performance for the Graphic Arts Industry: 
                    Publication Rotogravure Printing

    Source: 47 FR 50649, Nov. 8, 1982, unless otherwise noted.



Sec. 60.430  Applicability and designation of affected facility.

    (a) Except as provided in paragraph (b) of this section, the 
affected facility to which the provisions of this subpart apply is each 
publication rotogravure printing press.
    (b) The provisions of this subpart do not apply to proof presses.
    (c) Any facility under paragraph (a) of this section that commences 
construction, modification, or reconstruction after October 28, 1980 is 
subject to the requirements of this subpart.



Sec. 60.431  Definitions and notations.

    (a) All terms used in this subpart that are not defined below have 
the meaning given to them in the Act and in subpart A of this part.
    Automatic temperature compensator means a device that continuously 
senses the temperature of fluid flowing through a metering device and 
automatically adjusts the registration of the measured volume to the 
corrected equivalent volume at a base temperature.
    Base temperature means an arbitrary reference temperature for 
determining liquid densities or adjusting the measured volume of a 
liquid quantity.
    Density means the mass of a unit volume of liquid, expressed as 
grams per cubic centimeter, kilograms per liter, or pounds per gallon, 
at a specified temperature.
    Gravure cylinder means a printing cylinder with an intaglio image 
consisting of minute cells or indentations specially engraved or etched 
into the cylinder's surface to hold ink when continuously revolved 
through a fountain of ink.
    Performance averaging period means 30 calendar days, one calendar 
month, or four consecutive weeks as specified in sections of this 
subpart.
    Proof press means any device used only to check the quality of the 
image formation of newly engraved or etched gravure cylinders and prints 
only non-saleable items.
    Publication rotogravure printing press means any number of 
rotogravure printing units capable of printing simultaneously on the 
same continuous web or substrate and includes any associated device for 
continuously cutting and folding the printed web, where the following 
saleable paper products are printed:

    Catalogues, including mail order and premium,
    Direct mail advertisements, including circulars, letters, pamphlets, 
cards, and printed envelopes,
    Display advertisements, including general posters, outdoor 
advertisements, car cards, window posters; counter and floor displays; 
point-of-purchase, and other printed display material,
    Magazines,
    Miscellaneous advertisements, including brochures, pamphlets, 
catalogue sheets, circular folders, announcements, package inserts, book 
jackets, market circulars, magazine inserts, and shopping news,
    Newspapers, magazine and comic supplements for newspapers, and 
preprinted newspaper inserts, including hi-fi and spectacolor rolls and 
sections,
    Periodicals, and
    Telephone and other directories, including business reference 
services.

    Raw ink means all purchased ink.

[[Page 317]]

    Related coatings means all non-ink purchased liquids and liquid-
solid mixtures containing VOC solvent, usually referred to as extenders 
or varnishes, that are used at publication rotogravure printing presses.
    Rotogravure printing unit means any device designed to print one 
color ink on one side of a continuous web or substrate using a gravure 
cylinder.
    Solvent-borne ink systems means ink and related coating mixtures 
whose volatile portion consists essentially of VOC solvent with not more 
than five weight percent water, as applied to the gravure cylinder.
    Solvent recovery system means an air pollution control system by 
which VOC solvent vapors in air or other gases are captured and directed 
through a condenser(s) or a vessel(s) containing beds of activated 
carbon or other adsorbents. For the condensation method, the solvent is 
recovered directly from the condenser. For the adsorption method, the 
vapors are adsorbed, then desorbed by steam or other media, and finally 
condensed and recovered.
    VOC means volatile organic compound.
    VOC solvent means an organic liquid or liquid mixture consisting of 
VOC components.
    Waterborne ink systems means ink and related coating mixtures whose 
volatile portion consists of a mixture of VOC solvent and more than five 
weight percent water, as applied to the gravure cylinder.
    (b) Symbols used in this subpart are defined as follows:

DB=the density at the base temperature of VOC solvent used or 
          recovered during one performance averaging period.
Dci=the density of each color of raw ink and each related 
          coating (i) used at the subject facility (or facilities), at 
          the coating temperature when the volume of coating used is 
          measured.
Ddi=the density of each VOC solvent (i) added to the ink for 
          dilution at the subject facility (or facilities), at the 
          solvent temperature when the volume of solvent used is 
          measured.
Dgi=the density of each VOC solvent (i) used as a cleaning 
          agent at the subject facility (or facilities), at the solvent 
          temperature when the volume of cleaning solvent used is 
          measured.
Dhi=the density of each quantity of water (i) added at the 
          subject facility (or facilities) for dilution of waterborne 
          ink systems at the water temperature when the volume of 
          dilution water used is measured.
Dmi=the density of each quantity of VOC solvent and 
          miscellaneous solvent-borne waste inks and waste VOC solvents 
          (i) recovered from the subject facility (or facilities), at 
          the solvent temperature when the volume of solvent recovered 
          is measured.
Doi=the density of the VOC solvent contained in each raw ink 
          and related coating (i) used at the subject facility (or 
          facilities), at the coating temperature when the volume of 
          coating used is measured.
Dwi=the density of the water contained in each waterborne raw 
          ink and related coating (i) used at the subject facility (or 
          facilities), at the coating temperature when the volume of 
          coating used is measured.
Lci=the measured liquid volume of each color of raw ink and 
          each related coating (i) used at the facility of a 
          corresponding VOC content, Voi or Woi, 
          with a VOC density, Doi, and a coating density, 
          Dci.
Ldi=the measured liquid volume of each VOC solvent (i) with 
          corresponding density, Ddi, added to dilute the ink 
          used at
Mci=the mass, determined by direct weighing, of each color of 
          raw ink and each related coating (i) used at the subject 
          facility (or facilities).
Md=the mass, determined by direct weighing, of VOC solvent 
          added to dilute the ink used at the subject facility (or 
          facilities) during one performance averaging period.
Mg=the mass, determined by direct weighing, of VOC solvent 
          used as a cleaning agent at the subject facility (or 
          facilities) during one performance averaging period.
Mh=the mass, determined by direct weighing, of water added 
          for dilution with waterborne ink systems used at the subject 
          facility (or facilities) during one performance averaging 
          period.
Mm=the mass, determined by direct weighing, of VOC solvent 
          and miscellaneous solvent-borne waste inks and waste VOC 
          solvents recovered from the subject facility (or facilities) 
          during one performance averaging period.
Mo=the total mass of VOC solvent contained in the raw inks 
          and related coatings used at the subject facility (or 
          facilities) during one performance averaging period.
Mr=the total mass of VOC solvent recovered from the subject 
          facility (or facilities) during one performance averaging 
          period.
Mt=the total mass of VOC solvent used at the subject facility 
          (or facilities) during one performance averaging period.

[[Page 318]]

Mv=the total mass of water used with waterborne ink systems 
          at the subject facility (or facilities) during one performance 
          averaging period.
Mw=the total mass of water contained in the waterborne raw 
          inks and related coatings used at the subject facility (or 
          facilities) during one performance averaging period.
P=the average VOC emission percentage for the subject facility (or 
          facilities) for one performance averaging period.
Voi=the liquid VOC content, expressed as a volume fraction of 
          VOC volume per total volume of coating, of each color of raw 
          ink and related coating (i) used at the subject facility (or 
          facilities).
Vwi=the water content, expressed as a volume fraction of 
          water volume per total volume of coating, of each color of 
          waterborne raw ink and related coating (i) used at the subject 
          facility (or facilities).
Woi=the VOC content, expressed as a weight fraction of mass 
          of VOC per total mass of coating, of each color of raw ink and 
          related coating (i) used at the subject facility (or 
          facilities).
Wwi=the water content, expressed as a weight fraction of mass 
          of water per total mass of coating, of each color of 
          waterborne raw ink and related coating (i) used at the subject 
          facility (or facilities).

    (c) The following subscripts are used in this subpart with the above 
symbols to denote the applicable facility:

a=affected facility.
b=both affected and existing facilities controlled in common by the same 
          air pollution control equipment.
e=existing facility.
f=all affected and existing facilities located within the same plant 
          boundary.



Sec. 60.432  Standard for volatile organic compounds.

    During the period of the performance test required to be conducted 
by Sec. 60.8 and after the date required for completion of the test, no 
owner or operator subject to the provisions of this subpart shall cause 
to be discharged into the atmosphere from any affected facility VOC 
equal to more than 16 percent of the total mass of VOC solvent and water 
used at that facility during any one performance averaging period. The 
water used includes only that water contained in the waterborne raw inks 
and related coatings and the water added for dilution with waterborne 
ink systems.



Sec. 60.433  Performance test and compliance provisions.

    (a) The owner or operator of any affected facility (or facilities) 
shall conduct performance tests in accordance with Sec. 60.8, under the 
following conditions:
    (1) The performance averaging period for each test is 30 consecutive 
calendar days and not an average of three separate runs as prescribed 
under Sec. 60.8(f).
    (2) Except as provided under paragraphs (f) and (g) of this section, 
if affected facilities routinely share the same raw ink storage/handling 
system with existing facilities, then temporary measurement procedures 
for segregating the raw inks, related coatings, VOC solvent, and water 
used at the affected facilities must be employed during the test. For 
this case, an overall emission percentage for the combined facilities as 
well as for only the affected facilities must be calculated during the 
test.
    (3) For the purpose of measuring bulk storage tank quantities of 
each color of raw ink and each related coating used, the owner or 
operator of any affected facility shall install, calibrate, maintain, 
and continuously operate during the test one or more:
    (i) Non-resettable totalizer metering device(s) for indicating the 
cumulative liquid volumes used at each affected facility; or
    (ii) Segregated storage tanks for each affected facility to allow 
determination of the liquid quantities used by measuring devices other 
than the press meters required under item (i) of this article; or
    (iii) Storage tanks to serve more than one facility with the liquid 
quantities used determined by measuring devices other than press meters, 
if facilities are combined as decribed under paragraph (d), (f), or (g) 
of this section.
    (4) The owner or operator may choose to install an automatic 
temperature compensator with any liquid metering device used to measure 
the raw inks, related coatings, water, or VOC solvent used, or VOC 
solvent recovered.
    (5) Records of the measured amounts used at the affected facility 
and the liquid temperature at which the

[[Page 319]]

amounts were measured are maintained for each shipment of all purchased 
material or on at least a weekly basis for:
    (i) The raw inks and related coatings used;
    (ii) The VOC and water content of each raw ink and related coating 
used as determined according to Sec. 60.435.
    (iii) The VOC solvent and water added to the inks used;
    (iv) The VOC solvent used as a cleaning agent; and
    (v) The VOC solvent recovered.
    (6) The density variations with temperature of the raw inks, related 
coatings, VOC solvents used, and VOC solvent recovered are determined by 
the methods stipulated in Sec. 60.435(d).
    (7) The calculated emission percentage may be reported as rounded-
off to the nearest whole number.
    (8) Printing press startups and shutdowns are not included in the 
exemption provisions under Sec. 60.8(c). Frequent periods of press 
startups and shutdowns are normal operations and constitute 
representative conditions for the purpose of a performance test.
    (b) If an affected facility uses waterborne ink systems or a 
combination of waterborne and solvent-borne ink systems with a solvent 
recovery system, compliance is determined by the following procedures, 
except as provided in paragraphs (d), (e), (f), and (g) of this section:
    (1) The mass of VOC in the solvent-borne and waterborne raw inks and 
related coatings used is determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.015

where:

k is the total number of raw inks and related coatings measured as used 
          in direct mass quantities with different amounts of VOC 
          content.
m is the total number of raw inks and related coatings measured as used 
          by volume with different amounts of VOC content or different 
          densities.
n is the total number of raw inks and related coatings measured as used 
          by volume with different amounts of VOC content or different 
          VOC solvent densities.
    (2) The total mass of VOC used is determined by the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.016

where ``m'' and ``n'' are the respective total numbers of VOC dilution 
          and cleaning solvents measured as used by volume with 
          different densities.

    (3) The mass of water in the waterborne raw inks and related 
coatings used is determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.017

where:

k is the total number of raw inks and related coatings measured as used 
          in direct mass quantities with different amounts of water 
          content.
m is the total number of raw inks and related coatings measured as used 
          by volume with different amounts of water content or different 
          densities.
n is the total number of raw inks and related coatings measured as used 
          by volume with different amounts of water content or different 
          water densities.

    (4) The total mass of water used is determined by the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.018

where ``m'' is the total number of water dilution additions measured as 
          used by volume with different densities.

    (5) The total mass of VOC solvent recovered is determined by the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.019

where ``k'' if the total number of VOC solvents, miscellaneous solvent-
          borne waste inks, and waste VOC solvents measured as recovered 
          by volume with different densities.

    (6) The average VOC emission percentage for the affected facility is 
determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.020


[[Page 320]]


    (c) If an affected facility controlled by a solvent recovery system 
uses only solvent-borne ink systems, the owner or operator may choose to 
determine compliance on a direct mass or a density-corrected liquid 
volume basis. Except as provided in paragraphs (d), (e), (f), and (g) of 
this section, compliance is determined as follows:
    (1) On a direct mass basis, compliance is determined according to 
paragraph (b) of this section, except that the water term, 
Mv, does not apply.
    (2) On a density-corrected liquid volume basis, compliance is 
determined by the following procedures:
    (i) A base temperature corresponding to that for the largest 
individual amount of VOC solvent used or recovered from the affected 
facility, or other reference temperature, is chosen by the owner or 
operator.
    (ii) The corrected liquid volume of VOC in the raw inks and related 
coatings used is determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.021

where:

k is the total number of raw inks and related coatings measured as used 
          in direct mass quantities with different amounts of VOC 
          content.
m is the total number of raw inks and related coatings measured as used 
          by volume with different amounts of VOC content or different 
          densities.
n is the total number of raw inks and related coatings measured as used 
          by volume with different amounts of VOC content or different 
          VOC solvent densities.

    (iii) The total corrected liquid volume of VOC used is determined by 
the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.022

where ``m'' and ``n'' are the respective total numbers of VOC dilution 
          and cleaning solvents measured as used by volume with 
          different densities.
    (iv) The total corrected liquid volume of VOC solvent recovered is 
determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.023

where ``k'' is the total number of VOC solvents, miscellaneous solvent-
          borne waste inks, and waste VOC solvents measured as recovered 
          by volume with different densities.

    (v) The average VOC emission percentage for the affected facility is 
determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.024

    (d) If two or more affected facilities are controlled by the same 
solvent recovery system, compliance is determined by the procedures 
specified in paragraph (b) or (c) of this section, whichever applies, 
except that (Lt)a and (Lr)a, 
(Mt)a, (Mr)a, and 
(Mv)a, are the collective amounts of VOC solvent 
and water corresponding to all the affected facilities controlled by 
that solvent recovery system. The average VOC emission percentage for 
each of the affected facilities controlled by that same solvent recovery 
system is assumed to be equal.
    (e) Except as provided under paragraph (f) of this section, if an 
existing facility (or facilities) and an affected facility (or 
facilities) are controlled in common by the same solvent recovery 
system, the owner or operator shall determine compliance by conducting a 
separate emission test on the existing facility (or facilities) and then 
conducting a performance test on the combined facilities as follows:
    (1) Before the initial startup of the affected facility (or 
facilities) and at any other time as requested by the Administrator, the 
owner or operator shall conduct emission test(s) on the existing 
facility (or facilities) controlled by the subject solvent recovery 
system. The solvent recovery system must handle VOC emissions from only 
the subject existing facility (or facilities), not from affected 
facilities, during the emission test.
    (2) During the emission test, the affected facilities are subject to 
the standard stated in Sec. 60.432.
    (3) The emission test is conducted over a 30 consecutive calendar 
day averaging period according to the conditions stipulated in 
paragraphs (a)(1)

[[Page 321]]

through (a)(5) of this section, except that the conditions pertain to 
only existing facilities instead of affected facilities.
    (4) The owner or operator of the existing facility (or facilities) 
shall provide the Administrator at least 30 days prior notice of the 
emission test to afford the Administrator the opportunity to have an 
observer present.
    (5) The emission percentage for the existing facility (or 
facilities) during the emission test is determined by one of the 
following procedures:
    (i) If the existing facility (or facilities) uses a combination of 
waterborne and solvent-borne ink systems, the average VOC emission 
percentage must be determined on a direct mass basis according to 
paragraph (b) or (d) of this section, whichever applies, with the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.025

where the water and VOC solvent amounts pertain to only existing 
          facilities.

    (ii) If the existing facility (or facilities) uses only solvent-
borne ink systems, the owner or operator may choose to determine the 
emission percentage either on a direct mass basis or a density-corrected 
liquid volume basis according to paragraph (c) or (d) of this section, 
whichever applies. On a direct mass basis, the average VOC emission 
percentage is determined by the equation presented in article (i) of 
this paragraph. On a density-corrected liquid volume basis, the average 
VOC emission percentage is determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.026

where the VOC solvent amounts pertain to only existing facilities.

    (6) The owner or operator of the existing facility (or facilities) 
shall furnish the Administrator a written report of the results of the 
emission test.
    (7) After completion of the separate emission test on the existing 
facility (or facilities), the owner or operator shall conduct 
performance test(s) on the combined facilities with the solvent recovery 
system handling VOC emissions from both the existing and affected 
facilities.
    (8) During performance test(s), the emission percentage for the 
existing facility (or facilities), Pe, is assumed to be equal 
to that determined in the latest emission test. The administrator may 
request additional emission tests if any physical or operational changes 
occur to any of the subject existing facilities.
    (9) The emission percentage for the affected facility (or 
facilities) during performance test(s) with both existing and affected 
facilities connected to the solvent recovery system is determined by one 
of the following procedures:
    (i) If any of the combined facilities uses both waterborne and 
solvent-borne ink systems, the average VOC emission percentage must be 
determined on a direct mass basis according to paragraph (b) or (d) of 
this section, whichever applies, with the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.027

where (Mt)b and (Mr)b are 
          the collective VOC solvent amounts pertaining to all the 
          combined facilities.

    (ii) If all of the combined facilities use only solvent-borne ink 
systems, the owner or operator may choose to determine performance of 
the affected facility (or facilities) either on a direct mass basis or a 
density-corrected liquid volume basis according to paragraph (c) or (d) 
of this section, whichever applies. On a direct mass basis, the average 
VOC emission percentage is determined by the equation presented in 
article (i) of this paragraph. On a density-corrected liquid volume 
basis, the average VOC emission percentage is determined by the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.028

where (Lt)b and (Lr)b are 
          the collective VOC solvent amounts pertaining to all the 
          combined facilities.

    (f) The owner or operator may choose to show compliance of the 
combined performance of existing and affected facilities controlled in 
common by the

[[Page 322]]

same solvent recovery system. A separate emission test for existing 
facilities is not required for this option. The combined performance is 
determined by one of the following procedures:
    (1) If any of the combined facilities uses both waterborne and 
solvent-borne ink systems, the combined average VOC emission percentage 
must be determined on a direct mass basis according to paragraph (b) or 
(d) of this section, whichever applies, with the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.308

    (2) If all of the combined facilities use only solvent-borne ink 
systems, the owner or operator may choose to determine performance 
either on a direct mass basis or a density-corrected liquid volume basis 
according to paragraph (c) or (d) of this section, whichever applies. On 
a direct mass basis, the average VOC emission percentage is determined 
by the equation presented in article (i) of this paragraph. On a 
density-corrected liquid volume basis, the average VOC emission 
percentage is determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.029

      
    (g) If all existing and affected facilities located within the same 
plant boundary use waterborne ink systems or solvent-borne ink systems 
with solvent recovery systems, the owner or operator may choose to show 
compliance on a plantwide basis for all the existing and affected 
facilities together. No separate emission tests on existing facilities 
and no temporary segregated liquid measurement procedures for affected 
facilities are required for this option. The plantwide performance is 
determined by one of the following procedures:
    (1) If any of the facilities use waterborne ink systems, the total 
plant average VOC emission percentage must be determined on a direct 
mass basis according to paragraph (b) of this section with the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.030

Where (Mt)f and (Mv)f are 
          the collective VOC solvent and water amounts used at all the 
          subject plant facilities during the performance test.

    (2) If all of the plant facilities use only solvent-borne ink 
systems, the owner or operator may choose to determine performance 
either on a direct mass basis or a density-corrected liquid volume basis 
according to paragraph (c) of this section. On a direct mass basis, the 
total plant average VOC emission percentage is determined by the 
equation presented in article (i) of this paragraph. On a density-
corrected liquid volume basis, the total plant average VOC emission 
percentage is determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.031

Where (Lt)f is the collective VOC solvent amount 
          used at all the subject plant facilities during the 
          performance test.



Sec. 60.434  Monitoring of operations and recordkeeping.

    (a) After completion of the performance test required under 
Sec. 60.8, the owner or operator of any affected facility using 
waterborne ink systems or solvent-borne ink systems with solvent 
recovery systems shall record the amount of solvent and water used, 
solvent recovered, and estimated emission percentage for each 
performance averaging period and shall maintain these records for 2 
years. The emission percentage is estimated as follows:
    (1) The performance averaging period for monitoring of proper 
operation and maintenance is a calendar month or 4 consecutive weeks, at 
the option of the owner or operator.
    (2) If affected facilities share the same raw ink storage/handling 
system with existing facilities, solvent and water used, solvent 
recovered, and emission percentages for the combined facilities may be 
documented. Separate emission percentages for only the affected 
facilities are not required in this case. The combined emission 
percentage is compared to the overall average for the existing and 
affected facilities'

[[Page 323]]

emission percentage determined during the most recent performance test.
    (3) Except as provided in article (4) of this paragraph, 
temperatures and liquid densities determined during the most recent 
performance test are used to calculate corrected volumes and mass 
quantities.
    (4) The owner or operator may choose to measure temperatures for 
determination of actual liquid densities during each performance 
averaging period. A different base temperature may be used for each 
performance averaging period if desired by the owner or operator.
    (5) The emission percentage is calculated according to the 
procedures under Sec. 60.433 (b) through (g), whichever applies, or by a 
comparable calculation which compares the total solvent recovered to the 
total solvent used at the affected facility.



Sec. 60.435  Test methods and procedures.

    (a) The owner or operator of any affected facility using solvent-
borne ink systems shall determine the VOC content of the raw inks and 
related coatings used at the affected facility by:
    (1) Analysis using Reference Method 24A of routine weekly samples of 
raw ink and related coatings in each respective storage tank; or
    (2) Analysis using Reference Method 24A of samples of each shipment 
of all purchased raw inks and related coatings; or
    (3) Determination of the VOC content from the formulation data 
supplied by the ink manufacturer with each shipment of raw inks and 
related coatings used.
    (b) The owner or operator of any affected facility using solvent-
borne ink systems shall use the results of verification analyses by 
Reference Method 24A to determine compliance when discrepancies with ink 
manufacturers' formulation data occur.
    (c) The owner or operator of any affected facility using waterborne 
ink systems shall determine the VOC and water content of raw inks and 
related coatings used at the affected facility by:
    (1) Determination of the VOC and water content from the formulation 
data supplied by the ink manufacturer with each shipment of purchased 
raw inks and related coatings used; or
    (2) Analysis of samples of each shipment of purchased raw inks and 
related coatings using a test method approved by the Administrator in 
accordance with Sec. 60.8(b).
    (d) The owner or operator of any affected facility shall determine 
the density of raw inks, related coatings, and VOC solvents by:
    (1) Making a total of three determinations for each liquid sample at 
specified temperatures using the procedure outlined in ASTM D 1475-60 
(Reapproved 1980), which is incorporated by reference. It is available 
from the American Society of Testing and Materials, 1916 Race Street, 
Philadelphia, Pennsylvania 19103. It is also available for inspection at 
the Office of the Federal Register, 800 North Capitol Street, NW., suite 
700, Washington, DC. This incorporation by reference was approved by the 
Director of the Federal Register on November 8, 1982. This material is 
incorporated as it exists on the date of approval and a notice of any 
change in these materials will be published in the Federal Register. The 
temperature and density is recorded as the arithmetic average of the 
three determinations; or
    (2) Using literature values, at specified temperatures, acceptable 
to the Administrator.
    (e) If compliance is determined according to Sec. 60.433 (e), (f), 
or (g), the existing as well as affected facilities are subject to the 
requirements of paragraphs (a) through (d) of this section.



  Subpart RR--Standards of Performance for Pressure Sensitive Tape and 
                    Label Surface Coating Operations

    Source: 48 FR 48375, Oct. 18, 1983, unless otherwise noted.



Sec. 60.440  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each coating line used in the manufacture of pressure sensitive 
tape and label materials.
    (b) Any affected facility which inputs to the coating process 45 Mg 
of VOC or

[[Page 324]]

less per 12 month period is not subject to the emission limits of 
Sec. 60.442(a), however, the affected facility is subject to the 
requirements of all other applicable sections of this subpart. If the 
amount of VOC input exceeds 45 Mg per 12 month period, the coating line 
will become subject to Sec. 60.442(a) and all other sections of this 
subpart.
    (c) This subpart applies to any affected facility which begins 
construction, modification, or reconstruction after December 30, 1980.



Sec. 60.441  Definitions and symbols.

    (a) Except as otherwise required by the context, terms used in this 
subpart are defined in the Act, in subpart A of this part, or in this 
section as follows:
    Coating applicator means an apparatus used to apply a surface 
coating to a continuous web.
    Coating line means any number or combination of adhesive, release, 
or precoat coating applicators, flashoff areas, and ovens which coat a 
continuous web, located between a web unwind station and a web rewind 
station, to produce pressure sensitive tape and label materials.
    Coating solids applied means the solids content of the coated 
adhesive, release, or precoat as measured by Reference Method 24.
    Flashoff area means the portion of a coating line after the coating 
applicator and usually before the oven entrance.
    Fugitive volatile organic compounds means any volatile organic 
compounds which are emitted from the coating applicator and flashoff 
areas and are not emitted in the oven.
    Hood or enclosure means any device used to capture fugitive volatile 
organic compounds.
    Oven means a chamber which uses heat or irradiation to bake, cure, 
polymerize, or dry a surface coating.
    Precoat means a coating operation in which a coating other than an 
adhesive or release is applied to a surface during the production of a 
pressure sensitive tape or label product.
    Solvent applied in the coating means all organic solvent contained 
in the adhesive, release, and precoat formulations that is metered into 
the coating applicator from the formulation area.
    Total enclosure means a structure or building around the coating 
applicator and flashoff area or the entire coating line for the purpose 
of confining and totally capturing fugitive VOC emissions.
    VOC means volatile organic compound.
    (b) All symbols used in this subpart not defined below are given 
meaning in the Act or in subpart A of this part.

a=the gas stream vents exiting the emission control device.
b=the gas stream vents entering the emission control device.
Caj=the concentration of VOC (carbon equivalent) in each gas 
          stream (j) exiting the emission control device, in parts per 
          million by volume.
Cbi=the concentration of VOC (carbon equivalent) in each gas 
          stream (i) entering the emission control device, in parts per 
          million by volume.
Cfk=the concentration of VOC (carbon equivalent) in each gas 
          stream (k) emitted directly to the atmosphere, in parts per 
          million by volume.
G=the calculated weighted average mass (kg) of VOC per mass (kg) of 
          coating solids applied each calendar month.
Mci=the total mass (kg) of each coating (i) applied during 
          the calendar month as determined from facility records.
Mr=the total mass (kg) of solvent recovered for a calendar 
          month.
Qaj=the volumetric flow rate of each effluent gas stream (j) 
          exiting the emission control device, in dry standard cubic 
          meters per hour.
Qbi=the volumetric flow rate of each effluent gas stream (i) 
          entering the emission control device, in dry standard cubic 
          meters per hour.
Qfk=the volumetric flow rate of each effluent gas stream (k) 
          emitted to the atmosphere, in dry standard cubic meters per 
          hour.
R=the overall VOC emission reduction achieved for a calendar month (in 
          percent).
Rq=the required overall VOC emission reduction (in percent).
Woi=the weight fraction of organics applied of each coating 
          (i) applied during a calendar month as determined from 
          Reference Method 24 or coating manufacturer's formulation 
          data.
Wsi=the weight fraction of solids applied of each coating (i) 
          applied during a calendar month as determined from Reference 
          Method 24 or coating manufacturer's formulation data.

[[Page 325]]



Sec. 60.442  Standard for volatile organic compounds.

    (a) On and after the date on which the performance test required by 
Sec. 60.8 has been completed each owner or operator subject to this 
subpart shall:
    (1) Cause the discharge into the atmosphere from an affected 
facility not more than 0.20 kg VOC/kg of coating solids applied as 
calculated on a weighted average basis for one calendar month; or
    (2) Demonstrate for each affected facility;
    (i) A 90 percent overall VOC emission reduction as calculated over a 
calendar month; or
    (ii) The percent overall VOC emission reduction specified in 
Sec. 60.443(b) as calculated over a calendar month.



Sec. 60.443  Compliance provisions.

    (a) To determine compliance with Sec. 60.442 the owner or operator 
of the affected facility shall calculate a weighted average of the mass 
of solvent used per mass of coating solids applied for a one calendar 
month period according to the following procedures:
    (1) Determine the weight fraction of organics and the weight 
fraction of solids of each coating applied by using Reference Method 24 
or by the coating manufacturer's formulation data.
    (2) Compute the weighted average by the following equation:
    [GRAPHIC] [TIFF OMITTED] TC16NO91.032
    
    (3) For each affected facility where the value of G is less than or 
equal to 0.20 kg VOC per kg of coating solids applied, the affected 
facility is in compliance with Sec. 60.442(a)(1).
    (b) To determine compliance with Sec. 60.442(a)(2), the owner or 
operator shall calculate the required overall VOC emission reduction 
according to the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.033


If Rq less than or equal to 90 percent, then the required 
overall VOC emission reduction is Rq. If Rq is 
greater than 90 percent, then the required overall VOC emission 
reduction is 90 percent.
    (c) Where compliance with the emission limits specified in 
Sec. 60.442(a)(2) is achieved through the use of a solvent recovery 
system, the owner or operator shall determine the overall VOC emission 
reduction for a one calendar month period by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.034


If the R value is equal to or greater than the Rq value 
specified in paragraph (b) of this section, then compliance with 
Sec. 60.442(a)(2) is demonstrated.
    (d) Where compliance with the emission limit specified in 
Sec. 60.442(a)(2) is achieved through the use of a solvent destruction 
device, the owner or operator shall determine calendar monthly 
compliance by comparing the monthly required overall VOC emission 
reduction specified in paragraph (b)(1) of this section to the overall 
VOC emission reduction demonstrated in the most recent performance test 
which complied with Sec. 60.442(a)(2). If the monthly required overall 
VOC emission reduction is less than or equal to the overall VOC 
reduction of the most recent performance test, the affected facility is 
in compliance with Sec. 60.442(a)(2).
    (e) Where compliance with Sec. 60.442(a)(2) is achieved through the 
use of a solvent destruction device, the owner or operator shall 
continuously record the destruction device combustion temperature during 
coating operations for thermal incineration destruction devices or the 
gas temperature upstream and downstream of the incinerator catalyst bed 
during coating operations for catalytic incineration destruction 
devices. For thermal incineration destruction devices the owner or 
operator shall record all 3-hour periods (during actual coating 
operations) during which the average temperature of the device is more 
than 28 deg.C (50 deg.F) below the average temperature of the device 
during the most recent performance test complying with 
Sec. 60.442(a)(2).

[[Page 326]]

For catalytic incineration destruction devices, the owner or operator 
shall record all 3-hour periods (during actual coating operations) 
during which the average temperature of the device immediately before 
the catalyst bed is more than 38 deg.C (50 deg.F) below the average 
temperature of the device during the most recent performance test 
complying with Sec. 60.442(a)(2), and all 3-hour periods (during actual 
coating operations) during which the average temperature difference 
across the catalyst bed is less than 80 percent of the average 
temperature difference of the device during the most recent performance 
test complying with Sec. 60.442(a)(2).
    (f) After the initial performance test required for all affected 
facilities under Sec. 60.8, compliance with the VOC emission limitation 
and percentage reduction requirements under Sec. 60.442 is based on the 
average emission reduction for one calendar month. A separate compliance 
test is completed at the end of each calendar month after the initial 
performance test, and a new calendar month's average VOC emission 
reduction is calculated to show compliance with the standard.
    (g) If a common emission control device is used to recover or 
destroy solvent from more than one affected facility, the performance of 
that control device is assumed to be equal for each of the affected 
facilities. Compliance with Sec. 60.442(a)(2) is determined by the 
methods specified in paragraphs (c) and (d) of this section and is 
performed simultaneously on all affected facilities.
    (h) If a common emission control device is used to recover solvent 
from an existing facility (or facilities) as well as from an affected 
facility (or facilities), the overall VOC emission reduction for the 
affected facility (or facilities), for the purpose of compliance, shall 
be determined by the following procedures:
    (1) The owner or operator of the existing facility (or facilities) 
shall determine the mass of solvent recovered for a calendar month 
period from the existing facility (or facilities) prior to the 
connection of the affected facility (or facilities) to the emission 
control device.
    (2) The affected facility (or facilities) shall then be connected to 
the emission control device.
    (3) The owner or operator shall determine the total mass of solvent 
recovered from both the existing and affected facilities over a calendar 
month period. The mass of solvent determined in paragraph (h)(1) of this 
section from the existing facility shall be subtracted from the total 
mass of recovered solvent to obtain the mass of solvent recovered from 
the affected facility (or facilities). The overall VOC emission 
reduction of the affected facility (or facilities) can then be 
determined as specified in paragraph (c) of this section.
    (i) If a common emission control devices is used to destruct solvent 
from an existing facility (or facilities) as well as from an affected 
facility (or facilities), the overall VOC emission reduction for the 
affected facility (or facilities), for the purpose of compliance, shall 
be determined by the following procedures:
    (1) The owner or operator shall operate the emission control device 
with both the existing and affected facilities connected.
    (2) The concentration of VOC (in parts per million by volume) after 
the common emission control device shall be determined as specified in 
Sec. 60.444(c). This concentration is used in the calculation of 
compliance for both the existing and affected facilities.
    (3) The volumetric flow out of the common control device 
attributable to the affected facility (or facilities) shall be 
calculated by first determining the ratio of the volumetric flow 
entering the common control device attributable to the affected facility 
(facilities) to the total volumetric flow entering the common control 
device from both existing and affected facilities. The multiplication of 
this ratio by the total volumetric flow out of the common control device 
yields the flow attributable to the affected facility (facilities). 
Compliance is determined by the use of the equation specified in 
Sec. 60.444(c).
    (j) Startups and shutdowns are normal operation for this source 
category. Emissions from these operations are to be included when 
determining if the

[[Page 327]]

standard specified at Sec. 60.442(a)(2) is being attained.



Sec. 60.444  Performance test procedures.

    (a) The performance test for affected facilities complying with 
Sec. 60.442 without the use of add-on controls shall be identical to the 
procedures specified in Sec. 60.443(a).
    (b) The performance test for affected facilities controlled by a 
solvent recovery device shall be conducted as follows:
    (1) The performance test shall be a one calendar month test and not 
the average of three runs as specified in Sec. 60.8(f).
    (2) The weighted average mass of VOC per mass of coating solids 
applied for a one calendar month period shall be determined as specified 
in Sec. 60.443(a) (1) and (2).
    (3) Calculate the required percent overall VOC emission reduction as 
specified in Sec. 60.443(b).
    (4) Inventory VOC usage and VOC recovery for a one calendar month 
period.
    (5) Determine the percent overall VOC emission reduction as 
specified in Sec. 60.443(c).
    (c) The performance test for affected facilities controlled by a 
solvent destruction device shall be conducted as follows:
    (1) The performance of the solvent destruction device shall be 
determined by averaging the results of three test runs as specified in 
Sec. 60.8(f).
    (2) Determine for each affected facility prior to each test run the 
weighted average mass of VOC per mass of coating solids applied being 
used at the facility. The weighted average shall be determined as 
specified in Sec. 60.443(a). In this application the quantities of 
Woi, Wsi, and Mci shall be determined 
for the time period of each test run and not a calendar month as 
specified in Sec. 60.441.
    (3) Calculate the required percent overall VOC emission reduction as 
specified in Sec. 60.443(b).
    (4) Determine the percent overall VOC emission reduction of the 
solvent destruction device by the following equation and procedures:
[GRAPHIC] [TIFF OMITTED] TC01JN92.032

    (i) The owner or operator of the affected facility shall construct 
the overall VOC emission reduction system so that all volumetric flow 
rates and total VOC emissions can be accurately determined by the 
applicable test methods and procedures specified in Sec. 60.446(b).
    (ii) The owner or operator of an affected facility shall construct a 
temporary total enclosure around the coating line applicator and 
flashoff area during the performance test for the purpose of capturing 
fugitive VOC emissions. If a permanent total enclosure exists in the 
affected facility prior to the performance test and the Administrator is 
satisfied that the enclosure is totally capturing fugitive VOC 
emissions, then no additional total enclosure will be required for the 
performance test.
    (iii) For each affected facility where the value of R is greater 
than or equal to the value of Rq calculated in 
Sec. 60.443(b), compliance with Sec. 60.442(a)(2) is demonstrated.



Sec. 60.445  Monitoring of operations and recordkeeping.

    (a) The owner or operator of an affected facility subject to this 
subpart shall maintain a calendar month record of all coatings used and 
the results of the reference test method specified in Sec. 60.446(a) or 
the manufacturer's formulation data used for determining the VOC content 
of those coatings.
    (b) The owner or operator of an affected facility controlled by a 
solvent recovery device shall maintain a calendar month record of the 
amount of solvent applied in the coating at each affected facility.
    (c) The owner or operator of an affected facility controlled by a 
solvent recovery device shall install, calibrate, maintain, and operate 
a monitoring device for indicating the cumulative amount of solvent 
recovered by the device over a calendar month period. The monitoring 
device shall be accurate within 2.0 percent. The owner or 
operator shall maintain a calendar month

[[Page 328]]

record of the amount of solvent recovered by the device.
    (d) The owner or operator of an affected facility operating at the 
conditions specified in Sec. 60.440(b) shall maintain a 12 month record 
of the amount of solvent applied in the coating at the facility.
    (e) The owner or operator of an affected facility controlled by a 
thermal incineration solvent destruction device shall install, 
calibrate, maintain, and operate a monitoring device which continuously 
indicates and records the temperature of the solvent destruction 
device's exhaust gases. The monitoring device shall have an accuracy of 
the greater of 0.75 percent of the temperature being 
measured expressed in degrees Celsius or 2.5  deg.C.
    (f) The owner or operator of an affected facility controlled by a 
catalytic incineration solvent destruction device shall install, 
calibrate, maintain, and operate a monitoring device which continuously 
indicates and records the gas temperature both upstream and downstream 
of the catalyst bed.
    (g) The owner or operator of an affected facility controlled by a 
solvent destruction device which uses a hood or enclosure to capture 
fugitive VOC emissions shall install, calibrate, maintain, and operate a 
monitoring device which continuously indicates that the hood or 
enclosure is operating. No continuous monitor shall be required if the 
owner or operator can demonstrate that the hood or enclosure system is 
interlocked with the affected facility's oven recirculation air system.
    (h) Records of the measurements required in Secs. 60.443 and 60.445 
must be retained for at least two years following the date of the 
measurements.



Sec. 60.446  Test methods and procedures.

    (a) The VOC content per unit of coating solids applied and 
compliance with Sec. 60.422(a)(1) shall be determined by either 
Reference Method 24 and the equations specified in Sec. 60.443 or by 
manufacturers' formulation data. In the event of any inconsistency 
between a Method 24 test and manufacturers' formulation data, the Method 
24 test will govern. The Administrator may require an owner or operator 
to perform Method 24 tests during such months as he deems appropriate. 
For Reference Method 24, the coating sample must be a one liter sample 
taken into a one liter container at a point where the sample will be 
representative of the coating applied to the web substrate.
    (b) Reference Method 25 shall be used to determine the VOC 
concentration, in parts per million by volume, of each effluent gas 
stream entering and exiting the solvent destruction device or its 
equivalent, and each effluent gas stream emitted directly to the 
atmosphere. Reference Methods 1, 2, 3, and 4 shall be used to determine 
the sampling location, volumetric flowrate, molecular weight, and 
moisture of all sampled gas streams. For Reference Method 25, the 
sampling time for each of three runs must be at least 1 hour. The 
minimum sampling volume must be 0.003 dscm except that shorter sampling 
times or smaller volumes, when necessitated by process variables or 
other factors, may be approved by the Administrator.
    (c) If the owner or operator can demonstrate to the Administrator's 
satisfaction that testing of representative stacks yields results 
comparable to those that would be obtained by testing all stacks, the 
Administrator will approve testing of representative stacks on a case-
by-case basis.



Sec. 60.447  Reporting requirements.

    (a) For all affected facilities subject to compliance with 
Sec. 60.442, the performance test data and results from the performance 
test shall be submitted to the Administrator as specified in 
Sec. 60.8(a) of the General Provisions (40 CFR part 60, subpart A).
    (b) Following the initial performance test, the owner or operator of 
each affected facility shall submit quarterly reports to the 
Administrator of exceedances of the VOC emission limits specified in 
Sec. 60.442. If no such exceedances occur during a particular quarter, a 
report stating this shall be submitted to the Administrator 
semiannually.
    (c) The owner or operator of each affected facility shall also 
submit reports at the frequency specified in Sec. 60.7(c) when the 
incinerator temperature drops as defined under Sec. 60.443(e). If no

[[Page 329]]

such periods occur, the owner or operator shall state this in the 
report.
    (d) The requirements of this subsection remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternative 
means of compliance surveillance adopted by such States. In that event, 
affected sources within the State will be relieved of the obligation to 
comply with this subsection, provided that they comply with the 
requirements established by the State.

[48 FR 48375, Oct. 18, 1983, as amended at 55 FR 51383, Dec. 13, 1990]



  Subpart SS--Standards of Performance for Industrial Surface Coating: 
                            Large Appliances

    Source: 47 FR 47785, Oct. 27, 1982, unless otherwise noted.



Sec. 60.450  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to each surface coating 
operation in a large appliance surface coating line.
    (b) The provisions of this subpart apply to each affected facility 
identified in paragraph (a) of this section that commences construction, 
modification, or reconstruction after December 24, 1980.



Sec. 60.451  Definitions.

    (a) All terms used in this subpart not defined below are given the 
meaning in the Act or in subpart A of this part.
    Applied coating solids means the coating solids that adhere to the 
surface of the large appliance part being coated.
    Coating application station means that portion of the large 
appliance surface coating operation where a prime coat or a top coat is 
applied to large appliance parts or products (e.g., dip tank, spray 
booth, or flow coating unit).
    Curing oven means a device that uses heat to dry or cure the 
coating(s) applied to large appliance parts or products.
    Electrodeposition (EDP) means a method of coating application in 
which the large appliance part or product is submerged in a tank filled 
with coating material suspended in water and an electrical potential is 
used to enhance deposition of the material on the part or product.
    Flashoff area means the portion of a surface coating line between 
the coating application station and the curing oven.
    Large appliance part means any organic surface-coated metal lid, 
door, casing, panel, or other interior or exterior metal part or 
accessory that is assembled to form a large appliance product. Parts 
subject to in-use temperatures in excess of 250  deg.F are not included 
in this definition.
    Large appliance product means any organic surface-coated metal 
range, oven, microwave oven, refrigerator, freezer, washer, dryer, 
dishwasher, water heater, or trash compactor manufactured for household, 
commercial, or recreational use.
    Large appliance surface coating line means that portion of a large 
appliance assembly plant engaged in the application and curing of 
organic surface coatings on large appliance parts or products.
    Organic coating means any coating used in a surface coating 
operation, including dilution solvents, from which VOC emissions occur 
during the application or the curing process. For the purpose of this 
regulation, powder coatings are not included in this definition.
    Powder coating means any surface coating that is applied as a dry 
powder and is fused into a continuous coating film through the use of 
heat.
    Spray booth means the structure housing automatic or manual spray 
application equipment where a coating is applied to large appliance 
parts or products.
    Surface coating operation means the system on a large appliance 
surface coating line used to apply and dry or cure an organic coating on 
the surface of large appliance parts or products. The surface coating 
operation may be a prime coat or a topcoat operation and includes the 
coating application station(s), flashoff area, and curing oven.
    Transfer efficiency means the ratio of the amount of coating solids 
deposited onto the surface of a large appliance

[[Page 330]]

part or product to the total amount of coating solids used.
    VOC content means the proportion of a coating that is volatile 
organic compounds (VOC's), expressed as kilograms of VOC's per liter of 
coating solids.
    VOC emissions means the mass of volatile organic compounds (VOC's), 
expressed as kilograms of VOC's per liter of applied coating solids, 
emitted from a surface coating operation.
    (b) All symbols used in this subpart not defined below are given the 
meaning in the Act or subpart A of this part.

Ca=the concentration of VOC's in a gas stream leaving a 
          control device and entering the atmosphere (parts per million 
          by volume, as carbon).
Cb=the concentration of VOC's in a gas stream entering a 
          control device (parts per million by volume, as carbon).
Cf=the concentration of VOC's in a gas stream emitted 
          directly to the atmosphere (parts per million by volume, as 
          carbon).
Dc=density of coating (or input stream), as received 
          (kilograms per liter).
Dd=density of a VOC-solvent added to coatings (kilograms per 
          liter).
Dr=density of a VOC-solvent recovered by an emission control 
          device (kilograms per liter).
E=the VOC destruction efficiency of a control device (fraction).
F=the proportion of total VOC's emitted by an affected facility that 
          enters a control device (fraction).
G=the volume-weighted average mass of VOC's in coatings consumed in a 
          calendar month per unit volume of applied coating solids 
          (kilograms per liter).
Lc=the volume of coating consumed, as received (liters).
Ld=the volume of VOC-solvent added to coatings (liters).
Lr=the volume of VOC-solvent recovered by an emission control 
          device (liters).
Ls=the volume of coating solids consumed (liters).
Md=the mass of VOC-solvent added to coatings (kilograms).
Mo=the mass of VOC's in coatings consumed, as received 
          (kilograms).
Mr=the mass of VOC's recovered by an emission control device 
          (kilograms).
N=the volume-weighted average mass of VOC's emitted to the atmosphere 
          per unit volume of applied coating solids (kilograms per 
          liter).
Qa=the volumetric flow rate of a gas stream leaving a control 
          device and entering the atmosphere (dry standard cubic meters 
          per hour).
Qb=the volumetric flow rate of a gas stream entering a 
          control device (dry standard cubic meters per hour).
Qf=the volumetric flow rate of a gas stream emitted directly 
          to the atmosphere (dry standard cubic meters per hour).
R=the overall VOC emission reduction achieved for an affected facility 
          (fraction).
T=the transfer efficiency (fraction).
Vs=the proportion of solids in a coating (or input stream), 
          as received (fraction by volume).
Wo=the proportion of VOC's in a coating (or input stream), as 
          received (fraction by weight).



Sec. 60.452  Standard for volatile organic compounds.

    On or after the date on which the performance test required by 
Sec. 60.8 is completed, no owner or operator of an affected facility 
subject to the provisions of this supbart shall discharge or cause the 
discharge of VOC emissions that exceed 0.90 kilogram of VOC's per liter 
of applied coating solids from any surface coating operation on a large 
appliance surface coating line.



Sec. 60.453  Performance test and compliance provisions.

    (a) Sections 60.8 (d) and (f) do not apply to the performance test 
procedures required by this subpart.
    (b) The owner or operator of an affected facility shall conduct an 
initial performance text as required under Sec. 60.8(a) and thereafter a 
performance test each calendar month for each affected facility 
according to the procedures in this paragraph.
    (1) An owner or operator shall use the following procedures for any 
affected facility that does not use a capture system and control device 
to comply with the emissions limit specified under Sec. 60.452. The 
owner or operator shall determine the composition of the coatings by 
formulation data supplied by the coating manufacturer or by analysis of 
each coating, as received, using Reference Method 24. The Administrator 
may require the owner or operator who uses formulation data supplied by 
the coating manufacturer to determine the VOC content of coatings using 
Reference Method 24. The owner or operator shall determine the volume of 
coating and the mass of VOC-solvent

[[Page 331]]

used for thinning purposes from company records on a monthly basis. If a 
common coating distribution system serves more than one affected 
facility or serves both affected and existing facilities, the owner or 
operator shall estimate the volume of coatings used at each facility, by 
using the average dry weight of coating and the surface area coated by 
each affected and existing facility or by other procedures acceptable to 
the Administrator.
    (i) Except as provided in paragraph (b)(1)(iv) of this section, the 
weighted average of the total mass of VOC's consumed per unit volume of 
coating solids applied each calendar month will be determined as 
follows.
    (A) Calculate the mass of VOC's consumed (Mo + 
Md) during the calendar month for each affected facility by 
the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.035


(LdjDdj will be 0 if no VOC-solvent is 
added to the coatings, as received)

where:
n is the number of different coatings used during the calendar month, 
          and
m is the number of different VOC-solvents added to coatings during the 
          calendar month.

    (B) Calculate the total volume of coatings solids used 
(Ls) in the calendar month for each affected facility by the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.036

where n is the number of different coatings used during the calendar 
month.

    (C) Select the appropriate transfer efficiency from Table 1. If the 
owner or operator can demonstrate to the satisfaction of the 
Administrator that transfer efficiencies other than those shown are 
appropriate, the Administrator will approve their use on a case-by-case 
basis. Transfer efficiencies for application methods not listed shall be 
determined by the Administrator on a case-by-case basis. An owner or 
operator must submit sufficient data for the Administrator to judge the 
accuracy of the transfer efficiency claims.

                     Table 1--Transfer Efficiencies
------------------------------------------------------------------------
                                                               Transfer
                     Application method                       efficiency
                                                                 (Tk)
------------------------------------------------------------------------
Air-atomized spray..........................................        0.40
Airless spray...............................................        0.45
Manual electrostatic spray..................................        0.60
Flow coat...................................................        0.85
Dip coat....................................................        0.85
Nonrotational automatic electrostatic spray.................        0.85
Rotating head automatic electrostatic spray.................        0.90
Electrodeposition...........................................        0.95
------------------------------------------------------------------------

    Where more than one application method is used within a single 
surface coating operation, the owner or operator shall determine the 
composition and volume of each coating applied by each method through a 
means acceptable to the Administrator and compute the weighted average 
transfer efficiency by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.037

where:
n is the number of coatings (or input streams) used, and
m is the number of application methods used.

    (D) Calculate the volume-weighted average mass of VOC's consumed per 
unit volume of coating solids applied (G) during the calendar month for 
each affected facility by the following equation:

[[Page 332]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.038

    (ii) Calculate the volume-weighted average of VOC emissions to the 
atmosphere (N) during the calendar month for each affected facility by 
the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.039

    (iii) Where the volume-weighted average mass of VOC's discharged to 
the atmosphere per unit volume of coating solids applied (N) is equal to 
or less than 0.90 kilogram per liter, the affected facility is in 
compliance.
    (iv) If each individual coating used by an affected facility has a 
VOC content, as received, which when divided by the lowest transfer 
efficiency at which the coating is applied, results in a value equal to 
or less than 0.90 kilogram per liter, the affected facility is in 
compliance, provided no VOC's are added to the coating during 
distribution or application.
    (2) An owner or operator shall use the following procedures for any 
affected facility that uses a capture system and a control device that 
destroys VOC's (e.g., incinerator) to comply with the emission limit 
specified under Sec. 60.452.
    (i) Determine the overall reduction efficiency (R) for the capture 
system and control device. For the initial performance test the overall 
reduction efficiency (R) shall be determined as prescribed in A, B, and 
C below. In subsequent months, the owner or operator may use the most 
recently determined overall reduction efficiency (R) for the performance 
test, providing control device and capture system operating conditions 
have not changed. The procedure in A, B, and C, below, shall be repeated 
when directed by the Administrator or when the owner or operator elects 
to operate the control device or capture system at conditions different 
from the initial performance test.
    (A) Determine the fraction (F) of total VOC's emitted by an affected 
facility that enters the control device using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.033

where:
n is the number of gas streams entering the control device
p is the number of gas streams emitted directly to the atmosphere.
    (B) Determine the destruction efficiency of the control device (E) 
using values of the volumetric flow rate of each of the gas streams and 
the VOC content (as carbon) of each of the gas streams in and out of the 
device by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.034

where:
n is the number of gas streams entering the control device, and
m is the number of gas streams leaving the control device and entering 
          the atmosphere.

    (C) Determine overall reduction efficiency (R) using the following 
equation:

                               R=EF                                  (8)
 

    (ii) Calculate the volume-weighted average of the total mass of 
VOC's per unit volume of applied coating solids (G) during each calendar 
month for each affected facility using equations (1), (2), (3) if 
applicable, and (4).
    (iii) Calculate the volume-weighted average of VOC emissions to the 
atmosphere (N) during each calendar month by the following equation:

                             N=G(1-R)                                (9)
 

    (iv) If the volume-weighted average mass of VOC's emitted to the 
atmosphere for each calendar month (N) is equal to or less than 0.90 
kilogram per liter of applied coating solids, the affected facility is 
in compliance.
    (3) An owner or operator shall use the following procedure for any 
affected facility that uses a control device for VOC recovery (e.g., 
carbon adsorber) to comply with the applicable emission limit specified 
under Sec. 60.452.
    (i) Calculate the total mass of VOC's assumed 
(Mo+Md) and the volume-weighted average of the 
total mass of

[[Page 333]]

VOC's per unit volume of applied coating solids (G) during each calendar 
month for each affected facility using equations (1), (2), (3) if 
applicable, and (4).
    (ii) Calculate the total mass of VOC's recovered (Mr) 
during each calendar month using the following equation:

                             Mr=Lr Dr                               (10)
 

    (iii) Calculate overall reduction efficiency of the control device 
(R) for each calendar month for each affected facility using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.040

    (iv) Calculate the volume-weighted average mass of VOC's emitted to 
the atmosphere (N) for each calendar month for each affected facility 
using equation (9).
    (v) If the volume-weighted average mass of VOC's emitted to the 
atmosphere for each calendar month (N) is equal to or less than 0.90 
kilogram per liter of applied coating solids, the affected facility is 
in compliance. Each monthly calculation is considered a performance 
test.



Sec. 60.454  Monitoring of emissions and operations.

    (a) The owner or operator of an affected facility that uses a 
capture system and an incinerator to comply with the emission limits 
specified under Sec. 60.452 shall install, calibrate, maintain, and 
operate temperature measurement devices as prescribed below:
    (1) Where thermal incineration is used, a temperature measurement 
device shall be installed in the firebox. Where catalytic incineration 
is used, a temperature measurement device shall be installed in the gas 
stream immediately before and after the catalyst bed.
    (2) Each temperature measurement device shall be installed, 
calibrated, and maintained according to the manufacturer's 
specifications. The device shall have an accuracy of the greater of 0.75 
percent of the temperature being measured expressed in degrees Celsius 
or plus-minus2.5  deg.C.
    (3) Each temperature measurement device shall be equipped with a 
recording device so that a permanent continuous record is produced.



Sec. 60.455  Reporting and recordkeeping requirements.

    (a) The reporting requirements of Sec. 60.8(a) apply only to the 
initial performance test. Each owner or operator subject to the 
provisions of this subpart shall include the following data in the 
report of the initial performance test required under Sec. 60.8(a):
    (1) Except as provided in paragraph (a)(2) of this section, the 
volume-weighted average mass of VOC's emitted to the atmosphere per 
volume of applied coating solids (N) for a period of 1 calendar month 
from each affected facility.
    (2) For each affected facility where compliance is determined under 
the provisions of Sec. 60.453(b)(1)(iv), a list of the coatings used 
during a period of 1 calendar month, the VOC content of each coating 
calculated from data determined using Reference Method 24 or supplied by 
the coating manufacturer, and the minimum transfer efficiency of any 
coating application equipment used during the month.
    (3) For each affected facility where compliance is achieved through 
use of an incineration system, the following additional information will 
be reported:
    (i) The proportion of total VOC's emitted that enters the control 
device (F),
    (ii) The VOC reduction efficiency of the control device (E),
    (iii) The average combustion temperature (or the average temperature 
upstream and downstream of the catalyst bed), and
    (iv) A description of the method used to establish the amount of 
VOC's captured and sent to the incinerator.
    (4) For each affected facility where compliance is achieved through 
use of a solvent recovery system, the following additional information 
will be reported:
    (i) The volume of VOC-solvent recovered (Lr), and
    (ii) The overall VOC emission reduction achieved (R).
    (b) Following the initial performance test, the owner or operator of 
an affected facility shall identify, record,

[[Page 334]]

and submit a written report to the Administrator every calendar quarter 
of each instance in which the volume-weighted average of the total mass 
of VOC's emitted to the atmosphere per volume of applied coating solids 
(N) is greater than the limit specified under Sec. 60.452. If no such 
instances have occurred during a particular quarter, a report stating 
this shall be submitted to the Administrator semiannually.
    (c) Following the initial performance test, the owner or operator of 
an affected facility shall identify, record, and submit at the frequency 
specified in Sec. 60.7(c) the following:
    (1) Where compliance with Sec. 60.452 is achieved through use of 
thermal incineration, each 3-hour period of coating operation during 
which the average temperature of the device was more than 28  deg.C 
below the average temperature of the device during the most recent 
performance test at which destruction efficiency was determined as 
specified under Sec. 60.453.
    (2) Where compliance with Sec. 60.452 is achieved through the use of 
catalytic incineration, each 3-hour period of coating operation during 
which the average temperature recorded immediately before the catalyst 
bed is more than 28  deg.C below the average temperature at the same 
location during the most recent performance test at which destruction 
efficiency was determined as specified under Sec. 60.453. Additionally, 
all 3-hour periods of coating operation during which the average 
temperature difference across the catalyst bed is less than 80 percent 
of the average temperature difference across the catalyst bed during the 
most recent performance test at which destruction efficiency was 
determined as specified under Sec. 60.453 will be recorded.
    (3) For thermal and catalytic incinerators, if no such periods as 
described in paragraphs (c)(1) and (c)(2) of this section occur, the 
owner or operator shall state this in the report.
    (d) Each owner or opreator subject to the provisions of this subpart 
shall maintain at the source, for a period of at least 2 years, records 
of all data and calculations used to determine VOC emissions from each 
affected facility. Where compliance is achieved through the use of 
thermal incineration, each owner or operator shall maintain at the 
source daily records of the incinerator combustion chamber temperature. 
If catalytic incineration is used, the owner or operator shall maintain 
at the source daily records of the gas temperature, both upstream and 
downstream of the incinerator catalyst bed. Where compliance is achieved 
through the use of a solvent recovery system, the owner or operator 
shall maintain at the source daily records of the amount of solvent 
recovered by the system for each affected facility.

[47 FR 47785, Oct. 27, 1982, as amended at 55 FR 51383, Dec. 13, 1990]



Sec. 60.456  Test methods and procedures.

    (a) The reference methods in Appendix A to this part, except as 
provided under Sec. 60.8(b), shall be used to determine compliance with 
Sec. 60.452 as follows:
    (1) Method 24 or formulation data supplied by the coating 
manufacturer to determine the VOC content of a coating. In the event of 
dispute, Reference Method 24 shall be the reference method. For 
determining compliance only, results of Method 24 analyses of waterborne 
coatings shall be adjusted as described in subsection 4.4 of Method 24. 
Procedures to determine VOC emissions are provided in Sec. 60.453.
    (2) Method 25 for the measurement of the VOC concentration in the 
gas stream vent.
    (3) Method 1 for sample and velocity traverses.
    (4) Method 2 for volocity and volumetric flow rate.
    (5) Method 3 for gas analysis.
    (6) Method 4 for stack gas moisture.
    (b) For Method 24, the coating sample must be a 1-liter sample taken 
into a 1-liter container at a point where the sample will be 
representative of the coating material.
    (c) For Method 25, the sample time for each of three runs is to be 
at least 60 minutes and the minimum sample volume is to be at least 
0.003 dscm except that shorter sampling times or smaller volumes, when 
necessitated by process variables or other factors, may be approved by 
the Administrator.
    (d) The Administrator will approve sampling of representative stacks 
on a

[[Page 335]]

case-by-case basis if the owner or operator can demonstrate to the 
satisfaction of the Administrator that the testing of representative 
stacks would yield results comparable to those that would be obtained by 
testing all stacks.



   Subpart TT--Standards of Performance for Metal Coil Surface Coating

    Source: 47 FR 49612, Nov. 1, 1982, unless otherwise noted.



Sec. 60.460  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to the following affected 
facilities in a metal coil surface coating operation: each prime coat 
operation, each finish coat operation, and each prime and finish coat 
operation combined when the finish coat is applied wet on wet over the 
prime coat and both coatings are cured simultaneously.
    (b) This subpart applies to any facility identified in paragraph (a) 
of this section that commences construction, modification, or 
reconstruction after January 5, 1981.



Sec. 60.461  Definitions.

    (a) All terms used in this subpart not defined below are given the 
same meaning as in the Act or in subpart A of this part.
    Coating means any organic material that is applied to the surface of 
metal coil.
    Coating application station means that portion of the metal coil 
surface coating operation where the coating is applied to the surface of 
the metal coil. Included as part of the coating application station is 
the flashoff area between the coating application station and the curing 
oven.
    Curing oven means the device that uses heat or radiation to dry or 
cure the coating applied to the metal coil.
    Finish coat operation means the coating application station, curing 
oven, and quench station used to apply and dry or cure the final 
coating(s) on the surface of the metal coil. Where only a single coating 
is applied to the metal coil, that coating is considered a finish coat.
    Metal coil surface coating operation means the application system 
used to apply an organic coating to the surface of any continuous metal 
strip with thickness of 0.15 millimeter (mm) (0.006 in.) or more that is 
packaged in a roll or coil.
    Prime coat operation means the coating application station, curing 
oven, and quench station used to apply and dry or cure the initial 
coating(s) on the surface of the metal coil.
    Quench station means that portion of the metal coil surface coating 
operation where the coated metal coil is cooled, usually by a water 
spray, after baking or curing.
    VOC content means the quantity, in kilograms per liter of coating 
solids, of volatile organic compounds (VOC's) in a coating.
    (b) All symbols used in this subpart not defined below are given the 
same meaning as in the Act and in subpart A of this part.

Ca= the VOC concentration in each gas stream leaving the 
          control device and entering the atmosphere (parts per million 
          by volume, as carbon).
Cb= the VOC concentration in each gas stream entering the 
          control device (parts per million by volume, as carbon).
Cf= the VOC concentration in each gas steam emitted directly 
          to the atmosphere (parts per million by volume, as carbon).
Dc= density of each coating, as received (kilograms per 
          liter).
Dd= density of each VOC-solvent added to coatings (kilograms 
          per liter).
Dr= density of VOC-solvent recovered by an emission control 
          device (kilograms per liter).
E= VOC destruction efficiency of the control device (fraction).
F= the proportion of total VOC's emitted by an affected facility that 
          enters the control device (fraction).
G= volume-weighted average mass of VOC's in coatings consumed in a 
          calendar month per unit volume of coating solids applied 
          (kilograms per liter).
Lc= the volume of each coating consumed, as received 
          (liters).
Ld= the volume of each VOC-solvent added to coatings 
          (liters).
Lr= the volume of VOC-solvent recovered by an emission 
          control device (liters).
Ls= the volume of coating solids consumed (liters).
Md= the mass of VOC-solvent added to coatings (kilograms).

[[Page 336]]

Mo= the mass of VOC's in coatings consumed, as received 
          (kilograms).
Mr= the mass of VOC's recovered by an emission control device 
          (kilograms).
N= the volume-weighted average mass of VOC emissions to the atmosphere 
          per unit volume of coating solids applied (kilograms per 
          liter).
Qa= the volumetric flow rate of each gas stream leaving the 
          control device and entering the atmosphere (dry standard cubic 
          meters per hour).
Qb= the volumetric flow rate of each gas stream entering the 
          control device (dry standard cubic meters per hour).
Qf= the volumetric flow rate of each gas steam emitted 
          directly to the atmosphere (dry standard cubic meters per 
          hour).
R= the overall VOC emission reduction achieved for an affected facility 
          (fraction).
S= the calculated monthly allowable emission limit (kilograms of VOC per 
          liter of coating solids applied).
Vs= the proportion of solids in each coating, as received 
          (fraction by volume).
Wo= the proportion of VOC's in each coating, as received 
          (fraction by weight).



Sec. 60.462  Standards for volatile organic compounds.

    (a) On and after the date on which Sec. 60.8 requires a performance 
test to be completed, each owner or operator subject to this subpart 
shall not cause to be discharged into the atmosphere more than:
    (1) 0.28 kilogram VOC per liter (kg VOC/l) of coating solids applied 
for each calendar month for each affected facility that does not use an 
emission control device(s); or
    (2) 0.14 kg VOC/l of coating solids applied for each calendar month 
for each affected facility that continuously uses an emission control 
device(s) operated at the most recently demonstrated overall efficiency; 
or
    (3) 10 percent of the VOC's applied for each calendar month (90 
percent emission reduction) for each affected facility that continuously 
uses an emission control device(s) operated at the most recently 
demonstrated overall efficiency; or
    (4) A value between 0.14 (or a 90-percent emission reduction) and 
0.28 kg VOC/l of coating solids applied for each calendar month for each 
affected facility that intermittently uses an emission control device 
operated at the most recently demonstrated overall efficiency.



Sec. 60.463  Performance test and compliance provisions.

    (a) Section 60.8(d) and (f) do not apply to the performance test.
    (b) The owner or operator of an affected facility shall conduct an 
initial performance test as required under Sec. 60.8(a) and thereafter a 
performance test for each calendar month for each affected facility 
according to the procedures in this section.
    (c) The owner or operator shall use the following procedures for 
determining monthly volume-weighted average emissions of VOC's in kg/l 
of coating solids applied.
    (1) An owner or operator shall use the following procedures for each 
affected facility that does not use a capture system and control device 
to comply with the emission limit specified under Sec. 60.462(a)(1). The 
owner or operator shall determine the composition of the coatings by 
formulation data supplied by the manufacturer of the coating or by an 
analysisof each coating, as received, using Reference Method 24. The 
Administrator may require the owner or operator who uses formulation 
data supplied by the manufacturer of the coatings to determine the VOC 
content of coatings using Reference Method 24 or an equivalent or 
alternative method. The owner or operator shall determine the volume of 
coating and the mass of VOC-solvent added to coatings from company 
records on a monthly basis. If a common coating distribution system 
serves more than one affected facility or serves both affected and 
existing facilities, the owner or operator shall estimate the volume of 
coating used at each affected facility by using the average dry weight 
of coating and the surface area coated by each affected and existing 
facility or by other procedures acceptable to the Administrator.
    (i) Calculate the volume-weighted average of the total mass of VOC's 
consumed per unit volume of coating solids applied during each calendar 
month for each affected facility, except as provided under paragraph 
(c)(1)(iv) of this section. The weighted average of the total mass of 
VOC's used per unit volume of coating solids applied each

[[Page 337]]

calendar month is determined by the following procedures.
    (A) Calculate the mass of VOC's used (Mo+Md) during each calendar 
month for each affected facility by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.041

(LdjDdj will be 0 if no VOC solvent is 
added to the coatings, as received)
where
n is the number of different coatings used during the calendar month, 
          and
m is the number of different VOC solvents added to coatings used during 
          the calendar month.

    (B) Calculate the total volume of coating solids used 
(Ls) in each calendar month for each affected facility by the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.042

Where:
n is the number of different coatings used during the calendar month.

    (C) Calculate the volume-weighted average mass of VOC's used per 
unit volume of coating solids applied (G) during the calendar month for 
each affected facility by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.043

    (ii) Calculate the volume-weighted average of VOC emissions to the 
atmosphere (N) during the calendar month for each affected facility by 
the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.044

    (iii) Where the volume-weighted average mass of VOC's discharged to 
the atmosphere per unit volume of coating solids applied (N) is equal to 
or less than 0.28 kg/l, the affected facility is in compliance.
    (iv) If each individual coating used by an affected facility has a 
VOC content, as received, that is equal to or less than 0.28 kg/l of 
coating solids, the affected facility is in compliance provided no VOC's 
are added to the coatings during distribution or application.
    (2) An owner or operator shall use the following procedures for each 
affected facility that continuously uses a capture system and a control 
device that destroys VOC's (e.g., incinerator) to comply with the 
emission limit specified under Sec. 60.462(a) (2) or (3).
    (i) Determine the overall reduction efficiency (R) for the capture 
system and control device.

For the initial performance test, the overall reduction efficiency (R) 
shall be determined as prescribed in paragraphs (c)(2)(i) (A), (B), and 
(C) of this section. In subsequent months, the owner or operator may use 
the most recently determined overall reduction efficiency (R) for the 
performance test, providing control device and capture system operating 
conditions have not changed. The procedure in paragraphs (c)(2)(i) (A), 
(B), and (C) of this section, shall be repeated when directed by the 
Administrator or when the owner or operator elects to operate the 
control device or capture system at conditions different from the 
initial performance test.
    (A) Determine the fraction (F) of total VOC's emitted by an affected 
facility that enters the control device using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.035

                                                              Equation 5

Where:

l is the number of gas streams entering the control device, and
p is the number of gas streams emitted directly to the atmosphere.

    (B) Determine the destruction efficiency of the control device (E) 
using

[[Page 338]]

values of the volumetric flow rate of each of the gas streams and the 
VOC content (as carbon) of each of the gas streams in and out of the 
device by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.036

                                                              Equation 6

Where:
n is the number of gas streams entering the control device, and
m is the number of gas streams leaving the control device and entering 
          the atmosphere.


The owner or operator of the affected facility shall construct the VOC 
emission reduction system so that all volumetric flow rates and total 
VOC emissions can be accurately determined by the applicable test 
methods and procedures specified in Sec. 60.466. The owner or operator 
of the affected facility shall construct a temporary enclosure around 
the coating applicator and flashoff area during the performance test for 
the purpose of evaluating the capture efficiency of the system. The 
enclosure must be maintained at a negative pressure to ensure that all 
VOC emissions are measurable. If a permanent enclosure exists in the 
affected facility prior to the performance test and the Administrator is 
satisfied that the enclosure is adequately containing VOC emissions, no 
additional enclosure is required for the performance test.
    (C) Determine overall reduction efficiency (R) using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.045


If the overall reduction efficiency (R) is equal to or greater than 
0.90, the affected facility is in compliance and no further computations 
are necessary. If the overall reduction efficiency (R) is less than 
0.90, the average total VOC emissions to the atmosphere per unit volume 
of coating solids applied (N) shall be computed as follows.
    (ii) Calculate the volume-weighted average of the total mass of 
VOC's per unit volume of coating solids applied (G) during each calendar 
month for each affected facility using equations in paragraphs (c)(1)(i) 
(A), (B), and (C) of this section.
    (iii) Calculate the volume-weighted average of VOC emissions to the 
atmosphere (N) during each calendar month by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.046

    (iv) If the volume-weighted average mass of VOC's emitted to the 
atmosphere for each calendar month (N) is less than or equal to 0.14 kg/
l of coating solids applied, the affected facility is in compliance. 
Each monthly calculation is a performance test.
    (3) An owner or operator shall use the following procedure for each 
affected facility that uses a control device that recovers the VOC's 
(e.g., carbon adsorber) to comply with the applicable emission limit 
specified under Sec. 60.462(a) (2) or (3).
    (i) Calculate the total mass of VOC's consumed 
(Mo+Md) during each calendar month for each 
affected facility using equation (1).
    (ii) Calculate the total mass of VOC's recovered (Mr) 
during each calendar month using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.047

    (iii) Calculate the overall reduction efficiency of the control 
device (R) for each calendar month for each affected facility using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.048


If the overall reduction efficiency (R) is equal to or greater than 
0.90, the affected facility is in compliance and no further computation 
are necessary. If the overall reduction efficiency (R) is less than 
0.90, the average total VOC emissions to the atmosphere per unit volume 
of coating solids applied (N) must be computed as follows.
    (iv) Calculate the total volume of coating solids consumed 
(Ls) and the volume-weighted average of the total mass of 
VOC's per unit volume of coating solids applied (G) during each calendar 
month for each affected facility using equations in paragraphs (c)(1)(i) 
(B) and (C) of this section.
    (v) Calculate the volume-weighted average mass of VOC's emitted to 
the

[[Page 339]]

atmosphere (N) for each calendar month for each affected facility using 
equation (8).
    (vi) If the weighted average mass of VOC's emitted to the atmosphere 
for each calendar month (N) is less than or equal to 0.14 kg/l of 
coating solids applied, the affected facility is in compliance. Each 
monthly calculation is a performance test.
    (4) An owner or operator shall use the following procedures for each 
affected facility that intermittently uses a capture system and a 
control device to comply with the emission limit specified in 
Sec. 60.462(a)(4).
    (i) Calculate the total volume of coating solids applied without the 
control device in operation (Lsn) during each calendar month 
for each affected facility using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.049

Where:
n is the number of coatings used during the calendar month without the 
          control device in operation.

    (ii) Calculate the total volume of coating solids applied with the 
control device in operation (Lsc) during each calendar month 
for each affected facility using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.050

Where:
m is the number of coatings used during the calendar month with the 
          control device in operation.

    (iii) Calculate the mass of VOC's used without the control device in 
operation (Mon+Mdn) during each calendar month for 
each affected facility using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.051

Where:

n is the number of different coatings used without the control device in 
          operation during the calendar month, and
m is the number of different VOC-solvents added to coatings used without 
          the control device in operation during the calendar month.

    (iv) Calculate the volume-weighted average of the total mass of 
VOC's consumed per unit volume of coating solids applied without the 
control device in operation (Gn) during each calendar month 
for each affected facility using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.052

    (v) Calculate the mass of VOC's used with the control device in 
operation (Moc+Mdc) during each calendar month for 
each affected facility using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.053

Where:

n is the number of different coatings used with the control device in 
          operation during the calendar month, and
m is the number of different VOC-solvents added to coatings used with 
          the control device in operation during the calendar month.

    (vi) Calculate the volume-weighted average of the total mass of 
VOC's used

[[Page 340]]

per unit volume of coating solids applied with the control device in 
operation (Gc) during each calendar month for each affected 
facility using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.054

    (vii) Determine the overall reduction efficiency (R) for the capture 
system and control device using the procedures in paragraphs (c)(2)(i) 
(A), (B), and (C) or paragraphs (c)(3) (i), (ii), and (iii) of this 
section, whichever is applicable.
    (viii) Calculate the volume-weighted average of VOC emissions to the 
atmosphere (N) during each calendar month for each affected facility 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.055

                                                             Equation 17

    (ix) Calculate the emission limit(s) for each calendar month for 
each affected facility using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.056

      or
    [GRAPHIC] [TIFF OMITTED] TC16NO91.057
    
whichever is greater.

    (x) If the volume-weighted average mass of VOC's emitted to the 
atmosphere for each calendar month (N) is less than or equal to the 
calculated emission limit (S) for the calendar month, the affected 
facility is in compliance. Each monthly calculation is a performance 
test.

[47 FR 49612, Nov. 1, 1982; 48 FR 1056, Jan. 10, 1983]



Sec. 60.464  Monitoring of emissions and operations.

    (a) Where compliance with the numerical limit specified in 
Sec. 60.462(a) (1) or (2) is achieved through the use of low VOC-content 
coatings without the use of emission control devices or through the use 
of higher VOC-content coatings in conjunction with emission control 
devices, the owner or operator shall compute and record the average VOC 
content of coatings applied during each calendar month for each affected 
facility, according to the equations provided in Sec. 60.463.
    (b) Where compliance with the limit specified in Sec. 60.462(a)(4) 
is achieved through the intermittent use of emission control devices, 
the owner or operator shall compute and record for each affected 
facility the average VOC content of coatings applied during each 
calendar month according to the equations provided in Sec. 60.463.
    (c) If thermal incineration is used, each owner or operator subject 
to the provisions of this subpart shall install, calibrate, operate, and 
maintain a device that continuously records the combustion temperature 
of any effluent gases incinerated to achieve compliance with 
Sec. 60.462(a)(2), (3), or (4). This device shall have an accuracy of 
2.5  deg.C. or 0.75 percent of the temperature 
being measured expressed in degrees Celsius, which is greater. Each 
owner or operator shall also record all periods (during actual coating 
operations) in excess of 3 hours during which the average temperature in 
any thermal incinerator used to control emissions from an affected 
facility remains more than 28  deg.C (50  deg.F) below the temperature 
at which compliance with Sec. 60.462(a)(2), (3), or (4) was demonstrated 
during the most recent measurement of incinerator efficiency required by 
Sec. 60.8. The records required by Sec. 60.7 shall identify each such 
occurrence and its duration. If catalytic incineration is used, the 
owner or operator shall install, calibrate, operate, and maintain a 
device to monitor and

[[Page 341]]

record continuously the gas temperature both upstream and downstream of 
the incinerator catalyst bed. This device shall have an accuracy of 
2.5  deg.C. or 0.75 percent of the temperature 
being measured expressed in degrees Celsius, whichever is greater. 
During coating operations, the owner or operator shall record all 
periods in excess of 3 hours where the average difference between the 
temperature upstream and downstream of the incinerator catalyst bed 
remains below 80 percent of the temperature difference at which 
compliance was demonstrated during the most recent measurement of 
incinerator efficiency or when the inlet temperature falls more than 28 
deg.C (50  deg.F) below the temperature at which compliance with 
Sec. 60.462(a)(2), (3), or (4) was demonstrated during the most recent 
measurement of incinerator efficiency required by Sec. 60.8. The records 
required by Sec. 60.7 shall identify each such occurrence and its 
duration.

[47 FR 49612, Nov. 1, 1982; 48 FR 1056, Jan. 10, 1983]



Sec. 60.465  Reporting and recordkeeping requirements.

    (a) Where compliance with the numerical limit specified in 
Sec. 60.462(a) (1), (2), or (4) is achieved through the use of low VOC-
content coatings without emission control devices or through the use of 
higher VOC-content coatings in conjunction with emission control 
devices, each owner or operator subject to the provisions of this 
subpart shall include in the initial compliance report required by 
Sec. 60.8 the weighted average of the VOC content of coatings used 
during a period of one calendar month for each affected facility. Where 
compliance with Sec. 60.462(a)(4) is achieved through the intermittent 
use of a control device, reports shall include separate values of the 
weighted average VOC content of coatings used with and without the 
control device in operation.
    (b) Where compliance with Sec. 60.462(a)(2), (3), or (4) is achieved 
through the use of an emission control device that destroys VOC's, each 
owner or operator subject to the provisions of this subpart shall 
include the following data in the initial compliance report required by 
Sec. 60.8:
    (1) The overall VOC destruction rate used to attain compliance with 
Sec. 60.462(a)(2), (3), or (4) and the calculated emission limit used to 
attain compliance with Sec. 60.462(a)(4); and
    (2) The combustion temperature of the thermal incinerator or the gas 
temperature, both upstream and downstream of the incinerator catalyst 
bed, used to attain compliance with Sec. 60.462(a)(2), (3), or (4).
    (c) Following the initial performance test, the owner or operator of 
an affected facility shall identify, record, and submit a written report 
to the Administrator every calendar quarter of each instance in which 
the volume-weighted average of the local mass of VOC's emitted to the 
atmosphere per volume of applied coating solids (N) is greater than the 
limit specified under Sec. 69.462. If no such instances have occurred 
during a particular quarter, a report stating this shall be submitted to 
the Administrator semiannually.
    (d) The owner or operator of each affected facility shall also 
submit reports at the frequency specified in Sec. 60.7(c) when the 
incinerator temperature drops as defined under Sec. 69.464(c). If no 
such periods occur, the owner or operator shall state this in the 
report.
    (e) Each owner or operator subject to the provisions of this subpart 
shall maintain at the source, for a period of at least 2 years, records 
of all data and calculations used to determine monthly VOC emissions 
from each affected facility and to determine the monthly emission limit, 
where applicable. Where compliance is achieved through the use of 
thermal incineration, each owner or operator shall maintain, at the 
source, daily records of the incinerator combustion temperature. If 
catalytic incineration is used, the owner or operator shall maintain at 
the source daily records of the gas temperature, both upstream and 
downstream of the incinerator catalyst bed.

[47 FR 49612, Nov. 1, 1982, as amended at 55 FR 51383, Dec. 13, 1990; 56 
FR 20497, May 3, 1991]



Sec. 60.466  Test methods and procedures.

    (a) The reference methods in appendix A to this part, except as 
provided

[[Page 342]]

under Sec. 60.8(b), shall be used to determine compliance with 
Sec. 60.462 as follows:
    (1) Reference Method 24, or data provided by the formulator of the 
coating for determining the VOC content of each coating as applied to 
the surface of the metal coil. In the event of a dispute, Reference 
Method 24 shall be the reference method. When VOC content of waterborne 
coatings, determined by Reference Method 24, is used to determine 
compliance of affected facilities, the results of the Reference Method 
24 analysis shall be adjusted as described in section 4.4 of Reference 
Method 24;
    (2) Reference Method 25, both for measuring the VOC concentration in 
each gas stream entering and leaving the control device on each stack 
equipped with an emission control device and for measuring the VOC 
concentration in each gas stream emitted directly to the atmosphere;
    (3) Method 1 for sample and velocity traverses;
    (4) Method 2 for velocity and volumetric flow rate;
    (5) Method 3 for gas analysis; and
    (6) Method 4 for stack gas moisture.
    (b) For Method 24, the coating sample must be at least a 1-liter 
sample taken at a point where the sample will be representative of the 
coating as applied to the surface of the metal coil.
    (c) For Method 25, the sampling time for each of three runs is to be 
at least 60 minutes, and the minimum sampling volume is to be at least 
0.003 dry standard cubic meter (DSCM); however, shorter sampling times 
or smaller volumes, when necessitated by process variables or other 
factors, may be approved by the Administrator.
    (d) The Administrator will approve testing of representative stacks 
on a case-by-case basis if the owner or operator can demonstrate to the 
satisfaction of the Administrator that testing of representative stacks 
yields results comparable to those that would be obtained by testing all 
stacks.

[47 FR 49612, Nov. 1, 1982, as amended at 51 FR 22938, June 24, 1986]



Subpart UU--Standards of Performance for Asphalt Processing and Asphalt 
                           Roofing Manufacture

    Source: 47 FR 34143, Aug. 6, 1982, unless otherwise noted.



Sec. 60.470  Applicability and designation of affected facilities.

    (a) The affected facilities to which this subpart applies are each 
saturator and each mineral handling and storage facility at asphalt 
roofing plants; and each asphalt storage tank and each blowing still at 
asphalt processing plants, petroleum refineries, and asphalt roofing 
plants.
    (b) Any saturator or mineral handling and storage facility under 
paragraph (a) of this section that commences construction or 
modification after November 18, 1980, is subject to the requirements of 
this subpart. Any asphalt storage tank or blowing still that processes 
and/or stores asphalt used for roofing only or for roofing and other 
purposes, and that commences construction or modification after November 
18, 1980, is subject to the requirements of this subpart.

Any asphalt storage tank or blowing still that processes and/or stores 
only nonroofing asphalts and that commences construction or modification 
after May 26, 1981, is subject to the requirements of this subpart.



Sec. 60.471  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    Afterburner (A/B) means an exhaust gas incinerator used to control 
emissions of particulate matter.
    Asphalt processing means the storage and blowing of asphalt.
    Asphalt processing plant means a plant which blows asphalt for use 
in the manufacture of asphalt products.
    Asphalt roofing plant means a plant which produces asphalt roofing 
products (shingles, roll roofing, siding, or saturated felt).

[[Page 343]]

    Asphalt storage tank means any tank used to store asphalt at asphalt 
roofing plants, petroleum refineries, and asphalt processing plants. 
Storage tanks containing cutback asphalts (asphalts diluted with 
solvents to reduce viscosity for low temperature applications) and 
emulsified asphalts (asphalts dispersed in water with an emulsifying 
agent) are not subject to this regulation.
    Blowing still means the equipment in which air is blown through 
asphalt flux to change the softening point and penetration rate.
    Catalyst means means a substance which, when added to asphalt flux 
in a blowing still, alters the penetrating-softening point relationship 
or increases the rate of oxidation of the flux.
    Coating blow means the process in which air is blown through hot 
asphalt flux to produce coating asphalt. The coating blow starts when 
the air is turned on and stops when the air is turned off.
    Electrostatic precipitator (ESP) means an air pollution control 
device in which solid or liquid particulates in a gas stream are charged 
as they pass through an electric field and precipitated on a collection 
suface.
    High velocity air filter (HVAF) means an air pollution control 
filtration device for the removal of sticky, oily, or liquid aerosol 
particulate matter from exhaust gas streams.
    Mineral handling and storage facility means the areas in asphalt 
roofing plants in which minerals are unloaded from a carrier, the 
conveyor transfer points between the carrier and the storage silos, and 
the storage silos.
    Saturator means the equipment in which asphalt is applied to felt to 
make asphalt roofing products. The term saturator includes the 
saturator, wet looper, and coater.



Sec. 60.472  Standards for particulate matter.

    (a) On and after the date on which Sec. 60.8(b) requires a 
performance test to be completed, no owner or operator subject to the 
provisions of this subpart shall cause to be discharged into the 
atmosphere from any saturator:
    (1) Particulate matter in excess of: (i) 0.04 kilograms of 
particulate per megagram of asphalt shingle or mineral-surfaced roll 
roofing produced, or (ii) 0.4 kilograms per megagram of saturated felt 
or smooth-surfaced roll roofing produced;
    (2) Exhaust gases with opacity greater than 20 percent; and
    (3) Any visible emissions from a saturator capture system for more 
than 20 percent of any period of consecutive valid observations totaling 
60 minutes. Saturators that were constructed before November 18, 1980, 
and that have not been reconstructed since that date and that become 
subject to these standards through modification are exempt from the 
visible emissions standard. Saturators that have been newly constructed 
or reconstructed since November 18, 1980 are subject to the visible 
emissions standard.
    (b) On and after the date on which Sec. 60.8(b) requires a 
performance test to be completed, no owner or operator subject to the 
provisions of this subpart shall cause to be discharged into the 
atmosphere from any blowing still:
    (1) Particulate matter in excess of 0.67 kilograms of particulate 
per megagram of asphalt charged to the still when a catalyst is added to 
the still; and
    (2) Particulate matter in excess of 0.71 kilograms of particulate 
per megagram of asphalt charged to the still when a catalyst is added to 
the still and when No. 6 fuel oil is fired in the afterburner; and
    (3) Particulate matter in excess of 0.60 kilograms of particulate 
per megagram of asphalt charged to the still during blowing without a 
catalyst; and
    (4) Particulate matter in excess of 0.64 kilograms of particulate 
per megagram of asphalt charged to the still during blowing without a 
catalyst and when No. 6 fuel oil is fired in the afterburner; and
    (5) Exhaust gases with an opacity greater than 0 percent unless an 
opacity limit for the blowing still when fuel oil is used to fire the 
afterburner has been established by the Administrator in accordance with 
the procedures in Sec. 60.474(k).

[[Page 344]]

    (c) Within 60 days after achieving the maximum production rate at 
which the affected facility will be operated, but not later than 180 
days after initial startup of such facility, no owner or operator 
subject to the provisions of this subpart shall cause to be discharged 
into the atmosphere from any asphalt storage tank exhaust gases with 
opacity greater than 0 percent, except for one consecutive 15-minute 
period in any 24-hour period when the transfer lines are being blown for 
clearing. The control device shall not be bypassed during this 15-minute 
period. If, however, the emissions from any asphalt storage tank(s) are 
ducted to a control device for a saturator, the combined emissions shall 
meet the emission limit contained in paragraph (a) of this section 
during the time the saturator control device is operating. At any other 
time the asphalt storage tank(s) must meet the opacity limit specified 
above for storage tanks.
    (d) Within 60 days after achieving the maximum production rate at 
which the affected facility will be operated, but not later than 180 
days after initial startup of such facility, no owner or operator 
subject to the provisions of this subpart shall cause to be discharged 
into the atmosphere from any mineral handling and storage facility 
emissions with opacity greater than 1 percent.



Sec. 60.473  Monitoring of operations.

    (a) The owner or operator subject to the provisions of this subpart, 
and using either an electrostatic precipitator or a high velocity air 
filter to meet the emission limit in Sec. 60.472(a)(1) and/or (b)(1) 
shall continuously monitor and record the temperature of the gas at the 
inlet of the control device. The temperature monitoring instrument shall 
have an accuracy of plus-minus15  deg.C over its range.
    (b) The owner or operator subject to the provisions of this subpart 
and using an afterburner to meet the emission limit in Sec. 60.472(a)(1) 
and/or (b)(1) shall continuously monitor and record the temperature in 
the combustion zone of the afterburner. The monitoring instrument shall 
have an accuracy of plus-minus10  deg.C over its range.
    (c) An owner or operator subject to the provisions of this subpart 
and using a control device not mentioned in paragraphs (a) and (b) of 
this section shall provide to the Administrator information describing 
the operation of the control device and the process parameter(s) which 
would indicate proper operation and maintenance of the device. The 
Administrator may require continuous monitoring and will determine the 
process parameters to be monitored.
    (d) The industry is exempted from the quarterly reports required 
under Sec. 60.7(c). The owner/operator is required to record and report 
the operating temperature of the control device during the performance 
test and, as required by Sec. 60.7(d), maintain a file of the 
temperature monitoring results for at least two years.



Sec. 60.474  Test methods and procedures.

    (a) For saturators, the owner or operator shall conduct performance 
tests required in Sec. 60.8 as follows:
    (1) If the final product is shingle or mineral-surfaced roll 
roofing, the tests shall be conducted while 106.6-kg (235-lb) shingle is 
being produced.
    (2) If the final product is saturated felt or smooth-surfaced roll 
roofing, the tests shall be conducted while 6.8-kg (15-lb) felt is being 
produced.
    (3) If the final product is fiberglass shingle, the test shall be 
conducted while a nominal 100-kg (220-lb) shingle is being produced.
    (b) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (c) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.472 as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:

E=(cs Qsd)/(PK)
where:
E=emission rate of particulate matter, kg/Mg.
cs=concentration of particulate matter, g/dscm (g/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).

[[Page 345]]

P=asphalt roofing production rate or asphalt charging rate, Mg/hr (ton/
          hr).
K=conversion factor, 1000 g/kg [907.2/(g-Mg)/(kg-ton)].

    (2) Method 5A shall be used to determine the particulate matter 
concentration (cs) and volumetric flow rate (Qsd) 
of the effluent gas. For a saturator, the sampling time and sample 
volume for each run shall be at least 120 minutes and 3.00 dscm (106 
dscf), and for the blowing still, at least 90 minutes or the duration of 
the coating blow or non-coating blow, whichever is greater, and 2.25 
dscm (79.4 dscf).
    (3) For the saturator, the asphalt roofing production rate (P) for 
each run shall be determined as follows: The amount of asphalt roofing 
produced on the shingle or saturated felt process lines shall be 
obtained by direct measurement. The asphalt roofing production rate is 
the amount produced divided by the time taken for the run.
    (4) For the blowing still, the asphalt charging rate (P) shall be 
computed for each run using the following equation:

P=(Vd)/(K' )

where:
P=asphalt charging rate to blowing still, Mg/hr (ton/hr).
V=volume of asphalt charged, m3 (ft3).
d=density of asphalt, kg/m3 (llb/ft3).
K'=conversion factor, 1000 kg/Mg (2000 lb/ton).
=duration of test run, hr.

    (i) The volume (V) of asphalt charged shall be measured by any means 
accurate to within 10 percent.
    (ii) The density (d) of the asphalt shall be computed using the 
following equation:

        d=K'' (1056.1-0.6176  deg.C)
where:
 deg.C=temperature at the start of the blow,  deg.C.
K''=1.0 [0.06243 (lb-m3)/(ft3-kg).

    (5) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (d) The Administrator will determine compliance with the standards 
in Sec. 60.472(a)(3) by using Method 22, modified so that readings are 
recorded every 15 seconds for a period of consecutive observations 
during representative conditions (in accordance with Sec. 60.8(c)) 
totaling 60 minutes. A performance test shall consist of one run.
    (e) The owner or operator shall use the monitoring device in 
Sec. 60.473 (a) or (b) to monitor and record continuously the 
temperature during the particulate matter run and shall report the 
results to the Administrator with the performance test results.
    (f) If at a later date the owner or operator believes the emission 
limits in Sec. 60.472 (a) and (b) are being met even though the 
temperature measured in accordance with Sec. 60.473 (a) and (b) is 
exceeding that measured during the performance test, he may submit a 
written request to the Administrator to repeat the performance test and 
procedure outlined in paragraph (c) of this section.
    (g) If fuel oil is to be used to fire an afterburner used to control 
emissions from a blowing still, the owner or operator may petition the 
Administrator in accordance with Sec. 60.11(e) of the General Provisions 
to establish an opacity standard for the blowing still that will be the 
opacity standard when fuel oil is used to fire the afterburner. To 
obtain this opacity standard, the owner or operator must request the 
Administrator to determine opacity during an initial, or subsequent, 
performance test when fuel oil is used to fire the afterburner. Upon 
receipt of the results of the performance test, the Administrator will 
make a finding concerning compliance with the mass standard for the 
blowing still. If the Administrator finds that the facility was in 
compliance with the mass standard during the performance test but failed 
to meet the zero opacity standard, the Administrator will establish and 
promulgate in the Federal Register an opacity standard for the blowing 
still that will be the opacity standard when fuel oil is used to fire 
the afterburner. When the afterburner is fired with natural gas, the 
zero percent opacity remains the applicable opacity standard.

[54 FR 6677, Feb. 14, 1989, as amended 54 FR 27016, June 27, 1989]

[[Page 346]]



 Subpart VV--Standards of Performance for Equipment Leaks of VOC in the 
           Synthetic Organic Chemicals Manufacturing Industry

    Source: 48 FR 48335, Oct. 18, 1983, unless otherwise noted.



Sec. 60.480  Applicability and designation of affected facility.

    (a)(1) The provisions of this subpart apply to affected facilities 
in the synthetic organic chemicals manufacturing industry.
    (2) The group of all equipment (defined in Sec. 60.481) within a 
process unit is an affected facility.
    (b) Any affected facility under paragraph (a) of this section that 
commences construction or modification after January 5, 1981, shall be 
subject to the requirements of this subpart.
    (c) Addition or replacement of equipment for the purpose of process 
improvement which is accomplished without a capital expenditure shall 
not by itself be considered a modification under this subpart.
    (d)(1) If an owner or operator applies for one or more of the 
exemptions in this paragraph, then the owner or operator shall maintain 
records as required in Sec. 60.486(i).
    (2) Any affected facility that has the design capacity to produce 
less than 1,000 Mg/yr is exempt from Sec. 60.482.
    (3) If an affected facility produces heavy liquid chemicals only 
from heavy liquid feed or raw materials, then it is exempt from 
Sec. 60.482.
    (4) Any affected facility that produces beverage alcohol is exempt 
from Sec. 60.482.
    (5) Any affected facility that has no equipment in VOC service is 
exempt from Sec. 60.482.

[48 FR 48335, Oct. 18, 1983, as amended at 49 FR 22607, May 30, 1984]



Sec. 60.481  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act or in subpart A of part 60, and the 
following terms shall have the specific meanings given them.
    Capital expenditure means, in addition to the definition in 40 CFR 
60.2, an expenditure for a physical or operational change to an existing 
facility that:
    (a) Exceeds P, the product of the facility's replacement cost, R, 
and an adjusted annual asset guideline repair allowance, A, as reflected 
by the following equation: P = R  x  A, where
    (1) The adjusted annual asset guideline repair allowance, A, is the 
product of the percent of the replacement cost, Y, and the applicable 
basic annual asset guideline repair allowance, B, as reflected by the 
following equation:

                       A = Y  x  (B  100);

    (2) The percent Y is determined from the following equation: Y = 1.0 
- 0.575 log X, where X is 1982 minus the year of construction; and
    (3) The applicable basic annual asset guideline repair allowance, B, 
is selected from the following table consistent with the applicable 
subpart:

                 Table for Determining Applicable for B
------------------------------------------------------------------------
                                                              Value of B
               Subpart applicable to facility                 to be used
                                                             in equation
------------------------------------------------------------------------
VV.........................................................         12.5
DDD........................................................         12.5
GGG........................................................          7.0
KKK........................................................          4.5
------------------------------------------------------------------------

    Closed vent system means a system that is not open to the atmosphere 
and that is composed of piping, connections, and, if necessary, flow-
inducing devices that transport gas or vapor from a piece or pieces of 
equipment to a control device. If gas or vapor from regulated equipment 
is routed to a process (e.g., to a petroleum refinery fuel gas system), 
the process shall not be considered a closed vent system and is not 
subject to the closed vent system standards.
    Connector means flanged, screwed, welded, or other joined fittings 
used to connect two pipe lines or a pipe line and a piece of process 
equipment.
    Control device means an enclosed combustion device, vapor recovery 
system, or flare.
    Distance piece means an open or enclosed casing through which the 
piston rod travels, separating the compressor cylinder from the 
crankcase.

[[Page 347]]

    Double block and bleed system means two block valves connected in 
series with a bleed valve or line that can vent the line between the two 
block valves.
    Equipment means each pump, compressor, pressure relief device, 
sampling connection system, open-ended valve or line, valve, and flange 
or other connector in VOC service and any devices or systems required by 
this subpart.
    First attempt at repair means to take rapid action for the purpose 
of stopping or reducing leakage of organic material to atmosphere using 
best practices.
    In gas/vapor service means that the piece of equipment contains 
process fluid that is in the gaseous state at operating conditions.
    In heavy liquid service means that the piece of equipment is not in 
gas/vapor service or in light liquid service.
    In light liquid service means that the piece of equipment contains a 
liquid that meets the conditions specified in Sec. 60.485(e).
    In-situ sampling systems means nonextractive samplers or in-line 
samplers.
    In vacuum service means that equipment is operating at an internal 
pressure which is at least 5 kilopascals (kPa) below ambient pressure.
    In VOC service means that the piece of equipment contains or 
contacts a process fluid that is at least 10 percent VOC by weight. (The 
provisions of Sec. 60.485(d) specify how to determine that a piece of 
equipment is not in VOC service.)
    Liquids dripping means any visible leakage from the seal including 
spraying, misting, clouding, and ice formation.
    Open-ended valve or line means any valve, except safety relief 
valves, having one side of the valve seat in contact with process fluid 
and one side open to the atmosphere, either directly or through open 
piping.
    Pressure release means the emission of materials resulting from 
system pressure being greater than set pressure of the pressure relief 
device.
    Process improvement means routine changes made for safety and 
occupational health requirements, for energy savings, for better 
utility, for ease of maintenance and operation, for correction of design 
deficiencies, for bottleneck removal, for changing product requirements, 
or for environmental control.
    Process unit means components assembled to produce, as intermediate 
or final products, one or more of the chemicals listed in Sec. 60.489 of 
this part. A process unit can operate independently if supplied with 
sufficient feed or raw materials and sufficient storage facilities for 
the product.
    Process unit shutdown means a work practice or operational procedure 
that stops production from a process unit or part of a process unit. An 
unscheduled work practice or operational procedure that stops production 
from a process unit or part of a process unit for less than 24 hours is 
not a process unit shutdown. The use of spare equipment and technically 
feasible bypassing of equipment without stopping production are not 
process unit shutdowns.
    Quarter means a 3-month period; the first quarter concludes on the 
last day of the last full month during the 180 days following initial 
startup.
    Repaired means that equipment is adjusted, or otherwise altered, in 
order to eliminate a leak as indicated by one of the following: an 
instrument reading or 10,000 ppm or greater, indication of liquids 
dripping, or indication by a sensor that a seal or barrier fluid system 
has failed.
    Replacement cost means the capital needed to purchase all the 
depreciable components in a facility.
    Sensor means a device that measures a physical quantity or the 
change in a physical quantity such as temperature, pressure, flow rate, 
pH, or liquid level.
    Synthetic organic chemicals manufacturing industry means the 
industry that produces, as intermediates or final products, one or more 
of the chemicals listed in Sec. 60.489.
    Volatile organic compounds or VOC means, for the purposes of this 
subpart, any reactive organic compounds as defined in Sec. 60.2 
Definitions.

[48 FR 48335, Oct. 18, 1983, as amended at 49 FR 22607, May 30, 1984; 49 
FR 26738, June 29, 1984; 60 FR 43258, Aug. 18, 1995]



Sec. 60.482-1  Standards: General.

    (a) Each owner or operator subject to the provisions of this subpart 
shall

[[Page 348]]

demonstrate compliance with the requirements of Secs. 60.482-1 to 
60.482-10 for all equipment within 180 days of initial startup.
    (b) Compliance with Secs. 60.482-1 to 60.482-10 will be determined 
by review of records and reports, review of performance test results, 
and inspection using the methods and procedures specified in 
Sec. 60.485.
    (c)(1) An owner or operator may request a determination of 
equivalence of a means of emission limitation to the requirements of 
Secs. 60.482-2, 60.482-3, 60.482-5, 60.482-6, 60.482-7, 60.482-8, and 
60.482-10 as provided in Sec. 60.484.
    (2) If the Administrator makes a determination that a means of 
emission limitation is at least equivalent to the requirements of 
Secs. 60.482-2, 60.482-3, 60.482-5, 60.482-6, 60.482-7, 60.482-8, or 
60.482-10, an owner or operator shall comply with the requirements of 
that determination.
    (d) Equipment that is in vacuum service is excluded from the 
requirements of Secs. 60.482-2 to 60.482-10 if it is identified as 
required in Sec. 60.486(e)(5).

[48 FR 48335, Oct. 18, 1983, as amended at 49 FR 22608, May 30, 1984]



Sec. 60.482-2  Standards: Pumps in light liquid service.

    (a)(1) Each pump in light liquid service shall be monitored monthly 
to detect leaks by the methods specified in Sec. 60.485(b), except as 
provided in Sec. 60.482-1(c) and paragraphs (d), (e), and (f) of this 
section.
    (2) Each pump in light liquid service shall be checked by visual 
inspection each calendar week for indications of liquids dripping from 
the pump seal.
    (b)(1) If an instrument reading of 10,000 ppm or greater is 
measured, a leak is detected.
    (2) If there are indications of liquids dripping from the pump seal, 
a leak is detected.
    (c)(1) When a leak is detected, it shall be repaired as soon as 
practicable, but not later than 15 calendar days after it is detected, 
except as provided in Sec. 60.482-9.
    (2) A first attempt at repair shall be made no later than 5 calendar 
days after each leak is detected.
    (d) Each pump equipped with a dual mechanical seal system that 
includes a barrier fluid system is exempt from the requirements of 
paragraph (a), Provided the following requirements are met:
    (1) Each dual mechanical seal system is--
    (i) Operated with the barrier fluid at a pressure that is at all 
times greater than the pump stuffing box pressure; or
    (ii) Equipment with a barrier fluid degassing reservoir that is 
connected by a closed vent system to a control device that complies with 
the requirements of Sec. 60.482-10; or
    (iii) Equipped with a system that purges the barrier fluid into a 
process stream with zero VOC emissions to the atmosphere.
    (2) The barrier fluid system is in heavy liquid service or is not in 
VOC service.
    (3) Each barrier fluid system is equipped with a sensor that will 
detect failure of the seal system, the barrier fluid system, or both.
    (4) Each pump is checked by visual inspection, each calendar week, 
for indications of liquids dripping from the pump seals.
    (5)(i) Each sensor as described in paragraph (d)(3) is checked daily 
or is equipped with an audible alarm, and
    (ii) The owner or operator determines, based on design 
considerations and operating experience, a criterion that indicates 
failure of the seal system, the barrier fluid system, or both.
    (6)(i) If there are indications of liquids dripping from the pump 
seal or the sensor indicates failure of the seal system, the barrier 
fluid system, or both based on the criterion determined in paragraph 
(d)(5)(ii), a leak is detected.
    (ii) When a leak is detected, it shall be repaired as soon as 
practicable, but not later than 15 calendar days after it is detected, 
except as provided in Sec. 60.482-9.
    (iii) A first attempt at repair shall be made no later than 5 
calendar days after each leak is detected.
    (e) Any pump that is designated, as described in Sec. 60.486(e)(1) 
and (2), for no detectable emission, as indicated by an instrument 
reading of less than 500 ppm above background, is exempt from the 
requirements of paragraphs (a), (c), and (d) if the pump:
    (1) Has no externally actuated shaft penetrating the pump housing,

[[Page 349]]

    (2) Is demonstrated to be operating with no detectable emissions as 
indicated by an instrument reading of less than 500 ppm above background 
as measured by the methods specified in Sec. 60.485(c), and
    (3) Is tested for compliance with paragraph (e)(2) initially upon 
designation, annually, and at other times requested by the 
Administrator.
    (f) If any pump is equipped with a closed vent system capable of 
capturing and transporting any leakage from the seal or seals to a 
control device that complies with the requirements of Sec. 60.482-10, it 
is exempt from the paragraphs (a) through (e).



Sec. 60.482-3  Standards: Compressors.

    (a) Each compressor shall be equipped with a seal system that 
includes a barrier fluid system and that prevents leakage of VOC to the 
atmosphere, except as provided in Sec. 60.482-1(c) and paragraph (h) and 
(i) of this section.
    (b) Each compressor seal system as required in paragraph (a) shall 
be:
    (1) Operated with the barrier fluid at a pressure that is greater 
than the compressor stuffing box pressure; or
    (2) Equipped with a barrier fluid system that is connected by a 
closed vent system to a control device that complies with the 
requirements of Sec. 60.482-10; or
    (3) Equipped with a system that purges the barrier fluid into a 
process stream with zero VOC emissions to the atmosphere.
    (c) The barrier fluid system shall be in heavy liquid service or 
shall not be in VOC service.
    (d) Each barrier fluid system as described in paragraph (a) shall be 
equipped with a sensor that will detect failure of the seal system, 
barrier fluid system, or both.
    (e)(1) Each sensor as required in paragraph (d) shall be checked 
daily or shall be equipped with an audible alarm.
    (2) The owner or operator shall determine, based on design 
considerations and operating experience, a criterion that indicates 
failure of the seal system, the barrier fluid system, or both.
    (f) If the sensor indicates failure of the seal system, the barrier 
system, or both based on the criterion determined under paragraph 
(e)(2), a leak is detected.
    (g)(1) When a leak is detected, it shall be repaired as soon as 
practicable, but not later than 15 calendar days after it is detected, 
except as provided in Sec. 60.482-9.
    (2) A first attempt at repair shall be made no later than 5 calendar 
days after each leak is detected.
    (h) A compressor is exempt from the requirements of paragraphs (a) 
and (b), if it is equipped with a closed vent system capable of 
capturing and transporting any leakage from the seal to a control device 
that complies with the requirements of Sec. 60.482-10, except as 
provided in paragraph (i) of this section.
    (i) Any compressor that is designated, as described in 
Sec. 60.486(e) (1) and (2), for no detectable emissions, as indicated by 
an instrument reading of less than 500 ppm above background, is exempt 
from the requirements of paragraphs (a)-(h) if the compressor:
    (1) Is demonstrated to be operating with no detectable emissions, as 
indicated by an instrument reading of less than 500 ppm above 
background, as measured by the methods specified in Sec. 60.485(c); and
    (2) Is tested for compliance with paragraph (i)(1) initially upon 
designation, annually, and at other times requested by the 
Administrator.
    (j) Any existing reciprocating compressor in a process unit which 
becomes an affected facility under provisions of Sec. 60.14 or 
Sec. 60.15 is exempt from Sec. 60.482(a), (b), (c), (d), (e), and (h), 
provided the owner or operator demonstrates that recasting the distance 
piece or replacing the compressor are the only options available to 
bring the compressor into compliance with the provisions of paragraphs 
(a) through (e) and (h) of this section.



Sec. 60.482-4  Standards: Pressure relief devices in gas/vapor service.

    (a) Except during pressure releases, each pressure relief device in 
gas/vapor service shall be operated with no detectable emissions, as 
indicated by an instrument reading of less than 500 ppm above 
background, as determined by the methods specified in Sec. 60.485(c).

[[Page 350]]

    (b)(1) After each pressure release, the pressure relief device shall 
be returned to a condition of no detectable emissions, as indicated by 
an instrument reading of less than 500 ppm above background, as soon as 
practicable, but no later than 5 calendar days after the pressure 
release, except as provided in Sec. 60.482-9.
    (2) No later than 5 calendar days after the pressure release, the 
pressure relief device shall be monitored to confirm the conditions of 
no detectable emissions, as indicated by an instrument reading of less 
than 500 ppm above background, by the methods specified in 
Sec. 60.485(c).
    (c) Any pressure relief device that is equipped with a closed vent 
system capable of capturing and transporting leakage through the 
pressure relief device to a control device as described in Sec. 60.482-
10 is exempted from the requirements of paragraphs (a) and (b).



Sec. 60.482-5  Standards: Sampling connection systems.

    (a) Each sampling connection system shall be equipped with a closed-
purged, closed-loop, or closed-vent system, except as provided in 
Sec. 60.482-1(c).
    (b) Each closed-purge, closed-loop, or closed-vent system as 
required in paragraph (a) of this section shall comply with the 
requirements specified in paragraphs (b)(1) through (b)(3) of this 
section:
    (1) Return the purged process fluid directly to the process line; or
    (2) Collect and recycle the purged process fluid to a process; or
    (3) Be designed and operated to capture and transport all the purged 
process fluid to a control device that complies with the requirements of 
Sec. 60.482-10.
    (c) In situ sampling systems and sampling systems without purges are 
exempt from the requirements of paragraphs (a) and (b) of this section.

[60 FR 43258, Aug. 18, 1995]



Sec. 60.482-6  Standards: Open-ended valves or lines.

    (a)(1) Each open-ended valve or line shall be equipped with a cap, 
blind flange, plug, or a second valve, except as provided in 
Sec. 60.482-1(c).
    (2) The cap, blind flange, plug, or second valve shall seal the open 
end at all times except during operations requiring process fluid flow 
through the open-ended valve or line.
    (b) Each open-ended valve or line equipped with a second valve shall 
be operated in a manner such that the valve on the process fluid end is 
closed before the second valve is closed.
    (c) When a double block-and-bleed system is being used, the bleed 
valve or line may remain open during operations that require venting the 
line between the block valves but shall comply with paragraph (a) at all 
other times.

[48 FR 48335, Oct. 18, 1983, as amended at 49 FR 22607, May 30, 1984]



Sec. 60.482-7  Standards: Valves in gas/vapor service and in light liquid service.

    (a) Each valve shall be monitored monthly to detect leaks by the 
methods specified in Sec. 60.485(b) and shall comply with paragraphs (b) 
through (e), except as provided in paragraphs (f), (g), and (h), 
Sec. 60.483-1, 2, and Sec. 60.482-1(c).
    (b) If an instrument reading of 10,000 ppm or greater is measured, a 
leak is detected.
    (c)(1) Any valve for which a leak is not detected for 2 successive 
months may be monitored the first month of every quarter, beginning with 
the next quarter, until a leak is detected.
    (2) If a leak is detected, the valve shall be monitored monthly 
until a leak is not detected for 2 successive months.
    (d)(1) When a leak is detected, it shall be repaired as soon as 
practicable, but no later than 15 calendar days after the leak is 
detected, except as provided in Sec. 60.482-9.
    (2) A first attempt at repair shall be made no later than 5 calendar 
days after each leak is detected.
    (e) First attempts at repair include, but are not limited to, the 
following best practices where practicable:
    (1) Tightening of bonnet bolts;
    (2) Replacement of bonnet bolts;
    (3) Tightening of packing gland nuts;
    (4) Injection of lubricant into lubricated packing.

[[Page 351]]

    (f) Any valve that is designated, as described in Sec. 60.486(e)(2), 
for no detectable emissions, as indicated by an instrument reading of 
less than 500 ppm above background, is exempt from the requirements of 
paragraph (a) if the valve:
    (1) Has no external actuating mechanism in contact with the process 
fluid,
    (2) Is operated with emissions less than 500 ppm above background as 
determined by the method specified in Sec. 60.485(c), and
    (3) Is tested for compliance with paragraph (f)(2) initially upon 
designation, annually, and at other times requested by the 
Administrator.
    (g) Any valve that is designated, as described in Sec. 60.486(f)(1), 
as an unsafe-to-monitor valve is exempt from the requirements of 
paragraph (a) if:
    (1) The owner or operator of the valve demonstrates that the valve 
is unsafe to monitor because monitoring personnel would be exposed to an 
immediate danger as a consequence of complying with paragraph (a), and
    (2) The owner or operator of the valve adheres to a written plan 
that requires monitoring of the valve as frequently as practicable 
during safe-to-monitor times.
    (h) Any valve that is designated, as described in Sec. 60.486(f)(2), 
as a difficult-to-monitor valve is exempt from the requirements of 
paragraph (a) if:
    (1) The owner or operator of the valve demonstrates that the valve 
cannot be monitored without elevating the monitoring personnel more than 
2 meters above a support surface.
    (2) The process unit within which the valve is located either 
becomes an affected facility through Sec. 60.14 or Sec. 60.15 or the 
owner or operator designates less than 3.0 percent of the total number 
of valves as difficult-to-monitor, and
    (3) The owner or operator of the valve follows a written plan that 
requires monitoring of the valve at least once per calendar year.

[48 FR 48335, Oct. 18, 1983, as amended at 49 FR 22608, May 30, 1984]



Sec. 60.482-8  Standards: Pumps and valves in heavy liquid service, pressure relief devices in light liquid or heavy liquid service, and flanges and other 
          connectors.

    (a) Pumps and valves in heavy liquid service, pressure relief 
devices in light liquid or heavy liquid service, and flanges and other 
connectors shall be monitored within 5 days by the method specified in 
Sec. 60.485(b) if evidence of a potential leak is found by visual, 
audible, olfactory, or any other detection method.
    (b) If an instrument reading of 10,000 ppm or greater is measured, a 
leak is detected.
    (c)(1) When a leak is detected, it shall be repaired as soon as 
practicable, but not later than 15 calendar days after it is detected, 
except as provided in Sec. 60.482-9.
    (2) The first attempt at repair shall be made no later than 5 
calendar days after each leak is detected.
    (d) First attempts at repair include, but are not limited to, the 
best practices described under Sec. 60.482-7(e).



Sec. 60.482-9  Standards: Delay of repair.

    (a) Delay of repair of equipment for which leaks have been detected 
will be allowed if the repair is technically infeasible without a 
process unit shutdown. Repair of this equipment shall occur before the 
end of the next process unit shutdown.
    (b) Delay of repair of equipment will be allowed for equipment which 
is isolated from the process and which does not remain in VOC service.
    (c) Delay of repair for valves will be allowed if:
    (1) The owner or operator demonstrates that emissions of purged 
material resulting from immediate repair are greater than the fugitive 
emissions likely to result from delay of repair, and
    (2) When repair procedures are effected, the purged material is 
collected and destroyed or recovered in a control device complying with 
Sec. 60.482-10.
    (d) Delay of repair for pumps will be allowed if:

[[Page 352]]

    (1) Repair requires the use of a dual mechanical seal system that 
includes a barrier fluid system, and
    (2) Repair is completed as soon as practicable, but not later than 6 
months after the leak was detected.
    (e) Delay of repair beyond a process unit shutdown will be allowed 
for a valve, if valve assembly replacement is necessary during the 
process unit shutdown, valve assembly supplies have been depleted, and 
valve assembly supplies had been sufficiently stocked before the 
supplies were depleted. Delay of repair beyond the next process unit 
shutdown will not be allowed unless the next process unit shutdown 
occurs sooner than 6 months after the first process unit shutdown.



Sec. 60.482-10  Standards: Closed vent systems and control devices.

    (a) Owners or operators of closed vent systems and control devices 
used to comply with provisions of this subpart shall comply with the 
provisions of this section.
    (b) Vapor recovery systems (for example, condensers and adsorbers) 
shall be designed and operated to recover the VOC emissions vented to 
them with an efficiency of 95 percent or greater.
    (c) Enclosed combustion devices shall be designed and operated to 
reduce the VOC emissions vented to them with an efficiency of 95 percent 
or greater, or to provide a minimum residence time of 0.75 seconds at a 
minimum temperature of 816  deg.C.
    (d) Flares used to comply with this subpart shall comply with the 
requirements of Sec. 60.18.
    (e) Owners or operators of control devices used to comply with the 
provisions of this subpart shall monitor these control devices to ensure 
that they are operated and maintained in conformance with their designs.
    (f) Except as provided in paragraphs (i) through (k) of this 
section, each closed vent system shall be inspected according to the 
procedures and schedule specified in paragraphs (f)(1) and (f)(2) of 
this section.
    (1) If the vapor collection system or closed vent system is 
constructed of hard-piping, the owner or operator shall comply with the 
requirements specified in paragraphs (f)(1)(i) and (f)(1)(ii) of this 
section:
    (i) Conduct an initial inspection according to the procedures in 
Sec. 60.485(b); and
    (ii) Conduct annual visual inspections for visible, audible, or 
olfactory indications of leaks.
    (2) If the vapor collection system or closed vent system is 
constructed of ductwork, the owner or operator shall:
    (i) Conduct an initial inspection according to the procedures in 
Sec. 60.485(b); and
    (ii) Conduct annual inspections according to the procedures in 
Sec. 60.485(b).
    (g) Leaks, as indicated by an instrument reading greater than 500 
parts per million by volume above background or by visual inspections, 
shall be repaired as soon as practicable except as provided in paragraph 
(h) of this section.
    (1) A first attempt at repair shall be made no later than 5 calendar 
days after the leak is detected.
    (2) Repair shall be completed no later than 15 calendar days after 
the leak is detected.
    (h) Delay of repair of a closed vent system for which leaks have 
been detected is allowed if the repair is technically infeasible without 
a process unit shutdown or if the owner or operator determines that 
emissions resulting from immediate repair would be greater than the 
fugitive emissions likely to result from delay of repair. Repair of such 
equipment shall be complete by the end of the next process unit 
shutdown.
    (i) If a vapor collection system or closed vent system is operated 
under a vacuum, it is exempt from the inspection requirements of 
paragraphs (f)(1)(i) and (f)(2) of this section.
    (j) Any parts of the closed vent system that are designated, as 
described in paragraph (l)(1) of this section, as unsafe to inspect are 
exempt from the inspection requirements of paragraphs (f)(1)(i) and 
(f)(2) of this section if they comply with the requirements specified in 
paragraphs (j)(1) and (j)(2) of this section:
    (1) The owner or operator determines that the equipment is unsafe to 
inspect because inspecting personnel would be exposed to an imminent or 
potential

[[Page 353]]

danger as a consequence of complying with paragraphs (f)(1)(i) or (f)(2) 
of this section; and
    (2) The owner or operator has a written plan that requires 
inspection of the equipment as frequently as practicable during safe-to-
inspect times.
    (k) Any parts of the closed vent system that are designated, as 
described in paragraph (l)(2) of this section, as difficult to inspect 
are exempt from the inspection requirements of paragraphs (f)(1)(i) and 
(f)(2) of this section if they comply with the requirements specified in 
paragraphs (k)(1) through (k)(3) of this section:
    (1) The owner or operator determines that the equipment cannot be 
inspected without elevating the inspecting personnel more than 2 meters 
above a support surface; and
    (2) The process unit within which the closed vent system is located 
becomes an affected facility through Secs. 60.14 or 60.15, or the owner 
or operator designates less than 3.0 percent of the total number of 
closed vent system equipment as difficult to inspect; and
    (3) The owner or operator has a written plan that requires 
inspection of the equipment at least once every 5 years. A closed vent 
system is exempt from inspection if it is operated under a vacuum.
    (l) The owner or operator shall record the information specified in 
paragraphs (l)(1) through (l)(5) of this section.
    (1) Identification of all parts of the closed vent system that are 
designated as unsafe to inspect, an explanation of why the equipment is 
unsafe to inspect, and the plan for inspecting the equipment.
    (2) Identification of all parts of the closed vent system that are 
designated as difficult to inspect, an explanation of why the equipment 
is difficult to inspect, and the plan for inspecting the equipment.
    (3) For each inspection during which a leak is detected, a record of 
the information specified in Sec. 60.486(c).
    (4) For each inspection conducted in accordance with Sec. 60.485(b) 
during which no leaks are detected, a record that the inspection was 
performed, the date of the inspection, and a statement that no leaks 
were detected.
    (5) For each visual inspection conducted in accordance with 
paragraph (f)(1)(ii) of this section during which no leaks are detected, 
a record that the inspection was performed, the date of the inspection, 
and a statement that no leaks were detected.
    (m) Closed vent systems and control devices used to comply with 
provisions of this subpart shall be operated at all times when emissions 
may be vented to them.

[48 FR 48335, Oct. 18, 1983, as amended at 51 FR 2702, Jan. 21, 1986; 60 
FR 43258, Aug. 18, 1995; 61 FR 29878, June 12, 1996]



Sec. 60.483-1  Alternative standards for valves--allowable percentage of valves leaking.

    (a) An owner or operator may elect to comply with an allowable 
percentage of valves leaking of equal to or less than 2.0 percent.
    (b) The following requirements shall be met if an owner or operator 
wishes to comply with an allowable percentage of valves leaking:
    (1) An owner or operator must notify the Administrator that the 
owner or operator has elected to comply with the allowable percentage of 
valves leaking before implementing this alternative standard, as 
specified in Sec. 60.487(b).
    (2) A performance test as specified in paragraph (c) of this section 
shall be conducted initially upon designation, annually, and at other 
times requested by the Administrator.
    (3) If a valve leak is detected, it shall be repaired in accordance 
with Sec. 60.482-7(d) and (e).
    (c) Performance tests shall be conducted in the following manner:
    (1) All valves in gas/vapor and light liquid service within the 
affected facility shall be monitored within 1 week by the methods 
specified in Sec. 60.485(b).
    (2) If an instrument reading of 10,000 ppm or greater is measured, a 
leak is detected.
    (3) The leak percentage shall be determined by dividing the number 
of valves for which leaks are detected by the number of valves in gas/
vapor and light liquid service within the affected facility.
    (d) Owners and operators who elect to comply with this alternative 
standard

[[Page 354]]

shall not have an affected facility with a leak percentage greater than 
2.0 percent.



Sec. 60.483-2  Alternative standards for valves--skip period leak detection and repair.

    (a)(1) An owner or operator may elect to comply with one of the 
alternative work practices specified in paragraphs (b)(2) and (3) of 
this section.
    (2) An owner or operator must notify the Administrator before 
implementing one of the alternative work practices, as specified in 
Sec. 60.487(b).
    (b)(1) An owner or operator shall comply initially with the 
requirements for valves in gas/vapor service and valves in light liquid 
service, as described in Sec. 60.482-7.
    (2) After 2 consecutive quarterly leak detection periods with the 
percent of valves leaking equal to or less than 2.0, an owner or 
operator may begin to skip 1 of the quarterly leak detection periods for 
the valves in gas/vapor and light liquid service.
    (3) After 5 consecutive quarterly leak detection periods with the 
percent of valves leaking equal to or less than 2.0, an owner or 
operator may begin to skip 3 of the quarterly leak detection periods for 
the valves in gas/vapor and light liquid service.
    (4) If the percent of valves leaking is greater than 2.0, the owner 
or operator shall comply with the requirements as described in 
Sec. 60.482-7 but can again elect to use this section.
    (5) The percent of valves leaking shall be determined by dividing 
the sum of valves found leaking during current monitoring and valves for 
which repair has been delayed by the total number of valves subject to 
the requirements of this section.
    (6) An owner or operator must keep a record of the percent of valves 
found leaking during each leak detection period.



Sec. 60.484  Equivalence of means of emission limitation.

    (a) Each owner or operator subject to the provisions of this subpart 
may apply to the Administrator for determination of equivalance for any 
means of emission limitation that achieves a reduction in emissions of 
VOC at least equivalent to the reduction in emissions of VOC achieved by 
the controls required in this subpart.
    (b) Determination of equivalence to the equipment, design, and 
operational requirements of this subpart will be evaluated by the 
following guidelines:
    (1) Each owner or operator applying for an equivalence determination 
shall be responsible for collecting and verifying test data to 
demonstrate equivalence of means of emission limitation.
    (2) The Administrator will compare test data for the means of 
emission limitation to test data for the equipment, design, and 
operational requirements.
    (3) The Administrator may condition the approval of equivalence on 
requirements that may be necessary to assure operation and maintenance 
to achieve the same emission reduction as the equipment, design, and 
operational requirements.
    (c) Determination of equivalence to the required work practices in 
this subpart will be evaluated by the following guidelines:
    (1) Each owner or operator applying for a determination of 
equivalence shall be responsible for collecting and verifying test data 
to demonstrate equivalence of an equivalent means of emission 
limitation.
    (2) For each affected facility for which a determination of 
equivalence is requested, the emission reduction achieved by the 
required work practice shall be demonstrated.
    (3) For each affected facility, for which a determination of 
equivalence is requested, the emission reduction achieved by the 
equivalent means of emission limitation shall be demonstrated.
    (4) Each owner or operator applying for a determination of 
equivalence shall commit in writing to work practice(s) that provide for 
emission reductions equal to or greater than the emission reductions 
achieved by the required work practice.
    (5) The Administrator will compare the demonstrated emission 
reduction for the equivalent means of emission limitation to the 
demonstrated emission reduction for the required work

[[Page 355]]

practices and will consider the commitment in paragraph (c)(4).
    (6) The Administrator may condition the approval of equivalence on 
requirements that may be necessary to assure operation and maintenance 
to achieve the same emission reduction as the required work practice.
    (d) An owner or operator may offer a unique approach to demonstrate 
the equivalence of any equivalent means of emission limitation.
    (e)(1) After a request for determination of equivalence is received, 
the Administrator will publish a notice in the Federal Register and 
provide the opportunity for public hearing if the Administrator judges 
that the request may be approved.
    (2) After notice and opportunity for public hearing, the 
Administrator will determine the equivalence of a means of emission 
limitation and will publish the determination in the Federal Register.
    (3) Any equivalent means of emission limitations approved under this 
section shall constitute a required work practice, equipment, design, or 
operational standard within the meaning of section 111(h)(1) of the 
Clean Air Act.
    (f)(1) Manufacturers of equipment used to control equipment leaks of 
VOC may apply to the Administrator for determination of equivalence for 
any equivalent means of emission limitation that achieves a reduction in 
emissions of VOC achieved by the equipment, design, and operational 
requirements of this subpart.
    (2) The Administrator will make an equivalence determination 
according to the provisions of paragraphs (b), (c), (d), and (e).



Sec. 60.485  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
standards in Secs. 60.482, 60.483, and 60.484 as follows:
    (1) Method 21 shall be used to determine the presence of leaking 
sources. The instrument shall be calibrated before use each day of its 
use by the procedures specified in Method 21. The following calibration 
gases shall be used:
    (i) Zero air (less than 10 ppm of hydrocarbon in air); and
    (ii) A mixture of methane or n-hexane and air at a concentration of 
about, but less than, 10,000 ppm methane or n-hexane.
    (c) The owner or operator shall determine compliance with the no 
detectable emission standards in Secs. 60.482-2(e), 60.482-3(i), 60.482-
4, 60.482-7(f), and 60.482-10(e) as follows:
    (1) The requirements of paragraph (b) shall apply.
    (2) Method 21 shall be used to determine the background level. All 
potential leak interfaces shall be traversed as close to the interface 
as possible. The arithmetic difference between the maximum concentration 
indicates by the instrument and the background level is compared with 
500 ppm for determining compliance.
    (d) The owner or operator shall test each piece of equipment unless 
he demonstrates that a process unit is not in VOC series, i.e., that the 
VOC content would never be reasonably expected to exceed 10 percent by 
weight. For purposes of this demonstration, the following methods and 
procedures shall be used:
    (1) Procedures that conform to the general methods in ASTM E-260, E-
168, E-169 (incorporated by reference--see Sec. 60.17) shall be used to 
determine the percent VOC content in the process fluid that is contained 
in or contacts a piece of equipment.
    (2) Organic compounds that are considered by the Administrator to 
have negligible photochemical reactivity may be excluded from the total 
quantity of organic compounds in determining the VOC content of the 
process fluid.
    (3) Engineering judgment may be used to estimate the VOC content, if 
a piece of equipment had not been shown previously to be in service. If 
the Administrator disagrees with the judgment, paragraphs (d) (1) and 
(2) of this section shall be used to resolve the disagreement.
    (e) The owner or operator shall demonstrate that an equipment is in 
light

[[Page 356]]

liquid service by showing that all the following conditions apply:
    (1) The vapor pressure of one or more of the components is greater 
than 0.3 kPa at 20  deg.C. Standard reference texts or ASTM D-2879 
(incorporated by reference--see Sec. 60.17) shall be used to determine 
the vapor pressures.
    (2) The total concentration of the pure components having a vapor 
pressure greater than 0.3 kPa at 20  deg.C is equal to or greater than 
20 percent by weight.
    (3) The fluid is a liquid at operating conditions.
    (f) Samples used in conjunction with paragraphs (d), (e), and (g) 
shall be representative of the process fluid that is contained in or 
contacts the equipment or the gas being combusted in the flare.
    (g) The owner or operator shall determine compliance with the 
standards of flares as follows:
    (1) Method 22 shall be used to determine visible emissions.
    (2) A thermocouple or any other equivalent device shall be used to 
monitor the presence of a pilot flame in the flare.
    (3) The maximum permitted velocity (Vmax) for air-
assisted flares shall be computed using the following equation:

Vmax=8.706+0.7084 HT

where:

Vmax=maximum permitted velocity, m/sec.
HT=net heating value of the gas being combusted, MJ/scm.

    (4) The net heating value (HT) of the gas being combusted 
in a flare shall be computed as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.037

where:

K=conversion constant, 1.740 x 107 [(g-mole)(MJ)]/
          [(ppm)(scm)(kcal).
Ci=concentration of sample component ``i'', ppm.
Hi=net heat of combustion of sample component ``i'' at 25 
          deg.C and 760 mm Hg, kcal/g-mole.

    (5) Method 18 and ASTM D 2504-67 (incorporated by reference--see 
Sec. 60.17) shall be used to determine the concentration of sample 
component ``i.''
    (6) ASTM D 2382-76 (incorporated by reference--see Sec. 60.17) shall 
be used to determine the net heat of combustion of component ``i'' if 
published values are not available or cannot be calculated.
    (7) Method 2, 2A, 2C, or 2D, as appropriate, shall be used to 
determine the actual exit velocity of a flare. If needed, the 
unobstructed (free) cross-sectional area of the flare tip shall be used.

[54 FR 6678, Feb. 14, 1989, as amended at 54 FR 27016, June 27, 1989]



Sec. 60.486  Recordkeeping requirements.

    (a)(1) Each owner or operator subject to the provisions of this 
subpart shall comply with the recordkeeping requirements of this 
section.
    (2) An owner or operator of more than one affected facility subject 
to the provisions of this subpart may comply with the recordkeeping 
requirements for these facilities in one recordkeeping system if the 
system identifies each record by each facility.
    (b) When each leak is detected as specified in Secs. 60.482-2, 
60.482-3, 60.482-7, 60.482-8, and 60.483-2, the following requirements 
apply:
    (1) A weatherproof and readily visible identification, marked with 
the equipment identification number, shall be attached to the leaking 
equipment.
    (2) The identification on a valve may be removed after it has been 
monitored for 2 successive months as specified in Sec. 60.482-7(c) and 
no leak has been detected during those 2 months.
    (3) The identification on equipment except on a valve, may be 
removed after it has been repaired.
    (c) When each leak is detected as specified in Secs. 60.482-2, 
60.482-3, 60.482-7, 60.482-8, and 60.483-2, the following information 
shall be recorded in a log and shall be kept for 2 years in a readily 
accessible location:
    (1) The instrument and operator identification numbers and the 
equipment identification number.
    (2) The date the leak was detected and the dates of each attempt to 
repair the leak.
    (3) Repair methods applied in each attempt to repair the leak.
    (4) ``Above 10,000'' if the maximum instrument reading measured by 
the

[[Page 357]]

methods specified in Sec. 60.485(a) after each repair attempt is equal 
to or greater than 10,000 ppm.
    (5) ``Repair delayed'' and the reason for the delay if a leak is not 
repaired within 15 calendar days after discovery of the leak.
    (6) The signature of the owner or operator (or designate) whose 
decision it was that repair could not be effected without a process 
shutdown.
    (7) The expected date of successful repair of the leak if a leak is 
not repaired within 15 days.
    (8) Dates of process unit shutdown that occur while the equipment is 
unrepaired.
    (9) The date of successful repair of the leak.
    (d) The following information pertaining to the design requirements 
for closed vent systems and control devices described in Sec. 60.482-10 
shall be recorded and kept in a readily accessible location:
    (1) Detailed schematics, design specifications, and piping and 
instrumentation diagrams.
    (2) The dates and descriptions of any changes in the design 
specifications.
    (3) A description of the parameter or parameters monitored, as 
required in Sec. 60.482-10(e), to ensure that control devices are 
operated and maintained in conformance with their design and an 
explanation of why that parameter (or parameters) was selected for the 
monitoring.
    (4) Periods when the closed vent systems and control devices 
required in Secs. 60.482-2, 60.482-3, 60.482-4, and 60.482-5 are not 
operated as designed, including periods when a flare pilot light does 
not have a flame.
    (5) Dates of startups and shutdowns of the closed vent systems and 
control devices required in Secs. 60.482-2, 60.482-3, 60.482-4, and 
60.482-5.
    (e) The following information pertaining to all equipment subject to 
the requirements in Secs. 60.482-1 to 60.482-10 shall be recorded in a 
log that is kept in a readily accessible location:
    (1) A list of identification numbers for equipment subject to the 
requirements of this subpart.
    (2)(i) A list of identification numbers for equipment that are 
designated for no detectable emissions under the provisions of 
Secs. 60.482-2(e), 60.482-3(i) and 60.482-7(f).
    (ii) The designation of equipment as subject to the requirements of 
Sec. 60.482-2(e), Sec. 60.482-3(i), or Sec. 60.482-7(f) shall be signed 
by the owner or operator.
    (3) A list of equipment identification numbers for pressure relief 
devices required to comply with Sec. 60.482-4.
    (4)(i) The dates of each compliance test as required in 
Secs. 60.482-2(e), 60.482-3(i), 60.482-4, and 60.482-7(f).
    (ii) The background level measured during each compliance test.
    (iii) The maximum instrument reading measured at the equipment 
during each compliance test.
    (5) A list of identification numbers for equipment in vacuum 
service.
    (f) The following information pertaining to all valves subject to 
the requirements of Sec. 60.482-7(g) and (h) shall be recorded in a log 
that is kept in a readily accessible location:
    (1) A list of identification numbers for valves that are designated 
as unsafe-to-monitor, an explanation for each valve stating why the 
valve is unsafe-to-monitor, and the plan for monitoring each valve.
    (2) A list of identification numbers for valves that are designated 
as difficult-to-monitor, an explanation for each valve stating why the 
valve is difficult-to-monitor, and the schedule for monitoring each 
valve.
    (g) The following information shall be recorded for valves complying 
with Sec. 60.483-2:
    (1) A schedule of monitoring.
    (2) The percent of valves found leaking during each monitoring 
period.
    (h) The following information shall be recorded in a log that is 
kept in a readily accessible location:
    (1) Design criterion required in Secs. 60.482-2(d)(5) and 60.482-
3(e)(2) and explanation of the design criterion; and
    (2) Any changes to this criterion and the reasons for the changes.
    (i) The following information shall be recorded in a log that is 
kept in a readily accessible location for use in determining exemptions 
as provided in Sec. 60.480(d):
    (1) An analysis demonstrating the design capacity of the affected 
facility,
    (2) A statement listing the feed or raw materials and products from 
the

[[Page 358]]

affected facilities and an analysis demonstrating whether these 
chemicals are heavy liquids or beverage alcohol, and
    (3) An analysis demonstrating that equipment is not in VOC service.
    (j) Information and data used to demonstrate that a piece of 
equipment is not in VOC service shall be recorded in a log that is kept 
in a readily accessible location.
    (k) The provisions of Sec. 60.7 (b) and (d) do not apply to affected 
facilities subject to this subpart.



Sec. 60.487  Reporting requirements.

    (a) Each owner or operator subject to the provisions of this subpart 
shall submit semiannual reports to the Administrator beginning six 
months after the initial startup date.
    (b) The initial semiannual report to the Administrator shall include 
the following information:
    (1) Process unit identification.
    (2) Number of valves subject to the requirements of Sec. 60.482-7, 
excluding those valves designated for no detectable emissions under the 
provisions of Sec. 60.482-7(f).
    (3) Number of pumps subject to the requirements of Sec. 60.482-2, 
excluding those pumps designated for no detectable emissions under the 
provisions of Sec. 60.482-2(e) and those pumps complying with 
Sec. 60.482-2(f).
    (4) Number of compressors subject to the requirements of 
Sec. 60.482-3, excluding those compressors designated for no detectable 
emissions under the provisions of Sec. 60.482-3(i) and those compressors 
complying with Sec. 60.482-3(h).
    (c) All semiannual reports to the Administrator shall include the 
following information, summarized from the information in Sec. 60.486:
    (1) Process unit identification.
    (2) For each month during the semiannual reporting period,
    (i) Number of valves for which leaks were detected as described in 
Sec. 60.482(7)(b) or Sec. 60.483-2,
    (ii) Number of valves for which leaks were not repaired as required 
in Sec. 60.482-7(d)(1),
    (iii) Number of pumps for which leaks were detected as described in 
Sec. 60.482-2(b) and (d)(6)(i),
    (iv) Number of pumps for which leaks were not repaired as required 
in Sec. 60.482-2(c)(1) and (d)(6)(ii),
    (v) Number of compressors for which leaks were detected as described 
in Sec. 60.482-3(f),
    (vi) Number of compressors for which leaks were not repaired as 
required in Sec. 60.482-3(g)(1), and
    (vii) The facts that explain each delay of repair and, where 
appropriate, why a process unit shutdown was technically infeasible.
    (3) Dates of process unit shutdowns which occurred within the 
semiannual reporting period.
    (4) Revisions to items reported according to paragraph (b) if 
changes have occurred since the initial report or subsequent revisions 
to the initial report.
    (d) An owner or opertor electing to comply with the provisions of 
Secs. 60.483-1 and 60.483-2 shall notify the Administrator of the 
alternative standard selected 90 days before implementing either of the 
provisions.
    (e) An owner or operator shall report the results of all performance 
tests in accordance with Sec. 60.8 of the General Provisions. The 
provisions of Sec. 60.8(d) do not apply to affected facilities subject 
to the provisions of this subpart except that an owner or operator must 
notify the Administrator of the schedule for the initial performance 
tests at least 30 days before the initial performance tests.
    (f) The requirements of paragraphs (a) through (c) of this section 
remain in force until and unless EPA, in delegating enforcement 
authority to a State under section 111(c) of the Act, approves reporting 
requirements or an alternative means of compliance surveillance adopted 
by such State. In that event, affected sources within the State will be 
relieved of the obligation to comply with the requirements of paragraphs 
(a) through (c) of this section, provided that they comply with the 
requirements established by the State.

[48 FR 48335, Oct. 18, 1983, as amended at 49 FR 22608, May 30, 1984]



Sec. 60.488  Reconstruction.

    For the purposes of this subpart:

[[Page 359]]

    (a) The cost of the following frequently replaced components of the 
facility shall not be considered in calculating either the ``fixed 
capital cost of the new components'' or the ``fixed capital costs that 
would be required to construct a comparable new facility'' under 
Sec. 60.15: pump seals, nuts and bolts, rupture disks, and packings.
    (b) Under Sec. 60.15, the ``fixed capital cost of new components'' 
includes the fixed capital cost of all depreciable components (except 
components specified in Sec. 60.488 (a)) which are or will be replaced 
pursuant to all continuous programs of component replacement which are 
commenced within any 2-year period following the applicability date for 
the appropriate subpart. (See the ``Applicability and designation of 
affected facility'' section of the appropriate subpart.) For purposes of 
this paragraph, ``commenced'' means that an owner or operator has 
undertaken a continuous program of component replacement or that an 
owner or operator has entered into a contractual obligation to undertake 
and complete, within a reasonable time, a continuous program of 
component replacement.

[49 FR 22608, May 30, 1984]



Sec. 60.489  List of chemicals produced by affected facilities.

    The following chemicals are produced, as intermediates or final 
products, by process units covered under this subpart. The applicability 
date for process units producing one or more of these chemicals is 
January 5, 1981.

------------------------------------------------------------------------
              CAS No. a                            Chemical
------------------------------------------------------------------------
105-57-7............................  Acetal.
75-07-0.............................  Acetaldehyde.
107-89-1............................  Acetaldol.
60-35-5.............................  Acetamide.
103-84-4............................  Acetanilide.
64-19-7.............................  Acetic acid.
108-24-7............................  Acetic anhydride.
67-64-1.............................  Acetone.
75-86-5.............................  Acetone cyanohydrin.
75-05-8.............................  Acetonitrile.
98-86-2.............................  Acetophenone.
75-36-5.............................  Acetyl chloride.
74-86-2.............................  Acetylene.
107-02-8............................  Acrolein.
79-06-1.............................  Acrylamide.
79-10-7.............................  Acrylic acid.
107-13-1............................  Acrylonitrile.
124-04-9............................  Adipic acid.
111-69-3............................  Adiponitrile.
(b).................................  Alkyl naphthalenes.
107-18-6............................  Allyl alcohol.
107-05-1............................  Allyl chloride.
1321-11-5...........................  Aminobenzoic acid.
111-41-1............................  Aminoethylethanolamine.
123-30-8............................  p-Aminophenol.
628-63-7, 123-92-2..................  Amyl acetates.
71-41-0 c...........................  Amyl alcohols.
110-58-7............................  Amyl amine.
543-59-9............................  Amyl chloride.
110-66-7 c..........................  Amyl mercaptans.
1322-06-1...........................  Amyl phenol.
62-53-3.............................  Aniline.
142-04-1............................  Aniline hydrochloride.
29191-52-4..........................  Anisidine.
100-66-3............................  Anisole.
118-92-3............................  Anthranilic acid.
84-65-1.............................  Anthraquinone.
100-52-7............................  Benzaldehyde.
55-21-0.............................  Benzamide.
71-43-2.............................  Benzene.
98-48-6.............................  Benzenedisulfonic acid.
98-11-3.............................  Benzenesulfonic acid.
134-81-6............................  Benzil.
76-93-7.............................  Benzilic acid.
65-85-0.............................  Benzoic acid.
119-53-9............................  Benzoin.
100-47-0............................  Benzonitrile.
119-61-9............................  Benzophenone.
98-07-7.............................  Benzotrichloride.
98-88-4.............................  Benzoyl chloride.
100-51-6............................  Benzyl alcohol.
100-46-9............................  Benzylamine.
120-51-4............................  Benzyl benzoate.
100-44-7............................  Benzyl chloride.
98-87-3.............................  Benzyl dichloride.
92-52-4.............................  Biphenyl.
80-05-7.............................  Bisphenol A.
10-86-1.............................  Bromobenzene.
27497-51-4..........................  Bromonaphthalene.
106-99-0............................  Butadiene.
106-98-9............................  1-butene.
123-86-4............................  n-butyl acetate.
141-32-2............................  n-butyl acrylate.
71-36-3.............................  n-butyl alcohol.
78-92-2.............................  s-butyl alcohol.
75-65-0.............................  t-butyl alcohol.
109-73-9............................  n-butylamine.
13952-84-6..........................  s-butylamine.
75-64-9.............................  t-butylamine.
98-73-7.............................  p-tert-butyl benzoic acid.
107-88-0............................  1,3-butylene glycol.
123-72-8............................  n-butyraldehyde.
107-92-6............................  Butyric acid.
106-31-0............................  Butyric anhydride.
109-74-0............................  Butyronitrile.
105-60-2............................  Caprolactam.
75-1-50.............................  Carbon disulfide.
558-13-4............................  Carbon tetrabromide.
56-23-5.............................  Carbon tetrachloride.
9004-35-7...........................  Cellulose acetate.
79-11-8.............................  Chloroacetic acid.
108-42-9............................  m-chloroaniline.
95-51-2.............................  o-chloroaniline.
106-47-8............................  p-chloroaniline.
35913-09-8..........................  Chlorobenzaldehyde.
108-90-7............................  Chlorobenzene.
118-91-2, 535-80-8, 74-11-3 c.......  Chlorobenzoic acid.
2136-81-4, 2136-89-2, 5216-25-1c....  Chlorobenzotrichloride.
1321-03-5...........................  Chlorbenzoyl chloride.
25497-29-4..........................  Chlorodifluoromethane.

[[Page 360]]

 
75-45-6.............................  Chlorodifluoroethane.
67-66-3.............................  Chloroform.
25586-43-0..........................  Chloronapthalene.
88-73-3.............................  o-chloronitrobenzene.
100-00-5............................  p-chloronitrobenzene.
25167-80-0..........................  Chlorophenols.
126-99-8............................  Chloroprene.
7790-94-5...........................  Chlorosulfonic acid.
108-41-8............................  m-chlorotoluene.
95-49-8.............................  o-chlorotoluene.
106-43-4............................  p-chlorotoluene.
75-72-9.............................  Chlorotrifluoromethane.
108-39-4............................  m-cresol.
95-48-7.............................  o-cresol.
106-44-5............................  p-cresol.
1319-77-3...........................  Mixed cresols.
1319-77-3...........................  Cresylic acid.
4170-30-0...........................  Crotonaldehyde.
3724-65-0...........................  Crotonic acid.
98-82-8.............................  Cumene.
80-15-9.............................  Cumene hydroperoxide.
372-09-8............................  Cyanoacetic acid.
506-77-4............................  Cyanogen chloride.
108-80-5............................  Cyanuric acid.
108-77-0............................  Cyanuric chloride.
110-82-7............................  Cyclohexane.
108-93-0............................  Cyclohexanol.
108-94-1............................  Cyclohexanone.
110-83-8............................  Cyclohexene.
108-91-8............................  Cyclohexylamine.
111-78-4............................  Cyclooctadiene.
112-30-1............................  Decanol.
123-42-2............................  Diacetone alcohol.
27576-04-1..........................  Diaminobenzoic acid.
95-76-1, 95-82-9, 554-00-7, 608-27-   Dichloroaniline.
 5, 608-31-1, 626-43-7, 27134-27-6,
 57311-92-9 c.
541-73-1............................  m-dichlorobenzene.
95-50-1.............................  o-dichlorobenzene.
106-46-7............................  p-dichlorobenzene.
75-71-8.............................  Dichlorodifluoromethane.
111-44-4............................  Dichloroethyl ether.
107-06-2............................  1,2-dichloroethane (EDC).
96-23-1.............................  Dichlorohydrin.
26952-23-8..........................  Dichloropropene.
101-83-7............................  Dicyclohexylamine.
109-89-7............................  Diethylamine.
111-46-6............................  Diethylene glycol.
112-36-7............................  Diethylene glycol diethyl ether.
111-96-6............................  Diethylene glycol dimethyl ether.
112-34-5............................  Diethylene glycol monobutyl ether.
124-17-7............................  Diethylene glycol monobutyl ether
                                       acetate.
111-90-0............................  Diethylene glycol monoethyl ether.
112-15-2............................  Diethylene glycol monoethyl ether
                                       acetate.
111-77-3............................  Diethylene glycol monomethyl
                                       ether.
64-67-5.............................  Diethyl sulfate.
75-37-6.............................  Difluoroethane.
25167-70-8..........................  Diisobutylene.
26761-40-0..........................  Diisodecyl phthalate.
27554-26-3..........................  Diisooctyl phthalate.
674-82-8............................  Diketene.
124-40-3............................  Dimethylamine.
121-69-7............................  N,N-dimethylaniline.
115-10-6............................  N,N-dimethyl ether.
68-12-2.............................  N,N-dimethylformamide.
57-14-7.............................  Dimethylhydrazine.
77-78-1.............................  Dimethyl sulfate.
75-18-3.............................  Dimethyl sulfide.
67-68-5.............................  Dimethyl sulfoxide.
120-61-6............................  Dimethyl terephthalate.
99-34-3.............................  3,5-dinitrobenzoic acid.
51-28-5.............................  Dinitrophenol.
25321-14-6..........................  Dinitrotoluene.
123-91-1............................  Dioxane.
646-06-0............................  Dioxilane.
122-39-4............................  Diphenylamine.
101-84-8............................  Diphenyl oxide.
102-08-9............................  Diphenyl thiourea.
25265-71-8..........................  Dipropylene glycol.
25378-22-7..........................  Dodecene.
28675-17-4..........................  Dodecylaniline.
27193-86-8..........................  Dodecylphenol.
106-89-8............................  Epichlorohydrin.
64-17-5.............................  Ethanol.
141-43-5 c..........................  Ethanolamines.
141-78-6............................  Ethyl acetate.
141-97-9............................  Ethyl acetoacetate.
140-88-5............................  Ethyl acrylate.
75-04-7.............................  Ethylamine.
100-41-4............................  Ethylbenzene.
74-96-4.............................  Ethyl bromide.
9004-57-3...........................  Ethylcellulose.
75-00-3.............................  Ethyl chloride.
105-39-5............................  Ethyl chloroacetate.
105-56-6............................  Ethylcyanoacetate.
74-85-1.............................  Ethylene.
96-49-1.............................  Ethylne carbonate.
107-07-3............................  Ethylene chlorohydrin.
107-15-3............................  Ethylenediamine.
106-93-4............................  Ethylene dibromide.
107-21-1............................  Ethylene glycol.
111-55-7............................  Ethylene glycol diacetate.
110-71-4............................  Ethylene glycol dimethyl ether.
111-76-2............................  Ethylene glycol monobutyl ether.
112-07-2............................  Ethylene glycol monobutyl ether
                                       acetate.
110-80-5............................  Ethylene glycol monoethy ether.
111-15-9............................  Ethylene glycol monethyl ether
                                       acetate.
109-86-4............................  Ethylene glycol monomethyl ether.
110-49-6............................  Ethylene glycol monomethyl ether
                                       acetate.
122-99-6............................  Ethylene glycol monophenyl ether.
2807-30-9...........................  Ethylene glycol monopropyl ether.
75-21-8.............................  Ethylene oxide.
60-29-7.............................  Ethyl ether
104-76-7............................  2-ethylhexanol.
122-51-0............................  Ethyl orthoformate.
95-92-1.............................  Ethyl oxalate.
41892-71-1..........................  Ethyl sodium oxalacetate.
50-00-0.............................  Formaldehyde.
75-12-7.............................  Formamide.
64-18-6.............................  Formic acid.
110-17-8............................  Fumaric acid.
98-01-1.............................  Furfural.
56-81-5.............................  Glycerol.
26545-73-7..........................  Glycerol dichlorohydrin.
25791-96-2..........................  Glycerol triether.
56-40-6.............................  Glycine.
107-22-2............................  Glyoxal.
118-74-1............................  Hexachlorobenzene.
67-72-1.............................  Hexachloroethane.
36653-82-4..........................  Hexadecyl alcohol.
124-09-4............................  Hexamethylenediamine.
629-11-8............................  Hexamethylene glycol.
100-97-0............................  Hexamethylenetetramine.
74-90-8.............................  Hydrogen cyanide.
123-31-9............................  Hydroquinone.
99-96-7.............................  p-hydroxybenzoic acid.
26760-64-5..........................  Isoamylene.
78-83-1.............................  Isobutanol.
110-19-0............................  Isobutyl acetate.
115-11-7............................  Isobutylene.
78-84-2.............................  Isobutyraldehyde.

[[Page 361]]

 
79-31-2.............................  Isobutyric acid.
25339-17-7..........................  Isodecanol.
26952-21-6..........................  Isooctyl alcohol.
78-78-4.............................  Isopentane.
78-59-1.............................  Isophorone..
121-91-5............................  Isophthalic acid..
78-79-5.............................  Isoprene.
67-63-0.............................  Isopropanol.
108-21-4............................  Isopropyl acetate.
75-31-0.............................  Isopropylamine.
75-29-6.............................  Isopropyl chloride.
25168-06-3..........................  Isopropylphenol.
463-51-4............................  Ketene.
(b).................................  Linear alkyl sulfonate..
123-01-3............................  Linear alkylbenzene (linear
                                       dodecylbenzene)..
110-16-7............................  Maleic acid.
108-31-6............................  Maleic anhydride.
6915-15-7...........................  Malic acid.
141-79-7............................  Mesityl oxide.
121-47-1............................  Metanilic acid.
79-41-4.............................  Methacrylic acid.
563-47-3............................  Methallyl chloride.
67-56-1.............................  Methanol.
79-20-9.............................  Methyl acetate.
105-45-3............................  Methyl acetoacetate.
74-89-5.............................  Methylamine.
100-61-8............................  n-methylaniline.
74-83-9.............................  Methyl bromide.
37365-71-2..........................  Methyl butynol.
74-87-3.............................  Methyl chloride. .
108-87-2............................  Methylcyclohexane.
1331-22-2...........................  Methylcyclohexanone.
75-09-2.............................  Methylene chloride.
101-77-9............................  Methylene dianiline.
101-68-8............................  Methylene diphenyl diisocyanate.
78-93-3.............................  Methyl ethyl ketone.
107-31-3............................  Methyl formate.
108-11-2............................  Methyl isobutyl carbinol.
108-10-1............................  Methyl isobutyl ketone.
80-62-6.............................  Methyl methacrylate.
77-75-8.............................  Methylpentynol.
98-83-9.............................  a-methylstyrene.
110-91-8............................  Morpholine.
85-47-2.............................  a-naphthalene sulfonic acid.
120-18-3............................  b-naphthalene sulfonic acid .
90-15-3.............................  a-naphthol.
135-19-3............................  b-naphthol.
75-98-9.............................  Neopentanoic acid.
88-74-4.............................  o-nitroaniline.
100-01-6............................  p-nitroaniline.
91-23-6.............................  o-nitroanisole.
100-17-4............................  p-nitroanisole.
98-95-3.............................  Nitrobenzene.
27178-83-2c.........................  Nitrobenzoic acid (o,m, and p).
79-24-3.............................  Nitroethane.
75-52-5.............................  Nitromethane.
88-75-5.............................  2-Nitrophenol.
25322-01-4..........................  Nitropropane.
1321-12-6...........................  Nitrotoluene.
27215-95-8..........................  Nonene.
25154-52-3..........................  Nonylphenol.
27193-28-8..........................  Octylphenol.
123-63-7............................  Paraldehyde.
115-77-5............................  Pentaerythritol.
109-66-0............................  n-pentane.
109-67-1............................  1-pentene
127-18-4............................  Perchloroethylene.
594-42-3............................  Perchloromethyl mercaptan.
94-70-2.............................  o-phenetidine.
156-43-4............................  p-phenetidine.
108-95-2............................  Phenol.
98-67-9, 585-38-6, 609-46-1, 1333-39- Phenolsulfonic acids.
 7 c.
91-40-7.............................  Phenyl anthranilic acid.
(b).................................  Phenylenediamine.
75-44-5.............................  Phosgene.
85-44-9.............................  Phthalic anhydride.
85-41-6.............................  Phthalimide.
108-99-6............................  b-picoline.
110-85-0............................  Piperazine.
9003-29-6, 25036-29-7c..............  Polybutenes.
25322-68-3..........................  Polyethylene glycol.
25322-69-4..........................  Polypropylene glycol.
123-38-6............................  Propional dehyde.
79-09-4.............................  Propionic acid.
71-23-8.............................  n-propyl alcohol.
107-10-8............................  Propylamine.
540-54-5............................  Propyl chloride.
115-07-1............................  Propylene.
127-00-4............................  Propylene chlorohydrin.
78-87-5.............................  Propylene dichloride.
57-55-6.............................  Propylene glycol.
75-56-9.............................  Propylene oxide.
110-86-1............................  Pyridine.
106-51-4............................  Quinone.
108-46-3............................  Resorcinol.
27138-57-4..........................  Resorcylic acid.
69-72-7.............................  Salicylic acid.
127-09-3............................  Sodium acetate.
532-32-1............................  Sodium benzoate.
9004-32-4...........................  Sodium carboxymethyl cellulose.
3926-62-3...........................  Sodium chloroacetate.
141-53-7............................  Sodium formate.
139-02-6............................  Sodium phenate.
110-44-1............................  Sorbic acid.
100-42-5............................  Styrene..
110-15-6............................  Succinic acid.
110-61-2............................  Succinonitrile.
121-57-3............................  Sulfanilic acid.
126-33-0............................  Sulfolane.
1401-55-4...........................  Tannic acid.
100-21-0............................  Terephthalic acid.
79-34-5 c...........................  Tetrachloroethanes.
117-08-8............................  Tetrachlorophthalic anhydride.
78-00-2.............................  Tetraethyl lead.
119-64-2............................  Tetrahydronapthalene.
85-43-8.............................  Tetrahydrophthalic anhydride.
75-74-1.............................  Tetramethyl lead.
110-60-1............................  Tetramethylenediamine.
110-18-9............................  Tetramethylethylenediamine.
108-88-3............................  Toluene.
95-80-7.............................  Toluene-2,4-diamine.
584-84-9............................  Toluene-2,4-diisocyanate.
26471-62-5..........................  Toluene diisocyanates (mixture).
1333-07-9...........................  Toluenesulfonamide.
104-15-4 c..........................  Toluenesulfonic acids.
98-59-9.............................  Toluenesulfonyl chloride.
26915-12-8..........................  Toluidines.
87-61-6, 108-70-3, 120-82-1 c.......  Trichlorobenzenes.
71-55-6.............................  1,1,1-trichloroethane.
79-00-5.............................  1,1,2-trichloroethane.
79-01-6.............................  Trichloroethylene.
75-69-4.............................  Trichlorofluoromethane.
96-18-4.............................  1,2,3-trichloropropane.
76-13-1.............................  1,1,2-trichloro-1,2,2-
                                       trifluoroethane.
121-44-8............................  Triethylamine.
112-27-6............................  Triethylene glycol.
112-49-2............................  Triethylene glycol dimethyl ether.
7756-94-7...........................  Triisobutylene.
75-50-3.............................  Trimethylamine.
57-13-6.............................  Urea.
108-05-4............................  Vinyl acetate.
75-01-4.............................  Vinyl chloride.
75-35-4.............................  Vinylidene chloride.

[[Page 362]]

 
25013-15-4..........................  Vinyl toluene.
1330-20-7...........................  Xylenes (mixed).
95-47-6.............................  o-xylene.
106-42-3............................  p-xylene.
1300-71-6...........................  Xylenol.
1300-73-8...........................  Xylidine.
------------------------------------------------------------------------
a CAS numbers refer to the Chemical Abstracts Registry numbers assigned
  to specific chemicals, isomers, or mixtures of chemicals. Some isomers
  or mixtures that are covered by the standards do not have CAS numbers
  assigned to them. The standards apply to all of the chemicals listed,
  whether CAS numbers have been assigned or not.
b No CAS number(s) have been assigned to this chemical, its isomers, or
  mixtures containing these chemicals.
c CAS numbers for some of the isomers are listed; the standards apply to
  all of the isomers and mixtures, even if CAS numbers have not been
  assigned.



   Subpart WW--Standards of Performance for the Beverage Can Surface 
                            Coating Industry

    Source: 48 FR 38737, Aug. 25, 1983, unless otherwise noted.



Sec. 60.490  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to the following affected 
facilities in beverage can surface coating lines: each exterior base 
coat operation, each overvarnish coating operation, and each inside 
spray coating operation.
    (b) The provisions of this subpart apply to each affected facility 
which is identified in paragraph (a) of this section and commences 
construction, modification, or reconstruction after November 26, 1980.



Sec. 60.491  Definitions.

    (a) All terms which are used in this subpart and are not defined 
below are given the same meaning as in the Act and subpart A of this 
part.
    (1) Beverage can means any two-piece steel or aluminum container in 
which soft drinks or beer, including malt liquor, are packaged. The 
definition does not include containers in which fruit or vegetable 
juices are packaged.
    (2) Exterior base coating operation means the system on each 
beverage can surface coating line used to apply a coating to the 
exterior of a two-piece beverage can body. The exterior base coat 
provides corrosion resistance and a background for lithography or 
printing operations. The exterior base coat operation consists of the 
coating application station, flashoff area, and curing oven. The 
exterior base coat may be pigmented or clear (unpigmented).
    (3) Inside spray coating operation means the system on each beverage 
can surface coating line used to apply a coating to the interior of a 
two-piece beverage can body. This coating provides a protective film 
between the contents of the beverage can and the metal can body. The 
inside spray coating operation consists of the coating application 
station, flashoff area, and curing oven. Multiple applications of an 
inside spray coating are considered to be a single coating operation.
    (4) Overvarnish coating operation means the system on each beverage 
can surface coating line used to apply a coating over ink which reduces 
friction for automated beverage can filling equipment, provides gloss, 
and protects the finished beverage can body from abrasion and corrosion. 
The overvarnish coating is applied to two-piece beverage can bodies. The 
overvarnish coating operation consists of the coating application 
station, flashoff area, and curing oven.
    (5) Two-piece can means any beverage can that consists of a body 
manufactured from a single piece of steel or aluminum and a top. 
Coatings for a two-piece can are usually applied after fabrication of 
the can body.
    (6) VOC content means all volatile organic compounds (VOC) that are 
in a coating. VOC content is expressed in terms of kilograms of VOC per 
litre of coating solids.
    (b) Notations used under Sec. 60.493 of this subpart are defined 
below:

Ca=the VOC concentration in each gas stream leaving the 
          control device and entering the atmosphere (parts per million 
          as carbon)
Cb=the VOC concentration in each gas stream entering the 
          control device (parts per million as carbon)
Dc=density of each coating, as received (kilograms per litre)
Dd=density of each VOC-solvent added to coatings (kilograms 
          per litre)
Dr=density of VOC-solvent recovered by an emission control 
          device (kilograms per litre)
E=VOC destruction efficiency of the control device (fraction)
F=the proportion of total VOC emitted by an affected facility which 
          enters the control device to total emissions (fraction)

[[Page 363]]

G=the volume-weighted average of VOC in coatings consumed in a calendar 
          month per volume of coating solids applied (kilograms per 
          litre of coating solids)
He=the fraction of VOC emitted at the coater and flashoff 
          areas captured by a collection system
Hh=the fraction of VOC emitted at the cure oven captured by a 
          collection system
Lc=the volume of each coating consumed, as received (litres)
Ld=the volume of each VOC-solvent added to coatings (litres)
Lr=the volume of VOC-solvent recovered by an emission control 
          device (litres)
Ls=the volume of coating solids consumed (litres)
Md=the mass of VOC-solvent added to coatings (kilograms)
Mo=the mass of VOC-solvent in coatings consumed, as received 
          (kilograms)
Mr=the mass of VOC-solvent recovered by emission control 
          device (kilograms)
N=the volume-weighted average mass of VOC emissions to atmosphere per 
          unit volume of coating solids applied (kilograms per litre of 
          coating solids)
Qa=the volumetric flow rate of each gas stream leaving the 
          control device and entering the atmosphere (dry standard cubic 
          meters per hour)
Qb=the volumetric flow of each gas stream entering the 
          control device (dry standard cubic meters per hour)
R=the overall emission reduction efficiency for an affected facility 
          (fraction)
Se=the fraction of VOC in coating and diluent VOC-solvent 
          emitted at the coater and flashoff area for a coating 
          operation
Sh=the fraction of VOC in coating and diluent solvent emitted 
          at the cure oven for a coating operation
Vs=the proportion of solids in each coating, as received 
          (fraction by volume)
Wo=the proportion of VOC in each coating, as received 
          (fraction by weight).



Sec. 60.492  Standards for volatile organic compounds.

    On or after the date on which the initial performance test required 
by Sec. 60.8(a) is completed, no owner or operator subject to the 
provisions of this subpart shall discharge or cause the discharge of VOC 
emissions to the atmoshpere that exceed the following volume-weighted 
calendar-month average emissions:
    (a) 0.29 kilogram of VOC per litre of coating solids from each two-
piece can exterior base coating operation, except clear base coat;
    (b) 0.46 kilogram of VOC per litre of coating solids from each two-
piece can clear base coating operation and from each overvarnish coating 
operation; and
    (c) 0.89 kilogram of VOC per litre of coating solids from each two-
piece can inside spray coating operation.



Sec. 60.493  Performance test and compliance provisions.

    (a) Section 60.8(d) does not apply to monthly performance tests and 
Sec. 60.8(f) does not apply to the performance test procedures required 
by this subpart.
    (b) The owner or operator of an affected facility shall conduct an 
initial performance test as required under Sec. 60.8(a) and thereafter a 
performance test each calendar month for each affected facility.
    (1) The owner or operator shall use the following procedures for 
each affected facility that does not use a capture system and a control 
device to comply with the emission limit specified under Sec. 60.492. 
The owner or operator shall determine the VOC-content of the coatings 
from formulation data supplied by the manufacturer of the coating or by 
an analysis of each coating, as received, using Reference Method 24. The 
Administrator may require the owner or operator who uses formulation 
data supplied by the manufacturer of the coating to determine the VOC 
content of coatings using Reference Method 24 or an equivalent or 
alternative method. The owner or operator shall determine from company 
records the volume of coating and the mass of VOC-solvent added to 
coatings. If a common coating distribution system serves more than one 
affected facility or serves both affected and exiting facilities, the 
owner or operator shall estimate the volume of coating used at each 
facility by using the average dry weight of coating, number of cans, and 
size of cans being processed by each affected and existing facility or 
by other procedures acceptable to the Administrator.
    (i) Calculate the volume-weighted average of the total mass of VOC 
per volume of coating solids used during the calendar month for each 
affected facility, except as provided under paragraph (b)(1)(iv) of this 
section. The volume-weighted average of the total mass of VOC per volume 
of coating solids used

[[Page 364]]

each calendar month will be determined by the following procedures.
    (A) Calculate the mass of VOC used (Mo+Md) 
during the calendar month for the affected facility by the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.058

[LdjDdj will be 0 if no VOC solvent is 
added to the coatings, as received.] where n is the number of different 
coatings used during the calendar month and m is the number of different 
diluent VOC-solvents used during the calendar month.

    (B) Calculate the total volume of coating solids used 
(Ls) in the calendar month for the affected facility by the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.059

where n is the number of different coatings used during the calendar 
          month.

    (C) Calculate the volume-weighed average mass of VOC per volume of 
solids used (G) during the calendar month for the affected facility by 
the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.060

    (ii) Calculate the volume-weighted average of VOC emissions 
discharged to the atmosphere (N) during the calendar month for the 
affected facility by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.061

    (iii) Where the value of the volume-weighted average of mass of VOC 
per volume of solids discharged to the atmosphere (N) is equal to or 
less than the applicable emission limit specified under Sec. 60.492, the 
affected facility is in compliance.
    (iv) If each individual coating used by an affected facility has a 
VOC content equal to or less than the limit specified under Sec. 60.492, 
the affected facility is in compliance provided no VOC-solvents are 
added to the coating during distribution or application.
    (2) An owner or operator shall use the following procedures for each 
affected facility that uses a capture system and a control device that 
destroys VOC (e.g., incinerator) to comply with the emission limit 
specified under Sec. 60.492.
    (i) Determine the overall reduction efficiency (R) for the capture 
system and control device.

For the initial performance test, the overall reduction efficiency (R) 
shall be determined as prescribed in paragraphs (b)(2)(i) (A), (B), and 
(C) of this section. In subsequent months, the owner or operator may use 
the most recently determined overall reduction efficiency for the 
performance test providing control device and capture system operating 
conditions have not changed. The procedure in paragraphs (b)(2)(i), (A), 
(B), and (C) of this section, shall be repeated when directed by the 
Administrator or when the owner or operator elects to operate the 
control device or capture system at conditions different from the 
initial performance test.
    (A) Determine the fraction (F) of total VOC used by the affected 
facility that enters the control device using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.062


where He an Hh shall be determined by a method 
that has been previously approved by the Administrator. The owner or 
operator may use the values of Se and Sh specified 
in Table 1 or other values determined by a method that has been 
previously approved by the Administrator.

[[Page 365]]



                 Table 1--Distribution of VOC Emissions
------------------------------------------------------------------------
                                                          Emission
                                                        distribution
                                                   ---------------------
                 Coating operation                   Coater/
                                                     flashoff    Curing
                                                       (Se)    oven (Sh)
------------------------------------------------------------------------
Two-piece aluminum or steel can:
  Exterior base coat operation....................       0.75       0.25
  Overvarnish coating operation...................       0.75       0.25
  Inside spray coating operation..................       0.80       0.20
------------------------------------------------------------------------

    (B) Determine the destruction efficiency of the control device (E) 
using values of the volumetric flow rate of each of the gas streams and 
the VOC content (as carbon) of each of the gas streams in and out of the 
device by the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.241

where n is the number of vents before the control device, and m is the 
number of vents after the control device.

    (C) Determine overall reduction efficiency (R) using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.242

    (ii) Calculate the volume-weighted average of the total mass of VOC 
per volume of coating solids (G) used during the calendar month for the 
affected facility using equations (1), (2), and (3).
    (iii) Calculate the volume-weighted average of VOC emissions 
discharged to the atmosphere (N) during the calendar month by the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.243

    (iv) If the volume-weighted average of mass of VOC emitted to the 
atmosphere for the calendar month (N) is equal to or less than the 
applicable emission limit specified under Sec. 60.492, the affected 
facility is in compliance.
    (3) An owner or operator shall use the following procedure for each 
affected facility that uses a capture system and a control device that 
recovers the VOC (e.g., carbon adsorber) to comply with the applicable 
emission limit specified under Sec. 60.492.
    (i) Calculate the volume-weighted average of the total mass of VOC 
per unit volume of coating solids applied (G) used during the calendar 
month for the affected facility using equations (1), (2), and (3).
    (ii) Calculate the total mass of VOC recovered (Mr) 
during each calendar month using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.244

    (iii) Calculate overall reduction efficiency of the control device 
(R) for the calendar month for the affected facility using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.245

    (iv) Calculate the volume-weighted average mass of VOC discharged to 
the atmosphere (N) for the calendar month for the afffected facility 
using equation (8).
    (v) If the weighted average of VOC emitted to the atmosphere for the 
calendar month (N) is equal to or less than the applicable emission 
limit specified under Sec. 60.492, the affected facility is in 
compliance.



Sec. 60.494  Monitoring of emissions and operations

    The owner or operator of an affected facility that uses a capture 
system and an incinerator to comply with the emission limits specified 
under Sec. 60.492 shall install, calibrate, maintain, and operate 
temperature measurement devices as prescribed below.
    (a) Where thermal incineration is used, a temperature measurement 
device shall be installed in the firebox. Where catalytic incineration 
is used, temperature measurement devices shall be installed in the gas 
stream immediately before and after the catalyst bed.
    (b) Each temperature measurement device shall be installed, 
calibrated, and maintained according to the manufacturer's 
specifications. The device shall have an accuracy the greater of 
0.75 percent of the temperature being measured expressed in 
degrees Celsius or 2.5  deg.C.

[[Page 366]]

    (c) Each temperature measurement device shall be equipped with a 
recording device so that a permanent continuous record is produced.



Sec. 60.495  Reporting and recordkeeping requirements.

    (a) The owner or operator of an affected facility shall include the 
following data in the initial compliance report required under 
Sec. 60.8(a).
    (1) Where only coatings which individually have a VOC content equal 
to or less than the limits specified under Sec. 60.492 are used, and no 
VOC is added to the coating during the application or distribution 
process, the owner or operator shall provide a list of the coatings used 
for each affected facility and the VOC content of each coating 
calculated from data determined using Reference Method 24 or supplies by 
the manufacturers of the coatings.
    (2) Where one or more coatings which individually have a VOC content 
greater than the limits specified under Sec. 60.492 are used or where 
VOC are added or used in the coating process, the owner or operator 
shall report for each affected facility the volume-weighted average of 
the total mass of VOC per volume of coating solids.
    (3) Where compliance is achieved through the use of incineration, 
the owner or operator shall include in the initial performance test 
required under Sec. 60.8(a) the combustion temperature (or the gas 
temperature upstream and downstream of the catalyst bed), the total mass 
of VOC per volume of coating solids before and after the incinerator, 
capture efficiency, and the destruction efficiency of the incinerator 
used to attain compliance with the applicable emission limit specified 
under Sec. 60.492. The owner or operator shall also include a 
description of the method used to establish the amount of VOC captured 
by the capture system and sent to the control device.
    (b) Following the initial performance test, each owner or operator 
shall identify, record, and submit quarterly reports to the 
Administrator of each instance in which the volume-weighted average of 
the total mass of VOC per volume of coating solids, after the control 
device, if capture devices and control systems are used, is greater than 
the limit specified under Sec. 60.492. If no such instances occur during 
a particular quarter, a report stating this shall be submitted to the 
Administrator semiannually.
    (c) Following the initial performance test, the owner or operator of 
an affected facility shall identify, record, and submit at the frequency 
specified in Sec. 60.7(c) the following:
    (1) Where compliance with Sec. 60.492 is achieved through the use of 
thermal incineration, each 3-hour period when cans are processed, during 
which the average temperature of the device was more than 28  deg.C 
below the average temperature of the device during the most recent 
performance test at which destruction efficiency was determined as 
specified under Sec. 60.493.
    (2) Where compliance with Sec. 60.492 is achieved through the use of 
catalytic incineration, each 3-hour period when cans are being 
processed, during which the average temperature of the device 
immediately before the catalyst bed is more than 28  deg.C below the 
average temperature of the device immediately before the catalyst bed 
during the most recent performance test at which destruction efficiency 
was determined as specified under Sec. 60.493 and all 3-hour periods, 
when cans are being processed, during which the average temperature 
difference across the catalyst bed is less than 80 percent of the 
average temperature difference across the catalyst bed during the most 
recent performance test at which destruction efficiency was determined 
as specified under Sec. 60.494.
    (3) For thermal and catalytic incinerators, if no such periods as 
described in paragraphs (c)(1) and (c)(2) of this section occur, the 
owner or operator shall state this in the report.
    (d) Each owner or operator subject to the provisions of this subpart 
shall maintain at the source, for a period of at least 2 years, records 
of all data and calculations used to determine VOC emissions from each 
affected facility in the initial and monthly performance tests. Where 
compliance is achieved through the use of thermal incineration, each 
owner or operator shall maintain, at the source, daily records of the 
incinerator combustion chamber temperature. If catalytic incineration

[[Page 367]]

is used, the owner or operator shall maintain at the source daily 
records of the gas temperature, both upstream and downstream of the 
incinerator catalyst bed. Where compliance is achieved through the use 
of a solvent recovery system, the owner or operator shall maintain at 
the source daily records of the amount of solvent recovered by the 
system for each affected facility.
    (e) The requirements of this section remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternative 
means of compliance surveillance adopted by such State. In that event, 
affected facilities within the State will be relieved of the obligation 
to comply with this subsection, provided that they comply with the 
requirements established by the State.

[47 FR 49612, Nov. 1, 1982, as amended at 55 FR 51384, Dec. 13, 1990]



Sec. 60.496  Test methods and procedures.

    (a) The reference methods in appendix A to this part, except as 
provided in Sec. 60.8, shall be used to conduct performance tests.
    (1) Reference Method 24, an equivalent or alternative method 
approved by the Administrator, or manufacturers formulation for data 
from which the VOC content of the coatings used for each affected 
facility can be calculated. In the event of dispute, Reference Method 24 
shall be the referee method. When VOC content of waterborne coatings, 
determined from data generated by Reference Method 24, is used to 
determine compliance of affected facilities, the results of the Method 
24 analysis shall be adjusted as described in section 4.4 of Method 24.
    (2) Reference Method 25 or an equivalent or alternative method for 
the determination of the VOC concentration in the effluent gas entering 
and leaving the control device for each stack equipped with an emission 
control device. The owner or operator shall notify the Administrator 30 
days in advance of any State test using Reference Method 25. The 
following reference methods are to be used in conjunction with Reference 
Method 25:
    (i) Method 1 for sample and velocity traverses,
    (ii) Method 2 for velocity and volumetric flow rate,
    (iii) Method 3 for gas analysis, and
    (iv) Method 4 for stack gas moisture.
    (b) For Reference Method 24, the coating sample must be a 1-litre 
sample collected in a 1-litre container at a point where the sample will 
be representative of the coating material.
    (c) For Reference Method 25, the sampling time for each of three 
runs must be at least 1 hour. The minimum sample volume must be 0.003 
dscm except that shorter sampling times or smaller volumes, when 
necessitated by process variables or other factors, may be approved by 
the Administrator. The Administrator will approve the sampling of 
representative stacks on a case-by-case basis if the owner or operator 
can demonstrate to the satisfaction of the Administrator that the 
testing of representative stacks would yield results comparable to those 
that would be obtained by testing all stacks.



    Subpart XX--Standards of Performance for Bulk Gasoline Terminals

    Source: 48 FR 37590, Aug. 18, 1983, unless otherwise noted.



Sec. 60.500  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is the total of all the loading racks at a bulk gasoline terminal 
which deliver liquid product into gasoline tank trucks.
    (b) Each facility under paragraph (a) of this section, the 
construction or modification of which is commenced after December 17, 
1980, is subject to the provisions of this subpart.
    (c) For purposes of this subpart, any replacement of components of 
an existing facility, described in paragraph (a) of this section, 
commenced before August 18, 1983 in order to comply with any emission 
standard adopted by a State or political subdivision thereof will not be 
considered a reconstruction under the provisions of 40 CFR 60.15.
    Note: The intent of these standards is to minimize the emissions of 
VOC through the

[[Page 368]]

application of best demonstrated technologies (BDT). The numerical 
emission limits in this standard are expressed in terms of total organic 
compounds. This emission limit reflects the performance of BDT.



Sec. 60.501  Definitions.

    The terms used in this subpart are defined in the Clean Air Act, in 
Sec. 60.2 of this part, or in this section as follows:
    Bulk gasoline terminal means any gasoline facility which receives 
gasoline by pipeline, ship or barge, and has a gasoline throughput 
greater than 75,700 liters per day. Gasoline throughput shall be the 
maximum calculated design throughput as may be limited by compliance 
with an enforceable condition under Federal, State or local law and 
discoverable by the Administrator and any other person.
    Continuous vapor processing system means a vapor processing system 
that treats total organic compounds vapors collected from gasoline tank 
trucks on a demand basis without intermediate accumulation in a vapor 
holder.
    Existing vapor processing system means a vapor processing system 
[capable of achieving emissions to the atmosphere no greater than 80 
milligrams of total organic compounds per liter of gasoline loaded], the 
construction or refurbishment of which was commenced before December 17, 
1980, and which was not constructed or refurbished after that date.
    Gasoline means any petroleum distillate or petroleum distillate/
alcohol blend having a Reid vapor pressure of 27.6 kilopascals or 
greater which is used as a fuel for internal combustion engines.
    Gasoline tank truck means a delivery tank truck used at bulk 
gasoline terminals which is loading gasoline or which has loaded 
gasoline on the immediately previous load.
    Intermittent vapor processing system means a vapor processing system 
that employs an intermediate vapor holder to accumulate total organic 
compounds vapors collected from gasoline tank trucks, and treats the 
accumulated vapors only during automatically controlled cycles.
    Loading rack means the loading arms, pumps, meters, shutoff valves, 
relief valves, and other piping and valves necessary to fill delivery 
tank trucks.
    Refurbishment means, with reference to a vapor processing system, 
replacement of components of, or addition of components to, the system 
within any 2-year period such that the fixed capital cost of the new 
components required for such component replacement or addition exceeds 
50 percent of the cost of a comparable entirely new system.
    Total organic compounds means those compounds measured according to 
the procedures in Sec. 60.503.
    Vapor collection system means any equipment used for containing 
total organic compounds vapors displaced during the loading of gasoline 
tank trucks.
    Vapor processing system means all equipment used for recovering or 
oxidizing total organic compounds vapors displaced from the affected 
facility.
    Vapor-tight gasoline tank truck means a gasoline tank truck which 
has demonstrated within the 12 preceding months that its product 
delivery tank will sustain a pressure change of not more than 750 
pascals (75 mm of water) within 5 minutes after it is pressurized to 
4,500 pascals (450 mm of water). This capability is to be demonstrated 
using the pressure test procedure specified in Reference Method 27.



Sec. 60.502  Standard for Volatile Organic Compound (VOC) emissions from bulk gasoline terminals.

    On and after the date on which Sec. 60.8(a) requires a performance 
test to be completed, the owner or operator of each bulk gasoline 
terminal containing an affected facility shall comply with the 
requirements of this section.
    (a) Each affected facility shall be equipped with a vapor collection 
system designed to collect the total organic compounds vapors displaced 
from tank trucks during product loading.
    (b) The emissions to the atmosphere from the vapor collection system 
due to the loading of liquid product into gasoline tank trucks are not 
to exceed 35 milligrams of total organic compounds per liter of gasoline 
loaded, except as noted in paragraph (c) of this section.
    (c) For each affected facility equipped with an existing vapor 
processing system, the emissions to the atmosphere from the vapor 
collection

[[Page 369]]

system due to the loading of liquid product into gasoline tank trucks 
are not to exceed 80 milligrams of total organic compounds per liter of 
gasoline loaded.
    (d) Each vapor collection system shall be designed to prevent any 
total organic compounds vapors collected at one loading rack from 
passing to another loading rack.
    (e) Loadings of liquid product into gasoline tank trucks shall be 
limited to vapor-tight gasoline tank trucks using the following 
procedures:
    (1) The owner or operator shall obtain the vapor tightness 
documentation described in Sec. 60.505(b) for each gasoline tank truck 
which is to be loaded at the affected facility.
    (2) The owner or operator shall require the tank identification 
number to be recorded as each gasoline tank truck is loaded at the 
affected facility.
    (3)(i) The owner or operator shall cross-check each tank 
identification number obtained in paragraph (e)(2) of this section with 
the file of tank vapor tightness documentation within 2 weeks after the 
corresponding tank is loaded, unless either of the following conditions 
is maintained:
    (A) If less than an average of one gasoline tank truck per month 
over the last 26 weeks is loaded without vapor tightness documentation 
then the documentation cross-check shall be performed each quarter; or
    (B) If less than an average of one gasoline tank truck per month 
over the last 52 weeks is loaded without vapor tightness documentation 
then the documentation cross-check shall be performed semiannually.
    (ii) If either the quarterly or semiannual cross-check provided in 
paragraphs (e)(3)(i) (A) through (B) of this section reveals that these 
conditions were not maintained, the source must return to biweekly 
monitoring until such time as these conditions are again met.
    (4) The terminal owner or operator shall notify the owner or 
operator of each non-vapor-tight gasoline tank truck loaded at the 
affected facility within 1 week of the documentation cross-check in 
paragraph (e)(3) of this section.
    (5) The terminal owner or operator shall take steps assuring that 
the nonvapor-tight gasoline tank truck will not be reloaded at the 
affected facility until vapor tightness documentation for that tank is 
obtained.
    (6) Alternate procedures to those described in paragraphs (e)(1) 
through (5) of this section for limiting gasoline tank truck loadings 
may be used upon application to, and approval by, the Administrator.
    (f) The owner or operator shall act to assure that loadings of 
gasoline tank trucks at the affected facility are made only into tanks 
equipped with vapor collection equipment that is compatible with the 
terminal's vapor collection system.
    (g) The owner or operator shall act to assure that the terminal's 
and the tank truck's vapor collection systems are connected during each 
loading of a gasoline tank truck at the affected facility. Examples of 
actions to accomplish this include training drivers in the hookup 
procedures and posting visible reminder signs at the affected loading 
racks.
    (h) The vapor collection and liquid loading equipment shall be 
designed and operated to prevent gauge pressure in the delivery tank 
from exceeding 4,500 pascals (450 mm of water) during product loading. 
This level is not to be exceeded when measured by the procedures 
specified in Sec. 60.503(d).
    (i) No pressure-vacuum vent in the bulk gasoline terminal's vapor 
collection system shall begin to open at a system pressure less than 
4,500 pascals (450 mm of water).
    (j) Each calendar month, the vapor collection system, the vapor 
processing system, and each loading rack handling gasoline shall be 
inspected during the loading of gasoline tank trucks for total organic 
compounds liquid or vapor leaks. For purposes of this paragraph, 
detection methods incorporating sight, sound, or smell are acceptable. 
Each detection of a leak shall be recorded and the source of the leak 
repaired within 15 calendar days after it is detected.

[48 FR 37590, Aug. 18, 1983; 48 FR 56580, Dec. 22, 1983, as amended at 
54 FR 6678, Feb. 14, 1989; 64 FR 7466, Feb. 12, 1999]

[[Page 370]]



Sec. 60.503  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b). The 
three-run requirement of Sec. 60.8(f) does not apply to this subpart.
    (b) Immediately before the performance test required to determine 
compliance with Sec. 60.502 (b), (c), and (h), the owner or operator 
shall use Method 21 to monitor for leakage of vapor all potential 
sources in the terminal's vapor collection system equipment while a 
gasoline tank truck is being loaded. The owner or operator shall repair 
all leaks with readings of 10,000 ppm (as methane) or greater before 
conducting the performance test.
    (c) The owner or operator shall determine compliance with the 
standards in Sec. 60.502 (b) and (c) as follows:
    (1) The performance test shall be 6 hours long during which at least 
300,000 liters of gasoline is loaded. If this is not possible, the test 
may be continued the same day until 300,000 liters of gasoline is loaded 
or the test may be resumed the next day with another complete 6-hour 
period. In the latter case, the 300,000-liter criterion need not be met. 
However, as much as possible, testing should be conducted during the 6-
hour period in which the highest throughput normally occurs.
    (2) If the vapor processing system is intermittent in operation, the 
performance test shall begin at a reference vapor holder level and shall 
end at the same reference point. The test shall include at least two 
startups and shutdowns of the vapor processor. If this does not occur 
under automatically controlled operations, the system shall be manually 
controlled.
    (3) The emission rate (E) of total organic compounds shall be 
computed using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.063

where:
E=emission rate of total organic compounds, mg/liter of gasoline loaded.
Vesi=volume of air-vapor mixture exhausted at each interval 
          ``i'', scm.
Cei=concentration of total organic compounds at each interval 
          ``i'', ppm.
L=total volume of gasoline loaded, liters.
n=number of testing intervals.
i=emission testing interval of 5 minutes.
K=density of calibration gas, 1.83 x 106 for propane and 
          2.41 x 106 for butane, mg/scm.

    (4) The performance test shall be conducted in intervals of 5 
minutes. For each interval ``i'', readings from each measurement shall 
be recorded, and the volume exhausted (Vesi) and the 
corresponding average total organic compounds concentration 
(Cei) shall be determined. The sampling system response time 
shall be considered in determining the average total organic compounds 
concentration corresponding to the volume exhausted.
    (5) The following methods shall be used to determine the volume 
(Vesi) air-vapor mixture exhausted at each interval:
    (i) Method 2B shall be used for combustion vapor processing systems.
    (ii) Method 2A shall be used for all other vapor processing systems.
    (6) Method 25A or 25B shall be used for determining the total 
organic compounds concentration (Cei) at each interval. The 
calibration gas shall be either propane or butane. The owner or operator 
may exclude the methane and ethane content in the exhaust vent by any 
method (e.g., Method 18) approved by the Administrator.
    (7) To determine the volume (L) of gasoline dispensed during the 
performance test period at all loading racks whose vapor emissions are 
controlled by the processing system being tested, terminal records or 
readings from gasoline dispensing meters at each loading rack shall be 
used.
    (d) The owner or operator shall determine compliance with the 
standard in Sec. 60.502(h) as follows:
    (1) A pressure measurement device (liquid manometer, magnehelic 
gauge, or equivalent instrument), capable of measuring up to 500 mm of 
water gauge pressure with 2.5 mm of water precision, shall 
be calibrated and installed on the terminal's vapor collection system at 
a pressure tap located as close as possible to the connection with the 
gasoline tank truck.

[[Page 371]]

    (2) During the performance test, the pressure shall be recorded 
every 5 minutes while a gasoline truck is being loaded; the highest 
instantaneous pressure that occurs during each loading shall also be 
recorded. Every loading position must be tested at least once during the 
performance test.

[54 FR 6678, Feb. 14, 1989; 54 FR 21344, Feb. 14, 1989]



Sec. 60.504  [Reserved]



Sec. 60.505  Reporting and recordkeeping.

    (a) The tank truck vapor tightness documentation required under 
Sec. 60.502(e)(1) shall be kept on file at the terminal in a permanent 
form available for inspection.
    (b) The documentation file for each gasoline tank truck shall be 
updated at least once per year to reflect current test results as 
determined by Method 27. This documentation shall include, as a minimum, 
the following information:

    (1) Test title: Gasoline Delivery Tank Pressure Test--EPA Reference 
Method 27.
    (2) Tank owner and address.
    (3) Tank identification number.
    (4) Testing location.
    (5) Date of test.
    (6) Tester name and signature.
    (7) Witnessing inspector, if any: Name, signature, and affiliation.
    (8) Test results: Actual pressure change in 5 minutes, mm of water 
(average for 2 runs).

    (c) A record of each monthly leak inspection required under 
Sec. 60.502(j) shall be kept on file at the terminal for at least 2 
years. Inspection records shall include, as a minimum, the following 
information:

    (1) Date of inspection.
    (2) Findings (may indicate no leaks discovered; or location, nature, 
and severity of each leak).
    (3) Leak determination method.
    (4) Corrective action (date each leak repaired; reasons for any 
repair interval in excess of 15 days).
    (5) Inspector name and signature.

    (d) The terminal owner or operator shall keep documentation of all 
notifications required under Sec. 60.502(e)(4) on file at the terminal 
for at least 2 years.
    (e) [Reserved]
    (f) The owner or operator of an affected facility shall keep records 
of all replacements or additions of components performed on an existing 
vapor processing system for at least 3 years.

[48 FR 37590, Aug. 18, 1983; 48 FR 56580, Dec. 22, 1983]



Sec. 60.506  Reconstruction.

    For purposes of this subpart:
    (a) The cost of the following frequently replaced components of the 
affected facility shall not be considered in calculating either the 
``fixed capital cost of the new components'' or the ``fixed capital 
costs that would be required to construct a comparable entirely new 
facility'' under Sec. 60.15: pump seals, loading arm gaskets and 
swivels, coupler gaskets, overfill sensor couplers and cables, flexible 
vapor hoses, and grounding cables and connectors.
    (b) Under Sec. 60.15, the ``fixed capital cost of the new 
components'' includes the fixed capital cost of all depreciable 
components (except components specified in Sec. 60.506(a)) which are or 
will be replaced pursuant to all continuous programs of component 
replacement which are commenced within any 2-year period following 
December 17, 1980. For purposes of this paragraph, ``commenced'' means 
that an owner or operator has undertaken a continuous program of 
component replacement or that an owner or operator has entered into a 
contractual obligation to undertake and complete, within a reasonable 
time, a continuous program of component replacement.



 Subpart AAA--Standards of Performance for New Residential Wood Heaters

    Source: 53 FR 5873, Feb. 26, 1988, unless otherwise noted.



Sec. 60.530  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each wood heater manufactured on or after July 1, 1988, or sold 
at retail on or after July 1, 1990. The provisions of this subpart do 
not apply to wood heaters constructed prior to July 1, 1988, that are or 
have been owned by a noncommercial owner for his personal use.

[[Page 372]]

    (b) Each affected facility shall comply with the applicable emission 
limits in Sec. 60.532 unless exempted under paragraph (c), (d), (e), 
(f), (g) or (h) of this section.
    (c)--(d)  [Reserved]
    (e) Affected facilities manufactured in the U.S. for export are 
exempt from the applicable emission limits of Sec. 60.532 and the 
requirements of Sec. 60.533.
    (f) A wood heater used for research and development purposes that is 
never offered for sale or sold is exempt from the applicable emission 
limits of Sec. 60.532 and the requirements of Sec. 60.533. No more than 
50 wood heaters manufactured per model line may be exempted for this 
purpose.
    (g) A coal-only heater is exempt from the applicable emission limits 
of Sec. 60.532 and the requirements of Sec. 60.533.
    (h) The following are not affected facilities and are not subject to 
this subpart:
    (1) Open masonry fireplaces constructed on site,
    (2) Boilers,
    (3) Furnaces, and
    (4) Cookstoves.
    (i) Modification or reconstruction, as defined in Secs. 60.14 and 
60.15 of subpart A, shall not, by itself, make a wood heater an affected 
facility under this subpart.

[53 FR 5873, Feb. 26, 1988, as amended at 60 FR 33925, June 29, 1995]



Sec. 60.531  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and subpart A of this part.
    At retail means the sale by a commercial owner of a wood heater to 
the ultimate purchaser.
    Boiler means a solid fuel burning appliance used primarily for 
heating spaces, other than the space where the appliance is located, by 
the distribution through pipes of a gas or fluid heated in the 
appliance. The appliance must be tested and listed as a boiler under 
accepted American or Canadian safety testing codes. A manufacturer may 
request an exemption in writing from the Administrator by stating why 
the testing and listing requirement is not practicable and by 
demonstrating that his appliance is otherwise a boiler.
    Coal-only heater means an enclosed, coal-burning appliance capable 
of space heating, or domestic water heating, which has all of the 
following characteristics:
    (a) An opening for emptying ash that is located near the bottom or 
the side of the appliance,
    (b) A system that admits air primarily up and through the fuel bed,
    (c) A grate or other similar device for shaking or disturbing the 
fuel bed or power-driven mechanical stoker,
    (d) Installation instructions that state that the use of wood in the 
stove, except for coal ignition purposes, is prohibited by law, and
    (e) The model is listed by a nationally recognized safety-testing 
laboratory for use of coal only, except for coal ignition purposes.
    Commercial owner means any person who owns or controls a wood heater 
in the course of the manufacture, importation, distribution, or sale of 
the wood heater.
    Cookstove means a wood-fired appliance that is designed primarily 
for cooking food and that has the following characteristics:
    (a) An oven, with a volume of 0.028 cubic meters (1 cubic foot) or 
greater, and an oven rack,
    (b) A device for measuring oven temperatures,
    (c) A flame path that is routed around the oven,
    (d) A shaker grate,
    (e) An ash pan,
    (f) An ash clean-out door below the oven, and
    (g) The absence of a fan or heat channels to dissipate heat from the 
appliance.
    Furnace means a solid fuel burning appliance that is designed to be 
located outside of ordinary living areas and that warms spaces other 
than the space where the appliance is located, by the distribution of 
air heated in the appliance through ducts. The appliance must be tested 
and listed as a furnace under accepted American or Canadian safety 
testing codes unless exempted from this provision by the Administrator. 
A manufacturer may request an exemption in writing from the 
Administrator by stating why the testing and listing requirement is not 
practicable

[[Page 373]]

and by demonstrating that his appliance is otherwise a furnace.
    Manufactured means completed and ready for shipment (whether or not 
packaged).
    Manufacturer means any person who constructs or imports a wood 
heater.
    Model line means all wood heaters offered for sale by a single 
manufacturer that are similar in all material respects.
    Representative affected facility means an individual wood heater 
that is similar in all material respects to other wood heaters within 
the model line it represents.
    Sale means the transfer of ownership or control, except that 
transfer of control shall not constitute a sale for purposes of 
Sec. 60.530(f).
    Similar in all material respects means that the construction 
materials, exhaust and inlet air system, and other design features are 
within the allowed tolerances for components identified in 
Sec. 60.533(k).
    Wood heater means an enclosed, wood burning appliance capable of and 
intended for space heating or domestic water heating that meets all of 
the following criteria:
    (1) An air-to-fuel ratio in the combustion chamber averaging less 
than 35-to-1 as determined by the test procedure prescribed in 
Sec. 60.534 performed at an accredited laboratory;
    (2) A usable firebox volume of less than 20 cubic feet;
    (3) A minimum burn rate of less than 5 kg/hr as determined by the 
test procedure prescribed in Sec. 60.534 performed at an accredited 
laboratory; and
    (4) A maximum weight of 800 kg. In determining the weight of an 
appliance for these purposes, fixtures and devices that are normally 
sold separately, such as flue pipe, chimney, and masonry components that 
are not an integral part of the appliance or heat distribution ducting, 
shall not be included.

[53 FR 5873, Feb. 26, 1988, as amended at 64 FR 7466, Feb. 12, 1999]



Sec. 60.532  Standards for particulate      matter.

    Unless exempted under Sec. 60.530, each affected facility:
    (a)  [Reserved]
    (b) Manufactured on or after July 1, 1990, or sold at retail on or 
after July 1, 1992, shall comply with the following particulate matter 
emission limits as determined by the test methods and procedures in 
Sec. 60.534:
    (1) An affected facility equipped with a catalytic combustor shall 
not discharge into the atmosphere any gases which contain particulate 
matter in excess of a weighted average of 4.1 g/hr. Particulate 
emissions during any test run at any burn rate that is required to be 
used in the weighted average shall not exceed the value calculated for 
``C'' (rounded to 2 significant figures) calculated using the following 
equation:

(i) At burn rates less than or equal to 2.82 kg/hr,
C=3.55 g/kg x BR+4.98 g/hr, where
BR=burn rate in kg/hr,
(ii) At burn rates greater than 2.82 kg/hr,
C=15 g/hr.

    (2) An affected facility not equipped with a catalytic combustor 
shall not discharge into the atmosphere any gases which contain 
particulate matter in excess of a weighted average of 7.5 g/hr. 
Particulate emissions shall not exceed 15 g/hr during any test run at a 
burn rate less than or equal to 1.5 kg/hr that is required to be used in 
the weighted average, and particulate emissions shall not exceed 18 g/hr 
during any test run at a burn rate greater than 1.5 kg/hr that is 
required to be used in the weighted average.

[53 FR 5873, Feb. 26, 1988, as amended at 60 FR 33925, June 29, 1995]



Sec. 60.533  Compliance and certification.

    (a) For each model line, compliance with applicable emission limits 
may be determined based on testing of representative affected facilities 
within the model line.
    (b) Any manufacturer of an affected facility may apply to the 
Administrator for a certificate of compliance for a model line. The 
application shall be in writing to: Stationary Source Compliance 
Division (EN-341), U.S. EPA, 401 M Street, SW., Washington, DC, 20460, 
Attention: Wood Heater Program. The manufacturer must submit two 
complete copies of the application and attachments. The application must 
be signed by the manufacturer, or an

[[Page 374]]

authorized representative, and shall contain the following:
    (1) The model name and/or design number,
    (2) Two color photographs of the tested unit (or, for models being 
certified under Sec. 60.530(c), photographs of a representative unit), 
one showing a front view and the other, a side view,
    (3)(i) Engineering drawings and specifications of components that 
may affect emissions (including specifications for each component listed 
in paragraph (k) of this section). Manufacturers may use complete 
assembly or design drawings that have been prepared for other purposes, 
but should designate on the drawings the dimensions of each component 
listed in paragraph (k) of this section. Manufacturers shall identify 
tolerances of components of the tested unit listed in paragraph (k)(2) 
of this section that are different from those specified in that 
paragraph, and show that such tolerances may not reasonably be 
anticipated to cause wood heaters in the model line to exceed the 
applicable emission limits.
    (ii) A statement whether the firebox or any firebox component (other 
than one listed in paragraph (k)(3) of this section) will be composed of 
different material from the material used for the firebox or firebox 
component in the wood heater on which certification testing was 
performed and a description of any such differences.
    (iii) For applications to certify a model line of catalytic wood 
heaters to meet the emission limits in Sec. 60.532(b), a statement 
describing the manufacturer's program to ensure consistency in the size 
of any gap in the catalyst bypass mechanism. The statement shall 
describe, in narrative form, the components of the system that affect 
the size of the gap, any specifications for critical dimensions of any 
such components, and the procedure the manufacturer will use to ensure 
consistency in the size of the catalyst bypass gap.
    (4) All documentation pertaining to a valid certification test, 
including the complete test report and, for all test runs: Raw data 
sheets, laboratory technician notes, calculations, and test results. 
Documentation shall include the items specified in the applicable test 
methods. Recommended formats and guidance materials are available from 
the Administrator.
    (5) For catalytic wood heaters, a copy of the catalytic combustor 
warranty,
    (6) A statement that the manufacturer will conduct a quality 
assurance program for the model line which satisfies the requirements of 
paragraph (o) of this section,
    (7) A statement describing how the tested unit was sealed by the 
laboratory after the completion of certification testing, and
    (8) A statement that the manufacturer will notify the accredited 
laboratory if the application for certification is granted, within 
thirty days of receipt of notification from EPA.
    (9) Statements that the wood heaters manufactured under this 
certificate will be--
    (i) Similar in all material respects to the wood heater submitted 
for certification testing, and
    (ii) Will be labeled as prescribed in Sec. 60.536,
    (10) For catalytic wood heaters, a statement that the warranty, 
access and inspection, and temperature monitoring provisions in 
paragraphs (c), (d), and (m) of this section will be met,
    (11) A statement that the manufacturer will comply with the 
recordkeeping and reporting requirements in Sec. 60.537,
    (12) A written estimate of the number of wood heaters that the 
manufacturer anticipates that he will produce annually for the first two 
production years. Compliance with this provision may be obtained by 
designating one of the following ranges:
    (i) Less than 2,500,
    (ii) 2,500 to 4,999,
    (iii) 5,000 to 9,999,
    (iv) 10,000 to 49,999, and
    (v) 50,000 or greater; and
    (13) At the beginning of each test run in a certification test 
series, two photographs of the fuel load: One before and one after it is 
placed in the wood heater. One of the photographs shall show the front 
view of the wood load and the other shall show the side view.
    (14) For manufacturers seeking certification of model lines under 
Sec. 60.533(e) to meet the emission limits

[[Page 375]]

in Sec. 60.532(b), a statement that the manufacturer has entered into a 
contract with an accredited laboratory which satisfies the requirements 
of paragraph (g) of this section.
    (c) If the affected facility is a catalytic wood heater, the 
warranty for the catalytic combustor shall include the replacement of 
the combustor and any prior replacement combustor without charge to the 
consumer for:
    (1) 2 years from the date the consumer purchased the heater for any 
defects in workmanship or materials that prevent the combustor from 
functioning when installed and operated properly in the wood heater, and
    (2) 3 years from the date the consumer purchased the heater for 
thermal crumbling or disintegration of the substrate material for 
heaters manufactured after July 1, 1990.
    (d) The manufacturer of an affected facility equipped with a 
catalytic combustor shall provide for a means to allow the owner to gain 
access readily to the catalyst for inspection or replacement purposes 
and shall document in his application for certification how the catalyst 
is replaced.
    (e)(1) The Administrator shall issue a certificate of compliance for 
a model line if he determines, based on all information submitted by the 
applicant and any other relevant information available to him, that:
    (i) A valid certification test has demonstrated that the wood heater 
representative of the model line complies with the applicable 
particulate emission limits in Sec. 60.532,
    (ii) Any tolerances or materials for components listed in paragraph 
(k) (2) or (3) of this section that are different from those specified 
in those paragraphs may not reasonably be anticipated to cause wood 
heaters in the model line to exceed the applicable emission limits, and
    (iii) The requirements of paragraphs (b), (c), (d), and (m) of this 
section have been met. The program described under paragraph (b)(3)(iii) 
of this section shall be deemed a tolerance specified in the certified 
design.
    (2)  [Reserved]
    (3) Upon denying certification under this paragraph, the 
Administrator shall give written notice to the manufacturer setting 
forth the basis for his determination.
    (f) To be valid, a certification test must be:
    (1) Announced to the Administrator in accordance with 
Sec. 60.534(e),
    (2) Conducted by a testing laboratory accredited by the 
Administrator pursuant to Sec. 60.535,
    (3) Conducted on a wood heater similar in all material respects to 
other wood heaters of the model line that is to be certified, and
    (4) Conducted in accordance with the test methods and procedures 
specified in Sec. 60.534.
    (g) To have a wood heater model certified under Sec. 60.533(e) to 
meet the emission limits in Sec. 60.532(b), a manufacturer must enter 
into a contract with the accredited laboratory that performed the 
certification test, under which the laboratory will:
    (1) Conduct the random compliance audit test at no cost to the 
manufacturer if EPA selects that laboratory to conduct the test, or
    (2) Pay the manufacturer the reasonable cost of a random compliance 
audit test (as determined by EPA) if EPA selects any other laboratory to 
conduct the test.
    (h)  [Reserved]
    (i) An applicant for certification may apply for a waiver of the 
requirement to submit the results of a certification test pursuant to 
paragraph (b)(4) of this section, if the wood heaters of the model line 
are similar in all material respects to another model line that has 
already been issued a certificate of compliance. A manufacturer that 
seeks a waiver of certification testing must identify the model line 
that has been certified, and must submit a copy of an agreement with the 
owner of the design permitting the applicant to produce wood heaters of 
that design.
    (j)(1) Unless revoked sooner by the Administrator, a certificate of 
compliance shall be valid:
    (i)  [Reserved]
    (ii) For five years from the date of issuance, for a model line 
certified as meeting emission limits in Sec. 60.532(b).
    (2) Upon application for renewal of certification by the 
manufacturer, the

[[Page 376]]

Administrator may waive the requirement for certification testing upon 
determining that the model line continues to meet the requirements for 
certification in paragraph (e) of this section, or that a waiver of 
certification is otherwise appropriate.
    (3) Upon waiving certification testing under paragraph (j)(2) of 
this section, the Administrator shall give written notice to the 
manufacturer setting forth the basis for his determination.
    (k)(1) A model line must be recertified whenever any change is made 
in the design submitted pursuant to Sec. 60.533(b)(3) that is presumed 
to affect the particulate emission rate for that model line. The 
Administrator may waive this requirement upon written request by the 
manufacturer, if he determines that the change may not reasonably be 
anticipated to cause wood heaters in the model line to exceed the 
applicable emission limits. The grant of such a waiver does not relieve 
the manufacturer of any compliance obligations under this subpart.
    (2) Any change in the indicated tolerances of any of the following 
components (where such components are applicable) is presumed to affect 
particulate emissions if that change exceeds \1/4\ inch for 
any linear dimension and 5 percent for any cross-sectional 
area relating to air introduction systems and catalyst bypass gaps 
unless other dimensions and cross-sectional areas are previously 
approved by the Administrator under paragraph (e)(1)(ii) of this 
section:
    (i) Firebox: Dimensions,
    (ii) Air introduction systems: Cross-sectional area of restrictive 
air inlets, outlets, and location, and method of control,
    (iii) Baffles: Dimensions and locations,
    (iv) Refractory/insulation: Dimensions and location,
    (v) Catalyst: Dimensions and location,
    (vi) Catalyst bypass mechanism and, for model lines certified to 
meet the emissions limits in Sec. 60.532(b), catalyst bypass gap 
tolerances (when bypass mechanism is in closed position): Dimensions, 
cross-sectional area, and location,
    (vii) Flue gas exit: Dimensions and location,
    (viii) Door and catalyst bypass gaskets: Dimensions and fit,
    (ix) Outer shielding and coverings: Dimensions and location,
    (x) Fuel feed system: For wood heaters that are designed primarily 
to burn wood pellets and other wood heaters equipped with a fuel feed 
system, the fuel feed rate, auger motor design and power rating, and the 
angle of the auger to the firebox, and
    (xi) Forced air combustion system: For wood heaters so equipped, the 
location and horsepower of blower motors and the fan blade size.
    (3) Any change in the materials used for the following components is 
presumed to affect emissions:
    (i) Refractory/insulation or
    (ii) Door and catalyst bypass gaskets.
    (4) A change in the make, model, or composition of a catalyst is 
presumed to affect emissions, unless the change has been approved in 
advance by the Administrator, based on test data that demonstrate that 
the replacement catalyst is equivalent to or better than the original 
catalyst in terms of particulate emission reduction.
    (l)(1) The Administrator may revoke certification if he determines 
that the wood heaters being produced in that model line do not comply 
with the requirements of this section or Sec. 60.532. Such a 
determination shall be based on all available evidence, including:
    (i) Test data from a retesting of the original unit on which the 
certification test was conducted,
    (ii) A finding that the certification test was not valid. The 
finding must be based on problems or irregularities with the 
certification test or its documentation, but may be supplemented by 
other information.
    (iii) A finding that the labeling of the wood heater does not comply 
with the requirements of Sec. 60.536,
    (iv) Failure by the manufacturer to comply with reporting and 
recordkeeping requirements under Sec. 60.537,
    (v) Physical examination showing that a significant percentage of 
production units inspected are not similar in all material respects to 
the representative affected facility submitted for testing, or

[[Page 377]]

    (vi) Failure of the manufacturer to conduct a quality assurance 
program in conformity with paragraph (o) of this section.
    (2) Revocation of certification under this paragraph shall not take 
effect until the manufacturer concerned has been given written notice by 
the Administrator setting forth the basis for the proposed determination 
and an opportunity to request a hearing under Sec. 60.539.
    (3) Determination to revoke certification based upon audit testing 
shall be made only in accordance with paragraph (p) of this section.
    (m) A catalytic wood heater shall be equipped with a permanent 
provision to accommodate a commercially available temperature sensor 
which can monitor combustor gas stream temperatures within or 
immediately downstream [within 2.54 centimeters (1 inch)] of the 
combustor surface.
    (n) Any manufacturer of an affected facility subject under 
Sec. 60.530(b) to the applicable emission limits of this subpart that 
does not belong to a model line certified under this section shall cause 
that facility to be tested in an accredited laboratory in accordance 
with paragraphs (f) (1), (2), and (4) of this section before it leaves 
the manufacturer's possession and shall report the results to the 
Administrator.
    (o)(1) For each certified model line, the manufacturer shall conduct 
a quality assurance program which satisfies the following requirements:
    (2) Except as provided in paragraph (o)(5) of this section, the 
manufacturer or his authorized representative shall inspect at least one 
from every 150 units produced within a model line to determine that the 
wood heater is within applicable tolerances for all components that 
affect emissions as listed in paragraph (k)(2) of this section.
    (3)(i) Except as provided in paragraph (o)(3)(iii) or (o)(5) of this 
section, the manufacturer or his authorized representative shall conduct 
an emission test on a randomly selected affected facility produced 
within a model line certified under Sec. 60.533 (e) or (h), on the 
following schedule:

------------------------------------------------------------------------
   If weighted average          If yearly production per model is--
   certification test    -----------------------------------------------
     results were--                <2500                   >2500
------------------------------------------------------------------------
70% or less of std......  When directed by EPA,   Every 10,000 stoves or
                           not to exceed once      triennially
                           every 10,000 stoves.    (whichever is more
                                                   frequent).
Within 30% of std.......  Every 5,000 stoves....  Every 5,000 stoves or
                                                   annually (whichever
                                                   is more frequent).
------------------------------------------------------------------------

    (ii) Emission tests shall be conducted in conformity with 
Sec. 60.534(a), using either approved method for measuring particulate 
matter (as provided in Sec. 60.534). The manufacturer shall notify EPA 
by U.S. mail that an emissions test required pursuant to this paragraph 
will be conducted within one week of the mailing of the notification.
    (iii) If the manufacturer stated pursuant to paragraph (b)(3) of 
this section that the firebox or any firebox component would be composed 
of a different material than the material used in the wood heater on 
which certification testing was performed, the first test shall be 
performed before 1,000 wood heaters are produced. The manufacturer shall 
submit a report of the results of this emission test to the 
Administrator within 45 days of the completion of testing.
    (4) The manufacturer shall take remedial measures, as appropriate, 
when inspection or testing pursuant to paragraph (o) of this section 
indicate that affected facilities within the model line are not within 
applicable tolerances or do not comply with applicable emission limit. 
Manufacturers shall record the problem identified, the extent of the 
problem, the remedial measures taken, and the effect of such remedial 
measures as projected by the manufacturer or determined by any 
additional testing.
    (5)(i) If two consecutive passing tests are conducted under either 
paragraph (o) (2) or (3) of this section, the required frequency of 
testing under the applicable paragraph shall be modified as follows: 
Skip every other required test.
    (ii) If five consecutive passing tests are conducted under the 
modified schedule provided for in Paragraph (o)(5)(i) of this section, 
the required

[[Page 378]]

frequency of testing under the applicable paragraph shall be further 
modified as follows: Skip three consecutive required tests after each 
required test that is conducted.
    (iii) Testing shall resume on the frequency specified in the 
paragraph (o) (2) or (3), as applicable, if a test failure results 
during any test conducted under a modified schedule.
    (6) If emissions tests under paragraph (o) of this section are 
conducted at an altitude different from the altitude at which 
certification tests were conducted, and are not conducted under 
pressurized conditions, the results shall be adjusted for altitude in 
accordance with paragraph (h)(3)(iii) of this section.
    (p)(1)(i) The Administrator shall after July 1, 1990, select for 
random compliance audit testing certified wood heater model lines that 
have not already been subject to a random compliance audit under this 
paragraph. The Administrator shall not select more than one model line 
under this program for every five model lines for which certification is 
granted under Sec. 60.533(e) to meet the emission limits in 
Sec. 60.532(b). No accredited laboratory shall test or bear the expense 
of testing, as provided in the contract described in paragraph (g) of 
this section, more than one model line from every five model lines 
tested by the laboratory for which certification was granted. The 
Administrator shall use a procedure that ensures that the selection 
process is random.
    (ii) The Administrator may, by means of a neutral selection scheme, 
select model lines certified under Sec. 60.533(e) or Sec. 60.533(h) for 
selective enforcement audit testing under this paragraph. Prior to July 
1, 1990, the Administrator shall only select a model line for a 
selective enforcement audit on the basis of information indicating that 
affected facilities within the model line may exceed the applicable 
emission limit in Sec. 60.532.
    (2) The Administrator shall randomly select for audit testing five 
production wood heaters from each model line selected under paragraph 
(p)(1) of this section. These wood heaters shall be selected from 
completed units ready for shipment from the manufacturer's facility 
(whether or not the units are in a package or container). The wood 
heaters shall be sealed upon selection and remain sealed until they are 
tested or until the audit is completed. The wood heaters shall be 
numbered in the order that they were selected.
    (3)(i) The Administrator shall test, or direct the manufacturer to 
test, the first of the five wood heaters selected under paragraph (p)(2) 
of this section in a laboratory accredited under Sec. 60.535 that is 
selected pursuant to paragraph (p)(4) of this section.
    (ii) The expense of the random compliance audit test shall be the 
responsibility of the wood heater manufacturer. A manufacturer may 
require the laboratory that performed the certification test to bear the 
expense of a random compliance audit test by means of the contract 
required under paragraph (g) of this section. If the laboratory with 
which the manufacturer had a contract has ceased business due to 
bankruptcy or is otherwise legally unable to honor the contract, the 
Administrator will not select any of that manufacturer's model lines for 
which certification testing has been conducted by that laboratory for a 
random compliance audit test.
    (iii) The test shall be conducted using the same test method and 
procedure used to obtain certification. If the certification test 
consisted of more than one particulate sampling test method, the 
Adminstrator may use either one of these methods for the purpose of 
audit testing. If the test is performed in a pressure vessel, air 
pressure in the pressure vessel shall be maintained within 1 percent of 
the average of the barometric pressures recorded for each individual 
test run used to calculate the weighted average emission rate for the 
certification test. The Administrator shall notify the manufacturer at 
least one week prior to any test under this paragraph, and allow the 
manufacturer and/or his authorized representatives to observe the test.
    (4)(i) Except as provided in this paragraph, the Administrator may 
select any accredited laboratory for audit testing.

[[Page 379]]

    (ii)(A) The Administrator shall select the accredited laboratory 
that performed the test used to obtain certification for audit testing, 
until the Administrator has amended this subpart, based upon a 
determination pursuant to paragraph (p)(4)(ii)(B) of this section, to 
allow testing at another laboratory. If another laboratory is selected 
pursuant to this paragraph, and the overall precision of the test method 
and procedure is greater than 1 gram per hour of the 
weighted average at laboratories below 304 meters (1,000 feet) elevation 
(or equivalent), the interlaboratory component of the precision shall be 
added to the applicable emissions standard for the purposes of this 
paragraph.
    (B)  [Reserved]
    (iii) The Administrator shall not select an accredited laboratory 
that is located at an elevation more than 152 meters (500 feet) higher 
than the elevation of the laboratory which performed the test used to 
obtain certification, unless the audit test is performed in a pressure 
vessel.
    (5)(i) If emissions from a wood heater tested under paragraph (p)(3) 
of this section exceed the applicable weighted average emission limit by 
more than 50 percent, the Administrator shall so notify the manufacturer 
that certification for that model line is suspended effective 72 hours 
from the receipt of the notice, unless the suspension notice is 
withdrawn by the Administrator. The suspension shall remain in effect 
until withdrawn by the Administrator, or 30 days from its effective date 
(if a revocation notice under paragraph (p)(5)(ii) of this section is 
not issued within that period), or the date of final agency action on 
revocation, whichever occurs earlier.
    (ii)(A) If emissions from a wood heater tested under paragraph 
(p)(3) of this section exceed the applicable weighted average emission 
limit, the Administrator shall notify the manufacturer that 
certification is revoked for that model line.
    (B) A revocation notice under paragraph (p)(5)(ii)(A) shall become 
final and effective 60 days after receipt by the manufacturer, unless it 
is withdrawn, a hearing is requested under Sec. 60.539, or the deadline 
for requesting a hearing is extended.
    (C) The Administrator may extend the deadline for requesting a 
hearing for up to 60 days for good cause.
    (D) A manufacturer may extend the deadline for requesting a hearing 
for up to six months, by agreeing to a voluntary suspension of 
certification.
    (iii) Any notification under paragraph (p)(5)(i) or (p)(5)(ii) of 
this section shall include a copy of a preliminary test report from the 
accredited laboratory. The accredited laboratory shall provide a 
preliminary test report to the Administrator within 10 days of the 
completion of testing, if a wood heater exceeds the applicable emission 
limit in Sec. 60.532. The laboratory shall provide the Administrator and 
the manufacturer, within 30 days of the completion of testing, all 
documentation pertaining to the test, including the complete test report 
and raw data sheets, laboratory technician notes, and test results for 
all test runs.
    (iv) Upon receiving notification of a test failure under paragraph 
(p)(5)(ii) of this section, the manufacturer may submit some or all of 
the remaining four wood heaters selected under paragraph (p)(2) of this 
section for testing at his own expense, in the order they were selected 
by the Administrator, at the laboratory that performed the emissions 
test for the Administrator.
    (v) Whether or not the manufacturer proceeds under paragraph 
(p)(5)(iv) of this section, the manufacturer may submit any relevant 
information to the Administrator, including any other test data 
generated pursuant to this subpart. The manufacturer shall pay the 
expense of any testing performed for him.
    (vi) The Administrator shall withdraw any notice issued under 
paragraph (p)(5)(ii) of this section if tests under paragraph (p)(5)(iv) 
of this section show either--
    (A) That all four wood heaters tested for the manufacturer met the 
applicable weighted average emission limits, or
    (B) That the second and third wood heaters selected met the 
applicable weighted average emission limits and the average of all three 
weighted averages (including the original audit test)

[[Page 380]]

was below the applicable weighted average emission limits.
    (vii) The Administrator may withdraw any proposed revocation, if the 
Administrator finds that an audit test failure has been rebutted by 
information submitted by the manufacturer under paragraph (p)(5)(iv) of 
this section and/or (p)(5)(v) of this section or by any other relevant 
information available to him.
    (viii) Any withdrawal of a proposed revocation shall be accompanied 
by a document setting forth its basis.

[53 FR 5874, Feb. 26, 1988; 53 FR 14889, Apr. 26, 1988, as amended at 60 
FR 33925, June 29, 1995; 63 FR 64874, Nov. 24, 1998]



Sec. 60.534  Test methods and procedures.

    Test methods and procedures in appendix A of this part, except as 
provided under Sec. 60.8(b), shall be used to determine compliance with 
the standards and requirements for certification under Secs. 60.532 and 
60.533 as follows:
    (a) Method 28 shall be used to establish the certification test 
conditions and the particulate matter weighted emission values.
    (b) Emission concentrations may be measured with either:
    (1) Method 5G, if a dilution tunnel sampling location is used, or
    (2) Method 5H, if a stack location is used.
    (c) Method 28A shall be used to determine that a wood combustion 
unit qualifies under the definition of wood heater in Sec. 60.531(a). If 
such a determination is necessary, this test shall be conducted by an 
accredited laboratory.
    (d) Appendix J is used as an optional procedure in establishing the 
overall thermal efficiency of wood heaters. (To be proposed separately.)
    (e)(1) The manufacturer of an affected facility shall notify the 
Administrator of the date that certification testing is scheduled to 
begin. (A notice from the testing lab containing the information 
required in Sec. 60.533(f)(1) may be used to satisfy this requirement.) 
This notice shall be at least 30 days before the start of testing. The 
notification of testing shall be in writing, and include the 
manufacturer's name and address, the testing laboratory's name, the 
model name and number (or, if unavailable, some other way to distinguish 
between models), and the dates of testing.
    (2) Any emission testing conducted on the wood heater for which 
notice was delivered shall be presumed to be certification testing if 
such testing occurs on or after the scheduled date of testing and before 
a test report is submitted to the Administrator. If certification 
testing is interrupted for more than 24 hours, the laboratory shall 
notify the Administrator by telephone, as soon as practicable, and also 
by letter, stating why the testing was interrupted and when it is 
expected to be resumed.
    (3) A manufacturer or laboratory may change the date that testing is 
scheduled to begin by notifying the Administrator at least 14 days 
before the start of testing. Notification of schedule change shall be 
made at least two working days prior to the originally scheduled test 
date. This notice of rescheduling shall be made by telephone or other 
expeditious means and shall be documented in writing and sent 
concurrently.
    (4) A model line may be withdrawn from testing before the 
certification test is complete, provided the wood heater is sealed in 
accordance with Sec. 60.535(g). The manufacturer shall notify the 
Administrator 30 days before the resumption of testing.
    (5) The manufacturer or laboratory shall notify the Administrator if 
a test is not completed within the time allotted as set forth in the 
notice of testing. The notification shall be made by the end of the 
allotted testing period by telephone or other expeditious means, and 
documented in writing sent concurrently, and shall contain the dates 
when the test will be resumed. Unless otherwise approved by the 
Administrator, failure to conduct a certification test as scheduled 
without notifying the Administrator of any schedule change 14 days prior 
to the schedule or revised test dates will result in voiding the 
notification. In the case of a voided notification, the manufacturer 
shall provide the Administrator with a second notification at least 30 
days prior to the new test dates. The

[[Page 381]]

Administrator may waive the requirement for advance notice for test 
resumptions.
    (f) The testing laboratory shall allow the manufacturer to observe 
certification testing. However, manufacturers shall not involve 
themselves in the conduct of the test after the pretest burn (as defined 
by EPA Method 28) has begun. Communications between the manufacturer and 
laboratory personnel regarding operation of the wood heater shall be 
limited to written communications transmitted prior to the first pretest 
burn of the certification series. Written communications between the 
manufacturer and laboratory personnel may be exchanged during the 
certification test only if deviations from the test procedures are 
observed that constitute improper conduct of the test. All 
communications shall be included in the test documentation required to 
be submitted under Sec. 60.533(b)(4) and shall be consistent with 
instructions provided in the owner's manual required under 
Sec. 60.536(k), except to the extent that they address details of the 
certification tests that would not be relevant to owners.



Sec. 60.535  Laboratory accreditation.

    (a)(1) A laboratory may apply for accreditation by the Administrator 
to conduct wood heater certification tests pursuant to Sec. 60.533. The 
application shall be in writing to: Emission Measurement Branch (MD-13), 
U.S. EPA, Research Triangle Park, NC 27711, Attn: Wood Heater Laboratory 
Accreditation.
    (2)  [Reserved]
    (3) If accreditation is denied under this section, the Administrator 
shall give written notice to the laboratory setting forth the basis for 
his determination.
    (b) In order for a test laboratory to qualify for accreditation the 
laboratory must:
    (1) Submit its written application providing the information related 
to laboratory equipment and management and technical experience of 
laboratory personnel. Applications from laboratories shall establish 
that:
    (i) Laboratory personnel have a total of one year of relevant 
experience in particulate measurement, including at least three months 
experience in measuring particulate emissions from wood heaters,
    (ii) The laboratory has the equipment necessary to perform testing 
in accordance with either Sec. 60.534(b) (1) or (2), and
    (iii) Laboratory personnel have experience in test management or 
laboratory management.
    (2) Have no conflict of interest and receive no financial benefit 
from the outcome of certification testing conducted pursuant to 
Sec. 60.533,
    (3) Agree to enter into a contract as described in Sec. 60.533(g) 
with each wood heater manufacturer for whom a certification test has 
been performed.
    (4)  [Reserved]
    (5) Demonstrate proficiency to achieve reproducible results with at 
least one test method and procedure in Sec. 60.534(b), by:
    (i) Performing a test consisting of at least eight test runs (two in 
each of the four burn rate categories) on a wood heater identified by 
the Administrator,
    (ii) Providing the Administrator at least 30 days prior notice of 
the test to afford the Administrator the opportunity to have an observer 
present, and
    (iii) Submitting to the Administrator all documentation pertaining 
to the test, including a complete test report and raw data sheets, 
laboratory technical notes, and test results for all test runs,
    (6) Be located in the continental United States,
    (7) Agree to participate annually in a proficiency testing program 
conducted by the Administrator,
    (8) Agree to allow the Administrator access to observe certification 
testing,
    (9) Agree to comply with a reporting and recordkeeping requirements 
that affect testing laboratories, and
    (10) Agree to accept the reasonable cost of an RCA test (as 
determined by the Administrator) if it is selected to conduct the RCA 
test of a model line originally tested for certification at another 
laboratory.
    (c)--(d)  [Reserved]
    (e)(1) The Administrator may revoke EPA laboratory accreditation if 
he determines that the laboratory:

[[Page 382]]

    (i) No longer satisfies the requirements for accreditation in 
paragraph (b) or (c),
    (ii) Does not follow required procedures or practices,
    (iii) Had falsified data or otherwise misrepresented emission data,
    (iv) [Reserved]
    (v) Failed to participate in a proficiency testing program, in 
accordance with its commitment under paragraph (b)(5) of this section, 
or
    (vi) Failed to seal the wood heater in accordance with paragraph (g) 
of this section.
    (2) Revocation of accreditation under this paragraph shall not take 
effect until the laboratory concerned has been given written notice by 
the Administrator setting forth the basis for the proposed determination 
and an opportunity for a hearing under Sec. 60.539. However, if 
revocation is ultimately upheld, all tests conducted by the laboratory 
after written notice was given may, at the discretion of the 
Administrator, be declared invalid.
    (f) Unless revoked sooner, a certificate of accreditation granted by 
the Administrator shall be valid:
    (1) For five years from the date of issuance, for certificates 
issued under paragraph (b) of this section, or
    (2) Until July 1, 1990, for certificates issued under paragraph (c) 
of this section.
    (g) A laboratory accredited by the Administrator shall seal any wood 
heater on which it performed certification tests, immediately upon 
completion or suspension of certification testing, by using a 
laboratory-specific seal.

[53 FR 5873, Feb. 26, 1988, as amended at 60 FR 33925, June 29, 1995]



Sec. 60.536  Permanent label, temporary label, and owner's manual.

    (a)(1) Each affected facility manufactured on or after July 1, 1988, 
or offered for sale at retail on or after July 1, 1990, shall have a 
permanent label affixed to it that meets the requirements of this 
section.
    (2) Except for wood heaters subject to Sec. 60.530 (e), (f), or (g), 
the permanent label shall contain the following information:
    (i) Month and year of manufacture,
    (ii) Model name or number, and
    (iii) Serial number.
    (3) The permanent label shall:
    (i) Be affixed in a readily visible or accessible location,
    (ii) Be at least 3\1/2\ inches long and 2 inches wide,
    (iii) Be made of a material expected to last the lifetime of the 
wood heater,
    (iv) Present required information in a manner so that it is likely 
to remain legible for the lifetime of the wood heater, and
    (v) Be affixed in such a manner that it cannot be removed from the 
appliance without damage to the label.
    (4) The permanent label may be combined with any other label, as 
long as the required information is displayed, and the integrity of the 
permanent label is not compromised.
    (b) If the wood heater belongs to a model line certified under 
Sec. 60.533, and has not been found to exceed the applicable emission 
limits or tolerances through quality assurance testing, one of the 
following statements, as appropriate, shall appear on the permanent 
label:

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Certified to comply with July, 1988, particulate emission standards.
    Not approved for sale after June 30, 1992.


or

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Certified to comply with July, 1990, particulate emission standards.

    (c)(1) If compliance is demonstrated under Sec. 60.530(c), the 
following statement shall appear on the permanent label:

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Certified under 40 CFR 60.530(c). Not approved for sale after June 
30, 1992.

    (2) If compliance is demonstrated under Sec. 60.533(h), one of the 
following statements, as appropriate, shall appear on the permanent 
label:

[[Page 383]]

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Certified under 40 CFR 60.533(h) to comply with July, 1988 
particulate emissions standards. Not approved for sale after June 30, 
1992.


or

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Certified under 40 CFR 60.533(h), to comply with July, 1990 
particulate emissions standards.

    (d) Any label statement under paragraph (b) or (c) of this section 
constitutes a representation by the manufacturer as to any wood heater 
that bears it:
    (1) That certification was in effect at the time the wood heater 
left the possession of the manufacturer,
    (2) That the manufacturer was, at the time the label was affixed, 
conducting a quality assurance program in conformity with 
Sec. 60.533(o),
    (3) That as to any wood heater individually tested for emissions by 
the manufacturer under Sec. 60.533(o)(3), that it met the applicable 
emissions limits, and
    (4) That as to any wood heater individually inspected for tolerances 
under Sec. 60.533(o)(2), that the wood heater is within applicable 
tolerances.
    (e) If an affected facility is exempt from the emission limits in 
Sec. 60.532 under the provisions of Sec. 60.530(d), the following 
statement shall appear on the permanent label:

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Not certified. Approved for sale until June 30, 1991.

    (f)(1) If an affected facility is manufactured in the U.S. for 
export, the following statement shall appear on the permanent label:

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Export stove. May not be operated within the United States.

    (2) If an affected facility is manufactured for use for research and 
development purposes as provided in Sec. 60.530(f), the following 
statement shall appear on the permanent label:

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Not certified. Research Stove. Not approved for sale.

    (3) If an appliance is a coal-only heater as defined in Sec. 60.530, 
the following statement shall appear on the permanent label:

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    This heater is only for burning coal. Use of any other solid fuel 
except for coal ignition purposes is a violation of Federal law.

    (g) Any affected facility that does not qualify for labeling under 
any of paragraphs (b) through (f) of this section shall bear one of the 
following labels:
    (1) If the test conducted under Sec. 60.533(n) indicates that the 
facility does not meet applicable emissions limits:

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Not certified. Does not meet EPA particulate emission standards. IT 
IS AGAINST THE LAW TO OPERATE THIS WOOD HEATER.

    (2) If the test conducted under Sec. 60.533(n) indicates that the 
facility does meet applicable emissions limits:

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Not certified. Meets EPA particulate emission standards.

    (3) If the facility has not been tested as required by 
Sec. 60.533(e):

                  U.S. ENVIRONMENTAL PROTECTION AGENCY

    Not certified. Not tested. Not approved for sale. IT IS AGAINST THE 
LAW TO OPERATE THIS WOOD HEATER.

    (h) For affected facilities equipped with catalytic combustors, the 
following statement shall appear on the permanent label:

    This wood heater contains a catalytic combustor, which needs 
periodic inspection and replacement for proper operation. Consult 
owner's manual for further information. It is against the law to operate 
this wood heater in a manner inconsistent with operating instructions in 
the owner's manual, or if the catalytic element is deactivated or 
removed.


[[Page 384]]


    (i) An affected facility permanently labeled under paragraph (b) or 
(c) of this section shall have attached to it a temporary label that 
shall contain only the following:
    (1) A statement indicating the compliance status of the model. The 
statement shall be one of the statements provided in appendix I, section 
2.2.1. Instructions on the statement to select are provided in appendix 
I.
    (2) A graphic presentation of the composite particulate matter 
emission rate as determined in the certification test, or as determined 
by the Administrator if the wood heater is certified under 
Sec. 60.530(c). The method for presenting this information is provided 
in appendix I, section 2.2.2.
    (3) A graphic presentation of the overall thermal efficiency of the 
model. The method for presenting this information is provided in 
appendix I, section 2.2.3. At the discretion of the manufacturer, either 
the actual measured efficiency of the model or its estimated efficiency 
may be used for purposes of this paragraph. The actual efficiency is the 
efficiency measured in tests conducted pursuant to Sec. 60.534(d). The 
estimated efficiency shall be 72 percent if the model is catalyst-
equipped and 63 percent if the model is not catalyst equipped, and 78 
percent if the model is designed to burn wood pellets for fuel. Wood 
heaters certified under Sec. 60.530(c) shall use these estimated 
efficiencies.
    (4) A numerical expression of the heat output range of the unit, in 
British thermal units per hour (Btu/hr) rounded to the nearest 100 Btu/
hr.
    (i) If the manufacturer elects to report the overall efficiency of 
the model based on test results pursuant to paragraph (i)(3) of this 
section, he shall report the heat output range measured during the 
efficiency test. If an accessory device is used in the certification 
test to achieve any low burn rate criterion specified in this subpart, 
and if this accessory device is not sold as a part of the wood heater, 
the heat output range shall be determined using the formula in paragraph 
(i)(4)(ii) of this section based upon the lowest sustainable burn rate 
achieved without the accessory device.
    (ii) If the manufacturer elects to use the estimated efficiency as 
provided in paragraph (i)(3) of this section, he shall estimate the heat 
output of the model as follows:

HOE=(19,140)  x  (Estimated overall efficiency/100)  x  BR, 
          where
HOE=Estimated heat output in Btu/hr
BR=Burn rate in dry kilograms of test fuel per hour

    (5) Statements regarding the importance of operation and 
maintenance. (Instructions regarding which statements must be used are 
provided in appendix I, section 2.), and
    (6) The manufacturer and the identification of the model.
    (j)(1) An affected facility permanently labeled under paragraph (e), 
(f)(3), or (g) of this section have attached to it a temporary label 
that shall contain only the information provided for in appendix I, 
section 2.3, 2.4, or 2.5, as applicable.
    (2) The temporary label of an affected facility permently labeled 
under paragraph (b), (c), (e), (f)(3), or (g) of this section shall:
    (i) Be affixed to a location on the wood heater that is readily seen 
and accessible when the wood heater is offered for sale to consumers by 
any commercial owner;
    (ii) Not be combined with any other label or information;
    (iii) Be attached to the wood heater in such a way that it can be 
easily removed by the consumer upon purchase, except that the label on 
wood heaters displayed by a commercial owner may have an adhesive 
backing or other means to preserve the label to prevent its removal or 
destruction;
    (iv) Be printed on 90 pound bond paper in black ink with a white 
background except that those for models that are not otherwise exempted 
which do not meet the applicable emission limits, or have not been 
tested pursuant to this subpart, shall be on a red background as 
described in appendix I, section 2.5;
    (v) Have dimensions of five inches by seven inches as described in 
appendix I, section 2.1;
    (vi) Have wording, presentation of the graphic data, and typography 
as presented in appendix I.

[[Page 385]]

    (k)(1) Each affected facility offered for sale by a commercial owner 
must be accompanied by an owner's manual that shall contain the 
information listed in paragraph (k)(2) of this section (pertaining to 
installation), and paragraph (k)(3) of this section (pertaining to 
operation and maintenance) of this section. Such information shall be 
adequate to enable consumers to achieve optimal emissions performance. 
Such information shall be consistent with the operating instructions 
provided by the manufacturer to the laboratory for operating the wood 
heater during certification testing, except for details of the 
certification test that would not be relevant to the ultimate purchaser.
    (2) Installation information: Requirements for achieving proper 
draft.
    (3) Operation and maintenance information:
    (i) Wood loading procedures, recommendations on wood selection, and 
warnings on what fuels not to use, such as treated wood, colored paper, 
cardboard, solvents, trash and garbage,
    (ii) Fire starting procedures,
    (iii) Proper use of air controls,
    (iv) Ash removal procedures,
    (v) Instructions on gasket replacement,
    (vi) For catalytic models, information on the following pertaining 
to the catalytic combustor: Procedures for achieving and maintaining 
catalyst activity, maintenance procedures, procedures for determining 
deterioration or failure, procedures for replacement, and information on 
how to exercise warranty rights, and
    (vii) For catalytic models, the following statement--
    This wood heater contains a catalytic combustor, which needs 
periodic inspection and replacement for proper operation. It is against 
the law to operate this wood heater in a manner inconsistent with 
operating instructions in this manual, or if the catalytic element is 
deactivated or removed.

    (4) Any manufacturer using EPA model language contained in appendix 
I to satisfy any requirement of this paragraph shall be in compliance 
with that requirement, provided that the particular model language is 
printed in full, with only such changes as are necessary to ensure 
accuracy for the particular model line.
    (l) Wood heaters that are affected by this subpart, but that have 
been owned and operated by a noncommercial owner, are not subject to 
paragraphs (j) and (k) of this section when offered for resale.

[53 FR 5873, Feb. 26, 1988, as amended at 53 FR 12009, Apr. 12, 1988; 64 
FR 7466, Feb. 12, 1999]



Sec. 60.537  Reporting and recordkeeping.

    (a)(1) Each manufacturer who holds a certificate of compliance under 
Sec. 60.533(e) or (h) for a model line shall maintain records containing 
the information required by this paragraph with respect to that model 
line. Each manufacturer of a model line certified under Sec. 60.530(c) 
shall maintain the information required by paragraphs (a)(3) and (a)(5) 
of this section for that model line.
    (2)(i) All documentation pertaining to the certification test used 
to obtain certification, including the full test report and raw data 
sheets, laboratory technician notes, calculations, and the test results 
for all test runs.
    (ii) Where a model line is certified under Sec. 60.533(h) and later 
certified under Sec. 60.533(e), all documentation pertaining to the 
certification test used to obtain certification in each instance shall 
be retained.
    (3) For parameter inspections conducted pursuant to 
Sec. 60.533(o)(2), information indicating the extent to which tolerances 
for components that affect emissions as listed in Sec. 60.533(k)(2) were 
inspected, and at what frequency, the results of such inspections, 
remedial actions taken, if any, and any follow-up actions such as 
additional inspections,
    (4) For emissions tests conducted pursuant to Sec. 60.533(o)(3), all 
test reports, data sheets, laboratory technician notes, calculations, 
and test results for all test runs, the remedial actions taken, if any, 
and any follow-up actions such as additional testing,
    (5) The number of affected facilities that are sold each year, by 
certified model line,
    (b)(1) Each accredited laboratory shall maintain records consisting 
of all documentation pertaining to each certification test, including 
the full test report and raw data sheets, technician

[[Page 386]]

notes, calculations, and the test results for all test runs.
    (2)  [Reserved]
    (3) Each accredited laboratory shall report to the Administrator 
within 24 hours whenever a manufacturer which has notified the 
laboratory that it intends to apply for alternative certification for a 
model line fails to submit on schedule a representative unit of that 
model line for certification testing.
    (c) Any wood heater upon which certification tests were performed 
based upon which certification was granted under Sec. 60.533(e) shall be 
retained (sealed and unaltered) at the manufacturer's facility for as 
long as the model line in question is manufactured. Any such wood heater 
shall be made available upon request to the Administrator for inspection 
and testing.
    (d)--(e)  [Reserved]
    (f) Each manufacturer of an affected facility certified under 
Sec. 60.533 shall submit a report to the Administrator every 2 years 
following issuance of a certificate of compliance for each model line. 
This report shall certify that no changes in the design or manufacture 
of this model line have been made that require recertification under 
Sec. 60.533(k).
    (g) Each manufacturer shall maintain records of the model and number 
of wood heaters exempted under Sec. 60.530(f).
    (h) Each commercial owner of a wood heater previously owned by a 
noncommercial owner for his personal use shall maintain records of the 
name and address of the previous owner.
    (i)(1) Unless otherwise specified, all records required under this 
section shall be maintained by the manufacturer or commercial owner of 
the affected facility for a period of no less than 5 years.
    (2) Unless otherwise specified, all reports to the Administrator 
required under this subpart shall be made to: Stationary Source 
Compliance Division (EN-341), U.S. EPA, 401 M Street SW., Washington, 
DC, 20460 Attention: Wood Heater Program.
    (3) A report to the Administrator required under this subpart shall 
be deemed to have been made when it is properly addressed and mailed, or 
placed in the possession of a commercial courier service.

[53 FR 5873, Feb. 26, 1988, as amended at 60 FR 33925, June 29, 1995]



Sec. 60.538  Prohibitions.

    (a) No person shall operate an affected facility that does not have 
affixed to it a permanent label pursuant to Sec. 60.536 (b), (c), (e), 
(f)(2), (f)(3), or (g)(2).
    (b) No manufacturer shall advertise for sale, offer for sale, or 
sell an affected facility that--
    (1) Does not have affixed to it a permanent label pursuant to 
Sec. 60.536, and
    (2) Has not been tested when required by Sec. 60.533(n).
    (c) On or after July 1, 1990, no commercial owner shall advertise 
for sale, offer for sale, or sell an affected facility that does not 
have affixed to it a permanent label pursuant to Sec. 60.536 (b), (c), 
(e), (f)(1), (f)(3), (g)(1) or (g)(2). No person shall advertise for 
sale, offer for sale, or sell an affected facility labeled under 
Sec. 60.536(f)(1) except for export.
    (d)(1) No commercial owner shall advertise for sale, offer for sale 
or sell an affected facility permanently labeled under Sec. 60.536 (b) 
or (c) unless:
    (i) The affected facility has affixed to it a removable label 
pursuant to Sec. 60.536 of this subpart,
    (ii) He provides any purchaser or transferee with an owner's manual 
pursuant to Sec. 60.536(k) of this subpart, and
    (iii) He provides any purchaser or transferee with a copy of the 
catalytic combustor warranty (for affected facilities with catalytic 
combustors).
    (2) No commercial owner shall advertise for sale, offer for sale, or 
sell an affected facility permanently labeled under Sec. 60.536 (e), 
(f)(3), or (g), unless the affected facility has affixed to it a 
removable label pursuant to Sec. 60.536 of this subpart. This 
prohibition does not apply to wood heaters affected by this subpart that 
have been previously owned and operated by a noncommercial owner.
    (3) A commercial owner other than a manufacturer complies with the 
requirements of paragraph (d) of this section if he--
    (i) Receives the required documentation from the manufacturer or a 
previous commercial owner and

[[Page 387]]

    (ii) Provides that documentation unaltered to any person to whom the 
wood heater that it covers is sold or transferred.
    (e)(1) In any case in which the Administrator revokes a certificate 
of compliance either for the knowing submission of false or inaccurate 
information or other fraudulent acts, or based on a finding under 
Sec. 60.533(l)(1)(ii) that the certification test was not valid, he may 
give notice of that revocation and the grounds for it to all commercial 
owners.
    (2) From and after the date of receipt of the notice given under 
paragraph (e)(1) of this section, no commercial owner may sell any wood 
heater covered by the revoked certificate (other than to the 
manufacturer) unless
    (i) The wood heater has been tested as required by Sec. 60.533(n) 
and labeled as required by Sec. 60.536(g) or
    (ii) The model line has been recertified in accordance with this 
subpart.
    (f) No person shall install or operate an affected facility except 
in a manner consistent with the instructions on its permanent label and 
in the owner's manual pursuant to Sec. 60.536(l) of this subpart.
    (g) No person shall operate an affected facility which was 
originally equipped with a catalytic combustor if the catalytic element 
is deactivated or removed.
    (h) No person shall operate an affected facility that has been 
physically altered to exceed the tolerance limits of its certificate of 
compliance.
    (i) No person shall alter, deface, or remove any permanent label 
required to be affixed pursuant to Sec. 60.536 of this subpart.

[53 FR 5873, Feb. 26, 1988; 53 FR 14889, Apr. 26, 1988, as amended at 63 
FR 64874, Nov. 24, 1998]



Sec. 60.539  Hearing and appeal procedures.

    (a)(1) In any case where the Administrator--
    (i) Denies an application under Sec. 60.530(c) or Sec. 60.533(e),
    (ii) Issues a notice of revocation of certification under 
Sec. 60.533(l),
    (iii) Denies an application for laboratory accreditation under 
Sec. 60.535, or
    (iv) Issues a notice of revocation of laboratory accreditation under 
Sec. 60.535(e), the manufacturer or laboratory affected may request a 
hearing under this section within 30 days following receipt of the 
required notification of the action in question.
    (2) In any case where the Administrator issues a notice of 
revocation under Sec. 60.533(p), the manufacturer may request a hearing 
under this section with the time limits set out in Sec. 60.533(p)(5).
    (b) Any hearing request shall be in writing, shall be signed by an 
authorized representative of the petitioning manufacturer or laboratory, 
and shall include a statement setting forth with particularity the 
petitioner's objection to the Administrator's determination or proposed 
determination.
    (c)(1) Upon receipt of a request for a hearing under paragraph (a) 
of this section, the Administrator shall request the Chief 
Administrative Law Judge to designate an Administrative Law Judge as 
Presiding Officer for the hearing. If the Chief Administrative Law Judge 
replies that no Administrative Law Judge is available to perform this 
function, the Administrator shall designate a Presiding Officer who has 
not had any prior responsibility for the matter under review, and who is 
not subject to the direct control or supervision of someone who has had 
such responsibility.
    (2) The hearing shall commence as soon as practicable at a time and 
place fixed by the Presiding Officer.
    (3)(i) A motion for leave to intervene in any proceeding conducted 
under this section must set forth the grounds for the proposed 
intervention, the position and interest of the movant and the likely 
impact that intervention will have on the expeditious progress of the 
proceeding. Any person already a party to the proceeding may file an 
answer to a motion to intervene, making specific reference to the 
factors set forth in the foregoing sentence and paragraph (c)(3)(iii) of 
this section within ten (10) days after service of the motion for leave 
to intervene.
    (ii) A motion for leave to intervene in a proceeding must ordinarily 
be filed before the first prehearing conference or, in the absence of a 
prehearing conference, prior to the setting of a time and place for a 
hearing. Any motion

[[Page 388]]

filed after that time must include, in addition to the information set 
forth in paragraph (c)(3)(i) of this section, a statement of good cause 
for the failure to file in a timely manner. The intervenor shall be 
bound by any agreements, arrangements and other matters previously made 
in the proceeding.
    (iii) A motion for leave to intervene may be granted only if the 
movant demonstrates that his presence in the proceeding would not unduly 
prolong or otherwise prejudice the adjudication of the rights of the 
original parties, and that movant may be adversely affected by a final 
order. The intervenor shall become a full party to the proceeding upon 
the granting of leave to intervene.
    (iv) Persons not parties to the proceeding may move for leave to 
file amicus curiae briefs. The movant shall state his interest and the 
reasons why the proposed amicus brief is desirable. If the motion is 
granted, the Presiding Officer or Administrator shall issue an order 
setting the time for filing such brief. An amicus curia may participate 
in any briefing after his motion is granted, and shall be served with 
all briefs, reply briefs, motions, and orders relating to issues to be 
briefed.
    (4) In computing any period of time prescribed or allowed in this 
subpart, the day of the event from which the designated period begins to 
run shall not be included. Saturdays, Sundays, and Federal legal 
holidays shall be included. When a stated time expires on a Saturday, 
Sunday or legal holiday, the stated time period shall be extended to 
include the next business day.
    (d)(1) Upon his appointment the Presiding Officer shall establish a 
hearing file. The file shall consist of the notice issued by the 
Administrator under Sec. 60.530(c), Sec. 60.533(e), Sec. 60.533(l), 
Sec. 60.533(p), Sec. 60.535(a), or Sec. 60.535(e), together with any 
accompanying material, the request for a hearing and the supporting data 
submitted therewith, and all documents relating to the request for 
certification or accreditation, or the proposed revocation of either.
    (2) The hearing file shall be available for inspection by any party, 
to the extent authorized by law, at the office of the Presiding Officer, 
or other place designated by him.
    (e) Any party may appear in person, or may be represented by counsel 
or by any other duly authorized representative.
    (f)(1) The Presiding Officer upon the request of any party, or at 
his discretion, may order a prehearing conference at a time and place 
specified by him to consider the following:
    (i) Simplification of the issues,
    (ii) Stipulations, admissions of fact, and the introduction of 
documents,
    (iii) Limitation of the number of expert witnesses,
    (iv) Possibility of agreement disposing of all or any of the issues 
in dispute,
    (v) Such other matters as may aid in the disposition of the hearing, 
including such additional tests as may be agreed upon by the parties.
    (2) The results of the conference shall be reduced to writing by the 
Presiding Officer and made part of the record.
    (g)(1) Hearings shall be conducted by the Presiding Officer in an 
informal but orderly and expeditious manner. The parties may offer oral 
or written evidence, subject to the exclusion by the Presiding Officer 
of irrelevant, immaterial and repetitious evidence.
    (2) Witnesses will not be required to testify under oath. However, 
the Presiding Officer shall call to the attention of witnesses that 
their statements may be subject to penalties under title 18, U.S.C. 1001 
for knowingly making false statements or representations or using false 
documents in any matter within the jurisdiction of any department or 
agency of the United States.
    (3) Any witness may be examined or cross-examined by the Presiding 
Officer, the parties, or their representatives.
    (4) Hearings shall be recorded verbatim. Copies of transcripts of 
proceedings may be purchased by the applicant from the reporter.
    (5) All written statements, charts, tabulations, and similar data 
offered in evidence at the hearings shall, upon a showing satisfactory 
to the Presiding Officer of their authenticity, relevancy, and 
materiality, be received in evidence and shall constitute a part of the 
record.

[[Page 389]]

    (h)(1) The Presiding Officer shall make an initial decision which 
shall include written findings and conclusions and the reasons or basis 
therefor on all the material issues of fact, law, or discretion 
presented on the record. The findings, conclusions, and written decision 
shall be provided to the parties and made a part of the record. The 
initial decision shall become the decision of the Environmental Appeals 
Board without further proceedings unless there is an appeal to the 
Environmental Appeals Board or motion for review by the Environmental 
Appeals Board. Except as provided in paragraph (h)(3) of this section, 
any such appeal shall be taken within 20 days of the date the initial 
decision was filed.
    (2) The Administrator delegates authority to the Environmental 
Appeals Board to issue final decisions in appeals filed under this 
section. An appeal directed to the Administrator, rather than to the 
Environmental Appeals Board, will not be considered. This delegation of 
authority to the Environmental Appeals Board does not preclude the 
Environmental Appeals Board from referring an appeal or a motion filed 
under this part to the Administrator for decision when the Environmental 
Appeals Board, in its discretion, deems it appropriate to do so. When an 
appeal or motion is referred to the Administrator, all parties shall be 
so notified and the rules in this section referring to the Environmental 
Appeals Board shall be interpreted as referring to the Administrator. On 
appeal from or review of the initial decision, the Environmental Appeals 
Board shall have all the powers that it would have in making the initial 
decision including the discretion to require or allow briefs, oral 
argument, the taking of additional evidence or the remanding to the 
Presiding Officer for additional proceedings. The decision by the 
Environmental Appeals Board shall include written findings and 
conclusions and the reasons or basis therefor on all the material issues 
of fact, law, or discretion presented on the appeal or considered in the 
review.
    (3) In any hearing requested under paragraph (a)(2) of this section 
the Presiding Officer shall render his initial decision within 60 days 
of that request. Any appeal to the Environmental Appeals Board shall be 
taken within 10 days of the initial decision, and the Environmental 
Appeals Board shall render its decision in the appeal within 30 days of 
the filing of the appeal.

[53 FR 5873, Feb. 26, 1988, as amended at 57 FR 5328, Feb. 13, 1992]



Sec. 60.539a  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities that shall not be delegated to states:
    (1)  [Reserved]
    (2) Section 60.531, Definitions,
    (3) Section 60.533, Compliance and certification,
    (4) Section 60.534, Test methods and procedures,
    (5) Section 60.535, Laboratory accreditation,
    (6) Section 60.536(i)(2), determination of emission rates for 
purposes of labeling wood heaters certified under Sec. 60.530(c),
    (7) Section 60.537, Reporting and recordkeeping,
    (8) Section 60.538(e), revocation of certification, and
    (9) Section 60.539, Hearings and appeals procedures.

[53 FR 5873, Feb. 26, 1988, as amended at 60 FR 33925, June 29, 1995]



Sec. 60.539b  General provisions exclusions.

    The following provisions of subpart A of part 60 do not apply to 
this subpart:
    (a) Section 60.7,
    (b) Section 60.8(a), (c), (d), (e), and (f), and
    (c) Section 60.15(d).



Subpart BBB--Standards of Performance for the Rubber Tire Manufacturing 
                                Industry

    Source: 52 FR 34874, Sept. 15, 1987, unless otherwise noted.

[[Page 390]]



Sec. 60.540  Applicability and designation of affected facilities.

    (a) The provisions of this subpart, except as provided in paragraph 
(b) of this section, apply to each of the following affected facilities 
in rubber tire manufacturing plants that commence construction, 
modification, or reconstruction after January 20, 1983: each undertread 
cementing operation, each sidewall cementing operation, each tread end 
cementing operation, each bead cementing operation, each green tire 
spraying operation, each Michelin-A operation, each Michelin-B 
operation, and each Michelin-C automatic operation.
    (b) The owner or operator of each undertread cementing operation and 
each sidewall cementing operation in rubber tire manufacturing plants 
that commenced construction, modification, or reconstruction after 
January 20, 1983, and before September 15, 1987, shall have the option 
of complying with the alternate provisions in Sec. 60.542a. This 
election shall be irreversible. The alternate provisions in Sec. 60.542a 
do not apply to any undertread cementing operation or sidewall cementing 
operation that is modified or reconstructed after September 15, 1987. 
The affected facilities in this paragraph are subject to all applicable 
provisions of this subpart.
    (c) Although the affected facilities listed under Sec. 60.540(a) are 
defined in reference to the production of components of a ``tire,'' as 
defined under Sec. 60.541(a), the percent emission reduction 
requirements and VOC use cutoffs specified under Sec. 60.542(a)(1), (2), 
(6), (7)(iii), (7)(iv), (8), (9), and (10) refer to the total amount of 
VOC used (the amount allocated to the affected facility), including the 
VOC used in cements and organic solvent-based green tire spray materials 
for tire types not listed in the Sec. 60.541(a) definition of ``tire.''

[52 FR 34874, Sept. 15, 1987, as amended at 54 FR 38635, Sept. 19, 1989]



Sec. 60.541  Definitions.

    (a) All terms that are used in this subpart and are not defined 
below are given the same meaning as in the Act and in subpart A of this 
part.
    Bead means rubber-covered strands of wire, wound into a circular 
form, which ensure a seal between a tire and the rim of the wheel onto 
which the tire is mounted.
    Bead cementing operation means the system that is used to apply 
cement to the bead rubber before or after it is wound into its final 
circular form. A bead cementing operation consists of a cement 
application station, such as a dip tank, spray booth and nozzles, cement 
trough and roller or swab applicator, and all other equipment necessary 
to apply cement to wound beads or bead rubber and to allow evaporation 
of solvent from cemented beads.
    Component means a piece of tread, combined tread/sidewall, or 
separate sidewall rubber, or other rubber strip that is combined into 
the sidewall of a finished tire.
    Drying area means the area where VOC from applied cement or green 
tire sprays is allowed to evaporate.
    Enclosure means a structure that surrounds a VOC (cement, solvent, 
or spray) application area and drying area, and that captures and 
contains evaporated VOC and vents it to a control device. Enclosures may 
have permanent and temporary openings.
    Green tire means an assembled, uncured tire.
    Green tire spraying operation means the system used to apply a mold 
release agent and lubricant to the inside and/or outside of green tires 
to facilitate the curing process and to prevent rubber from sticking to 
the curing press. A green tire spraying operation consists of a booth 
where spraying is performed, the spray application station, and related 
equipment, such as the lubricant supply system.
    Michelin-A operation means the operation identified as Michelin-A in 
the Emission Standards and Engineering Division confidential file as 
referenced in Docket A-80-9, Entry II-B-12.
    Michelin-B operation means the operation identified as Michelin-B in 
the Emission Standards and Engineering Division confidential file as 
referenced in Docket A-80-9, Entry II-B-12.
    Michelin-C-automatic operation means the operation identifed as 
Michelin-C-automatic in the Emission Standards and Engineering Division 
confidential

[[Page 391]]

file as referenced in Docket A-80-9, Entry II-B-12.
    Month means a calendar month or a prespecified period of 28 days or 
35 days (utilizing a 4-4-5-week recordkeeping and reporting schedule).
    Organic solvent-based green tire spray means any mold release agent 
and lubricant applied to the inside or outside of green tires that 
contains more than 12 percent, by weight, of VOC as sprayed.
    Permanent opening means an opening designed into an enclosure to 
allow tire components to pass through the enclosure by conveyor or other 
mechanical means, to provide access for permanent mechanical or 
electrical equipment, or to direct air flow into the enclosure. A 
permanent opening is not equipped with a door or other means of 
obstruction of air flow.
    Sidewall cementing operation means the system used to apply cement 
to a continuous strip of sidewall component or any other continuous 
strip component (except combined tread/sidewall component) that is 
incorporated into the sidewall of a finished tire. A sidewall cementing 
operation consists of a cement application station and all other 
equipment, such as the cement supply system and feed and takeaway 
conveyors, necessary to apply cement to sidewall strips or other 
continuous strip component (except combined tread/sidewall component) 
and to allow evaporation of solvent from the cemented rubber.
    Temporary opening means an opening into an enclosure that is 
equipped with a means of obstruction, such as a door, window, or port, 
that is normally closed.
    Tire means any agricultural, airplane, industrial, mobile home, 
light-duty truck and/or passenger vehicle tire that has a bead diameter 
less than or equal to 0.5 meter (m) (19.7 inches) and a cross section 
dimension less than or equal to 0.325 m (12.8 in.), and that is mass 
produced in an assembly-line fashion.
    Tread end cementing operation means the system used to apply cement 
to one or both ends of the tread or combined tread/sidewall component. A 
tread end cementing operation consists of a cement application station 
and all other equipment, such as the cement supply system and feed and 
takeaway conveyors, necessary to apply cement to tread ends and to allow 
evaporation of solvent from the cemented tread ends.
    Undertread cementing operation means the system used to apply cement 
to a continuous strip of tread or combined tread/sidewall component. An 
undertread cementing operation consists of a cement application station 
and all other equipment, such as the cement supply system and feed and 
takeaway conveyors, necessary to apply cement to tread or combined 
tread/sidewall strips and to allow evaporation of solvent from the 
cemented tread or combined tread/sidewall.
    VOC emission control device means equipment that destroys or 
recovers VOC.
    VOC emission reduction system means a system composed of an 
enclosure, hood, or other device for containment and capture of VOC 
emissions and a VOC emission control device.
    Water-based green tire spray means any mold release agent and 
lubricant applied to the inside or outside of green tires that contains 
12 percent or less, by weight, of VOC as sprayed.
    (b) Notations used under this subpart are defined below:

Bo=total number of beads cemented at a particular bead 
          cementing affected facility for a month
Ca=concentration of VOC in gas stream in vents after a 
          control device (parts per million by volume)
Cb=concentration of VOC in gas stream in vents before a 
          control device (parts per million by volume)
Cf=concentration of VOC in each gas stream vented directly to 
          the atmosphere from an affected facility or from a temporary 
          enclosure around an affected facility (parts per million by 
          volume)
Dc=density of cement or spray material (grams per liter)
Dr=density of VOC recovered by an emission control device 
          (grams per liter)
E=emission control device efficiency, inlet versus outlet (fraction)
Fc=capture efficiency, VOC captured and routed to one control 
          device versus total VOC used for an affected facility 
          (fraction)
Fo=fraction of total mass of VOC used in a month by all 
          facilities served by a common cement or spray material 
          distribution system that is used by a particular

[[Page 392]]

          affected facility served by the common distribution system
G=monthly average mass of VOC used per tire cemented or sprayed with a 
          water-based green tire spray for a particular affected 
          facility (grams per tire)
Gb=monthly average mass of VOC used per bead cemented for a 
          particular bead cementing affected facility (grams per bead)
Lc=volume of cement or spray material used for a month 
          (liters)
Lr=volume of VOC recovered by an emission control device for 
          a month (liters)
M=total mass of VOC used for a month by all facilities served by a 
          common cement or spray material distribution system (grams)
Mo=total mass of VOC used at an affected facility for a month 
          (grams)
Mr=mass of VOC recovered by an emission control device for a 
          month (grams)
N=mass of VOC emitted to the atmosphere per tire cemented or sprayed 
          with a water-based green tire spray for an affected facility 
          for a month (grams per tire)
Nb=mass of VOC emitted per bead cemented for an affected 
          facility for a month (grams per bead)
Qa=volumetric flow rate in vents after a control device (dry 
          standard cubic meters per hour)
Qb=volumetric flow rate in vents before a control device (dry 
          standard cubic meters per hour)
Qf=volumetric flow rate of each stream vented directly to the 
          atmosphere from an affected facility or from a temporary 
          enclosure around an affected facility (dry standard cubic 
          meters per hour)
R=overall efficiency of an emission reduction system (fraction)
Td=total number of days in monthly compliance period (days)
To=total number of tires cemented or sprayed with water-based 
          green tire sprays at a particular affected facility for a 
          month
Wo=weight fraction of VOC in a cement or spray material.



Sec. 60.542  Standards for volatile organic compounds.

    (a) On and after the date on which the initial performance test, 
required by Sec. 60.8, is completed, but no later than 180 days after 
initial startup, each owner or operator subject to the provisions of 
this subpart shall comply with the following conditions:
    (1) For each undertread cementing operation:
    (i) Discharge into the atmosphere no more than 25 percent of the VOC 
used (75 percent emission reduction) for each month; or
    (ii) Maintain total (uncontrolled) VOC use less than or equal to the 
levels specified below, depending upon the duration of the compliance 
period:
    (A) 3,870 kilograms of VOC per 28 days,
    (B) 4,010 kilograms of VOC per 29 days,
    (C) 4,150 kilograms of VOC per 30 days,
    (D) 4,280 kilograms of VOC per 31 days, or
    (E) 4,840 kilograms of VOC per 35 days.
    (2) For each sidewall cementing operation:
    (i) Discharge into the atmosphere no more than 25 percent of the VOC 
used (75 percent emission reduction) for each month; or
    (ii) Maintain total (uncontrolled) VOC use less than or equal to the 
levels specified below, depending upon the duration of the compliance 
period:
    (A) 3,220 kilograms of VOC per 28 days,
    (B) 3,340 kilograms of VOC per 29 days,
    (C) 3,450 kilograms of VOC per 30 days,
    (D) 3,570 kilograms of VOC per 31 days, or
    (E) 4,030 kilograms of VOC per 35 days.
    (3) For each tread end cementing operation: Discharge into the 
atmosphere no more than 10 grams of VOC per tire (g/tire) cemented for 
each month.
    (4) For each bead cementing operation: Discharge into the atmosphere 
no more than 5 grams of VOC per bead (g/bead) cemented for each month.
    (5) For each green tire spraying operation where only water-based 
sprays are used:
    (i) Discharge into the atmosphere no more than 1.2 grams of VOC per 
tire sprayed with an inside green tire spray for each month; and
    (ii) Discharge into the atmosphere no more than 9.3 grams of VOC per 
tire sprayed with an outside green tire spray for each month.
    (6) For each green tire spraying operation where only ogranic 
solvent-based sprays are used:

[[Page 393]]

    (i) Discharge into the atmosphere no more than 25 percent of the VOC 
used (75 percent emission reduction) for each month; or
    (ii) Maintain total (uncontrolled) VOC use less than or equal to the 
levels specified below, depending upon the duration of the compliance 
period:
    (A) 3,220 kilograms of VOC per 28 days,
    (B) 3,340 kilograms of VOC per 29 days,
    (C) 3,450 kilograms of VOC per 30 days,
    (D) 3,570 kilograms of VOC per 31 days, or
    (E) 4,030 kilograms of VOC per 35 days.
    (7) For each green tire spraying operation where both water-based 
and organic solvent-based sprays are used:
    (i) Discharge into the atmosphere no more than 1.2 grams of VOC per 
tire sprayed with a water-based inside green tire spray for each month; 
and
    (ii) Discharge into the atmosphere no more than 9.3 grams of VOC per 
tire sprayed with a water-based outside green tire spray for each month; 
and either
    (iii) Discharge into the atmosphere no more than 25 percent of the 
VOC used in the organic solvent-based green tire sprays (75 percent 
emission reduction) for each month; or
    (iv) Maintain total (uncontrolled) VOC use for all organic solvent-
based green tire sprays less than or equal to the levels specified under 
paragraph (a)(6)(ii) of this section.
    (8) For each Michelin-A operation:
    (i) Discharge into the atmosphere no more than 35 percent of the VOC 
used (65 percent emission reduction) for each month; or
    (ii) Maintain total (uncontrolled) VOC use less than or equal to the 
levels specified below, depending upon the duration of the compliance 
period:
    (A) 1570 Kilograms of VOC per 28 days,
    (B) 1630 Kilograms of VOC per 29 days,
    (C) 1690 Kilograms of VOC per 30 days,
    (D) 1740 Kilograms of VOC per 31 days, or
    (E) 1970 Kilograms of VOC per 35 days.
    (9) For each Michelin-B operation:
    (i) Discharge into the atmosphere no more than 25 percent of the VOC 
used (75 percent emission reduction) for each month; or
    (ii) Maintain total (uncontrolled) VOC use less than or equal to the 
levels specified below, depending upon the duration of the compliance 
period:
    (A) 1310 Kilograms of VOC per 28 days,
    (B) 1360 Kilograms of VOC per 29 days,
    (C) 1400 Kilograms of VOC per 30 days,
    (D) 1450 Kilograms of VOC per 31 days, or
    (E) 1640 Kilograms of VOC per 35 days.
    (10) For each Michelin-C-automatic operation:
    (i) Discharge into the atmosphere no more than 35 percent of the VOC 
used (65 percent emission reduction) for each month; or
    (ii) Maintain total (uncontrolled) VOC use less than or equal to the 
levels specified under paragraph (a)(8)(ii) of this section.



Sec. 60.542a  Alternate standard for volatile organic compounds.

    (a) On and after the date on which the initial performance test, 
required by Sec. 60.8, is completed, but no later than 180 days after 
September 19, 1989, each owner or operator subject to the provisions in 
Sec. 60.540(b) shall not cause to be discharged into the atmosphere more 
than: 25 grams of VOC per tire processed for each month if the operation 
uses 25 grams or less of VOC per tire processed and does not employ a 
VOC emission reduction system.
    (b) [Reserved]

[54 FR 38635, Sept. 19, 1989]



Sec. 60.543  Performance test and compliance provisions.

    (a) Section 60.8(d) does not apply to the monthly performance test 
procedures required by this subpart. Section 60.8(d) does apply to 
initial performance tests and to the performance tests specified under 
paragraphs (b)(2) and (b)(3) of this section. Section 60.8(f) does not 
apply when Method 24 is used.
    (b) Performance tests shall be conducted as follows:

[[Page 394]]

    (1) The owner or operator of an affected facility shall conduct an 
initial performance test, as required under Sec. 60.8(a), except as 
described under paragraph (j) of this section. The owner or operator of 
an affected facility shall thereafter conduct a performance test each 
month, except as described under paragraphs (b)(4), (g)(1), and (j) of 
this section. Initial and monthly performance tests shall be conducted 
according to the procedures in this section.
    (2) The owner or operator of an affected facility who elects to use 
a VOC emission reduction system with a control device that destroys VOC 
(e.g., incinerator), as described under paragraphs (f) and (g) of this 
section, shall repeat the performance test when directed by the 
Administrator or when the owner or operator elects to operate the 
capture system or control device at conditions different from the most 
recent determination of overall reduction efficiency. The performance 
test shall be conducted in accordance with the procedures described 
under paragraphs (f)(2) (i) through (iv) of this section.
    (3) The owner or operator of an affected facility who seeks to 
comply with the equipment design and performance specifications, as 
described under paragraph (j) of this section, shall repeat the 
performance test when directed by the Administrator or when the owner or 
operator elects to operate the capture system or control device at 
conditions different from the most recent determination of control 
device efficiency or measurement of capture system retention time or 
face velocity. The performance test shall be conducted in accordance 
with the procedures described under paragraph (f)(2)(ii) of this 
section.
    (4) The owner or operator of each tread end cementing operation and 
each green tire spraying operation using only water-based sprays (inside 
and/or outside) containing less than 1.0 percent, by weight, of VOC is 
not required to conduct a monthly performance test as described in 
paragraph (d) of this section. In lieu of conducting a monthly 
performance test, the owner or operator of each tread end cementing 
operation and each green tire spraying operation shall submit 
formulation data or the results of Method 24 analysis annually to verify 
the VOC content of each tread end cement and each green tire spray 
material, provided the spraying formulation has not changed during the 
previous 12 months. If the spray material formulation changes, 
formulation data or Method 24 analysis of the new spray shall be 
conducted to determine the VOC content of the spray and reported within 
30 days as required under Sec. 60.546(j).
    (c) For each undertread cementing operation, each sidewall cementing 
operation, each green tire spraying operation where organic solvent-
based sprays are used, each Michelin-A operation, each Michelin-B 
operation, and each Michelin-C-automatic operation where the owner or 
operator seeks to comply with the uncontrolled monthly VOC use (kg/mo) 
limits, the owner or operator shall use the following procedure to 
determine compliance with the applicable (depending upon duration of 
compliance period) uncontrolled monthly VOC use limit specified under 
Sec. 60.542(a) (1)(ii), (2)(ii), (6)(ii), (7)(iv), (8)(ii), (9)(ii), and 
(10)(ii). If both undertread cementing and sidewall cementing are 
performed at the same affected facility during a month, then the kg/mo 
limit specified under Sec. 60.542(a)(1)(ii) shall apply for that month.
    (1) Determine the density and weight fraction VOC (including 
dilution VOC) of each cement or green tire spray from its formulation or 
by analysis of the cement or green tire spray using Method 24. If a 
dispute arises, the Administrator may require an owner or operator who 
used formulation data to analyze the cement or green tire spray using 
Method 24.
    (2) Calculate the total mass of VOC used at the affected facility 
for the month (Mo) by the following procedure:
    (i) For each affected facility for which cement or green tire spray 
is delivered in batch or via a distribution system that serves only the 
affected facility:
[GRAPHIC] [TIFF OMITTED] TC01JN92.038

Where:

[[Page 395]]

``a'' equals the number of different cements or green tire sprays used 
          during the month that are delivered in batch or via a 
          distribution system that serves only a single affected 
          facility.

    (ii) For each affected facility for which cement or green tire spray 
is delivered via a common distribution system that also serves other 
affected or existing facilities:
    (A) Calculate the total mass of VOC used for all of the facilities 
served by the common distribution system for the month (M):
[GRAPHIC] [TIFF OMITTED] TC01JN92.039

Where:
``b'' equals the number of different cements or green tire sprays used 
          during the month that are delivered via a common distribution 
          system that also serves other affected or existing facilities.

    (B) Determine the fraction (Fo) of M used at the affected 
facility by comparing the production records and process specifications 
for the material cemented or sprayed at the affected facility for the 
month to the production records and process specifications for the 
material cemented or sprayed at all other facilities served by the 
common distribution system for the month or by another procedure 
acceptable to the Administrator.
    (C) Calculate the total monthly mass of VOC used at the affected 
facility for the month (Mo):

                     Mo = MFo

    (3) Determine the time duration of the monthly compliance period 
(Td).
    (d) For each tread end cementing operation and each green tire 
spraying operation where water-based cements or sprays containing 1.0 
percent, by weight, of VOC or more are used (inside and/or outside) that 
do not use a VOC emission reduction system, the owner or operator shall 
use the following procedure to determine compliance with the g/tire 
limit specified under Sec. 60.542 (a)(3), (a)(5)(i), (a)(5)(ii), 
(a)(7)(i), and (a)(7)(ii).
    (1) Determine the density and weight fraction VOC as specified under 
paragraph (c)(1) of this section.
    (2) Calculate the total mass of VOC used at the affected facility 
for the month (Mo) as specified under paragraph (c)(2) of 
this section.
    (3) Determine the total number of tires cemented or sprayed at the 
affected facility for the month (To) by the following 
procedure:
    (i) For a trend end cementing operation, To equals the 
number of tread or combined tread/sidewall components that receive an 
application of tread end cement for the month.
    (ii) For a green tire spraying operation that uses water-based 
inside green tire sprays, To equals the number of green tires 
that receive an application of water-based inside green tire spray for 
the month.
    (iii) For a green tire spraying operation that uses water-based 
outside green tire sprays, To equals the number of green 
tires that receive an application of water-based outside green tire 
spray for the month.
    (4) Calculate the mass of VOC used per tire cemented or sprayed at 
the affected facility for the month (G):
[GRAPHIC] [TIFF OMITTED] TC16NO91.064

    (5) Calculate the mass of VOC emitted per tire cemented or sprayed 
at the affected facility for the month (N):

                                  N = G

    (e) For each bead cementing operation that does not use a VOC 
emission reduction system, the owner or operator shall use the following 
procedure to determine compliance with the g/bead limit specified under 
Sec. 60.542(a)(4).
    (1) Determine the density and weight fraction VOC as specified under 
paragraph (c)(1) of this section.
    (2) Calculate the total mass of VOC used at the affected facility 
for the month (Mo) as specified under paragraph (c)(2) of 
this section.
    (3) Determine the number of beads cemented at the affected facility 
during the month (Bo) using production records; Bo 
equals the number of beads that receive an application of cement for the 
month.
    (4) Calculate the mass of VOC used per bead cemented at the affected 
facility for the month (Gb):

[[Page 396]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.065

    (5) Calculate the mass of VOC emitted per bead cemented at the 
affected facility for the month (Nb):

                      Nb = Gb

    (f) For each tread end cementing operation and each bead cementing 
operation that use a VOC emission reduction system with a control device 
that destroys VOC (e.g., incinerator), the owner or operator shall use 
the following procedure to determine compliance with the emission limit 
specified under Sec. 60.542(a) (3) and (4).
    (1) Calculate the mass of VOC used per tire cemented at the affected 
facility for the month (G), as specified under paragraphs (d) (1) 
through (4) of this section, or mass of VOC used per bead cemented at 
the affected facility for the month (Gb), as specified under 
paragraphs (e) (1) through (4) of this section.
    (2) Calculate the mass of VOC emitted per tire cemented at the 
affected facility for the month (N) or mass of VOC emitted per bead 
cemented for the affected facility for the month (Nb):

                               N = G (1-R)

                   Nb = Gb (1-R)

For the initial performance test, the overall reduction efficiency (R) 
shall be determined as prescribed under paragraphs (f)(2) (i) through 
(iv) of this section. After the initial performance test, the owner or 
operator may use the most recently determined overall reduction 
efficiency (R) for the performance test. No monthly performance tests 
are required. The performance test shall be repeated during conditions 
described under paragraph (b)(2) of this section.
    (i) The owner or operator of an affected facility shall construct a 
temporary enclosure around the application and drying areas during the 
performance test for the purpose of capturing fugitive VOC emissions. 
The enclosure must be maintained at a negative pressure to ensure that 
all evaporated VOC are measurable. Determine the fraction 
(Fc) of total VOC used at the affected facility that enters 
the control device:
[GRAPHIC] [TIFF OMITTED] TC01JN92.040

Where:
``m'' is the number of vents from the affected facility to the control 
          device, and ``n'' is the number of vents from the affected 
          facility to the atmosphere and from the temporary enclosure.

    (ii) Determine the destruction efficiency of the control device (E) 
by using values of the volumetric flow rate of each of the gas streams 
and the VOC content (as carbon) of each of the gas streams in and out of 
the control device:
[GRAPHIC] [TIFF OMITTED] TC01JN92.041

Where:
``m'' is the number of vents from the affected facility to the control 
          device, and ``p'' is the number of vents after the control 
          device.

    (iii) Determine the overall reduction efficiency (R):

                           R = EFc

    (iv) The owner or operator of an affected facility shall have the 
option of substituting the following procedure as an acceptable 
alternative to the requirements prescribed under paragraph (f)(2)(i) of 
this section. This alternative procedure is acceptable only in cases 
where a single VOC is used and is present in the capture system. The 
average capture efficiency value derived from a minimum of three runs 
shall constitute a test.
    (A) For each run, ``i,'' measure the mass of the material containing 
a single VOC used. This measurement shall be made using a scale that has 
both a calibration and a readability to within 1 percent of the mass 
used during the run. This measurement may be made by filling the direct 
supply reservoir (e.g., trough, tray, or drum that is integral to the 
operation) and related application equipment (e.g., rollers, pumps, 
hoses) to a marked level at the

[[Page 397]]

start of the run and then refilling to the same mark from a more easily 
weighed container (e.g., separate supply drum) at the end of the run. 
The change in mass of the supply drum would equal the mass of material 
used from the direct supply reservoir. Alternatively, this measurement 
may be made by weighing the direct supply reservoir at the start and end 
of the run or by weighing the direct supply reservoir and related 
application equipment at the start and end of the run. The change in 
mass would equal the mass of the material used in the run. If only the 
direct supply reservoir is weighed, the amount of material in or on the 
related application equipment must be the same at the start and end of 
the run. All additions of VOC containing material made to the direct 
supply reservoir during a run must be properly accounted for in 
determining the mass of material used during that run.
    (B) For each run, ``i,'' measure the mass of the material containing 
a single VOC which is present in the direct supply reservoir and related 
application equipment at the start of the run, unless the ending weight 
fraction VOC in the material is greater than or equal to 98.5 percent of 
the starting weight fraction VOC in the material, in which case, this 
measurement is not required. This measurement may be made directly by 
emptying the direct supply reservoir and related application equipment 
and then filling them to a marked level from an easily weighed container 
(e.g. separate supply drum). The change in mass of the supply drum would 
equal the mass of material in the filled direct supply reservoir and 
related application equipment. Alternatively, this measurement may be 
made by weighing the direct supply reservoir and related application 
equipment at the start of the run and subtracting the mass of the empty 
direct supply reservoir and related application equipment (tare weight).
    (C) For each run, ``i,'' the starting weight fraction VOC in the 
material shall be determined by Method 24 analysis of a sample taken 
from the direct supply reservoir at the beginning of the run.
    (D) For each run, ``i,'' the ending weight fraction VOC in the 
material shall be determined by Method 24 analysis of a sample taken 
from the direct supply reservoir at the end of the run.
    (E) For each run, ``i,'' in which the ending weight fraction VOC in 
the material is greater than or equal to 98.5 percent of the starting 
weight fraction VOC in the material, calculate the mass of the single 
VOC used (Mi) by multiplying the mass of the material used in the run by 
the starting weight fraction VOC of the material used in the run.
    (F) For each run, ``i,'' in which the ending weight fraction VOC in 
the material is less than 98.5 percent of the starting weight fraction 
VOC in the material, calculate the mass of the single VOC used 
(Mi) as follows:
    (1) Calculate the mass of VOC present in the direct supply reservoir 
and related application equipment at the start of the run by multiplying 
the mass of material in the direct supply reservoir and related 
application equipment at the start of the run by the starting weight 
fraction VOC in the material for that run.
    (2) Calculate the mass of VOC present in the direct supply reservoir 
and related application equipment at the end of the run by multiplying 
the mass of material in the direct supply reservoir and related 
application equipment at the end of the run by the ending weight 
fraction VOC in the material for that run. The mass of material in the 
direct supply reservoir and related application equipment at the end of 
the run shall be calculated by subtracting the mass of material used in 
the run from the mass of material in the direct supply reservoir and 
related application equipment at the start of the run.
    (3) The mass of the single VOC used (Mi) equals the mass 
of VOC present in the direct supply reservoir and related application 
equipment at the start of the run minus the mass of VOC present in the 
direct supply reservoir and related application eqiupment at the end of 
the run.
    (G) If Method 25A is used to determine the concentration of the 
single VOC in the capture system, then calculate the capture efficiency 
(FCi) for each run, ``i,'' as follows:

[[Page 398]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.042

Where:
Ci = Average concentration of the single VOC in the capture 
          system during run ``i'' (parts per million by volume) 
          corrected for background VOC (see Sec. 60.547(a)(5)).
W = Molecular weight of the single VOC, expressed as mg per mg-mole.
V = 2.405 x 10-5 m3/mg-mole. This is the volume 
          occupied by one mg-mole of ideal gas at standard conditions 
          (20  deg.C, 1 atmosphere) on a wet basis.
Qi = Volumetric flow in m3 in the capture system 
          during run ``i'' adjusted to standard conditions (20  deg.C, 1 
          atmosphere) on a wet basis (see Sec. 60.547(a)(5)).
106 = ppm per unity.
Mi = Mass in mg of the single VOC used during run ``i.''.
    (H) If Method 25 is used to determine the concentration of the 
single VOC in the capture system, then calculate the capture efficiency 
(FCi) for each run, ``i,'' as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.043

Where: Ci = Average concentration of the single VOC in the 
          capture system during run ``i'' (parts per million, as carbon, 
          by volume) corrected for background VOC (see 
          Sec. 60.547(a)(5)).
W = Molecular weight of the single VOC, expressed as mg per mg-mole.
V = 2.405 x 10-5 m3/mg-mole. This is the volume 
          occupied by one mg-mole of ideal gas at standard conditions 
          (20  deg.C, 1 atmosphere) on a wet basis.
Qi = Volumetric flow in m3 in the capture system 
          during run ``i'' adjusted to standard conditions (20  deg.C, 1 
          atmosphere) on a dry basis (see Sec. 60.547(a)(5)).
106 = ppm per unity.
Mi = Mass in mg of the single VOC used during run ``i''.
NC = Number of carbon atoms in one molecule of the single VOC.
    (I) Calculate the average capture efficiency value, Fc as 
follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.044

Where:
``n'' equals the number of runs made in the test (n  3). In 
          cases where an alternative procedure in this paragraph is 
          used, the requirements in paragraphs (f)(2) (ii) and (iii) of 
          this section remain unchanged.
    (g) For each undertread cementing operation, each sidewall cementing 
operation, each green tire spraying operation where organic solvent-
based sprays are used, each Michelin-A operation, each Michelin-B 
operation, and each Michelin-C-automatic operation that use a VOC 
emission reduction system with a control device that destroys VOC (e.g., 
incinerator), the owner or operator shall use the following procedure to 
determine compliance with the percent emission reduction requirement 
specified under Sec. 60.542 (a) (1)(i), (2)(i), (6)(i), (7)(iii), 
(8)(i), (9)(i), and (10)(i).
    (1) For the initial performance test, the overall reduction 
efficiency (R) shall be determined as prescribed under paragraphs (f)(2) 
(i) through (iii) of this section. The performance test shall be 
repeated during conditions described under paragraph (b)(2) of this 
section. No monthly performance tests are required.
    (h) For each tread end cementing operation and each bead cementing 
operation that uses a VOC emission reduction system with a control 
device that recovers VOC (e.g., carbon adsorber),

[[Page 399]]

the owner or operator shall use the following procedure to determine 
compliance with the emission limit specified under Sec. 60.542(a) (3) 
and (4).
    (1) Calculate the mass of VOC used per tire cemented at the affected 
facility for the month (G), as specified under paragraphs (d) (1) 
through (4) of this section, or mass of VOC used per bead cemented at 
the affected facility for the month (Gb), as specified under 
paragraphs (e) (1) through (4) of this section.
    (2) Calculate the total mass of VOC recovered from the affected 
facility for the month (Mr):

               Mr = Lr Dr

    (3) Calculate the overall reduction efficiency for the VOC emission 
reduction system (R) for the month:
[GRAPHIC] [TIFF OMITTED] TC16NO91.066

    (4) Calculate the mass of VOC emitted per tire cemented at the 
affected facility for the month (N) or mass of VOC emitted per bead 
cemeted at the affected facility for the month (Nb):

                               N = G (1-R)

                   Nb = Gb (1-R)

    (i) For each undertread cementing operation, each sidewall cemeting 
operation, each green tire spraying operation where organic solvent-
based sprays are used, each Michelin-A operation, each Michelin-B 
operation, and each Michelin-C-automatic operation that use a VOC 
emission reduction system with a control device that recovers (VOC) 
(e.g., carbon adsorber), the owner or operator shall use the following 
procedure to determine compliance with the percent reduction requirement 
specified under Sec. 60.542(a) (1)(i), (2)(i), (6)(i), (7)(iii), (8)(i), 
(9)(i), and (10)(i).
    (1) Determine the density and weight fraction VOC as specified under 
paragraph (c)(1) of this section.
    (2) Calculate the total mass of VOC used at the affected facility 
for the month (Mo) as described under paragraph (c)(2) of 
this section.
    (3) Calculate the total mass of VOC recovered from the affected 
facility for the month (Mr) as described under paragraph 
(h)(2) of this section.
    (4) Calculate the overall reduction efficiency for the VOC emission 
reduction system (R) for the month as described under paragraph (h)(3) 
of this section.
    (j) Rather than seeking to demonstrate compliance with the 
provisions of Sec. 60.542(a) (1)(i), (2)(i), (6)(i), (7)(iii), or (9)(i) 
using the performance test procedures described under paragraphs (g) and 
(i) of this section, an owner or operator of an undertread cementing 
operation, sidewall cementing operation, green tire spraying operation 
where organic solvent-based sprays are used, or Michelin-B operation 
that use a VOC emission reduction system may seek to demonstrate 
compliance by meeting the equipment design and performance 
specifications listed under paragraphs (j)(1), (2), and (4) through (6) 
or under paragraphs (j)(1) and (3) through (6) of this section, and by 
conducting a control device efficiency performance test to determine 
compliance as described under paragraph (j)(7) of this section. The 
owner or operator shall conduct this performance test of the control 
device efficiency no later than 180 days after initial startup of the 
affected facility, as specified under Sec. 60.8(a). Meeting the capture 
system design and performance specifications, in conjunction with 
operating a 95 percent efficient control device, is an acceptable means 
of demonstrating compliance with the standard. Therefore, the 
requirement for the initial performance test on the enclosure, as 
specified under Sec. 60.8(a), is waived. No monthly performance tests 
are required.
    (1) For each undertread cementing operation, each sidewall cementing 
operation, and each Michelin-B operation, the cement application and 
drying area shall be contained in an enclosure that meets the criteria 
specified under paragraphs (j) (2), (4), and (5) of this section; for 
each green tire spraying operation where organic solvent-based sprays 
are used, the spray application and drying area shall be contained in an 
enclosure that meets the criteria specified under paragraphs (j) (3), 
(4), and (5) of this section.

[[Page 400]]

    (2) The drying area shall be enclosed between the application area 
and the water bath or to the extent necessary to contain all tire 
components for at least 30 seconds after cement application, whichever 
distance is less.
    (3) Sprayed green tires shall remain in the enclosure for a minimum 
of 30 seconds after spray application.
    (4) A minimum face velocity of 100 feet per minute shall be 
maintained continuously through each permanent opening into the 
enclosure when all temporary enclosure openings are closed. The cross-
sectional area of each permanent opening shall be divided into at least 
12 equal areas, and a velocity measurement shall be performed at the 
centroid of each equal area with an anemometer or similar velocity 
monitoring device; the face velocity of each permanent opening is the 
average value of the velocity measurements taken. The monitoring device 
shall be calibrated and operated according to the manufacturer's 
instructions.

Temporary enclosure openings shall remain closed at all times except 
when worker access is necessary.
    (5) The total area of all permanent openings into the enclosure 
shall not exceed the area that would be necessary to maintain the VOC 
concentration of the exhaust gas stream at 25 percent of the lower 
explosive limit (LEL) under the following conditions:
    (i) The facility is operating at the maximum solvent use rate;
    (ii) The face velocity through each permanent opening is 100 feet 
per minute; and
    (iii) All temporary openings are closed.
    (6) All captured VOC are ducted to a VOC emission control device 
that is operated on a continuous basis and that achieves at least a 95 
percent destruction or recovery efficiency.
    (7) The efficiency of the control device (E) for the initial 
performance test is determined by using values of the volumetric flow 
rate of each of the gas streams and the VOC content (as carbon) of each 
of the gas streams in and out of the control device as described under 
paragraph (f)(2)(ii) of this section. The control device efficiency 
shall be redetermined during conditions specified under paragraph (b)(3) 
of this section.
    (k) Each owner or operator of an affected facility who initially 
elected to be subject to the applicable percent emission reduction 
requirement specified under Sec. 60.542(a)(1)(i), (2)(i), (6)(i), 
(7)(iii), (8)(i), (9)(i), or (10)(i) and who later seeks to comply with 
the applicable total (uncontrolled) monthly VOC use limit specified 
under Sec. 60.542(a)(1)(ii), (2)(ii), (6)(ii), (7)(iv), (8)(ii), 
(9)(ii), or (10)(ii) shall demonstrate, using the procedures described 
under paragraph (c) of this section, that the total VOC use at the 
affected facility has not exceeded the applicable total (uncontrolled) 
monthly VOC use limit during each of the last 6 months of operation. The 
owner or operator shall be subject to the applicable percent emission 
reduction requirement until the conditions of this paragraph and 
Sec. 60.546(h) are satisfied.
    (l) In determining compliance for each undertread cementing 
operation, each sidewall cementing operation, each green tire spraying 
operation, each Michelin-A operation, each Michelin-B operation, and 
each Michelin-C-automatic operation, the owner or operator shall include 
all the VOC used, recovered, or destroyed from cements and organic 
solvent-based green tire sprays including those cements or sprays used 
for tires other than those defined under Sec. 60.541(a).
    (m) In determining compliance for each tread end cementing 
operation, each bead cementing operation, and each green tire spraying 
operation, the owner or operator shall include only those tires defined 
under Sec. 60.541(a) when determining To and Bo.
    (n) For each undertread cementing operation and each sidewall 
cementing operation that does not use a VOC emission reduction system, 
the owner or operator shall use the following procedure to determine 
compliance with the 25 g/tire limit specified in Sec. 60.542a:
    (1) Calculate the total mass of VOC (Mo) used at the 
affected facility for the month by the following procedure.
    (i) For each affected facility for which cement is delivered in 
batch or via a distribution system which serves only that affected 
facility:

[[Page 401]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.045

Where: ``n'' equals the number of different cements or sprays used 
          during the month.
    (ii) For each affected facility for which cement is delivered via a 
common distribution system which also serves other affected or existing 
facilities.
    (A) Calculate the total mass (M) of VOC used for all of the 
facilities served by the common distribution system for the month:

[GRAPHIC] [TIFF OMITTED] TC01JN92.046

Where: ``n'' equals the number of different cements or sprays used 
          during the month.
    (B) Determine the fraction (Fo) of ``M'' used by the 
affected facility by comparing the production records and process 
specifications for the material cemented at the affected facility for 
the month to the production records and process specifications for the 
material cemented at all other facilities served by the common 
distribution system for the month or by another procedure acceptable to 
the Administrator.
    (C) Calculate the total monthly mass of VOC(Mo) used at 
the affected facility:
[GRAPHIC] [TIFF OMITTED] TC16NO91.067

    (2) Determine the total number of tires (To) processed at 
the affected facility for the month by the following procedure.
    (i) For undertread cementing, To equals the number of 
tread or combined tread/sidewall components which receive an application 
of undertread cement.
    (ii) For sidewall cementing, To equals the number of 
sidewall components which receive an application of sidewall cement, 
divided by 2.
    (3) Calculate the mass of VOC used per tire processed (G) by the 
affected facility for the month:
[GRAPHIC] [TIFF OMITTED] TC16NO91.068

    (4) Calculate the mass of VOC emitted per tire processed (N) for the 
affected facility for the month:
[GRAPHIC] [TIFF OMITTED] TC16NO91.069

    (5) Where the value of the mass of VOC emitted per tire processed 
(N) is less than or equal to the 25 g/tire limit specified under 
Sec. 60.542a, the affected facility is in compliance.

[52 FR 34874, Sept. 15, 1987; 52 FR 37874, Oct. 9, 1987, as amended at 
54 FR 38635, Sept. 19, 1989]



Sec. 60.544  Monitoring of operations.

    (a) Each owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain, and operate according to 
manufacturer's specifications the following equipment, unless 
alternative monitoring procedures or requirements are approved for that 
facility by the Administrator:
    (1) Where a thermal incinerator is used for VOC emission reduction, 
a temperature monitoring device equipped with a continuous recorder for 
the temperature of the gas stream in the combustion zone of the 
incinerator. The temperature monitoring device shall have an accuracy of 
1 percent of the temperature being measured in  deg.C or 0.5 
 deg.C, whichever is greater.
    (2) Where a catalytic incinerator is used for VOC emission 
reduction, temperatrue monitoring devices, each equipped with a 
continuous recorder, for the temperature in the gas stream immediately 
before and after the catalyst bed of the incinerator. The temperature 
monitoring devices shall have an accuracy of 1 percent of the 
temperature being measured in  deg.C or 0.5  deg.C, 
whichever is greater.
    (3) For an undertread cementing operation, sidewall cementing 
operation, green tire spraying operation where organic solvent-based 
sprays are used, or Michelin-B operation where a carbon adsorber is used 
to meet the performance requirements specified under Sec. 60.543(j)(6), 
an organics monitoring device used to indicate the concentration level 
of organic compounds based on a detection principle such as infrared,

[[Page 402]]

photoionization, or thermal conductivity, equipped with a continous 
recorder, for the outlet of the carbon bed.
    (b) An owner or operator of an undertread cementing operation, 
sidewall cementing operation, green tire spraying operation where 
organic solvent-based sprays are used, or Michelin-B operation where a 
VOC recovery device other than a carbon adsorber is used to meet the 
performance requirements specified under Sec. 60.543(j)(6), shall 
provide to the Administrator information describing the operation of the 
control device and the process parameter(s) which would indicate proper 
operation and maintenance of the device. The Administrator may request 
further information and will specify appropriate monitoring procedures 
or requirements.



Sec. 60.545  Recordkeeping requirements.

    (a) Each owner or operator of an affected facility that uses a 
thermal incinerator shall maintain continuous records of the temperature 
of the gas stream in the combustion zone of the incinerator and records 
of all 3-hour periods of operation for which the average temperature of 
the gas stream in the combustion zone was more than 28  deg.C (50 
deg.F) below the combustion zone temperature measured during the most 
recent determination of the destruction efficiency of the thermal 
incinerator that demonstrated that the affected facility was in 
compliance.
    (b) Each owner or operator of an affected facility that uses a 
catalytic incinerator shall maintain continuous records of the 
temperature of the gas stream both upstream and downstream of the 
catalyst bed of the incinerator, records of all 3-hour periods of 
operation for which the average temperature measured before the catalyst 
bed is more than 28  deg.C below the gas stream temperature measured 
before the catalyst bed during the most recent determination of 
destruction efficiency of the catalytic incinerator that demonstrated 
that the affected facility was in compliance, and records of all 3-hour 
periods for which the average temperature difference across the catalyst 
bed is less than 80 percent of the temperature difference measured 
during the most recent determination of the destruction efficiency of 
the catalytic incinerator that demonstrated that the affected facility 
was in compliance.
    (c) Each owner or operator of an undertread cementing operation, 
sidewall cementing operation, green tire spraying operation where 
organic solvent-based sprays are used, or Michelin-B operation that uses 
a carbon adsorber to meet the requirements specified under 
Sec. 60.543(j)(6) shall maintain continuous records of all 3-hour 
periods of operation during which the average VOC concentration level or 
reading of organics in the exhaust gases is more than 20 percent greater 
than the exhaust gas concentration level or reading measured by the 
organics monitoring device during the most recent determination of the 
recovery efficiency of the carbon adsorber that demonstrated that the 
affected facility was in compliance.
    (d) Each owner or operator of an undertread cementing operation, 
sidewall cementing operation, green tires spraying operation where 
organic solvent-based sprays are used, Michelin-A operation, Michelin-B 
operation, or Michelin-C-automatic operation who seeks to comply with a 
specified kg/mo uncontrolled VOC use limit shall maintain records of 
monthly VOC use and the number of days in each compliance period.
    (e) Each owner or operator that is required to conduct monthly 
performance tests, as specified under Sec. 60.543(b)(1), shall maintain 
records of the results of all monthly tests.
    (f) Each owner or operator of a tread end cementing operation and 
green tire spraying operation using water-based cements or sprays 
containing less than 1.0 percent by weight of VOC, as specified under 
Sec. 60.543(B)(4), shall maintain records of formulation data or the 
results of Method 24 analysis conducted to verify the VOC content of the 
spray.

[52 FR 34874, Sept. 15, 1987, as amended at 54 FR 38637, Sept. 19, 1989]



Sec. 60.546  Reporting requirements.

    (a) Each owner or operator subject to the provisions of this 
subpart, at the time of notification of the anticipated initial startup 
of an affected facility pursuant to Sec. 60.7(a)(2), shall provide a

[[Page 403]]

written report to the Administrator declaring for each undertread 
cementing operation, each sidewall cementing operation, each green tires 
spraying operation where organic solvent-based spray are used, each 
Michelin-A operation, each Michelin-B operation, and each Michelin-C 
automatic operation the emission limit he intends to comply with and the 
compliance method (where Sec. 60.543(j) is applicable) to be employed.
    (b) Each owner or operator subject to the provisions of this 
subpart, at the time of notification of the anticipated initial startup 
of an affected facility pursuant to Sec. 60.7(a)(2), shall specify the 
monthly schedule (each calendar month or a 4-4-5-week schedule) to be 
used in making compliance determinations.
    (c) Each owner or operator subject to the provisions of this subpart 
shall report the results of all initial performance tests, as required 
under Sec. 60.8(a), and the results of the performance tests required 
under Sec. 60.543 (b)(2) and (b)(3). The following data shall be 
included in the report for each of the above performance tests:
    (1) For each affected facility for which the owner or operator seeks 
to comply with a kg/mo uncontrolled VOC use limit specified under 
Sec. 60.542(a): The monthly mass of VOC used (Mo) and the 
number days in the compliance period (Td).
    (2) For each affected facility that seeks to comply with a g/tire or 
g/bead limit specified under Sec. 60.542(a) without the use of a VOC 
emission reduction system: the mass of VOC used (Mo), the 
number of tires cemented or sprayed (To), the mass of VOC 
emitted per tire cemented or sprayed (N), the number of beads cemeted 
(Bo), and the mass of VOC emitted per bead cemented 
(Nb).
    (3) For each affected facility that uses a VOC emission reduction 
system with a control device that destroys VOC (e.g., incinerator) to 
comply with a g/tire or g/bead limit specified under Sec. 60.542(a): The 
mass of VOC used (Mo), the number of tires cemented or 
sprayed (To), the mass of VOC emitted per tire cemented or 
sprayed (N), the number of beads cemented (Bo), the mass of 
VOC emitted per bead cemented (Nb), the mass of VOC used per 
tire cemented or sprayed (G), the mass of VOC per bead cemented 
(Gb), the emission control device efficiency (E), the capture 
system efficiency (Fc), the face velocity through each 
permanent opening for the capture system with the temporary openings 
closed, and the overall system emission reduction (R).
    (4) For each affected facility that uses a VOC emission reduction 
system with a control device that destroys VOC (e.g., incinerator) to 
comply with a percent emission reduction requirement specified under 
Sec. 60.542(a): The emission control device efficiency (E), the capture 
system efficiency (Fc), the face velocity through each 
permanent opening in the capture system with the temporary openings 
closed, and the overall system emission reduction (R).
    (5) For each affected facility that uses a carbon adsorber to comply 
with a g/tire or g/bead limit specified under Sec. 60.542(a): The mass 
of VOC used (Mo), the number of tires cemented or sprayed 
(To), the mass of VOC used per tire cemented or sprayed (G), 
the number of beads cemented (Bo), the mass of VOC used per 
bead (Gb), the mass of VOC recovered (Mr), the 
overall system emission reduction (R), the mass of VOC emitted per tire 
cemented or sprayed (N), and the mass of VOC emitted per bead cemented 
(Nb).
    (6) For each affected facility that uses a VOC emission reduction 
system with a control device that recovers VOC (e.g., carbon adsorber) 
to comply with a percent emission reduction requirement specified under 
Sec. 60.542(a): The mass of VOC used (Mo), the mass of VOC 
recovered (Mr), and the overall system emission reduction 
(R).
    (7) For each affected facility that elects to comply with the 
alternate limit specified under Sec. 60.542a: The mass of VOC used 
(Mo), the number of tires processed (To), and the 
mass of VOC emitted per tire processed (N).
    (d) Each owner or operator of an undertread cementing operation, 
sidewall cementing operation, green tire spraying operation where 
organic solvent-based sprays are used, or Michelin-B operation who seeks 
to comply with the requirements described under Sec. 60.543(j) shall 
include in the initial compliance report a statement specifying, in 
detail, how each of

[[Page 404]]

the equipment design and performance specifications has been met. The 
initial compliance report also shall include the following data: The 
emission control device efficiency (E), the face velocity through each 
permanent enclosure opening with all temporary enclosure openings 
closed, the total area of all permanent enclosure openings, the total 
area of all temporary enclosure openings, the maximum solvent use rate 
(kg/hr), the type(s) of VOC used, the lower explosive limit (LEL) for 
each VOC used, and the length of time each component is enclosed after 
application of cement or spray material.
    (e) Each owner or operator of an affected facility shall include the 
following data measured by the required monitoring device(s), as 
applicable, in the report for each performance test specified under 
paragraph (c) of this section.
    (1) The average combustion temperature measured at least every 15 
minutes and averaged over the performance test period of incinerator 
destruction efficiency for each thermal incinerator.
    (2) The average temperature before and after the catalyst bed 
measured at least every 15 minutes and averaged over the performance 
test period of incinerator destruction efficiency for each catalytic 
incinerator.
    (3) The concentration level or reading indicated by the organics 
monitoring device at the outlet of the adsorber, measured at least every 
15 minutes and averaged over the performance test period of carbon 
adsorber recovery efficiency while the vent stream is normally routed 
and constituted.
    (4) The appropriate data to be specified by the Administrator where 
a VOC recovery device other than a carbon adsorber is used.
    (f) Once every 6 months each owner or operator subject to the 
provisions of Sec. 60.545 shall report, as applicable:
    (1) Each monthly average VOC emission rate that exceeds the g/tire 
or g/bead limit specified under Sec. 60.542(a), as applicable for the 
affected facility.
    (2) Each monthly average VOC use rate that exceeds the kg/mo VOC use 
limit specified under Sec. 60.542(a), as applicable for the affected 
facility.
    (3) Each monthly average VOC emission reduction efficiency for a VOC 
recovery device (e.g., carbon adsorber) less than the percent efficiency 
limit specified under Sec. 60.542(a), as applicable for the affected 
facility.
    (4) Each 3-hour period of operation for which the average 
temperature of the gas stream in the combustion zone of a thermal 
incinerator, as measured by the temperature monitoring device, is more 
than 28 deg.C (50 deg.F) below the combustion zone temperature measured 
during the most recent determination of the destruction efficiency of 
the thermal incinerator that demonstrated that the affected facility was 
in compliance.
    (5) Each 3-hour period of operation for which the average 
temperature of the gas stream immediately before the catalyst bed of a 
catalytic incinerator, as measured by the temperature monitoring device, 
is more than 28 deg.C (50 deg.F) below the gas stream temperature 
measured before the catalyst bed during the most recent determination of 
the destruction efficiency of the catalyst incinerator that demonstrated 
that the affected facility was in compliance, and any 3-hour period for 
which the average temperature difference across the catalyst bed (i.e., 
the difference between the temperatures of the gas stream immediately 
before and after the catalyst bed), as measured by the temperature 
monitoring device, is less than 80 percent of the temperature difference 
measured during the most recent determination of the destruction 
efficiency of the catalytic incinerator that demonstrated that the 
affected facility was in compliance.
    (6) Each 3-hour period of operation during which the average 
concentration level or reading of VOC's in the exhaust gases from a 
carbon adsorber is more than 20 percent greater than the exhaust gas 
concentration level or reading measured by the organics monitoring 
device during the most recent determination of the recovery efficiency 
of the carbon adsorber that demonstrated that the affected facility was 
in compliance.
    (g) The requirements for semiannual reports remain in force until 
and unless EPA, in delegating enforcement

[[Page 405]]

authority to a State under Section 111(c) of the Act, approves reporting 
requirements or an alternative means of compliance surveillance adopted 
by such State. In that event, affected facilities within the State will 
be relieved of the obligation to comply with these requirements, 
provided that they comply with the requirements established by the 
State.
    (h) Each owner or operator of an affected facility who initially 
elected to be subject to the applicable percent emission reduction 
requirement specified under Sec. 60.542(a) and who later seeks to comply 
with the applicable total (uncontrolled) monthly VOC use limit specified 
under Sec. 60.542(a) and who has satisfied the provisions specified 
under Sec. 60.543(k) shall furnish the Administrator written 
notification no less than 30 days in advance of the date when he intends 
to be subject to the applicable VOC use limit instead of the applicable 
percent emission reduction requirement.
    (i) The owner or operator of each undertread cementing operation and 
each sidewall cementing operation who qualifies for the alternate 
provisions as described in Sec. 60.542a, shall furnish the Administrator 
written notification of the election no less than 60 days after 
September 19, 1989.
    (j) The owner or operator of each tread end cementing operation and 
each green tire spraying (inside and/or outside) operation using water-
based sprays containing less than 1.0 percent, by weight, of VOC as 
described in Sec. 60.543(b)(1) shall furnish the Administrator, within 
60 days initially and annually thereafter, formulation data or Method 24 
results to verify the VOC content of the water-based sprays in use. If 
the spray formulation changes before the end of the 12-month period, 
formulation data or Method 24 results to verify the VOC content of the 
spray shall be reported within 30 days.

[52 FR 34874, Sept. 15, 1987; 52 FR 37874, Oct. 9, 1987, as amended at 
54 FR 38637, Sept. 19, 1989]



Sec. 60.547  Test methods and procedures.

    (a) The test methods in appendix A to this part, except as provided 
under Sec. 60.8(b), shall be used to determine compliance with 
Sec. 60.542(a) as follows:
    (1) Method 24 or formulation data for the determination of the VOC 
content of cements or green tire spray materials. In the event of 
dispute, Method 24 shall be the reference method. For Method 24, the 
cement or green tire spray sample shall be a 1-liter sample collected in 
a 1-liter container at a point where the sample will be representative 
of the material as applied in the affected facility.
    (2) Method 25 as the reference method for the determination of the 
VOC concentrations in each stack, both entering and leaving an emission 
control device. The owner or operator shall notify the Administrator 30 
days in advance of any test by Method 25. For Method 25, the sampling 
time for each of three runs shall be at least 1 hour. Method 1 shall be 
used to select the sampling site, and the sampling point shall be the 
centroid of the duct or at a point no closer to the walls than 1 meter. 
The minimum sample volume shall be 0.003 dry standard cubic meter (dscm) 
except that shorter sampling times or smaller volumes, when necessitated 
by process variables or other factors, may be approved by the 
Administrator.
    (3) Method 2, 2A, 2C, or 2D, as appropriate, as the reference method 
for determination of the flow rate of the stack gas. The measurement 
site shall be the same as for the Method 25 sampling. A velocity 
traverse shall be made once per run within the hour that the Method 25 
sample is taken.
    (4) Method 4 for determination of stack gas moisture.
    (5) Method 25 or Method 25A for determination of the VOC 
concentration in a capture system prior to a control device when only a 
single VOC is present (see Sec. 60.543 (f)(2)(iv)(G) and (f)(2)(iv)(H)). 
The owner or operator shall notify the Administrator 30 days in advance 
of any test by either Method 25 or Method 25A. Method 1 shall be used to 
select the sampling site and the sampling point shall be the centroid of 
the duct or at a point no closer to the walls than 1 meter. Method 2, 
2A, 2C, or 2D, as appropriate, shall be used as the test method for the 
concurrent determination of gas flow rate in the capture system.

[[Page 406]]

    (i) For Method 25, the sampling time for each run shall be at least 
1 hour. For each run, a concurrent sample shall be taken immediately 
upwind of the application area to determine the background VOC 
concentration of air drawn into the capture system. Subtract this 
reading from the reading obtained in the capture system for that run. 
The minimum sample volume shall be 0.003 dry standard cubic meter (dscm) 
except that shorter sampling times or smaller volumes, when necessitated 
by process variable or other factors, may be approved by the 
Administrator. Use Method 3 to determine the moisture content of the 
stack gas.
    (ii) For Method 25A, the sampling time for each run shall be at 
least 1 hour. Instrument calibration shall be performed by the procedure 
given in Method 25A using the single VOC present in the capture system. 
A different calibration gas may be used if the results are corrected 
using an experimentally determined response factor comparing the 
alternative calibration gas to the single VOC used in the process. After 
the instrument has been calibrated, determine the background VOC 
concentration of the air drawn into the capture system immediately 
upwind of the application area for each run. The instrument does not 
need to be recalibrated for the background measurement. Subtract this 
reading from the reading obtained in the capture system for that run. 
The Method 25A results shall only be used in the alternative procedure 
for determination of capture efficiency described under 
Sec. 60.543(f)(2)(iv)(G).

[52 FR 34874, Sept. 15, 1987, as amended at 54 FR 38638, Sept. 19, 1989]



Sec. 60.548  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authority which will not be delegated to States: 
Sec. 60.543(c)(2)(ii)(B).

Subpart CCC  [Reserved]



  Subpart DDD--Standards of Performance for Volatile Organic Compound 
         (VOC) Emissions from the Polymer Manufacturing Industry

    Source: 55 FR 51035, Dec. 11, 1990, unless otherwise noted.



Sec. 60.560  Applicability and designation of affected facilities.

    (a) Affected facilities. The provisions of this subpart apply to 
affected facilities involved in the manufacture of polypropylene, 
polyethylene, polystyrene, or poly (ethylene terephthalate) as defined 
in Sec. 60.561 of this subpart. The affected facilities designated below 
for polypropylene and polyethylene are inclusive of all equipment used 
in the manufacture of these polymers, beginning with raw materials 
preparation and ending with product storage, and cover all emissions 
emanating from such equipment.
    (1) For process emissions from any polypropylene and polyethylene 
manufacturing process that uses a continuous process, the affected 
facilities are each of the following process sections: each raw 
materials preparation section, each polymerization reaction section, 
each material recovery section, each product finishing section, and each 
product storage section. These process sections are affected facilities 
for process emissions that are emitted continuously and for process 
emissions that are emitted intermittently.
    (2) For process emissions from polystyrene manufacturing processes 
that use a continuous process, the affected facilities are each material 
recovery section. These process sections are affected facilities for 
only those process emissions that are emitted continuously.
    (3) For process emissions from poly(ethylene terephthalate) 
manufacturing processes that use a continuous process, the affected 
facilities are each polymerization reaction section. If the process uses 
dimethyl terephthalate, then each material recovery section is also an 
affected facility. If the process uses terephthalic acid, then each raw

[[Page 407]]

materials preparation section is also an affected facility. These 
process sections are affected facilities for only those process 
emissions that are emitted continuously.
    (4) For VOC emissions from equipment leaks from polypropylene, 
polyethylene, and polystyrene (including expandable polystyrene) 
manufacturing processes, the affected facilities are each group of 
fugitive emissions equipment (as defined in Sec. 60.561) within any 
process unit (as defined in Sec. 60.561). This subpart does not apply to 
VOC emissions from equipment leaks from poly(ethylene terephthalate) 
manufacturing processes.
    (i) Affected facilities with a design capacity to produce less than 
1,000 Mg/yr shall be exempt from Sec. 60.562-2.
    (ii) Addition or replacement of equipment for the purposes of 
improvement which is accomplished without a capital expenditure shall 
not by itself be considered a modification under Sec. 60.562-2.
    (b) Applicability dates. The applicability date identifies when an 
affected facility becomes subject to a standard. Usually, a standard has 
a single applicability date. However, some polypropylene and 
polyethylene affected facilities have a September 30, 1987, 
applicability date and others have a January 10, 1989, applicability 
date. The following paragraphs identify the applicability dates for all 
affected facilities subject to this subpart.
    (1) Polypropylene and polyethylene. Each process section in a 
polypropylene or polyethylene production process is a potential affected 
facility for both continuous and intermittent emissions. The 
applicability date depends on when the process section was constructed, 
modified, or reconstructed and, in some instances, on the type of 
production process.
    (i) The applicability date for any polypropylene or polyethylene 
affected facility that is constructed, modified, or reconstructed after 
January 10, 1989, regardless of the type of production process being 
used, is January 10, 1989.
    (ii) Only some polypropylene or polyethylene process sections that 
are constructed, modified, or reconstructed on or before January 10, 
1989, but after September 30, 1987, are affected facilities. These 
process sections (and the type of emissions to be controlled) are 
identified by an ``x'' in Table 1. The applicability date for the 
process sections (and the emissions to be controlled) that are 
identified by an ``x'' in Table 1 is September 30, 1987. Since the 
affected facilities that have a September 30, 1987, applicability date 
are determined by the type of production process (e.g., liquid phase, 
gas phase), each owner or operator shall identify the particular 
production process that applies to his or her particular process.

     Table 1--Polypropylene and Polyethylene Affected Facilities With September 30, 1987, Applicability Date
----------------------------------------------------------------------------------------------------------------
                                                                                           Emissions
             Polymer                Production process     Process section   -----------------------------------
                                                                                 Continuous       Intermittent
----------------------------------------------------------------------------------------------------------------
Polypropylene....................  Liquid phase........  Raw Materials        X...............  --
                                                          Preparation.        X...............  --
                                                         Material Recovery..  X...............  X
                                                         Polymerization       X...............  --
                                                          Reaction.           --..............  --
                                                         Product Finishing..
                                                         Product Storage....
Polypropylene....................  Gas Phase...........  Raw Materials        --..............  --
                                                          Preparation.        --..............  X
                                                         Polymerization       X...............  --
                                                          Reaction.           --..............  --
                                                         Material Recovery..  --..............  --
                                                         Product Finishing..
                                                         Product Storage....
Low Density Polyethylene.........  High Pressure.......  Raw Materials        --..............  X
                                                          Preparation.        --..............  X
                                                         Polymerization       --..............  X
                                                          Reaction.           --..............  X
                                                         Material Recovery..  --..............  X
                                                         Product Finishing..
                                                         Product Storage....
Low Density Polyethylene.........  Low Pressure........  Raw Materials        X...............  X
                                                          Preparation.        --..............  X
                                                         Polymerization       --..............  --
                                                          Reaction.
                                                         Material Recovery..
High Density Polyethylene........  Gas Phase...........  Product Finishing..  X...............  --
                                                         Product Storage....  --..............  --

[[Page 408]]

 
High Density Polyethylene........  Liquid Phase Slurry.  Raw Materials        --..............  X
                                                          Preparation.        --..............  --
                                                         Polymerization       X...............  --
                                                          Reaction.           X...............  --
                                                         Material Recovery..  --..............  --
                                                         Product Finishing..
                                                         Product Storage....
High Density Polyethylene........  Liquid Phase          Raw Materials        X...............  X
                                    Solution.             Preparation.        --..............  X
                                                         Polymerization       X...............  X
                                                          Reaction.           --..............  --
                                                         Material Recovery..  --..............  --
                                                         Product Finishing..
                                                         Product Storage....
----------------------------------------------------------------------------------------------------------------
NOTE: ``X'' denotes that that process section is an affected facility for continuous or intermittent emissions
  or both, as shown, which has a September 30, 1987, applicability date.
``--'' denotes that that process section is not considered an affected facility for continous or intermittent
  emissions or both, as shown, if the process section is constructed, modified, or reconstructed after September
  30, 1987, and on or before January 10, 1989. These process sections are affected facilities if they are
  constructed, modified, or reconstructed after January 10, 1989.

    (2) Polystyrene. The applicability date for each polystyrene 
affected facility is September 30, 1987.
    (3) Poly(ethylene terephthalate). The applicability date for each 
poly(ethylene terephthalate) affected facility is September 30, 1987.
    (c) Any facility under paragraph (a) of this section that commences 
construction, modification, or reconstruction after its applicability 
date as identified under paragraph (b) of this section is subject to the 
requirements of this subpart, except as provided in paragraphs (d) 
through (f) of this section.
    (d) Any polypropylene or polyethylene affected facility with a 
September 30, 1987, applicability date that commenced construction, 
modification, or reconstruction after September 30, 1987, and on or 
before January 10, 1989, with an uncontrolled emission rate (as defined 
in footnote a to Table 2) at or below those identified in Table 2 is not 
subject to the requirements of Sec. 60.562-1 unless and until its 
uncontrolled emission rate exceeds that rate listed for it in Table 2 or 
it is modified or reconstructed after January 10, 1989. At such time, 
such facility becomes subject to Sec. 60.562-1 and the procedures 
identified in Sec. 60.562-1(a) shall be used to determine the control of 
emissions from the facility.

        Table 2--Maximum Uncontrolled Threshold Emission Rates a
------------------------------------------------------------------------
                                                          Uncontrolled
                                                         emission rate,
       Production process            Process section        kg TOC/Mg
                                                             product
------------------------------------------------------------------------
Polypropylene, liquid phase       Raw Materials         0.15 b
 process.                          Preparation.
                                  Polymerization        0.14 b, 0.24 c
                                   Reaction.
                                  Material Recovery...  0.19 b
                                  Product Finishing...  1.57 b
Polypropylene, gas phase process  Polymerization        0.12 c
                                   Reaction.
                                  Material Recovery...  0.02 b
Low Density Polyethylene, low     Raw Materials         0.41 d
 pressure process.                 Preparation.
                                  Polymerization        (e)
                                   Reaction.
                                  Material Recovery...  (e)
                                  Product Finishing...  (e)
                                  Product Storage.....  (e)
Low Density Polyethylene, low     Raw Materials         0.05 f
 pressure process.                 Preparation.
                                  Polymerization        0.03 g
                                   Reaction.
                                  Production Finishing  0.01 b
High Density Polyethylene,        Raw Materials         0.25 c
 liquid phase slurry process.      Preparation.
                                  Material Recovery...  0.11 b
                                  Product Finishing...  0.41 b
High Density Polyethylene,        Raw Materials         0.24 f
 liquid phase solution process.    Preparation.
                                  Polymerization        0.16 c
                                   Reaction.
                                  Material Recovery...  1.68 f

[[Page 409]]

 
High Density Polyethylene, gas    Raw Materials         0.05 f
 phase process.                    Preparation.
                                  Polymerization        0.03 g
                                   Reaction.
                                  Product Finishing...  0.01 b
Polystyrene, continuous process.  Material Recovery...  0.05 b, h
Poly(ethylene terephthalate),     Material Recovery...  0.12 b, h
 dimethyl terephthalate process.
                                  Polymerization        1.80 h, i, j
                                   Reaction.
Poly(ethylene terephthalate),     Raw Materials         (l)
 terephthalic acid process.        Preparation.
                                  Polymerization        1.80 h, j, m
                                   Reaction.
                                                        3.92 h, k, m
------------------------------------------------------------------------
a ``Uncontrolled emission rate'' refers to the emission rate of a vent
  stream that vents directly to the atmosphere and to the emission rate
  of a vent stream to the atmosphere that would occur in the absence of
  any add-on control devices but after any material recovery devices
  that constitute part of the normal material recovery operations in a
  process line where potential emissions are recovered for recycle or
  resale.
b Emission rate applies to continuous emissions only.
c Emission rate applies to intermittent emissions only.
d Total emission rate for non-emergency intermittent emissions from raw
  materials preparation, polymerization reaction, material recovery,
  product finishing, and product storage process sections.
e See footnote d.
f Emission rate applies to both continuous and intermittent emissions.
g Emission rate applies to non-emergency intermittent emissions only.
h Applies to modified or reconstructed affected facilities only.
i Includes emissions from the cooling water tower.
j Applies to a process line producing low viscosity poly(ethylene
  terephthalate).
k Applies to a process line producing high viscosity poly(ethylene
  terephathlate).
l See footnote m.
m Applies to the sum of emissions to the atmosphere from the
  polymerization reaction section (including emissions from the cooling
  water tower) and the raw materials preparation section (i.e., the
  esterifiers).

    (e)(1) Modified or reconstructed affected facilities at polystyrene 
and poly(ethylene terephthalate) plants with uncontrolled emission rates 
at or below those identified in Table 2 are exempt from the requirements 
of Sec. 60.562-1 unless and until its uncontrolled emission rate exceeds 
that rate listed for it in Table 2. This exemption does not apply to new 
polystyrene or poly(ethylene terephthalate) affected facilities.
    (2) Emissions from modified or reconstructed affected facilities 
that are controlled by an existing control device and that have 
uncontrolled emission rates greater than the uncontrolled threshold 
emission rates identified in Table 2 are exempt from the requirements of 
Sec. 60.562-1 unless and until the existing control device is modified, 
reconstructed, or replaced.
    (f) No process section of an experimental process line is considered 
an affected facility for continuous or intermittent process emissions.
    (g) Individual vent streams that emit continuous emissions with 
uncontrolled annual emissions of less than 1.6 Mg/yr or with a weight 
percent TOC of less than 0.10 percent from a new, modified, or 
reconstructed polypropylene or polyethylene affected facility are exempt 
from the requirements of Sec. 60.562-1(a)(1). If at a later date, an 
individual stream's uncontrolled annual emissions become 1.6 Mg/yr or 
greater (if the stream was exempted on the basis of the uncontrolled 
annual emissions exemption) or VOC concentration becomes 0.10 weight 
percent or higher (if the stream was exempted on the basis of the VOC 
concentration exemption), then the stream is subject to the requirements 
of Sec. 60.562-1.
    (h) Emergency vent streams, as defined in Sec. 60.561, from a new, 
modified, or reconstructed polypropylene or polyethylene affected 
facility are exempt from the requirements of Sec. 60.562-1(a)(2).
    (i) An owner or operator of a polypropylene or polyethylene affected 
facility that commenced construction, modification, or reconstruction 
after September 30, 1987, and on or before January 10, 1989, and that is 
in a process line in which more than one type of

[[Page 410]]

polyolefin (i.e., polypropylene, low density polyethylene, high density 
polyethylene, or their copolymers) is produced shall select one of the 
polymer/production process combinations in Table 1 for purposes of 
determining applicable affected facilities and uncontrolled threshold 
emissions rates.
    (Note: The numerical emission limits in these standards are 
expressed in terms of total organic compounds, measured as total organic 
compounds less methane and ethane.)

[55 FR 51035, Dec. 11, 1990; 56 FR 12299, Mar. 22, 1991]



Sec. 60.561  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act, in subpart A of part 60, or in subpart VV 
of part 60, and the following terms shall have the specific meanings 
given them.
    Boiler means any enclosed combustion device that extracts useful 
energy in the form of steam.
    Capital expenditure means, in addition to the definition in 40 CFR 
60.2, an expenditure for a physical or operational change to an existing 
facility that exceeds P, the product of the facility's replacement cost, 
R, and an adjusted annual asset guideline repair allowance, A, as 
reflected by the following equation: P = R  x A, where
    (a) The adjusted annual asset guideline repair allowance, A, is the 
product of the percent of the replacement cost, Y, and the applicable 
basic annual asset guideline repair allowance, B, as reflected by the 
following equation: A = Y  x (B  100);
    (b) The percent Y is determined from the following equation: Y = 1.0 
- 0.57 log X, where X is 1986 minus the year of construction; and
    (c) The applicable basic annual asset guideline repair allowance, B, 
is equal to 12.5.
    Car-sealed means, for purposes of these standards, a seal that is 
placed on the device used to change the position of a valve (e.g., from 
opened to closed) such that the position of the valve cannot be changed 
without breaking the seal and requiring the replacement of the old seal 
once broken with a new seal.
    Closed vent system means a system that is not open to the atmosphere 
and that is composed of piping, connections, and, if necessary, flow 
inducing devices that transport gas or vapor from a piece or pieces of 
equipment to a control device.
    Continuous emissions means any gas stream containing VOC that is 
generated essentially continuously when the process line or any piece of 
equipment in the process line is operating.
    Continuous process means a polymerization process in which reactants 
are introduced in a continuous manner and products are removed either 
continuously or intermittently at regular intervals so that the process 
can be operated and polymers produced essentially continuously.
    Control device means an enclosed combustion device, vapor recovery 
system, or flare.
    Copolymer means a polymer that has two different repeat units in its 
chain.
    Decomposition means, for the purposes of these standards, an event 
in a polymerization reactor that advances to the point where the 
polymerization reaction becomes uncontrollable, the polymer begins to 
break down (decompose), and it becomes necessary to relieve the reactor 
instantaneously in order to avoid catastrophic equipment damage or 
serious adverse personnel safety consequences.
    Decomposition emissions refers to those emissions released from a 
polymer production process as the result of a decomposition or during 
attempts to prevent a decomposition.
    Emergency vent stream means, for the purposes of these standards, an 
intermittent emission that results from a decomposition, attempts to 
prevent decompositions, power failure, equipment failure, or other 
unexpected cause that requires immediate venting of gases from process 
equipment in order to avoid safety hazards or equipment damage. This 
includes intermittent vents that occur from process equipment where 
normal operating parameters (e.g., pressure or temperature) are exceeded 
such that the process equipment can not be returned to normal operating 
conditions using the design features of the system and venting must 
occur to avoid equipment

[[Page 411]]

failure or adverse safety personnel consequences and to minimize adverse 
effects of the runaway reaction. This does not include intermittent 
vents that are designed into the process to maintain normal operating 
conditions of process vessels including those vents that regulate normal 
process vessel pressure.
    End finisher means a polymerization reaction vessel operated under 
very low pressures, typically at pressures of 2 torr or less, in order 
to produce high viscosity poly(ethylene terephthalate). An end finisher 
is preceded in a high viscosity poly(ethylene terephthalate) process 
line by one or more polymerization vessels operated under less severe 
vacuums, typically between 5 and 10 torr. A high viscosity poly(ethylene 
terephthalate) process line may have one or more end finishers.
    Existing control device means, for the purposes of these standards, 
an air pollution control device that has been in operation on or before 
September 30, 1987, or that has been in operation between September 30, 
1987, and January 10, 1989, on those continuous or intermittent 
emissions from a process section that is marked by an ``--'' in Table 1 
of this subpart.
    Existing control device is reconstructed means, for the purposes of 
these standards, the capital expenditure of at least 50 percent of the 
replacement cost of the existing control device.
    Existing control device is replaced means, for the purposes of these 
standards, the replacement of an existing control device with another 
control device.
    Expandable polystyrene means a polystyrene bead to which a blowing 
agent has been added using either an in-situ suspension process or a 
post-impregnation suspension process.
    Experimental process line means a polymer or copolymer manufacturing 
process line with the sole purpose of operating to evaluate polymer 
manufacturing processes, technologies, or products. An experimental 
process line does not produce a polymer or resin that is sold or that is 
used as a raw material for nonexperimental process lines.
    Flame zone means that portion of the combustion chamber in a boiler 
occupied by the flame envelope.
    Fugitive emissions equipment means each pump, compressor, pressure 
relief device, sampling connection system, open-ended valve or line, 
valve, and flange or other connector in VOC service and any devices or 
systems required by subpart VV of this part.
    Gas phase process means a polymerization process in which the 
polymerization reaction is carried out in the gas phase; i.e., the 
monomer(s) are gases in a fluidized bed of catalyst particles and 
granular polymer.
    High density polyethylene (HDPE) means a thermoplastic polymer or 
copolymer comprised of at least 50 percent ethylene by weight and having 
a density of greater than 0.940 g/cm\3\.
    High pressure process means the conventional production process for 
the manufacture of low density polyethylene in which a reaction pressure 
of about 15,000 psig or greater is used.
    High viscosity poly(ethylene terephthalate) means poly(ethylene 
terephthalate) that has an intrinsic viscosity of 0.9 or higher and is 
used in such applications as tire cord and seat belts.
    Incinerator means an enclosed combustion device that is used for 
destroying VOC.
    In-situ suspension process means a manufacturing process in which 
styrene, blowing agent, and other raw materials are added together 
within a reactor for the production of expandable polystyrene.
    Intermittent emissions means those gas streams containing VOC that 
are generated at intervals during process line operation and includes 
both planned and emergency releases.
    Liquid phase process means a polymerization process in which the 
polymerization reaction is carried out in the liquid phase; i.e., the 
monomer(s) and any catalyst are dissolved, or suspended in a liquid 
solvent.
    Liquid phase slurry process means a liquid phase polymerization 
process in which the monomer(s) are in solution (completely dissolved) 
in a liquid solvent, but the polymer is in the form of solid particles 
suspended in the liquid

[[Page 412]]

reaction mixture during the polymerization reaction; sometimes called a 
particle form process.
    Liquid phase solution process means a liquid phase polymerization 
process in which both the monomer(s) and polymer are in solution 
(completely dissolved) in the liquid reaction mixture.
    Low density polyethylene (LDPE) means a thermoplastic polymer or 
copolymer comprised of at least 50 percent ethylene by weight and having 
a density of 0.940 g/cm\3\ or less.
    Low pressure process means a production process for the manufacture 
of low density polyethylene in which a reaction pressure markedly below 
that used in a high pressure process is used. Reaction pressure of 
current low pressure processes typically go up to about 300 psig.
    Low viscosity poly(ethylene terephthalate) means a poly(ethylene 
terephthalate) that has an intrinsic viscosity of less than 0.75 and is 
used in such applications as clothing, bottle, and film production.
    Material recovery section means the equipment that recovers 
unreacted or by-product materials from any process section for return to 
the process line, off-site purification or treatment, or sale. Equipment 
designed to separate unreacted or by-product material from the polymer 
product are to be included in this process section, provided at least 
some of the material is recovered for reuse in the process, off-site 
purification or treatment, or sale, at the time the process section 
becomes an affected facility. Otherwise such equipment are to be 
assigned to one of the other process sections, as appropriate. Equipment 
that treats recovered materials are to be included in this process 
section, but equipment that also treats raw materials are not to be 
included in this process section. The latter equipment are to be 
included in the raw materials preparation section. If equipment is used 
to return unreacted or by-product material directly to the same piece of 
process equipment from which it was emitted, then that equipment is 
considered part of the process section that contains the process 
equipment. If equipment is used to recover unreacted or by-product 
material from a process section and return it to another process section 
or a different piece of process equipment in the same process section or 
sends it off-site for purification, treatment, or sale, then such 
equipment are considered part of a material recovery section. Equipment 
used for the on-site recovery of ethylene glycol from poly(ethylene 
terephthalate) plants, however, are not included in the material 
recovery section, but are covered under the standards applicable to the 
polymerization reaction section (Sec. 60.562-1(c)(1)(ii)(A) or 
(2)(ii)(A)).
    Operating day means, for the purposes of these standards, any 
calendar day during which equipment used in the manufacture of polymer 
was operating for at least 8 hours or one labor shift, whichever is 
shorter. Only operating days shall be used in determining compliance 
with the standards specified in Sec. 60.562-1(c)(1)(ii)(B), (1)(ii)(C), 
(2)(ii)(B), and (2)(ii)(C). Any calendar day in which equipment is used 
for less than 8 hours or one labor shift, whichever is less, is not an 
``operating day'' and shall not be used as part of the rolling 14-day 
period for determining compliance with the standards specified in 
Sec. 60.562-1(c)(1)(ii)(B), (1)(ii)(C), (2)(ii)(B), and (2)(ii)(C).
    Polyethylene means a thermoplastic polymer or copolymer comprised of 
at least 50 percent ethylene by weight; see low density polyethylene and 
high density polyethylene.
    Poly(ethylene terephthalate) (PET) means a polymer or copolymer 
comprised of at least 50 percent bis-(2-hydroxyethyl)-terephthalate 
(BHET) by weight.
    Poly(ethylene terephthalate) (PET) manufacture using dimethyl 
terephthalate means the manufacturing of poly(ethylene terephthalate) 
based on the esterification of dimethyl terephthalate (DMT) with 
ethylene glycol to form the intermediate monomer bis-(2-hydroxyethyl)-
terephthalate (BHET) that is subsequently polymerized to form PET.
    Poly(ethylene terephthalate) (PET) manufacture using terephthalic 
acid means the manufacturing of poly(ethylene terephthalate) based on 
the esterification reaction of terephthalic acid (TPA) with ethylene 
glycol to form the intermediate monomer bis-(2-hydroxyethyl)-

[[Page 413]]

terephthalate (BHET) that is subsequently polymerized to form PET.
    Polymerization reaction section means the equipment designed to 
cause monomer(s) to react to form polymers, including equipment designed 
primarily to cause the formation of short polymer chains (oligomers or 
low polymers), but not including equipment designed to prepare raw 
materials for polymerization, e.g., esterification vessels. For the 
purposes of these standards, the polymerization reaction section begins 
with the equipment used to transfer the materials from the raw materials 
preparation section and ends with the last vessel in which 
polymerization occurs. Equipment used for the on-site recovery of 
ethylene glycol from poly(ethylene terephthalate) plants, however, are 
included in this process section, rather than in the material recovery 
process section.
    Polypropylene (PP) means a thermoplastic polymer or copolymer 
comprised of at least 50 percent propylene by weight.
    Polystyrene (PS) means a thermoplastic polymer or copolymer 
comprised of at least 80 percent styrene or para-methylstyrene by 
weight.
    Post-impregnation suspension process means a manufacturing process 
in which polystyrene beads are first formed in a suspension process, 
washed, dried, or otherwise finished and then added with a blowing agent 
to another reactor in which the beads and blowing agent are reacted to 
produce expandable polystyrene.
    Process heater means a device that transfers heat liberated by 
burning fuel to fluids contained in tubular coils, including all fluids 
except water that is heated to produce steam.
    Process line means a group of equipment assembled that can operate 
independently if supplied with sufficient raw materials to produce 
polypropylene, polyethylene, polystyrene, (general purpose, crystal, or 
expandable) or poly(ethylene terephthalate) or one of their copolymers. 
A process line consists of the equipment in the following process 
sections (to the extent that these process sections are present at a 
plant): raw materials preparation, polymerization reaction, product 
finishing, product storage, and material recovery.
    Process section means the equipment designed to accomplish a general 
but well-defined task in polymer production. Process sections include 
raw materials preparation, polymerization reaction, material recovery, 
product finishing, and product storage and may be dedicated to a single 
process line or common to more than one process line.
    Process unit means equipment assembled to perform any of the 
physical and chemical operations in the production of polypropylene, 
polyethylene, polystyrene, (general purpose, crystal, or expandable), or 
poly(ethylene terephthalate) or one of their copolymers. A process unit 
can operate independently if supplied with sufficient feed or raw 
materials and sufficient storage facilities for the product. Examples of 
process units are raw materials handling and monomer recovery.
    Product finishing section means the equipment that treats, shapes, 
or modifies the polymer or resin to produce the finished end product of 
the particular facility, including equipment that prepares the product 
for product finishing. For the purposes of these standards, the product 
finishing section begins with the equipment used to transfer the 
polymerized product from the polymerization reaction section and ends 
with the last piece of equipment that modifies the characteristics of 
the polymer. Product finishing equipment may accomplish product 
separation, extruding and pelletizing, cooling and drying, blending, 
additives introduction, curing, or annealing. Equipment used to separate 
unreacted or by-product material from the product are to be included in 
this process section, provided the material separated from the polymer 
product is not recovered at the time the process section becomes an 
affected facility. If the material is being recovered, then the 
separation equipment are to be included in the material recovery 
section. Product finishing does not include polymerization, the physical 
mixing of the pellets to obtain a homogenous mixture of the polymer 
(except as noted below), or the shaping (such as fiber spinning, 
molding, or fabricating) or modification (such as fiber stretching and 
crimping)

[[Page 414]]

of the finished end product. If physical mixing occurs in equipment 
located between product finishing equipment (i.e., before all the 
chemical and physical characteristics have been ``set'' by virtue of 
having passed through the last piece of equipment in the product 
finishing section), then such equipment are to be included in this 
process section. Equipment used to physically mix the finished product 
that are located after the last piece of equipment in the product 
finishing section are part of the product storage section.
    Product storage section means the equipment that is designed to 
store the finished polymer or resin end product of the particular 
facility. For the purposes of these standards, the product storage 
section begins with the equipment used to transfer the finished product 
out of the product finishing section and ends with the containers used 
to store the final product. Any equipment used after the product 
finishing section to recover unreacted or by-product material are to be 
considered part of a material recovery section. Product storage does not 
include any intentional modification of the characteristics of any 
polymer or resin product, but does include equipment that provide a 
uniform mixture of product, provided such equipment are used after the 
last product finishing piece of equipment. This process section also 
does not include the shipment of a finished polymer or resin product to 
another facility for further finishing or fabrication.
    Raw materials preparation section means the equipment located at a 
polymer manufacturing plant designed to prepare raw materials, such as 
monomers and solvents, for polymerization. For the purposes of these 
standards, this process section begins with the equipment used to 
transfer raw materials from storage and recovered material from material 
recovery process sections, and ends with the last piece of equipment 
that prepares the material for polymerization. The raw materials 
preparation section may include equipment that accomplishes 
purification, drying, or other treatment of raw materials or of raw and 
recovered materials together, activation of catalysts, and 
esterification including the formation of some short polymer chains 
(oligomers), but does not include equipment that is designed primarily 
to accomplish the formation of oligomers, the treatment of recovered 
materials alone, or the storage of raw materials.
    Recovery system means an individual unit or series of material 
recovery units, such as absorbers, condensers, and carbon adsorbers, 
used for recovering volatile organic compounds.
    Total organic compounds (TOC) means those compounds measured 
according to the procedures specified in Sec. 60.564.
    Vent stream means any gas stream released to the atmosphere directly 
from an emission source or indirectly either through another piece of 
process equipment or a material recovery device that constitutes part of 
the normal recovery operations in a polymer process line where potential 
emissions are recovered for recycle or resale, and any gas stream 
directed to an air pollution control device. The emissions released from 
an air pollution control device are not considered a vent stream unless, 
as noted above, the control device is part of the normal material 
recovery operations in a polymer process line where potential emissions 
are recovered for recycle or resale.
    Volatile organic compounds (VOC) means, for the purposes of these 
standards, any reactive organic compounds as defined in Sec. 60.2 
Definitions.

[55 FR 51035, Dec. 11, 1990; 56 FR 9178, Mar. 5, 1991; 56 FR 12299, Mar. 
22, 1991]



Sec. 60.562-1  Standards: Process      emissions.

    (a) Polypropylene, low density polyethylene, and high density 
polyethylene. Each owner or operator of a polypropylene, low density 
polyethylene, or high density polyethylene process line containing a 
process section subject to the provisions of this subpart shall comply 
with the provisions in this section on and after the date on which the 
initial performance test required by Sec. 60.8 is completed, but not 
later than 60 days after achieving the maximum production rate at which 
the affected facility will be operated, or 180 days after initial 
startup whichever comes first.

[[Page 415]]

    (1) Continuous emissions. For each vent stream that emits continuous 
emissions from an affected facility as defined in Sec. 60.560(a)(1), the 
owner or operator shall use the procedures identified in paragraphs 
(a)(1) (ii) and (iii) of this section for determining which continuous 
emissions are to be controlled and which level of control listed in 
paragraph (a)(1)(i) of this section is to be met. The owner or operator 
shall use the procedures identified in paragraphs (a)(1) (ii) and (iii) 
of this section each time a process section is constructed, modified, or 
reconstructed at the plant site.
    (i) Level of control Continuous emission streams determined to be 
subject to control pursuant to the procedures identified in paragraphs 
(a)(1) (ii) and (iii) of this section, as applicable, shall meet one of 
the control levels identified in paragraphs (a)(1)(i) (A) through (D) of 
this section. The procedures in paragraphs (a)(1) (ii) and (iii) of this 
section identify which level of control may be met. The level of control 
identified in paragraph (a)(1)(i)(D) of this section is limited to 
certain continuous emission streams, which are identified through the 
procedures in paragraphs (a)(1) (ii) and (iii) of this section.
    (A) Reduce emissions of total organic compounds (minus methane and 
ethane) (TOC) by 98 weight percent, or to a concentration of 20 parts 
per million by volume (ppmv) on a dry basis, whichever is less 
stringent. The TOC is expressed as the sum of the actual compounds, not 
carbon equivalents. If an owner or operator elects to comply with the 20 
ppmv standard, the concentration shall include a correction to 3 percent 
oxygen only when supplemental combustion air is used to combust the vent 
stream.
    (B) Combust the emissions in a boiler or process heater with a 
design heat input capacity of 150 million Btu/hour or greater by 
introducing the vent stream into the flame zone of the boiler or process 
heater. (Note: A boiler or process heater of lesser design heat capacity 
may be used, but must demonstrate compliance with paragraph (a)(1)(i)(A) 
of this section.)
    (C) Combust the emissions in a flare that meets the conditions 
specified in Sec. 60.18. If the flare is used to control both continuous 
and intermittent emissions, the flare shall meet the conditions 
specified in Sec. 60.18 at all times (i.e., which controlling continuous 
emissions alone or when controlling both continuous and intermittent 
emissions).
    (D) Vent the emissions to a control device located on the plant 
site.
    (ii) Uncontrolled Continuous Emissions. For each vent stream that 
emits continuous emissions from an affected facility as defined in 
Sec. 60.560(a)(1) and that is not controlled in an existing control 
device, the owner or operator shall use the procedures identified in 
Table 3 to identify those continuous emissions from each constructed, 
modified, or reconstructed affected facility that are to be controlled. 
The owner shall include in the procedure all uncontrolled continuous 
vent streams from previously constructed, modified, or reconstructed 
affected facilities at the plant site each time a process section is 
constructed, modified, or reconstructed at the plant site. In applying 
the procedures shown in Table 3, the stream characteristics may be 
either measured or calculated as specified in Sec. 60.564(d). For 
modified or reconstructed affected facilities, these stream 
characteristics are to be determined after a modification or 
reconstruction determination has been made by the Administrator, but 
before any actual changes have been undertaken, and then again after the 
actual changes have been made. Figure 1 provides a summary overview of 
the control determination procedure described in Table 3.

[[Page 416]]



  Table 3--Procedure for Determining Control and Applicable Standard for Continuous Emission Streams From New,
                  Modified, or Reconstructed Polypropylene and Polyethylene Affected Facilities
----------------------------------------------------------------------------------------------------------------
                                     Applicable TOC
          Procedure /a/              weight percent    Control/no control           Applicable standard
                                         range              criteria
----------------------------------------------------------------------------------------------------------------
1. Sum all uncontrolled streams    0.10 < 5.5         1. If total          1. Sec.  60.562-1(a)(1)(i) (A), (B),
 with TOC weight percent within                        combined             or (C).
 the applicable weight percent                         uncontrolled
 range from all affected                               emissions are
 facilities at a plant site.                           equal to or
                                                       greater than the
                                                       calculated
                                                       threshold
                                                       emissions (CTE) /b/
                                                       , control.
2. Calculate total uncontrolled                       2. If total          2. Sec.  60.562-1(a)(1)(i) (A)
 annual emissions for each weight                      combined             through (D).
 percent range. For modified or                        uncontrolled
 affected facilities, use the                          emission are less
 total uncontrolled emissions                          than the CTE /b/,
 after modification or                                 control only
 reconstruction.                                       individual streams
                                                       with volume flow
                                                       rates of 8 scfm or
                                                       less.
3. Calculate composite TOC         5.5 < 20           1. If total          1. Sec.  60.562-1(a)(1)(i) (A), (B),
 concentration (weight percent)                        combined             or (C)
 for streams in the 0.10 to less                       uncontrolled        2. If total combined uncontrolled
 than 5.5 weight percent range                         emissions are        emissions are less than the CTE /b/,
 and for streams in the 5.5 to                         equal to or          control only individual streams with
 less than 20 weight percent                           greater than CTE /   volume flow rates of 8 scfm or less.
 range. For modified or                                b/, control.
 reconstructed affected
 facilities, calculate the
 composite VOC concentration
 before and after modification
 and reconstruction.
4. Select the higher of the two    20 to 100          1. If total          1. Sec.  60.562-1(a)(1)(i) (A), (B),
 TOC concentrations for each                           combined             or (C).
 weight percent range for vent                         uncontrolled
 streams from a modified or                            emissions are
 reconstructed affected facility.                      equal to or
                                                       greater than 18.2
                                                       Mg/yr, control.
5. Calculate the threshold         .................  2. If total          2. Sec.  60.562-1(a)(1)(i) (A)
 emissions for the 0.10 to less                        combined             through (D).
 than 5.5 weight percent range                         uncontrolled
 and for the 5.5 to less than 20                       emissions are less
 weight percent range using the                        than 18.2 Mg/yr,
 respective composite TOC                              control.
 concentration selected above.
----------------------------------------------------------------------------------------------------------------
a Individual streams excluded under Sec.  60.560(g) from the requirements of Sec.  60.562-1 are to be excluded
  from all calculations in this table. This paragraph exempts all individual emission streams with individual
  uncontrolled annual emission rates of less than 1.6 Mg/yr and all individual emission streams with individual
  TOC concentrations of less than 0.10 percent TOC by weight.
b For the 0.10 to less than 5.5 weight percent range, the following equations are used:


------------------------------------------------------------------------
                                                Use this equation to
If the percent composite TOC concentration       calculate threshold
                    is                                emissions
------------------------------------------------------------------------
0.10<0.12.................................  (a x 7.5 x 10\6\)+226
0.12<0.2..................................  (b x 58.3)+116.8
0.2<0.3...................................  (c x 3020)+71.8
0.3<0.4...................................  (d x 547)+54.5
0.4<0.6...................................  48.3+31 (0.6-weight percent
                                             TOC)
0.6<5.5...................................  48.3
------------------------------------------------------------------------

where: a=(0.12-weight percent TOC).2,5
[GRAPHIC] [TIFF OMITTED] TC16NO91.070

    c=(0.3-weight percent TOC)\2\

    d=(0.4-weight percent TOC).1,5

    For the 5.5 to less than 20 weight percent range, the following 
equations are used.

------------------------------------------------------------------------
                                                Use this equation to
If the percent composite TOC concentration       calculate threshold
                    is                                emissions
------------------------------------------------------------------------
5.5<7.0...................................  (e x 740)+31
7.0<9.0...................................  (f x 324)+25.0
9.0<20....................................  (g x 125)+18.2
------------------------------------------------------------------------

where

[[Page 417]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.071


[[Page 418]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.048

    (iii) Controlled Continuous Emissions. For each vent stream that 
emits continuous emissions from an affected facility as defined in 
Sec. 60.560(a)(1) and that is controlled in an existing control device, 
each owner or operator shall determine whether the emissions entering 
the control device are greater

[[Page 419]]

than or equal to the calculated threshold emissions (CTE) level, which 
is to be calculated using the TOC concentration of the inlet vent stream 
and the equations in footnote b of Table 3. If the inlet stream's TOC 
concentration is equal to or greater than 20 weight percent, the 
calculated threshold emissions level is 18.2 Mg/yr. If multiple emission 
streams are vented to the control device, the individual streams are not 
to be separated into individual weight percent ranges for calculation 
purposes as would be done for uncontrolled emission streams. Emissions 
vented to an existing control device are required to be controlled as 
described in paragraphs (a)(1)(iii) (A) and (B) of this section. Figure 
2 illustrates the control determination procedure for controlled 
continuous emissions.

[[Page 420]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.049

    (A) If the annual emissions of the stream entering the control 
device are equal to or greater than the CTE levels, then compliance with 
one of the requirements identified in Sec. 60.562-1(a)(1)(i) (A), (B), 
or (C) is required at such time the control device is reconstructed or 
replaced or has its operating conditions modified as a result of State 
or local regulations (including changes in the operating permit) 
including those instances where the control device is reconstructed, 
replaced, or modified in its operation at the same time the existing 
process section

[[Page 421]]

is modified or reconstructed and becomes an affected facility. If the 
existing control device already complies with one of the requirements 
identified in Sec. 60.562-1(a)(1)(i) (A), (B), or (C), no further 
control is required.
    (B) If the annual emissions of the stream entering the control 
device are less than the CTE level, then the requirements of 
Sec. 60.562-1(a)(1)(i) (A), (B), or (C) are not applicable at that time. 
However, if the control device is replaced, reconstructed, or modified 
at a later date, each owner or operator shall reevaluate the 
applicability of these standards. This is done by combining with the 
vent stream entering the control device any uncontrolled vent streams in 
the same weight percent range as the controlled vent stream and 
determining whether the annual emissions of the stream entering the 
control device plus the applicable uncontrolled vent streams are greater 
than or equal to the CTE level, which is based on the weighted TOC 
concentration of the controlled vent stream and the uncontrolled vent 
streams. If the annual emissions entering the control device (including 
the applicable uncontrolled vent streams) are greater than or equal to 
the CTE level, then compliance with one of the requirements identified 
in Sec. 60.562-1(a)(1)(i) (A), (B), or (C) is required at that time for 
both the controlled and uncontrolled vent streams. If the annual 
emissions are less than the CTE level, compliance with these standards 
is again not required at such time. However, if the control device is 
again replaced, reconstructed, or modified, each owner or operator shall 
repeat this determination procedure.
    (2) Intermittent emissions. The owner or operator shall control each 
vent stream that emits intermittent emissions from an affected facility 
as defined in Sec. 60.560-1(a)(1) by meeting one of the control 
requirements specified in paragraphs (a)(2) (i) and (ii) of this 
section. If a vent stream that emits intermittent emissions is 
controlled in an existing flare, incinerator, boiler, or process heater, 
the requirements of this paragraph are waived until such time the 
control device is reconstructed or replaced or is modified in its 
operating conditions as a result of State or local regulation, including 
changes in the operating permit. This paragraph does not apply to 
emergency vent streams exempted by Sec. 60.560(h) and as defined in 
Sec. 60.561.
    (i) Combust the emissions in a flare that is:
    (A) Designed for and operated with no visible emissions, except for 
periods not to exceed a total of 5 minutes during any 2 consecutive 
hours,
    (B) Operated with a flame present at all times, and
    (C) Designed to maintain a stable flame.
    (ii) Combust the emissions in an incinerator, boiler, or process 
heater. Such emissions shall be introduced into the flame zone of a 
boiler or process heater.
    (b) Polystyrene. Each owner or operator of a polystyrene process 
line containing process sections subject to the provisions of this 
subpart shall comply with the provisions in this section on and after 
the date on which the initial performance test required by Sec. 60.8 is 
completed, but not later than 60 days after achieving the maximum 
production rate at which the affected facility will be operated, or 180 
days after initial startup, whichever comes first. Each owner or 
operator of a polystyrene process line using a continuous process shall:
    (1) Limit the continuous TOC emissions from the material recovery 
section by complying with one of the following:
    (i) Not allow continuous TOC emissions to be greater than 0.0036 kg 
TOC/Mg product; or
    (ii) Not allow the outlet gas stream temperature from each final 
condenser in the material recovery section to exceed -25  deg.C (-13 
deg.F). For purposes of this standard, temperature excursions above this 
limit shall not be considered a violation when such excursions occur 
during periods of startup, shutdown, or malfunction; or
    (iii) Comply with Sec. 60.562-1(a)(1)(i) (A), (B), or (C).
    (2) If continuous TOC emissions from the material recovery section 
are routed through an existing emergency vapor recovery system, then 
compliance with these standards is required when the emergency vapor 
recovery

[[Page 422]]

system undergoes modification, reconstruction, or replacement. In such 
instances, compliance with these standards shall be achieved no later 
than 180 days after completion of the modification, reconstruction, or 
replacement.
    (c) Poly(ethylene terephthalate). Each owner or operator of a 
poly(ethylene terephthalate) process line containing process sections 
subject to the provisions of this subpart shall comply with the 
provisions in this section on and after the date on which the initial 
performance test required by Sec. 60.8 is completed, but not later than 
60 days after achieving the maximum production rate at which the 
affected facility will be operated, or 180 days after initial startup, 
whichever comes first.
    (1) Each owner or operator of a PET process line using a dimethyl 
terephthalate process shall:
    (i) Limit the continuous TOC emissions from the material recovery 
section (i.e., methanol recovery) by complying with one of the 
following:
    (A) Not allow the continuous TOC emissions to be greater than 0.018 
kg TOC/Mg product; or
    (B) Not allow the outlet gas stream temperature from each final 
condenser in the material recovery section (i.e., methanol recovery) to 
exceed +3   deg.C (+37   deg.F). For purposes of this standard, 
temperature excursions above this limit shall not be considered a 
violation when such excursions occur during periods of startup, 
shutdown, or malfunction.
    (ii) Limit the continuous TOC emissions and, if steam-jet ejectors 
are used to provide vacuum to the polymerization reactors, the ethylene 
glycol concentration from the polymerization reaction section by 
complying with the appropriate standard set forth below. The ethylene 
glycol concentration limits specified in paragraphs (c)(1)(ii) (B) and 
(C) of this section shall be determined by the procedures specified in 
Sec. 60.564(j).
    (A) Not allow continuous TOC emissions from the polymerization 
reaction section (including emissions from any equipment used to further 
recover the ethylene glycol, but excluding those emissions from the 
cooling tower) to be greater than 0.02 kg TOC/Mg product; and
    (B) If steam-jet ejectors are used as vacuum producers and a low 
viscosity product is being produced using single or multiple end 
finishers or a high viscosity product is being produced using a single 
end finisher, maintain the concentration of ethylene glycol in the 
liquid effluent exiting the vacuum system servicing the polymerization 
reaction section at or below 0.35 percent by weight, averaged on a daily 
basis over a rolling 14-day period of operating days; or
    (C) If steam-jet ejectors are used as vacuum producers and a high 
viscosity product is being produced using multiple end finishers, 
maintain an ethylene glycol concentration in the cooling tower at or 
below 6.0 percent by weight averaged on a daily basis over a rolling 14-
day period of operating days.
    (2) Each owner or operator of a PET process line using a 
terephthalic acid process shall:
    (i) Not allow the continuous TOC emissions from the esterification 
vessels in the raw materials preparation section to be greater than 0.04 
kg TOC/Mg product.
    (ii) Limit the continuous TOC emissions and, if steam-jet ejectors 
are used to provide vaccum to the polymerization reactors, the ethylene 
glycol concentration from the polymerization reaction section by 
complying with the appropriate standard set forth below. The ethylene 
glycol concentration limits specified in paragraphs (c)(2)(ii) (B) and 
(C) of this section shall be determined by the procedures specified in 
Sec. 60.564(j).
    (A) Not allow continuous TOC emissions from the polymerization 
reaction section (including emissions from any equipment used to further 
recover the ethylene glycol, but excluding those emissions from the 
cooling tower) to be greater than 0.02 kg TOC/Mg product; and
    (B) If steam-jet ejectors are used as vacuum producers and a low 
viscosity product is being produced using single or multiple end 
finishers or a high viscosity product is being produced using a single 
end finisher, maintain the concentration of ethylene glycol in the 
liquid effluent exiting the vacuum system servicing the polymerization 
reaction section at or below 0.35 percent by

[[Page 423]]

weight, averaged on a daily basis over a rolling 14-day period of 
operating days; or
    (C) If steam-jet ejectors are used as vacuum producers and a high 
viscosity product is being produced using multiple end finishers, 
maintain an ethylene glycol concentration in the cooling tower at or 
below 6.0 percent by weight averaged on a daily basis over a rolling 14-
day period of operating days.
    (d) Closed vent systems and control devices used to comply with this 
subpart shall be operated at all times when emissions may be vented to 
them.
    (e) Vent systems that contain valves that could divert a vent stream 
from a control device shall have car-sealed opened all valves in the 
vent system from the emission source to the control device and car-
sealed closed all valves in vent system that would lead the vent stream 
to the atmosphere, either directly or indirectly, bypassing the control 
device.

[55 FR 51035, Dec. 11, 1990; 56 FR 9178, Mar. 5, 1991, as amended at 56 
FR 12299, Mar. 22, 1991]



Sec. 60.562-2  Standards: Equipment leaks of VOC.

    (a) Each owner or operator of an affected facility subject to the 
provisions of this subpart shall comply with the requirements specified 
in Sec. 60.482-1 through Sec. 60.482-10 as soon as practicable, but no 
later than 180 days after initial startup, except that indications of 
liquids dripping from bleed ports in existing pumps in light liquid 
service are not considered to be a leak as defined in Sec. 60.482-
2(b)(2). For purposes of this standard, a ``bleed port'' is a 
technologically-required feature of the pump whereby polymer fluid used 
to provide lubrication and/or cooling of the pump shaft exits the pump, 
thereby resulting in a visible leak of fluid. This exemption expires 
when the existing pump is replaced or reconstructed.
    (b) An owner or operator may elect to comply with the requirements 
specified in Sec. 60.483-1 and Sec. 60.483-2.
    (c) An owner or operator may apply to the Administrator for a 
determination of equivalency for any means of emission limitation that 
achieves a reduction in emissions of VOC at least equivalent to the 
reduction in emissions of VOC achieved by the controls required in this 
subpart. In doing so, the owner or operator shall comply with 
requirements specified in Sec. 60.484.
    (d) Each owner or operator subject to the provisions of this subpart 
shall comply with the provisions specified in Sec. 60.485 except an 
owner or operator may use the following provision in addition to 
Sec. 60.485(e): Equipment is in light liquid service if the percent 
evaporated is greater than 10 percent at 150  deg.C as determined by 
ASTM Method D86-78 (incorporated by reference as specified in 
Sec. 60.17).
    (e) Each owner or operator subject to the provisions of this subpart 
shall comply with Sec. 60.486 and Sec. 60.487.

[55 FR 51035, Dec. 11, 1990; 56 FR 12299, Mar. 22, 1991]



Sec. 60.563  Monitoring requirements.

    (a) Whenever a particular item of monitoring equipment is specified 
in this section to be installed, the owner or operator shall install, 
calibrate, maintain, and operate according to manufacturer's 
specifications that item as follows:
    (1) A temperature monitoring device to measure and record 
continuously the operating temperature to within 1 percent (relative to 
degrees Celsius) or  0.5  deg.C ( 0.9  deg.F), 
whichever is greater.
    (2) A flame monitoring device, such as a thermocouple, an 
ultraviolet sensor, an infrared beam sensor, or similar device to 
indicate and record continuously whether a flare or pilot light flame is 
present, as specified.
    (3) A flow monitoring indicator to indicate and record whether or 
not flow exists at least once every fifteen minutes.
    (4) An organic monitoring device (based on a detection principle 
such as infrared, photoionization, or thermal conductivity) to indicate 
and record continuously the concentration level of organic compounds.
    (5) A specific gravity monitoring device to measure and record 
continuously to within 0.02 specific gravity unit.
    (b) The owner or operator shall install, as applicable, the 
monitoring equipment for the control means used to comply with 
Sec. 60.562-1, except Sec. 60.562-1(a)(1)(i)(D), as follows:

[[Page 424]]

    (1) If the control equipment is an incinerator:
    (i) For a noncatalytic incinerator, a temperature monitoring device 
shall be installed in the firebox.
    (ii) For a catalytic incinerator, temperature monitoring devices 
shall be installed in the gas stream immediately before and after the 
catalytic bed.
    (2) If a flare is used:
    (i) A flame monitoring device shall be installed to indicate the 
presence of a flare flame or a flame for each pilot light, if the flare 
is used to comply with Sec. 60.562-1(a)(1), including those flares 
controlling both continuous and intermittent emissions.
    (ii) A thermocouple or equivalent monitoring device to indicate the 
presence of a flame at each pilot light, if used to comply with 
Sec. 60.562-1(a)(2).
    (3) If a boiler or process heater is used:
    (i) If the boiler or process heater has a heat input design capacity 
of less than 150 million Btu/hr, a temperature monitoring device shall 
be installed between the radiant section and the convection zone for 
watertube boilers and between the furnace (combustion zone) and the 
firetubes for firetube boilers.
    (ii) If the boiler or process heater has a heat input design 
capacity of 150 million Btu/hr or greater, such records to indicate the 
periods of operation of the boiler or process heater shall be 
maintained. The records must be readily available for inspection.
    (4) If an absorber is the final unit in a system:
    (i) A temperature monitoring device and a specific gravity 
monitoring device for the scrubber liquid shall be installed, or
    (ii) An organic monitoring device shall be installed at the outlet 
of the absorber.
    (5) If a condenser is the final unit in a system:
    (i) A temperature monitoring device shall be installed at the 
condenser exit (product side), or
    (ii) An organic monitoring device shall be installed at the outlet 
of the condenser.
    (6) If a carbon adsorber is the final unit in a system, an organic 
monitoring device shall be installed at the outlet of the carbon bed.
    (c) Owners or operators of control devices used to comply with the 
provisions of this subpart, except Sec. 60.562-1(a)(1)(i)(D), shall 
monitor these control devices to ensure that they are operated and 
maintained in conformance with their designs.
    (d) Owners or operators using a vent system that contains valves 
that could divert a vent stream from a control device used to comply 
with the provisions of this subpart shall do one or a combination of the 
following:
    (1) Install a flow indicator immediately downstream of each valve 
that if opened would allow a vent stream to bypass the control device 
and be emitted, either directly or indirectly, to the atmosphere. The 
flow indicator shall be capable of recording flow at least once every 
fifteen minutes.
    (2) Monitor the valves once a month, checking the position of the 
valves and the condition of the car seal, and identify all times when 
the car seals have been broken and the valve position has been changed 
(i.e., from opened to closed for valves in the vent piping to the 
control device and from closed to open for valves that allow the stream 
to be vented directly or indirectly to the atmosphere).
    (e) An owner or operator complying with the standards specified 
under Sec. 60.562-1, except Sec. 60.562-1(a)(1)(i)(D), with control 
devices other than an incinerator, boiler, process heater, flare, 
absorber, condenser, or carbon adsorber or by any other means shall 
provide to the Administrator information describing the operation of the 
control device and the process parameter(s) which would indicate proper 
operation and maintenance of the device. The Administrator may request 
further information and will specify appropriate monitoring procedures 
or requirements.

[55 FR 51035, Dec. 11, 1990; 56 FR 12299, Mar. 22, 1991]



Sec. 60.564  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods

[[Page 425]]

and procedures specified in this section, except as provided under 
Sec. 60.8(b). Owners or operators complying with Sec. 60.562-
1(a)(1)(i)(D) need not perform a performance test on the control device, 
provided the control device is not used to comply with any other 
requirement of Sec. 60.562-1(a).
    (1) Whenever changes are made in production capacity, feedstock type 
or catalyst type, or whenever there is replacement, removal, or addition 
of a control device, each owner or operator shall conduct a performance 
test according to the procedures in this section as appropriate, in 
order to determine compliance with Sec. 60.562-1.
    (2) Where a boiler or process heater with a design heat input 
capacity of 150 million Btu/hour or greater is used, the requirement for 
an initial performance test is waived, in accordance with Sec. 60.8(b). 
However, the Administrator reserves the option to require testing at 
such other times as may be required, as provided for in Sec. 114 of the 
Act.
    (3) The owner or operator shall determine the average organic 
concentration for each performance test run using the equipment 
described in Sec. 60.563(a)(4). The average organic concentration shall 
be determined from measurements taken at least every 15 minutes during 
each performance test run. The average of the three runs shall be the 
base value for the monitoring program.
    (4) When an absorber is the final unit in the system, the owner or 
operator shall determine the average specific gravity for each 
performance test run using specific gravity monitoring equipment 
described in Sec. 60.563(a)(5). An average specific gravity shall be 
determined from measurements taken at least every 15 minutes during each 
performance test run. The average of the three runs shall be the base 
value for the monitoring program.
    (5) When a condenser is the final unit in the system, the owner or 
operator shall determine the average outlet temperature for each 
performance test run using the temperature monitoring equipment 
described in Sec. 60.563(a)(1). An average temperature shall be 
determined from measurements taken at least every 15 minutes during each 
performance test run while the vent stream is normally routed and 
constituted. The average of the three runs shall be the base value for 
the monitoring program.
    (b) The owner or operator shall determine compliance with the 
emission concentration standard in Sec. 60.562-1 (a)(1)(i)(A) or 
(b)(1)(iii) if applicable [if not, see paragraph (c) of this section] as 
follows:
    (1) The TOC concentration is the sum of the individual components 
and shall be computed for each run using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.072

where:

    CTOC = Concentration of TOC (minus methane and ethane), 
dry basis, ppmv.
    Cj = the concentration of sample component j, ppm.
    n =  Number of components in the sample.

    (i) Method 18 shall be used to determine the concentration of each 
individual organic component (Cj) in the gas stream. Method 1 
or 1A, as appropriate, shall be used to determine the sampling site at 
the outlet of the control device. Method 4 shall be used to determine 
the moisture content, if necessary.
    (ii) The sampling time for each run shall be 1 hour in which either 
an integrated sample or four grab samples shall be taken. If grab 
sampling is used, then the samples shall be taken at 15 minute 
intervals.
    (2) If supplemental combustion air is used, the TOC concentration 
shall be corrected to 3 percent oxygen and shall be computed using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.073

where:

    CCORR =  Concentration of TOC corrected to 3 percent 
oxygen, dry basis, ppm by volume.
    CMEAS = Concentration of TOC (minus methane and ethane), 
dry basis, ppm by volume, as calculated in paragraph (b)(1) of this 
section.
    %O2d = Concentration of O2, dry basis, percent 
by volume.


[[Page 426]]



The emission rate correction factor, integrated sampling and analysis 
procedure of Method 3 shall be used to determine the oxygen 
concentration (%O2d). The sampling site shall be the same as 
that of the TOC sample and the samples shall be taken during the same 
time that the TOC samples are taken.
    (c) If paragraph (b) of this section is not applicable, then the 
owner or operator shall determine compliance with the percent emission 
reduction standard in Sec. 60.562-1 (a)(1)(i)(A) or (b)(1)(iii) as 
follows:
    (1) The emission reduction of TOC (minus methane and ethane) shall 
be determined using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.075

where:

    P = Percent emission reduction, by weight.
    Einlet = Mass rate of TOC entering the control device, kg 
TOC/hr.
    Eoutlet = Mass rate of TOC, discharged to the atmosphere, 
kg TOC/hr.

    (2) The mass rates of TOC (Ei, Eo) shall be 
computed using the following equations:
[GRAPHIC] [TIFF OMITTED] TC16NO91.076

[GRAPHIC] [TIFF OMITTED] TC16NO91.074

where:

    Cij,Coj = Concentration of sample component 
``j'' of the gas stream at the inlet and outlet of the control device, 
respectively, dry basis, ppmv.
    Mij,Moj = Molecular weight of sample component 
``j'' of the gas stream at the inlet and outlet of the control device 
respectively, g/g-mole (lb/lb-mole).
    Qi,Qo = Flow rate of the gas stream at the 
inlet and outlet of the control device, respectively, dscm/hr (dscf/hr).
    K1 = 4.157  x  10-8 [(kg)/g-mole)]/
[(g)(ppm)(dscm)] {5.711 x 10-15 [(lb)/(lb-mole)]/
(lb)(ppm)(dscf)]}

    (i) Method 18 shall be used to determine the concentration of each 
individual organic component (Cij, Coj) in the gas 
stream. Method 1 or 1A, as appropriate, shall be used to determine the 
inlet and outlet sampling sites. The inlet site shall be before the 
inlet of the control device and after all product recovery units.
    (ii) Method 2, 2A, 2C, or 2D, as appropriate, shall be used to 
determine the volumetric flow rates (Qi, Qo). If 
necessary, Method 4 shall be used to determine the moisture content. 
Both determinations shall be compatible with the Method 18 
determinations.
    (iii) Inlet and outlet samples shall be taken simultaneously. The 
sampling time for each run shall be 1 hour in which either an integrated 
sample or four grab samples shall be taken. If grab sampling is used, 
then the samples shall be taken at 15 minute intervals.
    (d) An owner or operator shall determine compliance with the 
individual stream exemptions in Sec. 60.560(g) and the procedures 
specified in Table 3 for compliance with Sec. 60.562-1(a)(1) as 
identified in paragraphs (d)(1) and (2) of this section. An owner or 
operator using the procedures specified in Sec. 60.562-1(a)(1) for 
determining which continuous process emissions are to be controlled may 
use calculations demonstrated to be sufficiently accurate as to preclude 
the necessity of actual testing for purposes of calculating the 
uncontrolled annual emissions and weight percent of TOC. Owners or 
operators seeking to exempt streams under Sec. 60.560(g) must use the 
appropriate test procedures specified in this section.
    (1) The uncontrolled annual emissions of the individual vent stream 
shall be determined using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.077


[[Page 427]]


where:

Eunc=uncontrolled annual emissions, Mg/yr
    Cj=concentration of sample component ``j'' of the gas 
stream, dry basis, ppmv.
    Mj=Molecular weight of sample component ``j'' of the gas 
stream, g/g-mole (lb/lb-mole).
    Q=Flow rate of the gas stream, dscm/hr (dscf/hr).
    K1=4.157  x  10-8 [(kg)/g-mole)]/
[(g)(ppm)(dscm)] {5.711  x  10-15 [(lb)/(lb-mole)]/
(lb)(ppm)(dscf)]}
    8,600=operating hours per year

    (i) Method 18 shall be used to determine the concentration of each 
individual organic component (Cj) in the gas stream. Method 1 
or 1A, as appropriate, shall be used to determine the sampling site. If 
the gas stream is controlled in an existing control device, the sampling 
site shall be before the inlet of the control device and after all 
product recovery units.
    (ii) Method 2, 2A, 2C, or 2D, as appropriate, shall be used to 
determine the volumetric flow rate (Q). If necessary, Method 4 shall be 
used to determine the moisture content. Both determinations shall be 
compatible with the Method 18 determinations.
    (iii) The sampling time for each run shall be 1 hour in which either 
an integrated sample or four grab samples shall be taken. If grab 
sampling is used, then the samples shall be taken at 15 minute 
intervals.
    (2) The weight percent VOC of the uncontrolled individual vent 
stream shall be determined using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.078

where:

    Cj=concentration of sample TOC component ``j'' of the gas 
stream, dry basis, ppmv.
    Mj=Molecular weight of sample TOC component ``j'' of the 
gas stream, g/g-mole (1b/1b-mole).
    MWgas=Average molecular weight of the entire gas stream, 
g/g-mole (1b/1b-mole).

    (i) Method 18 shall be used to determine the concentration of each 
individual organic component (Cj) in the gas stream. Method 1 
or 1A, as appropriate, shall be used to determine the sampling site. If 
the gas stream is controlled in an existing control device, the sampling 
site shall be before the inlet of the control device and after all 
product recovery units. If necessary, Method 4 shall be used to 
determine the moisture content. This determination shall be compatible 
with the Method 18 determinations.
    (ii) The average molecular weight of the gas stream shall be 
determined using methods approved by the Administrator. If the carrier 
component of the gas stream is nitrogen, then an average molecular 
weight of 28 g/g-mole (lb/lb-mole) may be used in lieu of testing. If 
the carrier component of the gas stream is air, then an average 
molecular weight of 29 g/g-mole (lb/lb-mole) may be used in lieu of 
testing.
    (iii) The sampling time for each run shall be 1 hour in which either 
an integrated sample or four grab samples shall be taken. If grab 
sampling is used, then the samples shall be taken at 15 minute 
intervals.
    (e) The owner or operator shall determine compliance of flares with 
the visible emission and flare provisions in Sec. 60.562-1 as follows:
    (1) Method 22 shall be used to determine visible emissions. The 
observation period for each run shall be 2 hours.
    (2) The monitoring device of Sec. 60.563(b)(2) shall be used to 
determine whether a flame is present.
    (f) The owner or operator shall determine compliance with the net 
heating value provisions in Sec. 60.18 as referenced by Sec. 60.562-
1(a)(1)(i)(C). The net heating value of the process vent stream being 
combusted in a flare shall be computed as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.079

where:
    HT=Net heating value of the sample based on the net 
enthalpy per mole of offgas combusted at 25   deg.C and 760 mmHg, but 
the standard temperature for determining the volume corresponding to one 
mole is 20   deg.C, MJ/scm.
    K2=Conversion constant,
    [GRAPHIC] [TIFF OMITTED] TC16NO91.080
    

[[Page 428]]


where standard temperature for
[GRAPHIC] [TIFF OMITTED] TC16NO91.081

    Cj=Concentration of sample component j in ppm on a wet 
basis.
    Hj=Net heat of combustion of sample component j, at 25  
deg.C and 760 mm Hg, kcal/g-mole.

    (1) Method 18 shall be used to determine the concentration of each 
individual organic component (Cj) in the gas stream. Method 1 
or 1A, as appropriate, shall be used to determine the sampling site to 
the inlet of the flare. Using this same sample, ASTM D1946-77 
(incorporated by reference--see Sec. 60.17) shall be used to determine 
the hydrogen and carbon monoxide content.
    (2) The sampling time for each run shall be 1 hour in which either 
an integrated sample or four grab samples shall be taken. If grab 
sampling is used, then the samples shall be taken at 15 minute 
intervals.
    (3) Published or calculated values shall be used for the net heats 
of combustion of the sample components. If values are not published or 
cannot be calculated, ASTM D2382-76 (incorporated by reference--see 
Sec. 60.17) may be used to determine the net heat of combustion of 
component ``j.''
    (g) The owner or operator shall determine compliance with the exit 
velocity provisions in Sec. 60.18 as referenced by Sec. 60.562-
1(a)(1)(i)(C) as follows:
    (1) If applicable, the net heating value (HT) of the 
process vent shall be determined according to the procedures in 
paragraph (f) of this section to determine the applicable velocity 
requirements.
    (2) If applicable, the maximum permitted velocity (Vmax) 
for steam-assisted and nonassisted flares shall be computed using the 
following equation:

    Log10(Vmax)=(HT+28.8)/31.7
where:
    Vmax=Maximum permitted velocity, m/sec.
    28.8=Constant.
    31.7=Constant.
    HT=The net heating value as determined in paragraph (f) 
of this section.

    (3) The maximum permitted velocity, Vmax, for air-
assisted flares shall be determined by the following equation:

    Vmax=8.706+0.7084(HT)
where:
    Vmax=Maximum permitted velocity, m/sec.
    8.706=Constant.
    0.7084=Constant.
    HT=The net heating value as determined in paragraph (f) 
of this section.

    (4) The actual exit velocity of a flare shall be determined by 
dividing the volumetric flow rate (in units of standard temperature and 
pressure), as determined by Method 2, 2A, 2C, or 2D as appropriate, by 
the unobstructed (free) cross sectional area of the flare tip.
    (h) The owner or operator shall determine compliance with the mass 
emission per mass product standards in Secs. 60.560(d) and (e) and in 
Secs. 60.562-1(b)(1)(i), (c)(1)(i)(A), (c)(1)(ii)(A), (c)(2)(i), and 
(c)(2)(ii)(A).
    The emission rate of TOC shall be computed using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR09MR99.004


Where:
ERTOC = Emission rate of total organic compounds (minus 
methane and ethane), kg TOC/Mg product.
ETOC = Emission rate of total organic compounds (minus 
methane and ethane) in the sample, kg/hr.
Pp = The rate of polymer produced, kg/hr.
Mg/1000 kg = Mg of polymer produced per kg of polymer produced.

    (1) The mass rate of TOC, ETOC, shall be determined 
according to the procedures, as appropriate, in paragraph (c)(2) of this 
section. The sampling site for determining compliance with Secs. 60.560 
(d) and (e) shall be before any add-on control devices and after all 
product recovery devices. Otherwise, the sampling site shall be at the 
outlet of the control device.
    (2) The rate of polymer produced, Pp (kg/hr), shall be 
determined by dividing the weight of polymer pulled in kilograms (kg) 
from the process line during the performance test by the number of hours 
(hr) taken to perform the performance test. The polymer pulled, in 
kilograms, shall be determined by direct measurement or, subject to 
prior approval by the Administrator, computed from materials balance by 
good engineering practice.
    (i) The owner or operator shall determine continuous compliance with 
the

[[Page 429]]

temperature requirements in Secs. 60.562-1(b)(1)(ii) and 60.562-
1(c)(1)(i)(B) by using the temperature monitoring equipment described in 
Sec. 60.563(a)(1). An average temperature shall be determined from 
measurements taken at least every 15 minutes every three hours while the 
vent stream is normally routed and constituted. Each three-hour period 
constitutes a performance test.
    (j) For purposes of determining compliance with Sec. 60.562-1(c) 
(1)(ii)(B), (1)(ii)(C), (2)(ii)(B), or (2)(ii)(C), the ethylene glycol 
concentration in either the cooling tower or the liquid effluent from 
steam-jet ejectors used to produce a vacuum in the polymerization 
reactors, whichever is applicable, shall be determined:
    (1) Using procedures that conform to the methods described in ASTM 
D2908-74, ``Standard Practice for Measuring Volatile Organic Matter in 
Water by Aqueous-Injection Gas Chromatography'' (incorporated by 
reference--see Sec. 60.17), except as provided in paragraph (j)(2) of 
this section:
    (i) At least one sample per operating day shall be collected using 
the grab sampling procedures of ASTM D3370-76, ``Standard Practices for 
Sampling Water'' (incorporated by reference--see Sec. 60.17). An average 
ethylene glycol concentration by weight shall be calculated on a daily 
basis over a rolling 14-day period of operating days, except as provided 
in paragraphs (j)(1) (ii) and (iii) of this section. Each daily average 
ethylene glycol concentration so calculated constitutes a performance 
test. Exceedance of the standard during the reduced testing program 
specified in paragraphs (j)(1) (ii) and (iii) of this section is a 
violation of these standards.
    (ii) For those determining compliance with Sec. 60.562-1(c) 
(1)(ii)(B) or (2)(ii)(B), the owner or operator may elect to reduce the 
sampling program to any 14 consecutive day period once every two 
calendar months, if at least seventeen consecutive 14-day rolling 
average concentrations immediately preceding the reduced sampling 
program are each less than 0.10 weight percent ethylene glycol. If the 
average concentration obtained over the 14 day sampling during the 
reduced testing period exceeds the upper 95 percent confidence interval 
calculated from the most recent test results in which no one 14-day 
average exceeded 0.10 weight percent ethylene glycol, then the owner or 
operator shall reinstitute a daily sampling program. A reduced sampling 
program can be reinstituted if the requirements specified in this 
paragraph are met.
    (iii) For those determining compliance with Sec. 60.562-
1(c)(1)(ii)(C) or (c)(2)(ii)(C), the owner or operator may elect to 
reduce the sampling program to any 14 consecutive day period once every 
two calendar months, if at least seventeen consecutive 14-day rolling 
average concentrations immediately preceding the reduced sampling 
program are each less than 1.8 weight percent ethylene glycol. If the 
average concentration obtained over the 14 day sampling during the 
reduced test period exceeds the upper 95 percent confidence interval 
calculated from the most recent test results in which no one 14-day 
average exceeded 1.8 weight percent ethylene glycol, then the owner or 
operator shall reinstitute a daily sampling program. A reduced program 
can be reinstituted if the requirements specified in this paragraph are 
met.
    (iv) The upper 95 percent confidence interval shall be calculated 
using the equation:
[GRAPHIC] [TIFF OMITTED] TN30AU93.030

where:

Xi=daily ethylene glycol concentration for each day used to 
          calculate each 14-day rolling average used in test results to 
          justify implementing the reduced testing program.
n=number of ethylene glycol concentrations.

    (2) Measuring an alternative parameter, such as carbon oxygen demand 
or biological oxygen demand, that is demonstrated to be directly 
proportional to the ethylene glycol concentration. Such parameter shall 
be measured during the initial 14-day performance test during which the 
facility is shown to be in compliance with the ethylene glycol 
concentration standard whereby

[[Page 430]]

the ethylene glycol concentration is determined using the procedures 
described in paragraph (j)(1) of this section. The alternative parameter 
shall be measured on a daily basis and the average value of the 
alternative parameter shall be calculated on a daily basis over a 
rolling 14-day period of operating days. Each daily average value of the 
alternative parameter constitutes a performance test.

[55 FR 51035, Dec. 11, 1990; 56 FR 9178, Mar. 5, 1991, as amended at 56 
FR 12299, Mar. 22, 1991; 64 FR 11541, Mar. 9, 1999]



Sec. 60.565  Reporting and recordkeeping requirements.

    (a) Each owner or operator subject to the provisions of this subpart 
shall keep an up-to-date, readily-accessible record of the following 
information measured during each performance test, and shall include the 
following information in the report of the initial performance test in 
addition to the written results of such performance tests as required 
under Sec. 60.8. Where a control device is used to comply with 
Sec. 60.562-1(a)(1)(i)(D) only, a report containing performance test 
data need not be submitted, but a report containing the information in 
Sec. 60.565(a)(11) is required. Where a boiler or process heater with a 
design heat input capacity of 150 million Btu/hour or greater is used to 
comply with Sec. 60.562-1(a), a report containing performance test data 
need not be submitted, but a report containing the information in 
Sec. 60.565(a)(2)(i) is required. The same information specified in this 
section shall be submitted in the reports of all subsequently required 
performance tests where either the emission control efficiency of a 
combustion device or the outlet concentration of TOC (minus methane and 
ethane) is determined.
    (1) When an incinerator is used to demonstrate compliance with 
Sec. 60.562-1, except Sec. 60.562-1(a)(2):
    (i) The average firebox temperature of the incinerator (or the 
average temperature upstream and downstream of the catalyst bed), 
measured at least every 15 minutes and averaged over the performance 
test period, and
    (ii) The percent reduction of TOC (minus methane and ethane) 
achieved by the incinerator, the concentration of TOC (minus methane and 
ethane) (ppmv, by compound) at the outlet of the control device on a dry 
basis, or the emission rate in terms of kilograms TOC (minus methane and 
ethane) per megagram of product at the outlet of the control device, 
whichever is appropriate. If supplemental combustion air is used, the 
TOC concentration corrected to 3 percent oxygen shall be recorded and 
reported.
    (2) When a boiler or process heater is used to demonstrate 
compliance with Sec. 60.562-1, except Sec. 60.562-1(a)(2):
    (i) A description of the location at which the vent stream is 
introduced into the boiler or process heater, and
    (ii) For boiler or process heaters with a design heat input capacity 
of less than 150 million Btu/hr, all 3-hour periods of operation during 
which the average combustion temperature was more than 28  deg.C (50 
deg.F) below the average combustion temperature during the most recent 
performance test at which compliance was determined.
    (3) When a flare is used to demonstrate compliance with Sec. 60.562-
1, except Sec. 60.562-1(a)(2):
    (i) All visible emission readings, heat content determinations, flow 
rate measurements, and exit velocity determinations made during the 
performance test,
    (ii) Continuous records of the pilot flame heat-sensing monitoring, 
and
    (iii) Records of all periods of operations during which the pilot 
flame is absent.
    (4) When an incinerator, boiler, or process heater is used to 
demonstrate compliance with Sec. 60.562-1(a)(2), a description of the 
location at which the vent stream is introduced into the incinerator, 
boiler, or process heater.
    (5) When a flare is used to demonstrate compliance with Sec. 60.562-
1(a)(2):
    (i) All visible emission readings made during the performance test,
    (ii) Continuous records of the pilot flame heat-sensing monitoring, 
and
    (iii) Records of all periods of operation during which the pilot 
flame is absent.
    (6) When an absorber is the final unit in a system to demonstrate 
compliance with Sec. 60.562-1, except Sec. 60.562-1(a)(2),

[[Page 431]]

the specific gravity (or alternative parameter that is a measure of the 
degree of absorbing liquid saturation, if approved by the 
Administrator), and average temperature, measured at least every 15 
minutes and averaged over the performance test period, of the absorbing 
liquid (both measured while the vent stream is normally routed and 
constituted).
    (7) When a condenser is the final unit in a system to demonstrate 
compliance with Sec. 60.562-1, except Sec. 60.562-1(a)(2), the average 
exit (product side) temperature, measured at least every 15 minutes and 
averaged over the performance test period while the vent stream is 
normally routed and constituted.
    (8) Daily measurement and daily average 14-day rolling average of 
the ethylene glycol concentration in the liquid effluent exiting the 
vacuum system servicing the polymerization reaction section, if an owner 
or operator is subject to Sec. 60.562-1(c) (1)(ii)(B) or (2)(ii)(B), or 
of the ethylene glycol concentration in the cooling water in the cooling 
tower, if subject to Sec. 60.562-1(c) (2)(ii)(C) or (2)(iii)(C).
    (9) When a carbon adsorber is the final unit in a system to 
demonstrate compliance with Sec. 60.562-1, except Sec. 60.562-1(a)(2): 
the concentration level or reading indicated by the organics monitoring 
device at the outlet of the adsorber, measured at least every 15 minutes 
and averaged over the performance test period while the vent stream is 
normally routed and constituted.
    (10) When an owner or operator seeks to comply with the requirements 
of this subpart by complying with the uncontrolled threshold emission 
rate cutoff provision in Secs. 60.560 (d) and (e) or with the individual 
stream exemptions in Sec. 60.560(g), each process operation variable 
(e.g., pressure, temperature, type of catalyst) that may result in an 
increase in the uncontrolled emission rate, if Sec. 60.560(d) or (e) is 
applicable, or in an increase in the uncontrolled annual emissions or 
the VOC weight percent, as appropriate, if Sec. 60.560(g) is applicable, 
should such operating variable be changed.
    (11) When an owner or operator uses a control device to comply with 
Sec. 60.562-1(a)(1)(i)(D) alone: all periods when the control device is 
not operating.
    (b)(1) Each owner or operator subject to the provisions of this 
subpart shall submit with the initial performance test or, if complying 
with Sec. 60.562-1(a)(1)(i)(D), as a separate report, an engineering 
report describing in detail the vent system used to vent each affected 
vent stream to a control device. This report shall include all valves 
and vent pipes that could vent the stream to the atmosphere, thereby 
bypassing the control device, and identify which valves are car-sealed 
opened and which valves are car-sealed closed.
    (2) If a vent system containing valves that could divert the 
emission stream away from the control device is used, each owner or 
operator subject to the provisions of this subpart shall keep for at 
least two years up-to-date, readily accessible continuous records of:
    (i) All periods when flow is indicated if flow indicators are 
installed under Sec. 69.563(d)(1).
    (ii) All times when maintenance is performed on car-sealed valves, 
when the car seal is broken, and when the valve position is changed 
(i.e., from open to closed for valves in the vent piping to the control 
device and from closed to open for valves that vent the stream directly 
or indirectly to the atmosphere bypassing the control device).
    (c) Where an incinerator is used to comply with Sec. 60.562-1, 
except Secs. 60.562(a)(1)(i)(D) and (a)(2), each owner or operator 
subject to the provisions of this subpart shall keep for at least 2 
years up-to-date, readily accessible continuous records of:
    (1) The temperature measurements specified under Sec. 60.563(b)(1).
    (2) Records of periods of operation during which the parameter 
boundaries established during the most recent performance test are 
exceeded. Periods of operation during which the parameter boundaries 
established during the most recent performance test are exceeded are 
defined as follows:
    (i) For noncatalytic incinerators, all 3-hour periods of operation 
during which the average combustion temperature was more than 28  deg.C 
(50  deg.F)

[[Page 432]]

below the average combustion temperature during the most recent 
performance test at which compliance was demonstrated.
    (ii) For catalytic incinerators, all 3-hour periods of operation 
during which the average temperature of the vent stream immediately 
before the catalyst bed is more than 28  deg.C (50  deg.F) below the 
average temperature of the vent stream during the most recent 
performance test at which compliance was demonstrated. The owner or 
operator also shall record all 3-hour periods of operation during which 
the average temperature difference across the catalyst bed is less than 
80 percent of the average temperature difference across the catalyst bed 
during the most recent performance test at which compliance was 
demonstrated.
    (d) Where a boiler or process heater is used to comply with 
Sec. 60.562-1, except Secs. 60.562-1 (a)(1)(i)(D) and (a)(2), each owner 
or operator subject to the provisions of this subpart shall keep for at 
least 2 years up-to-date, readily accessible continuous records of:
    (1) Where a boiler or process heater with a heat input design 
capacity of 150 million Btu/hr or greater is used, all periods of 
operation of the boiler or process heater. (Examples of such records 
could include records of steam use, fuel use, or monitoring data 
collected pursuant to other State or Federal regulatory requirements), 
and
    (2) Where a boiler or process heater with a heat input design 
capacity of less than 150 million Btu/hr is used, all periods of 
operation during which the parameter boundaries established during the 
most recent performance test are exceeded. Periods of operation during 
which the parameter boundaries established during the most recent 
performance test are exceeded are defined as all 3-hour periods of 
operation during which the average combustion temperature was more than 
28  deg.C (50  deg.F) below the average combustion temperature during 
the most recent performance test at which compliance was demonstrated.
    (e) Where a flare is used to comply with Sec. 60.562-1, except 
Sec. 60.562-1(a)(1)(i)(D), each owner or operator subject to the 
provisions of this subpart shall keep for at least 2 years up-to-date, 
readily accessible continuous records of:
    (1) The flare or pilot light flame heat sensing monitoring specified 
under Sec. 60.563(b)(2), and
    (2) All periods of operation in which the flare or pilot flame, as 
appropriate, is absent.
    (f) Where an adsorber, condenser, absorber, or a control device 
other than a flare, incinerator, boiler, or process heater is used to 
comply with Sec. 60.562-1, except Sec. 60.562-1(a)(1)(i)(D), each owner 
or operator subject to the provisions of this subpart shall keep for at 
least 2 years up-to-date, readily-accessible continuous records of the 
periods of operation during which the parameter boundaries established 
during the most recent performance test are exceeded. Where an owner or 
operator seeks to comply with Sec. 60.562-1, periods of operation during 
which the parameter boundaries established during the most recent 
performance tests are exceeded are defined as follows:
    (1) Where an absorber is the final unit in a system:
    (i) All 3-hour periods of operation during which the average 
absorbing liquid temperature was more than 11  deg.C (20  deg.F) above 
the average absorbing liquid temperature during the most recent 
performance test at which compliance was demonstrated are exceeded, and
    (ii) All 3-hour periods of operation during which the average 
absorbing liquid specific gravity was more than 0.1 unit above, or more 
than 0.1 unit below, the average absorbing liquid specific gravity 
during the most recent performance test at which compliance was 
demonstrated (unless monitoring of an alternative parameter that is a 
measure of the degree of absorbing liquid saturation is approved by the 
Administrator, in which case he or she will define appropriate parameter 
boundaries and periods of operation during which they are exceeded).
    (2) Where a condenser is the final unit in a system, all 3-hour 
periods of operation during which the average condenser operating 
temperature was more than 6  deg.C (10  deg.F) above the average 
operating temperature during the most recent performance test at which 
compliance was demonstrated.

[[Page 433]]

    (3) Where a carbon adsorber is the final unit in a system, all 3-
hour periods of operation during which the average organic concentration 
level in the carbon adsorber gases is more than 20 percent greater than 
the exhaust gas concentration level or reading measured by the organics 
monitoring system during the most recent performance test at which 
compliance was demonstrated.
    (g) Each owner or operator of an affected facility subject to the 
provisions of this subpart and seeking to demonstrate compliance with 
Sec. 60.562-1 shall keep up-to-date, readily accessible records of:
    (1) Any changes in production capacity, feedstock type, or catalyst 
type, or of any replacement, removal or addition of product recovery 
equipment; and
    (2) The results of any performance test performed pursuant to the 
procedures specified by Sec. 60.564.
    (h) Each owner or operator of an affected facility that seeks to 
comply with the requirements of this subpart by complying with the 
uncontrolled threshold emission rate cutoff provision in Secs. 60.560 
(d) and (e) or with the individual stream exemptions in Sec. 60.560(g) 
shall keep for at least 2 years up-to-date, readily accessible records 
of any change in process operation that increases the uncontrolled 
emission rate of the process line in which the affected facility is 
located, if Sec. 60.560 (d) or (e) is applicable, or that increases the 
uncontrolled annual emissions or the VOC weight percent of the 
individual stream, if Sec. 60.560(g) is applicable.
    (i) Each owner and operator subject to the provisions of this 
subpart is exempt from Sec. 60.7(c) of the General Provisions.
    (j) The Administrator will specify appropriate reporting and 
recordkeeping requirements where the owner or operator of an affected 
facility complies with the standards specified under Sec. 60.562-1 other 
than as provided under Sec. 60.565 (a) through (e).
    (k) Each owner or operator that seeks to comply with the 
requirements of this subpart by complying with the uncontrolled 
threshold emission rate cutoff provision of Secs. 60.560 (d) and (e), 
the individual stream exemptions of Sec. 60.560(g), or the requirements 
of Sec. 60.562-1 shall submit to the Administrator semiannual reports of 
the following recorded information, as applicable. The initial report 
shall be submitted within 6 months after the initial start-up date.
    (1) Exceedances of monitored parameters recorded under Secs. 60.565 
(c), (d)(2), and (f).
    (2) All periods recorded under Sec. 60.565(b) when the vent stream 
has been diverted from the control device.
    (3) All periods recorded under Sec. 60.565(d) when the boiler or 
process heater was not operating.
    (4) All periods recorded under Sec. 60.565(e) in which the flare or 
pilot flame was absent.
    (5) All periods recorded under Sec. 60.565(a)(8) when the 14-day 
rolling average exceeded the standard specified in Sec. 60.562-1(c) 
(1)(ii)(B), (1)(ii)(C), (2)(ii)(B), or (2)(ii)(C), as applicable.
    (6) Any change in process operations that increases the uncontrolled 
emission rate of the process line in which the affected facility is 
located, as recorded in Sec. 60.565(h).
    (7) Any change in process operations that increases the uncontrolled 
annual emissions or the VOC weight percent of the individual stream, as 
recorded in Sec. 60.565(h).
    (l) Each owner or operator subject to the provisions of this subpart 
shall notify the Administrator of the specific provisions of 
Sec. 60.562, Sec. 60.560(d), or Sec. 60.560(e), as applicable, with 
which the owner or operator has elected to comply. Notification shall be 
submitted with the notification of initial startup required by 
Sec. 60.7(a)(3). If an owner or operator elects at a later date to use 
an alternative provision of Sec. 60.562 with which he or she will comply 
or becomes subject to Sec. 60.562 for the first time (i.e., the owner or 
operator can no longer meet the requirements of this subpart by 
complying with the uncontrolled threshold emission rate cutoff provision 
in Sec. 60.560 (d) or (e)), then the owner or operator shall notify the 
Administrator 90 days before implementing a change and, upon 
implementing a change, a performance test shall be performed as 
specified in Sec. 60.564.

[[Page 434]]

    (m) The requirements of this subsection remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves alternative reporting requirements or means 
of compliance surveillance adopted by such State. In that event, 
affected sources within the State will be relieved of the obligation to 
comply with this subsection, provided that they comply with the 
requirements established by the State.

[55 FR 51035, Dec. 11, 1990; 56 FR 9178, Mar. 5, 1991, as amended at 56 
FR 12299, Mar. 22, 1991]



Sec. 60.566  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authority contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authority which will not be delegated to States: Sec. 60.562-
2(c).

Subpart EEE  [Reserved]



 Subpart FFF--Standards of Performance for Flexible Vinyl and Urethane 
                          Coating and Printing

    Source: 49 FR 26892, June 29, 1984, unless otherwise noted.



Sec. 60.580  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each rotogravure printing line used to print or coat flexible 
vinyl or urethane products.
    (b) This subpart applies to any affected facility which begins 
construction, modification, or reconstruction after January 18, 1983.
    (c) For facilities controlled by a solvent recovery emission control 
device, the provisions of Sec. 60.584(a) requiring monitoring of 
operations will not apply until EPA has promulgated performance 
specifications under appendix B for the continuous monitoring system. 
After the promulgation of performance specifications, these provisions 
will apply to each affected facility under paragraph (b) of this 
section. Facilities controlled by a solvent recovery emission control 
device that become subject to the standard prior to promulgation of 
performance specifications must conduct performance tests in accordance 
with Sec. 60.13(b) after performance specifications are promulgated.



Sec. 60.581  Definitions and symbols.

    (a) All terms used in this subpart, not defined below, are given the 
same meaning as in the Act or in subpart A of this part.
    Emission control device means any solvent recovery or solvent 
destruction device used to control volatile organic compounds (VOC) 
emissions from flexible vinyl and urethane rotogravure printing lines.
    Emission control system means the combination of an emission control 
device and a vapor capture system for the purpose of reducing VOC 
emissions from flexible vinyl and urethane rotogravure printing lines.
    Flexible vinyl and urethane products mean those products, except for 
resilient floor coverings (1977 Standard Industry Code 3996) and 
flexible packaging, that are more than 50 micrometers (0.002 inches) 
thick, and that consist of or contain a vinyl or urethane sheet or a 
vinyl or urethane coated web.
    Gravure cylinder means a plated cylinder with a printing image 
consisting of minute cells or indentations, specifically engraved or 
etched into the cylinder's surface to hold ink when continuously 
revolved through a fountain of ink.
    Ink means any mixture of ink, coating solids, organic solvents 
including dilution solvent, and water that is applied to the web of 
flexible vinyl or urethane on a rotogravure printing line.
    Ink solids means the solids content of an ink as determined by 
Reference Method 24, ink manufacturer's formulation data, or plant 
blending records.
    Inventory system means a method of physically accounting for the 
quantity of ink, solvent, and solids used at one or more affected 
facilities during a time period. The system is based on plant purchase 
or inventory records.

[[Page 435]]

    Plant blending records means those records which document the weight 
fraction of organic solvents and solids used in the formulation or 
preparation of inks at the vinyl or urethane printing plant where they 
are used.
    Rotogravure print station means any device designed to print or coat 
inks on one side of a continuous web or substrate using the intaglio 
printing process with a gravure cylinder.
    Rotogravure printing line means any number of rotogravure print 
stations and associated dryers capable of printing or coating 
simultaneously on the same continuous vinyl or urethane web or 
substrate, which is fed from a continuous roll.
    Vapor capture system means any device or combination of devices 
designed to contain, collect, and route organic solvent vapors emitted 
from the flexible vinyl or urethane rotogravure printing line.
    (b) All symbols used in this subpart not defined below are given the 
same meaning as in the Act or in subpart A of this part.

a=the gas stream vents exiting the emission control device.
b=the gas stream vents entering the emission control device.
f=the gas stream vents which are not directed to an emission control 
          device.
Caj=the concentration of VOC in each gas stream (j) for the 
          time period exiting the emission control device, in parts per 
          million by volume.
Cbi=the concentration of VOC in each gas stream (i) for the 
          time period entering the emission control device, in parts per 
          million by volume.
Cfk=the concentration of VOC in each gas stream (k) for the 
          time period which is not directed to an emission control 
          device, in parts per million by volume.
G=the weighted average mass of VOC per mass of ink solids applied, in 
          kilograms per kilogram.
Mci=the total mass of each ink (i) applied in the time period 
          as determined from plant records, in kilograms.
Mdj=the total mass of each dilution solvent (j) added at the 
          print line in the time period determined from plant records, 
          in kilograms.
Qaj=the volumetric flow rate of each effluent gas stream (j) 
          exiting the emission control device, in standard cubic meters 
          per hour.
Qbi=the volumetric flow rate of each effluent gas stream (i) 
          entering the emission control device, in standard cubic meters 
          per hour.
Qfk=the volumetric flow rate of each effluent gas stream (k) 
          not directed to an emission control device, in standard cubic 
          meters per hour.
E=the VOC emission reduction efficiency (as a fraction) of the emission 
          control device during performance testing.
F=the VOC emission capture efficiency (as a fraction) of the vapor 
          capture system during performance testing.
Woi=the weight fraction of VOC in each ink (i) used in the 
          time period as determined from Reference Method 24, 
          manufacturer's formulation data, or plant blending records, in 
          kilograms per kilogram.
Wsi''means the weight fraction of solids in each ink (i) used 
          in the time period as determined from Reference Method 24, 
          manufacturer's formulation data, or plant blending records, in 
          kilograms per kilogram.
Woj=the weight fraction of VOC in each dilution solvent (j) 
          added at the print line in the time period determined from 
          Reference Method 24, manufacturer's formulation data, or plant 
          blending records, in kilograms per kilogram.

[49 FR 26892, June 29, 1984; 49 FR 32848, Aug. 17, 1984]



Sec. 60.582  Standard for volatile organic compounds.

    (a) On and after the date on which the performance test required by 
Sec. 60.8 has been completed, each owner or operator subject to this 
subpart shall either:
    (1) Use inks with a weighted average VOC content less than 1.0 
kilogram VOC per kilogram ink solids at each affected facility, or
    (2) Reduce VOC emissions to the atmosphere by 85 percent from each 
affected facility.
    (b) [Reserved]



Sec. 60.583  Test methods and procedures.

    (a) Reference Methods in appendix A of this part, except as provided 
under Sec. 60.8(b), shall be used to determine compliance with 
Sec. 60.582(a) as follows:
    (1) Method 24 for analysis of inks. If nonphotochemically reactive 
solvents are used in the inks, standard gas chromatographic techniques 
may be used to identify and quantify these solvents. The results of 
Reference Method 24 may be adjusted to subtract these solvents from the 
measured VOC content.

[[Page 436]]

    (2) Method 25A for VOC concentration (the calibration gas shall be 
propane);
    (3) Method 1 for sample and velocity traverses;
    (4) Method 2 for velocity and volumetric flow rates;
    (5) Method 3 for gas analysis;
    (6) Method 4 for stack gas moisture.
    (b) To demonstrate compliance with Sec. 60.582(a)(1), the owner or 
operator of an affected facility shall determine the weighted average 
VOC content of the inks according to the following procedures:
    (1) Determine and record the VOC content and amount of each ink used 
at the print head, including the VOC content and amount of diluent 
solvent, for any time periods when VOC emission control equipment is not 
used.
    (2) Compute the weighted average VOC content by the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.050

    (3) The weighted average VOC content of the inks shall be calculated 
over a period that does not exceed one calendar month, or four 
consecutive weeks. A facility that uses an accounting system based on 
quarters consisting of two 28 calendar day periods and one 35 calendar 
day period may use an averaging period of 35 calendar days four times 
per year, provided the use of such an accounting system is documented in 
the initial performance test.
    (4) Each determination of the weighted average VOC content shall 
constitute a performance test for any period when VOC emission control 
equipment is not used. Results of the initial performance test must be 
reported to the Administrator. Reference Method 24 or ink manufacturers' 
formulation data along with plant blending records (if plant blending is 
done) may be used to determine VOC content. The Administrator may 
require the use of Reference Method 24 if there is a question concerning 
the accuracy of the ink manufacturer's data or plant blending records.
    (5) If, during the time periods when emission control equipment is 
not used, all inks used contain less than 1.0 kilogram VOC per kilogram 
ink solids, the owner or operator is not required to calculate the 
weighted average VOC content, but must verify and record the VOC content 
of each ink (including any added dilution solvent) used as determined by 
Reference Method 24, ink manufacturers' formulation data, or plant 
blending records.
    (c) To demonstrate compliance with Sec. 60.582(a)(1), the owner or 
operator may determine the weighted average VOC content using an 
inventory system.
    (1) The inventory system shall accurately account to the nearest 
kilogram for the VOC content of all inks and dilution solvent used, 
recycled, and discarded for each affected facility during the averaging 
period. Separate records must be kept for each affected facility.
    (2) To determine VOC content of inks and dilution solvent used or 
recycled, Reference Method 24 or ink manufacturers' formulation data 
must be used in combination with plant blending records (if plant 
blending is done) or inventory records or purchase records for new inks 
or dilution solvent.
    (3) For inks to be discarded, only Reference Method 24 shall be used 
to determine the VOC content. Inks to be discarded may be combined prior 
to measurement of volume or weight and testing by Reference Method 24.
    (4) The Administrator may require the use of Reference Method 24 if 
there is a question concerning the accuracy of the ink manufacturer's 
data or plant records.
    (5) The Administrator shall approve the inventory system of 
accounting for

[[Page 437]]

VOC content prior to the initial performance test.
    (d) To demonstrate compliance with Sec. 60.582(a)(2), the owner or 
operator of an affected facility controlled by a solvent recovery 
emission control device or an incineration control device shall conduct 
a performance test to determine overall VOC emission control efficiency 
according to the following procedures:
    (1) The performance test shall consist of three runs. Each test run 
must last a minimum of 30 minutes and shall continue until the printing 
operation is interrupted or until 180 minutes of continuous operation 
occurs. During each test run, the print line shall be printing 
continuously and operating normally. The VOC emission reduction 
efficiency achieved for each test run is averaged over the entire test 
run period.
    (2) VOC concentration values at each site shall be measured 
simultaneously.
    (3) The volumetric flow rate shall be determined from one Method 2 
measurement for each test run conducted immediately prior to, during, or 
after that test run. Volumetric flow rates at each site do not need to 
be measured simultaneously.
    (4) In order to determine capture efficiency from an affected 
facility, all fugitive VOC emissions from the affected facility shall be 
captured and vented through stacks suitable for measurement. During a 
performance test, the owner or operator of an affected facility located 
in an area with other sources of VOC shall isolate the affected facility 
from other sources of VOC. These two requirements shall be accomplished 
using one of the following methods:
    (i) Build a permanent enclosure around the affected facility;
    (ii) Build a temporary enclosure around the affected facility and 
duplicate, to an extent that is reasonably feasible, the ventilation 
conditions that are in effect when the affected facility is not enclosed 
(one way to do this is to divide the room exhaust rate by the volume of 
the room and then duplicate that quotient or 20 air changes per hour, 
whichever is smaller, in the temporary enclosure); or
    (iii) Shut down all other sources of VOC and continue to exhaust 
fugitive emissions from the affected facility through any building 
ventilation system and other room exhausts such as print line ovens and 
embossers.
    (5) For each affected facility, compliance with Sec. 60.582(a)(2) 
has been demonstrated if the average value of the overall control 
efficiency (EF) for the three runs is equal to or greater than 85 
percent. An overall control efficiency is calculated for each run as 
follows:
    (i) For efficiency of the emission control device,
    [GRAPHIC] [TIFF OMITTED] TC01JN92.051
    
    (ii) For efficiency of the vapor capture system,
    [GRAPHIC] [TIFF OMITTED] TC01JN92.052
    

[49 FR 26892, June 29, 1984; 49 FR 32848, Aug. 17, 1984]



Sec. 60.584  Monitoring of operations and recordkeeping requirements.

    (a) The owner or operator of an affected facility controlled by a 
solvent recovery emission control device shall install, calibrate, 
operate, and maintain a monitoring system which continuously measures 
and records the VOC concentration of the exhaust vent stream from the 
control device and shall comply with the following requirements:
    (1) The continuous monitoring system shall be installed in a 
location that is representative of the VOC concentration in the exhaust 
vent, at least two equivalent stack diameters from the exhaust point, 
and protected from interferences due to wind, weather, or other 
processes.
    (2) During the performance test, the owner or operator shall 
determine and record the average exhaust vent VOC

[[Page 438]]

concentration in parts per million by volume. After the performance 
test, the owner or operator shall determine and, in addition to the 
record made by the continuous monitoring device, record the average 
exhaust vent VOC concentration for each 3-hour clock period of printing 
operation when the average concentration is greater than 50 ppm and more 
than 20 percent greater than the average concentration value 
demonstrated during the most recent performance test.
    (b) The owner or operator of an affected facility controlled by a 
thermal incineration emission control device shall install, calibrate, 
operate, and maintain a monitoring device that continuously measures and 
records the temperature of the control device exhaust gases and shall 
comply with the following requirements:
    (1) The continuous monitoring device shall be calibrated annually 
and have an accuracy of 0.75 percent of the temperature 
being measured or 2.5 deg.C, whichever is greater.
    (2) During the performance test, the owner or operator shall 
determine and record the average temperature of the control device 
exhaust gases. After the performance test, the owner or operator shall 
determine and record, in addition to the record made by the continuous 
monitoring device, the average temperature for each 3-hour clock period 
of printing operation when the average temperature of the exhaust gases 
is more than 28 deg.C below the average temperature demonstrated during 
the most recent performance test.
    (c) The owner or operator of an affected facility controlled by a 
catalytic incineration emission control device shall install, calibrate, 
operate, and maintain monitoring devices that continuously measure and 
record the gas temperatures both upstream and downstream of the catalyst 
bed and shall comply with the following requirements:
    (1) Each continuous monitoring device shall be calibrated annually 
and have an accuracy of 0.75 percent of the temperature 
being measured or 2.5 deg.C, whichever is greater.
    (2) During the performance test, the owner or operator shall 
determine and record the average gas temperature both upstream and 
downstream of the catalyst bed. After the performance test, the owner or 
operator shall determine and record, in addition to the record made by 
the continuous monitoring device, the average temperatures for each 3-
hour clock period of printing operation when the average temperature of 
the gas stream before the catalyst bed is more than 28 deg.C below the 
average temperature demonstrated during the most recent performance test 
or the average temperature difference across the catalyst bed is less 
than 80 percent of the average temperature difference of the device 
during the most recent performance test.
    (d) The owner or operator of an affected facility shall record time 
periods of operation when an emission control device is not in use.



Sec. 60.585  Reporting requirements.

    (a) For all affected facilities subject to compliance with 
Sec. 60.582, the performance test data and results from the performance 
test shall be submitted to the Administrator as specified in 
Sec. 60.8(a).
    (b) The owner or operator of each affected facility shall submit 
semiannual reports to the Administrator of occurrences of the following:
    (1) Exceedances of the weighted average VOC content specified in 
Sec. 60.582(a)(1);
    (2) Exceedances of the average value of the exhaust vent VOC 
concentration as defined under Sec. 60.584(a)(2);
    (3) Drops in the incinerator temperature as defined under 
Sec. 60.584(b)(2); and
    (4) Drops in the average temperature of the gas stream immediately 
before the catalyst bed or drops in the average temperature across the 
catalyst bed as defined under Sec. 60.584(c)(2).
    (c) The reports required under paragraph (b) shall be postmarked 
within 30 days following the end of the second and fourth calendar 
quarters.
    (d) The requirements of this subsection remain in force until and 
unless the Agency, in delegating enforcement authority to a State under 
section 111(c) of the Act, approves reporting requirements or an 
alternative means of compliance surveillance adopted by such States. In 
that event,

[[Page 439]]

affected sources within the State will be relieved of the obligation to 
comply with this subsection, provided that they comply with requirements 
established by the State.



  Subpart GGG--Standards of Performance for Equipment Leaks of VOC in 
                          Petroleum Refineries

    Source: 49 FR 22606, May 30, 1984, unless otherwise noted.



Sec. 60.590  Applicability and designation of affected facility.

    (a)(1) The provisions of this subpart apply to affected facilities 
in petroleum refineries.
    (2) A compressor is an affected facility.
    (3) The group of all the equipment (defined in Sec. 60.591) within a 
process unit is an affected facility.
    (b) Any affected facility under paragraph (a) of this section that 
commences construction or modification after January 4, 1983, is subject 
to the requirements of this subpart.
    (c) Addition or replacement of equipment (defined in Sec. 60.591) 
for the purpose of process improvement which is accomplished without a 
capital expenditure shall not by itself be considered a modification 
under this subpart.
    (d) Facilities subject to subpart VV or subpart KKK of 40 CFR part 
60 are excluded from this subpart.



Sec. 60.591  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the act, in subpart A of part 60, or in subpart VV 
of part 60, and the following terms shall have the specific meanings 
given them.
    Alaskan North Slope means the approximately 69,000 square mile area 
extending from the Brooks Range to the Arctic Ocean.
    Equipment means each valve, pump, pressure relief device, sampling 
connection system, open-ended valve or line, and flange or other 
connector in VOC service. For the purposes of recordkeeping and 
reporting only, compressors are considered equipment.
    In hydrogen service means that a compressor contains a process fluid 
that meets the conditions specified in Sec. 60.593(b).
    In light liquid service means that the piece of equipment contains a 
liquid that meets the conditions specified in Sec. 60.593(c).
    Petroleum means the crude oil removed from the earth and the oils 
derived from tar sands, shale, and coal.
    Petroleum refinery means any facility engaged in producing gasoline, 
kerosene, distillate fuel oils, residual fuel oils, lubricants, or other 
products through the distillation of petroleum, or through the 
redistillation, cracking, or reforming of unfinished petroleum 
derivatives.
    Process unit means components assembled to produce intermediate or 
final products from petroleum, unfinished petroleum derivatives, or 
other intermediates; a process unit can operate independently if 
supplied with sufficient feed or raw materials and sufficient storage 
facilities for the product.



Sec. 60.592  Standards.

    (a) Each owner or operator subject to the provisions of this subpart 
shall comply with the requirements of Secs. 60.482-1 to 60.482-10 as 
soon as practicable, but no later than 180 days after initial startup.
    (b) An owner or operator may elect to comply with the requirements 
of Secs. 60.483-1 and 60.483-2.
    (c) An owner or operator may apply to the Administrator for a 
determination of equivalency for any means of emission limitation that 
achieves a reduction in emissions of VOC at least equivalent to the 
reduction in emissions of VOC achieved by the controls required in this 
subpart. In doing so, the owner or operator shall comply with 
requirements of Sec. 60.484.
    (d) Each owner or operator subject to the provisions of this subpart 
shall comply with the provisions of Sec. 60.485 except as provided in 
Sec. 60.593.
    (e) Each owner or operator subject to the provisions of this subpart 
shall comply with the provisions of Secs. 60.486 and 60.487.

[[Page 440]]



Sec. 60.593  Exceptions.

    (a) Each owner or operator subject to the provisions of this subpart 
may comply with the following exceptions to the provisions of subpart 
VV.
    (b)(1) Compressors in hydrogen service are exempt from the 
requirements of Sec. 60.592 if an owner or operator demonstrates that a 
compressor is in hydrogen service.
    (2) Each compressor is presumed not be be in hydrogen service unless 
an owner or operator demonstrates that the piece of equipment is in 
hydrogen service. For a piece of equipment to be considered in hydrogen 
service, it must be determined that the percent hydrogen content can be 
reasonably expected always to exceed 50 percent by volume. For purposes 
of determining the percent hydrogen content in the process fluid that is 
contained in or contacts a compressor, procedures that conform to the 
general method described in ASTM E-260, E-168, or E-169 (incorporated by 
reference as specified in Sec. 60.17) shall be used.
    (3)(i) An owner or operator may use engineering judgment rather than 
procedures in paragraph (b)(2) of this section to demonstrate that the 
percent content exceeds 50 percent by volume, provided the engineering 
judgment demonstrates that the content clearly exceeds 50 percent by 
volume. When an owner or operator and the Administrator do not agree on 
whether a piece of equipment is in hydrogen service, however, the 
procedures in paragraph (b)(2) shall be used to resolve the 
disagreement.
    (ii) If an owner or operator determines that a piece of equipment is 
in hydrogen service, the determination can be revised only after 
following the procedures in paragraph (b)(2).
    (c) Any existing reciprocating compressor that becomes an affected 
facility under provisions of Sec. 60.14 or Sec. 60.15 is exempt from 
Sec. 60.482 (a), (b), (c), (d), (e), and (h) provided the owner or 
operator demonstrates that recasting the distance piece or replacing the 
compressor are the only options available to bring the compressor into 
compliance with the provisions of Sec. 60.482 (a), (b), (c), (d), (e), 
and (h).
    (d) An owner or operator may use the following provision in addition 
to Sec. 60.485(e): Equipment is in light liquid service if the percent 
evaporated is greater than 10 percent at 150 deg.C as determined by ASTM 
Method D-86 (incorporated by reference as specified in Sec. 60.18).
    (e) Pumps in light liquid service and valves in gas/vapor and light 
liquid service within a procesic compounds of usually high molecular 
weight that consist of many repeated links, each link being a relatively 
light and simple molecule.



  Subpart HHH--Standards of Performance for Synthetic Fiber Production 
                               Facilities

    Source: 49 FR 13651, Apr. 5, 1984, unless otherwise noted.



Sec. 60.600  Applicability and designation of affected facility.

    (a) Except as provided in paragraph (b) of this section, the 
affected facility to which the provisions of this subpart apply is each 
solvent-spun synthetic fiber process that produces more than 500 
megagrams of fiber per year.
    (b) The provisions of this subpart do not apply to any facility that 
uses the reaction spinning process to produce spandex fiber or the 
viscose process to produce rayon fiber.
    (c) The provisions of this subpart apply to each facility as 
identified in paragraph (a) of this section and that commences 
construction or reconstruction after November 23, 1982. The provisions 
of this subpart do not apply to facilities that commence modification 
but not reconstruction after November 23, 1982.



Sec. 60.601  Definitions.

    All terms that are used in this subpart and are not defined below 
are given the same meaning as in the Act and in subpart A of this part.
    Acrylic fiber means a manufactured synthetic fiber in which the 
fiber-forming substance is any long-chain synthetic polymer composed of 
at least 85 percent by weight of acrylonitrile units.
    Makeup solvent means the solvent introduced into the affected 
facility that compensates for solvent lost from the

[[Page 441]]

affected facility during the manufacturing process.
    Nongaseous losses means the solvent that is not volatilized during 
fiber production, and that escapes the process and is unavailable for 
recovery, or is in a form or concentration unsuitable for economical 
recovery.
    Polymer means any of the natural or synthetic compounds of usually 
high molecular weight that consist of many repeated links, each link 
being a relatively light and simple molecule.
    Precipitation bath means the water, solvent, or other chemical bath 
into which the polymer or prepolymer (partially reacted material) 
solution is extruded, and that causes physical or chemical changes to 
occur in the extruded solution to result in a semihardened polymeric 
fiber.
    Rayon fiber means a manufactured fiber composed of regenerated 
cellulose, as well as manufactured fibers composed of regenerated 
cellulose in which substituents have replaced not more than 15 percent 
of the hydrogens of the hydroxyl groups.
    Reaction spinning process means the fiber-forming process where a 
prepolymer is extruded into a fluid medium and solidification takes 
place by chemical reaction to form the final polymeric material.
    Recovered solvent means the solvent captured from liquid and gaseous 
process streams that is concentrated in a control device and that may be 
purified for reuse.
    Solvent feed means the solvent introduced into the spinning solution 
preparation system or precipitation bath. This feed stream includes the 
combination of recovered solvent and makeup solvent.
    Solvent inventory variation means the normal changes in the total 
amount of solvent contained in the affected facility.
    Solvent recovery system means the equipment associated with capture, 
transportation, collection, concentration, and purification of organic 
solvents. It may include enclosures, hoods, ducting, piping, scrubbers, 
condensers, carbon adsorbers, distillation equipment, and associated 
storage vessels.
    Solvent-spun synthetic fiber means any synthetic fiber produced by a 
process that uses an organic solvent in the spinning solution, the 
precipitation bath, or processing of the sun fiber.
    Solvent-spun synthetic fiber process means the total of all 
equipment having a common spinning solution preparation system or a 
common solvent recovery system, and that is used in the manufacture of 
solvent-spun synthetic fiber. It includes spinning solution preparation, 
spinning, fiber processing and solvent recovery, but does not include 
the polymer production equipment.
    Spandex fiber means a manufactured fiber in which the fiber-forming 
substance is a long chain synthetic polymer comprised of at least 85 
percent of a segmented polyurethane.
    Spinning solution means the mixture of polymer, prepolymer, or 
copolymer and additives dissolved in solvent. The solution is prepared 
at a viscosity and solvent-to-polymer ratio that is suitable for 
extrusion into fibers.
    Spinning solution preparation system means the equipment used to 
prepare spinning solutions; the system includes equipment for mixing, 
filtering, blending, and storage of the spinning solutions.
    Synthetic fiber means any fiber composed partially or entirely of 
materials made by chemical synthesis, or made partially or entirely from 
chemically-modified naturally-occurring materials.
    Viscose process means the fiber forming process where cellulose and 
concentrated caustic soda are reacted to form soda or alkali cellulose. 
This reacts with carbon disulfide to form sodium cellulose xanthate, 
which is then dissolved in a solution of caustic soda. After ripening, 
the solution is spun into an acid coagulating bath. This precipitates 
the cellulose in the form of a regenerated cellulose filament.

[49 FR 13651, Apr. 5, 1984; 49 FR 18096, Apr. 27, 1984]



Sec. 60.602  Standard for volatile organic compounds.

    (a) On and after the date on which the initial performance test 
required to be conducted by Sec. 60.8 is completed, no

[[Page 442]]

owner or operator subject to the provisions of this subpart shall cause 
the discharge into the atmosphere from any affected facility that 
produces acrylic fibers, VOC emissions that exceed 10 kilograms (kg) VOC 
per megagram (Mg) solvent feed to the spinning solution preparation 
system or precipitation bath. VOC emissions from affected facilities 
that produce both acrylic and nonacrylic fiber types shall not exceed 10 
kg VOC per Mg solvent feed. VOC emissions from affected facilities that 
produce only nonacrylic fiber types shall not exceed 17 kg VOC per Mg 
solvent feed. Compliance with the emission limitations is determined on 
a 6-month rolling average basis as described in Sec. 60.603.



Sec. 60.603  Performance test and compliance provisions.

    (a) Section 60.8(f) does not apply to the performance test 
procedures required by this subpart.
    (b) Each owner or operator of an affected facility shall determine 
compliance with the applicable standard in Sec. 60.602(a) by determining 
and recording monthly the VOC emissions per Mg solvent feed from each 
affected facility for the current and preceding 5 consecutive calendar 
months and using these values to calculate the 6-month average 
emissions. Each calculation is considered a performance test. The owner 
or operator of an affected facility shall use the following procedure to 
determine VOC emissions for each calendar month;
    (1) Install, calibrate, maintain, and operate monitoring devices 
that continuously measure and permanently record for each calendar month 
the amount of makeup solvent and solvent feed. These values shall be 
used in calculating VOC emissions according to paragraph (b)(2) of this 
section. All monitoring devices, meters, and peripheral equipment shall 
be calibrated and any error recorded. Total compounded error of the flow 
measuring and recording devices shall not exceed 1 percent accuracy over 
the operating range. As an alternative to measuring solvent feed, the 
owner or operator may:
    (i) Measure the amount of recovered solvent returned to the solvent 
feed storage tanks, and use the following equation to determine the 
amount of solvent feed:

Solvent Feed=Makeup Solvent+Recovered
Solvent+Change in the Amount of Solvent
Contained in the Solvent Feed Holding Tank.
    (ii) Measure and record the amount of polymer introduced into the 
affected facility and the solvent-to-polymer ratio of the spinning 
solutions, and use the following equation to determine the amount of 
solvent feed:
[GRAPHIC] [TIFF OMITTED] TC16NO91.083


where subscript ``i'' denotes each particular spinning solution used 
during the test period; values of ``i'' vary from one to the total 
number of spinning solutions, ``n,'' used during the calendar month.
    (2) VOC emissions shall be determined each calendar month by use of 
the following equations:
[GRAPHIC] [TIFF OMITTED] TC16NO91.084


where all values are for the calendar month only and where

E=Emissions in kg per Mg solvent feed;
Sv=Measured or calculated volume of solvent feed in liters;
SW=Weight of solvent feed in Mg;
MV=Measured volume of makeup solvent in liters;
MW=Weight of makeup in kg;
N=Allowance for nongaseous losses per Mg solvent feed; (13 kg/Mg);
Sp=Fraction of measured volume that is actual solvent 
          (excludes water);
D=Density of the solvent in kg/liter;
I=Allowance for solvent inventory variation or changes in the amount of 
          solvent contained in the affected facility per Mg solvent feed 
          (may be positive or negative);
IS=Amount in kg of solvent contained in the affected facility 
          at the beginning of test period, as determined by owner or 
          operator;
IE=Amount in kg of solvent contained in the affected facility 
          at the close of test period, as determined by owner or 
          operator.


[[Page 443]]


    (i) N, as used in the equation in paragraph (b)(2) of this section, 
equals 13 kg per Mg solvent feed to the spinning solution preparation 
system and precipitation bath. This value shall be used in all cases 
unless an owner or operator demonstrates to the satisfaction of the 
Administrator that greater nongaseous losses occur at the affected 
facility. In this case, the greater value may be substituted in the 
equation.

[49 FR 13651, Apr. 5, 1984; 49 FR 18096, Apr. 27, 1984]



Sec. 60.604  Reporting requirements.

    (a) The owner or operator of an affected facility shall submit a 
written report to the Administrator of the following:
    (1) The results of the initial performance test; and
    (2) The results of subsequent performance tests that indicate that 
VOC emissions exceed the standards in Sec. 60.602. These reports shall 
be submitted quarterly at 3-month intervals after the initial 
performance test. If no exceedances occur during a particular quarter, a 
report stating this shall be submitted to the Administrator 
semiannually.
    (b) Solvent-spun synthetic fiber producing facilities exempted from 
these standards in Sec. 60.600(a) (those producing less than 500 
megagrams annually) shall report to the Administrator within 30 days 
whenever extruded fiber for the preceding 12 calendar months exceeds 500 
megagrams.
    (c) The requirements of this section remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternate means 
of compliance surveillance adopted by such State. In that event, 
affected sources within the State will be relieved of the obligation to 
comply with this section, provided that they comply with the 
requirements established by the State.

[49 FR 13651, Apr. 5, 1984, as amended at 55 FR 51384, Dec. 13, 1990; 59 
FR 32341, June 23, 1994]



  Subpart III--Standards of Performance for Volatile Organic Compound 
   (VOC) Emissions From the Synthetic Organic Chemical Manufacturing 
              Industry (SOCMI) Air Oxidation Unit Processes

    Source: 55 FR 26922, June 29, 1990, unless otherwise noted.



Sec. 60.610  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to each affected facility 
designated in paragraph (b) of this section that produces any of the 
chemicals listed in Sec. 60.617 as a product, co-product, by-product, or 
intermediate, except as provided in paragraph (c) of this section.
    (b) The affected facility is any of the following for which 
construction, modification, or reconstruction commenced after October 
21, 1983:
    (1) Each air oxidation reactor not discharging its vent stream into 
a recovery system.
    (2) Each combination of an air oxidation reactor and the recovery 
system into which its vent stream is discharged.
    (3) Each combination of two or more air oxidation reactors and the 
common recovery system into which their vent streams are discharged.
    (c) Each affected facility that has a total resource effectiveness 
(TRE) index value greater than 4.0 is exempt from all provisions of this 
subpart except for Secs. 60.612, 60.614(f), 60.615(h), and 60.615(l).
    Note: The intent of these standards is to minimize the emissions of 
VOC through the application of BDT. The numerical emission limits in 
these standards are expressed in terms of total organic compounds (TOC), 
measured as TOC minus methane and ethane. This emission limit reflects 
the performance of BDT.



Sec. 60.611  Definitions.

    As used in this subpart, all terms not defined here shall have the 
meaning given them in the Act and in subpart A of part 60, and the 
following terms

[[Page 444]]

shall have the specific meanings given them.
    Air Oxidation Reactor means any device or process vessel in which 
one or more organic reactants are combined with air, or a combination of 
air and oxygen, to produce one or more organic compounds. Ammoxidation 
and oxychlorination reactions are included in this definition.
    Air Oxidation Reactor Recovery Train means an individual recovery 
system receiving the vent stream from at least one air oxidation 
reactor, along with all air oxidation reactors feeding vent streams into 
this system.
    Air Oxidation Unit Process means a unit process, including 
ammoxidation and oxychlorination unit process, that uses air, or a 
combination of air and oxygen, as an oxygen source in combination with 
one or more organic reactants to produce one or more organic compounds.
    Boilers means any enclosed combustion device that extracts useful 
energy in the form of steam.
    By Compound means by individual stream components, not carbon 
equivalents.
    Continuous recorder means a data recording device recording an 
instantaneous data value at least once every 15 minutes.
    Flame zone means the portion of the combustion chamber in a boiler 
occupied by the flame envelope.
    Flow indicator means a device which indicates whether gas flow is 
present in a vent stream.
    Halogenated Vent Stream means any vent stream determined to have a 
total concentration (by volume) of compounds containing halogens of 20 
ppmv (by compound) or greater.
    Incinerator means any enclosed combustion device that is used for 
destroying organic compounds and does not extract energy in the form of 
steam or process heat.
    Process Heater means a device that transfers heat liberated by 
burning fuel to fluids contained in tubes, including all fluids except 
water that is heated to produce steam.
    Process Unit means equipment assembled and connected by pipes or 
ducts to produce, as intermediates or final products, one or more of the 
chemicals in Sec. 60.617. A process unit can operate independently if 
supplied with sufficient fuel or raw materials and sufficient product 
storage facilities.
    Product means any compound or chemical listed in Sec. 60.617 that is 
produced for sale as a final product as that chemical or is produced for 
use in a process that needs that chemical for the production of other 
chemicals in another facility. By-products, co-products, and 
intermediates are considered to be products.
    Recovery Device means an individual unit of equipment, such as an 
absorber, condenser, and carbon adsorber, capable of and used to recover 
chemicals for use, reuse or sale.
    Recovery System means an individual recovery device or series of 
such devices applied to the same process stream.
    Total organic compounds (TOC) means those compounds measured 
according to the procedures in Sec. 60.614(b)(4). For the purposes of 
measuring molar composition as required in Sec. 60.614(d)(2)(i), hourly 
emissions rate as required in Sec. 60.614(d)(5) and Sec. 60.614(e) and 
TOC concentration as required in Sec. 60.615(b)(4) and 
Sec. 60.615(g)(4), those compounds which the Administrator has 
determined do not contribute appreciably to the formation of ozone are 
to be excluded. The compounds to be excluded are identified in 
Environmental Protection Agency's statements on ozone abatement policy 
for SIP revisions (42 FR 35314; 44 FR 32042; 45 FR 32424; 45 FR 48942).
    Total resource effectiveness (TRE) Index Value means a measure of 
the supplemental total resource requirement per unit reduction of TOC 
associated with an individual air oxidation vent stream, based on vent 
stream flow rate, emission rate of TOC, net heating value, and corrosion 
properties (whether or not the vent stream is halogenated), as 
quantified by the equation given under Sec. 60.614(e).
    Vent Stream means any gas stream, containing nitrogen which was 
introduced as air to the air oxidation reactor, released to the 
atmosphere directly from any air oxidation reactor

[[Page 445]]

recovery train or indirectly, after diversion through other process 
equipment. The vent stream excludes equipment leaks and relief valve 
discharges including, but not limited to, pumps, compressors, and 
valves.

[55 FR 26922, June 29, 1990; 55 FR 36932, Sept. 7, 1990]



Sec. 60.612  Standards.

    Each owner or operator of any affected facility shall comply with 
paragraph (a), (b), or (c) of this section for each vent stream on and 
after the date on which the initial performance test required by 
Secs. 60.8 and 60.614 is completed, but not later than 60 days after 
achieving the maximum production rate at which the affected facility 
will be operated, or 180 days after the initial start-up, whichever date 
comes first. Each owner or operator shall either:
    (a) Reduce emissions of TOC (minus methane and ethane) by 98 weight-
percent, or to a TOC (minus methane and ethane) concentration of 20 ppmv 
on a dry basis corrected to 3 percent oxygen, whichever is less 
stringent. If a boiler or process heater is used to comply with this 
paragraph, then the vent stream shall be introduced into the flame zone 
of the boiler or process heater; or
    (b) Combust the emissions in a flare that meets the requirements of 
Sec. 60.18; or
    (c) Maintain a TRE index value greater than 1.0 without use of VOC 
emission control devices.



Sec. 60.613  Monitoring of emissions and operations.

    (a) The owner or operator of an affected facility that uses an 
incinerator to seek to comply with the TOC emission limit specified 
under Sec. 60.612(a) shall install, calibrate, maintain, and operate 
according to manufacturer's specifications the following equipment:
    (1) A temperature monitoring device equipped with a continuous 
recorder and having an accuracy of 1 percent of the 
temperature being monitored expressed in degrees Celsius or 
0.5  deg.C, whichever is greater.
    (i) Where an incinerator other than a catalytic incinerator is used, 
a temperature monitoring device shall be installed in the firebox.
    (ii) Where a catalytic incinerator is used, temperature monitoring 
devices shall be installed in the gas stream immediately before and 
after the catalyst bed.
    (2) A flow indicator that provides a record of vent stream flow to 
the incinerator at least once every hour for each affected facility. The 
flow indicator shall be installed in the vent stream from each affected 
facility at a point closest to the inlet of each incinerator and before 
being joined with any other vent stream.
    (b) The owner or operator of an affected facility that uses a flare 
to seek to comply with Sec. 60.612(b) shall install, calibrate, 
maintain, and operate according to manufacturer's specifications the 
following equipment:
    (1) A heat sensing device, such as an ultra-violet sensor or 
thermocouple, at the pilot light to indicate the continuous presence of 
a flame.
    (2) A flow indicator that provides a record of vent stream flow to 
the flare at least once every hour for each affected facility. The flow 
indicator shall be installed in the vent stream from each affected 
facility at a point closest to the flare and before being joined with 
any other vent stream.
    (c) The owner or operator of an affected facility that uses a boiler 
or process heater to seek to comply with Sec. 60.612(a) shall install, 
calibrate, maintain and operate according to the manufacturer's 
specifications in the following equipment:
    (1) A flow indicator that provides a record of vent stream flow to 
the boiler or process heater at least once every hour for each affected 
facility. The flow indicator shall be installed in the vent stream from 
each air oxidation reactor within an affected facility at a point 
closest to the inlet of each boiler or process heater and before being 
joined with any other vent stream.
    (2) A temperature monitoring device in the firebox equipped with a 
continuous recorder and having an accuracy of 1 percent of 
the temperature being measured expressed in degrees Celsius or 
0.5  deg.C, whichever is greater, for boilers or process 
heaters of less than

[[Page 446]]

44 MW (150 million Btu/hr) heat input design capacity.
    (3) Monitor and record the periods of operation of the boiler or 
process heater if the design input capacity of the boiler is 44 MW (150 
million Btu/hr) or greater. The records must be readily available for 
inspection.
    (d) The owner or operator of an affected facility that seeks to 
demonstrate compliance with the TRE index value limit specified under 
Sec. 60.612(c) shall install, calibrate, maintain, and operate according 
to manufacturer's specifications the following equipment, unless 
alternative monitoring procedures or requirements are approved for that 
facility by the Administrator:
    (1) Where an absorber is the final recovery device in a recovery 
system:
    (i) A scrubbing liquid temperature monitoring device having an 
accuracy of 1 percent of the temperature being monitored 
expressed in degrees Celsius or 0.5  deg.C, whichever is greater, and a 
specific gravity monitoring device having an accuracy of 0.02 specific 
gravity units, each equipped with a continuous recorder;
    (ii) An organic monitoring device used to indicate the concentration 
level of organic compounds exiting the recovery device based on a 
detection principle such as infra-red, photoionization, or thermal 
conductivity, each equipped with a continuous recorder.
    (2) Where a condenser is the final recovery device in a recovery 
system:
    (i) A condenser exit (product side) temperature monitoring device 
equipped with a continuous recorder and having an acuracy of 
1 percent of the temperature being monitored expressed in 
degrees Celsius or 0.5  deg.C, whichever is greater;
    (ii) An organic monitoring device used to indicate the concentration 
level of organic compounds exiting the recovery device based on a 
detection principle such as infra-red, photoionization, or thermal 
conductivity, each equipped with a continuous recorder.
    (3) Where a carbon adsorber is the final recovery device in a 
recovery system:
    (i) An integrating steam flow monitoring device having an accuracy 
of 10 percent, and a carbon bed temperature monitoring device having an 
accuracy of 1 percent of the temperature being monitored 
expressed in degrees Celsius or 0.5  deg.C, whichever is 
greater, both equipped with a continuous recorder;
    (ii) An organic monitoring device used to indicate the concentration 
level of organic compounds exiting the recovery device based on a 
detection principle such as infra-red, photoionization, or thermal 
conductivity, each equipped with a continuous recorder.
    (e) An owner or operator of an affected facility seeking to 
demonstrate compliance with the standards specified under Sec. 60.612 
with control devices other than an incinerator, boiler, process heater, 
or flare; or recovery devices other than an absorber, condenser, or 
carbon adsorber shall provide to the Administrator information 
describing the operation of the control device or recovery device and 
the process parameter(s) which would indicate proper operation and 
maintenance of the device. The Administrator may request further 
information and will specify appropriate monitoring procedures or 
requirements.



Sec. 60.614  Test methods and procedures.

    (a) For the purpose of demonstrating compliance with Sec. 60.612, 
all affected facilities shall be run at full operating conditions and 
flow rates during any performance test.
    (b) The following methods in appendix A to this part, except as 
provided under Sec. 60.8(b) shall be used as reference methods to 
determine compliance with the emission limit or percent reduction 
efficiency specified under Sec. 60.612(a).
    (1) Method 1 or 1A, as appropriate, for selection of the sampling 
sites. The control device inlet sampling site for determination of vent 
stream molar composition or TOC (less methane and ethane) reduction 
efficiency shall be prior to the inlet of the control device and after 
the recovery system.
    (2) Method 2, 2A, 2C, or 2D, as appropriate, for determination of 
the volumetric flow rates.
    (3) The emission rate correction factor, integrated sampling and 
analysis procedure of Method 3 shall be used to determine the oxygen 
concentration (%O2d) for the purposes of determining 
compliance with the 20 ppmv limit.

[[Page 447]]

The sampling site shall be the same as that of the TOC samples and the 
samples shall be taken during the same time that the TOC samples are 
taken. The TOC concentration corrected to 3 percent O2 
(Cc) shall be computed using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.085

where:

Cc=Concentration of TOC corrected to 3 percent 02, 
          dry basis, ppm by volume.
CTOC=Concentration of TOC (minus methane and ethane), dry 
          basis, ppm by volume.
%O2d=Concentration of O2, dry basis, percent by 
          volume.

    (4) Method 18 to determine concentration of TOC in the control 
device outlet and the concentration of TOC in the inlet when the 
reduction efficiency of the control device is to be determined.
    (i) The sampling time for each run shall be 1 hour in which either 
an integrated sample or four grab samples shall be taken. If grab 
sampling is used then the samples shall be taken at 15-minute intervals.
    (ii) The emission reduction (R) of TOC (minus methane and ethane) 
shall be determined using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.086

where:

R=Emission reduction, percent by weight.
Ei=Mass rate of TOC entering the control device, kg TOC/hr.
Eo=Mass rate of TOC discharged to the atmosphere, kg TOC/hr.

    (iii) The mass rates of TOC (Ei, Eo) shall be 
computed using the following equations:
[GRAPHIC] [TIFF OMITTED] TC16NO91.087

Where:
Cij, Coj=Concentration of sample component ``j'' 
          of the gas stream at the inlet and outlet of the control 
          device, respectively, dry basis ppm by volume.
Mij, Moj=Molecular weight of sample component 
          ``j`` of the gas stream at the inlet and outlet of the control 
          device, respectively, g/g-mole (lb/lb-mole).
Qi, Qo=Flow rate of gas stream at the inlet and 
          outlet of the control device, respectively, dscm/min (dscf/
          hr).
K2=Constant, 2.494 x 10-6 (1/ppm) (g-mole/scm) 
          (kg/g) (min/hr), where standard temperature for (g-mole/scm) 
          is 20  deg.C.

    (iv) The TOC concentration (CTOC) is the sum of the 
individual components and shall be computed for each run using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.088

where:

CTOC=Concentration of TOC (minus methane and ethane), dry 
          basis, ppm by volume.
Cj=Concentration of sample components in the sample.
n=Number of components in the sample.

    (5) When a boiler or process heater with a design heat input 
capacity of 44 MW (150 million Btu/hour) or greater is used to seek to 
comply with Sec. 60.612(a), the requirement for an initial performance 
test is waived, in accordance with Sec. 60.8(b). However, the 
Administrator reserves the option to require testing at such other times 
as may be required, as provided for in section 114 of the Act.
    (c) When a flare is used to seek to comply with Sec. 60.612(b), the 
flare shall comply with the requirements of Sec. 60.18.
    (d) The following test methods in appendix A to this part, except as 
provided under Sec. 60.8(b), shall be used for determining the net 
heating value of the gas combusted to determine compliance under 
Sec. 60.612(b) and for determining the process vent stream TRE index 
value to determine compliance under Sec. 60.612(c).
    (1)(i) Method 1 or 1A, as appropriate, for selection of the sampling 
site. The sampling site for the vent stream flow rate and molar 
composition determination prescribed in Sec. 60.614(d) (2) and (3) shall 
be, except for the situations outlined in paragraph (d)(1)(ii) of this 
section, prior to the inlet of any control device, prior to any post-
reactor dilution of the stream with air, and prior

[[Page 448]]

to any post-reactor introduction of halogenated compounds into the vent 
stream. No transverse site selection method is needed for vents smaller 
than 4 inches in diameter.
    (ii) If any gas stream other than the air oxidation vent stream from 
the affected facility is normally conducted through the final recovery 
device.
    (A) The sampling site for vent stream flow rate and molar 
composition shall be prior to the final recovery device and prior to the 
point at which the nonair oxidation stream is introduced.
    (B) The efficiency of the final recovery device is determined by 
measuring the TOC concentration using Method 18 at the inlet to the 
final recovery device after the introduction of any nonair oxidation 
vent stream and at the outlet of the final recovery device.
    (C) This efficiency is applied to the TOC concentration measured 
prior to the final recovery device and prior to the introduction of the 
nonair oxidation stream to determine the concentration of TOC in the air 
oxidation stream from the final recovery device. This concentration of 
TOC is then used to perform the calculations outlined in Sec. 60.614(d) 
(4) and (5).
    (2) The molar composition of the process vent stream shall be 
determined as follows:
    (i) Method 18 to measure the concentration of TOC including those 
containing halogens.
    (ii) ASTM D1946-77 (incorporation by reference as specified in 
Sec. 60.17 of this part) to measure the concentration of carbon monoxide 
and hydrogen.
    (iii) Method 4 to measure the content of water vapor.
    (3) The volumetric flow rate shall be determined using Method 2, 2A, 
2C, or 2D, as appropriate.
    (4) The net heating value of the vent stream shall be calculated 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.089

where:
HT=Net heating value of the sample, MJ/scm, where the net 
          enthalpy per mole of offgas is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to one mole is 20  deg.C, 
          as in the definition of Qs (offgas flow rate).
K1=Constant, 1.740  x  10-7
[GRAPHIC] [TIFF OMITTED] TC16NO91.090

    where standard temperature for
[GRAPHIC] [TIFF OMITTED] TC16NO91.091

    is 20  deg.C.
Cj=Concentration of compound j in ppm, as measured for 
          organics by Method 18 and measured for hydrogen and carbon 
          monoxide by ASTM D1946-77 (incorporated by reference as 
          specified in Sec. 60.17 of this part) as indicated in 
          Sec. 60.614(d)(2).
Hj=Net heat of combustion j, kcal/g-mole, based on combustion 
          at 25  deg.C and 760 mm Hg. The heats of combustion of vent 
          stream components would be required to be determined using 
          ASTM D2382-76 (incorporation by reference as specified in 
          Sec. 60.17 of this part) if published values are not available 
          or cannot be calculated.

    (5) The emission rate of TOC in the process vent stream shall be 
calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.092

where:

ETOC=Emission rate of TOC in the sample, kg/hr
K2=Constant, 2.494  x  10-6 (1/ppm) (g-mole/scm) 
          (kg/g) (min/hr), where standard temperature for (g-mole/scm) 
          is 20  deg.C
Cj=Concentration on a basis of compound j in ppm as measured 
          by Method 18 as indicated in Sec. 60.614(d)(2)
Mj=Molecular weight of sample j, g/g-mole
Qs=Vent stream flow rate (scm/min) at a standard temperature 
          of 20  deg.C

    (6) The total process vent stream concentration (by volume) of 
compounds containing halogens (ppmv, by compound) shall be summed from 
the individual concentrations of compounds containing halogens which 
were measured by Method 18.
    (e) For purposes of complying with Sec. 60.612(c), the owner or 
operator of a facility affected by this subpart shall calculate the TRE 
index value of the vent stream using the equation for incineration in 
paragraph (e)(1) of this section for halogenated vent streams. The owner 
or operator of an affected

[[Page 449]]

facility with a nonhalogenated vent stream shall determine the TRE index 
value by calculating values using both the incinerator equation in 
paragraph (e)(1) of this section and the flare equation in paragraph 
(e)(2) of this section and selecting the lower of the two values.
    (1) The TRE index value of the vent stream controlled by an 
incinerator shall be calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.093

    (i) where for a vent stream flow rate (scm/min) at a standard 
temperature of 20  deg.C that is greater than or equal to 14.2 scm/min:

TRE=TRE index value.
Qs=Vent stream flow rate (scm/min), at a standard temperature 
          of 20  deg.C.
HT=Vent stream net heating value (MJ/scm), where the net 
          enthalpy of combustion per mole of vent stream is based on 
          combustion at 25  deg.C and 760 mm Hg, but the standard 
          temperature for determining the volume corresponding to one 
          mole is 20  deg.C, as in the definition of Qs.
Ys=Qs for all vent stream categories listed in 
          Table 1 except for Category E vent streams where 
          Ys=(Qs)(HT)/3.6.
ETOC=Hourly emissions of TOC reported in kg/hr.
a, b, c, d, e, and f are coefficients.

    The set of coefficients which apply to a vent stream shall be 
obtained from Table 1.

[[Page 450]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.053

    (ii) Where for a vent stream flow rate (scm/min) at a standard 
temperature of 20  deg.C that is less than 14.2 scm/min:

TRE=TRE index value.
Qs=14.2 scm/min.
HT=(FLOW)(HVAL)/14.2.
Where the following inputs are used:

FLOW=Vent stream flow rate (scm/min), at a standard temperature of 20 
          deg.C.

[[Page 451]]

HVAL=Vent stream net heating value (MJ/scm), where the net enthalpy per 
          mole of vent stream is based on combustion at 25  deg.C and 
          760 mm Hg, but the standard temperature for determining the 
          volume corresponding to 1 mole is 20  deg.C as in the 
          definition of Qs.
Ys=14.2 scm/min for all vent stream categories listed in 
          Table 1 except for Category E vent streams, where 
          Ys=(14.2)(HT)/3.6.
ETOC=Hourly emissions of TOC reported in kg/hr.
a, b, c, d, e, and f are coefficients.

    The set of coefficients that apply to a vent stream can be obtained 
from Table 1.
    (2) The equation for calculating the TRE index value of a vent 
stream controlled by a flare is as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.094

where:

TRE=TRE index value.
ETOC=Hourly emission rate of TOC reported in kg/hr.
Qs=Vent stream flow rate (scm/min) at a standard temperature 
          of 20  deg.C.
HT=Vent stream net heating value (MJ/scm) where the net 
          enthalpy per mole of offgas is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to 1 mole is 20  deg.C as 
          in the definition of Qs.
a, b, c, d, and e are coefficients.

    The set of coefficients that apply to a vent stream shall be 
obtained from Table 2.

          Table 2--Air Oxidation Processes NSPS TRE Coefficients for Vent Streams Controlled by a Flare
----------------------------------------------------------------------------------------------------------------
                                                    a             b             c            d            e
----------------------------------------------------------------------------------------------------------------
HT <11.2 MJ/scm..............................        2.25         0.288        -0.193       -0.0051         2.08
HT 11.2 MJ/scm...............................        0.309        0.0619       -0.0043      -0.0034         2.08
----------------------------------------------------------------------------------------------------------------

    (f) Each owner or operator of an affected facility seeking to comply 
with Sec. 60.610(c) or Sec. 60.612(c) shall recalculate the TRE index 
value for that affected facility whenever process changes are made. Some 
examples of process changes are changes in production capacity, 
feedstock type, or catalyst type, or whenever there is replacement, 
removal, or addition of recovery equipment. The TRE index value shall be 
recalculated based on test data, or on best engineering estimates of the 
effects of the change to the recovery system.
    (1) Where the recalculated TRE index value is less than or equal to 
1.0, the owner or operator shall notify the Administrator within 1 week 
of the recalculation and shall conduct a performance test according to 
the methods and procedures required by Sec. 60.614 to determine 
compliance with Sec. 60.612(a). Performance tests must be conducted as 
soon as possible after the process change but no later than 180 days 
from the time of the process change.
    (2) Where the initial TRE index value is greater than 4.0 and the 
recalculated TRE index value is less than or equal to 4.0, but greater 
than 1.0, the owner or operator shall conduct a performance test in 
accordance with Sec. 60.8 and Sec. 60.614 and shall comply with 
Secs. 60.613, 60.614, and 60.615. Performance tests must be conducted as 
soon as possible after the process change but no later than 180 days 
from the time of the process change.

[55 FR 26922, June 29, 1990; 55 FR 36932, Sept. 7, 1990]



Sec. 60.615  Reporting and recordkeeping requirements.

    (a) Each owner or operator subject to Sec. 60.612 shall notify the 
Administrator of the specific provisions of Sec. 60.612 (Sec. 60.612 (a) 
(b), or (c)) with which the

[[Page 452]]

owner or operator has elected to comply. Notification shall be submitted 
with the notification of initial start-up required by Sec. 60.7(a)(3). 
If an owner or operator elects at a later date to use an alternative 
provision of Sec. 60.612 with which he or she will comply, then the 
Administrator shall be notified by the owner or operator 90 days before 
implementing a change and, upon implementing the change, a performance 
test shall be performed as specified by Sec. 60.614 within 180 days.
    (b) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible records of the following data 
measured during each performance test, and also include the following 
data in the report of the initial performance test required under 
Sec. 60.8. Where a boiler or process heater with a design heat input 
capacity of 44 MW (150 million Btu/hour) or greater is used to comply 
with Sec. 60.612(a), a report containing performance test data need not 
be submitted, but a report containing the information of 
Sec. 60.615(b)(2)(i) is required. The same data specified in this 
section shall be submitted in the reports of all subsequently required 
performance tests where either the emission control efficiency of a 
control device, outlet concentration of TOC, or the TRE index value of a 
vent stream from a recovery system is determined.
    (1) Where an owner or operator subject to this subpart seeks to 
demonstrate compliance with Sec. 60.612(a) through use of either a 
thermal or catalytic incinerator:
    (i) The average firebox temperature of the incinerator (or the 
average temperature upstream and downstream of the catalyst bed for a 
catalytic incinerator), measured at least every 15 minutes and averaged 
over the same time period of the performance testing, and
    (ii) The percent reduction of TOC determined as specified in 
Sec. 60.614(b) achieved by the incinerator, or the concentration of TOC 
(ppmv, by compound) determined as specified in Sec. 60.614(b) at the 
outlet of the control device on a dry basis corrected to 3 percent 
oxygen.
    (2) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.612(a) through use 
of a boiler or process heater:
    (i) A description of the location at which the vent stream is 
introduced into the boiler or process heater, and
    (ii) The average combustion temperature of the boiler or process 
heater with a design heat input capacity of less than 44 MW (150 million 
Btu/hr) measured at least every 15 minutes and averaged over the same 
time period of the performance testing.
    (3) Where an owner or operator subject to the provisions of this 
subpart seeks to comply with Sec. 60.612(b) through the use of a 
smokeless flare, flare design (i.e., steam-assisted, air-assisted, or 
nonassisted), all visible emission readings, heat content 
determinations, flow rate measurements, and exit velocity determinations 
made during the performance test, continuous records of the flare pilot 
flame monitoring, and records of all periods of operations during which 
the pilot flame is absent.
    (4) Where an owner or operator seeks to demonstrate compliance with 
Sec. 60.612(c):
    (i) Where an absorber is the final recovery device in a recovery 
system, the exit specific gravity (or alternative parameter which is a 
measure of the degree of absorbing liquid saturation, if approved by the 
Administrator), and average exit temperature of the absorbing liquid, 
measured at least every 15 minutes and averaged over the same time 
period of the performance testing (both measured while the vent stream 
is normally routed and constituted), or
    (ii) Where a condenser is the final recovery device in a recovery 
system, the average exit (product side) temperature, measured at least 
every 15 minutes and average over the same time period of the 
performance testing while the vent stream is normally routed and 
constituted.
    (iii) Where a carbon adsorber is the final recovery device in a 
recovery system, the total steam mass flow measured at least every 15 
minutes and averaged over the same time period of the performance test 
(full carbon bed cycle), temperature of the carbon bed after 
regeneration (and within 15 minutes of completion of any cooling 
cycle(s), and duration of the carbon bed steaming cycle (all measured 
while the

[[Page 453]]

vent stream is normally routed and constituted), or
    (iv) As an alternative to Sec. 60.615(b)(4)(i), (ii) or (iii), the 
concentration level or reading indicated by the organic monitoring 
device at the outlet of the absorber, condenser, or carbon adsorber 
measured at least every 15 minutes and averaged over the same time 
period of the performance testing while the vent stream is normally 
routed and constituted.
    (v) All measurements and calculations performed to determine the TRE 
index value of the vent stream.
    (c) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
equipment operating parameters specified to be monitored under 
Sec. 60.613(a) and (c) as well as up-to-date, readily accessible records 
of periods of operation during which the parameter boundaries 
established during the most recent performance test are exceeded. The 
Administrator may at any time require a report of these data. Where a 
combustion device is used by an owner or operator seeking to demonstrate 
compliance with Sec. 60.612(a) or (c), periods of operation during which 
the parameter boundaries established during the most recent performance 
tests are exceeded are defined as follows:
    (1) For thermal incinerators, all 3-hour periods of operation during 
which the average combustion temperature was more than 28  deg.C (50 
deg.F) below the average combustion temperature during the most recent 
performance test at which compliance with Sec. 60.612(a) was determined.
    (2) For catalytic incinerators, all 3-hour periods of operation 
during which the average temperature of the vent stream immediately 
before the catalyst bed is more than 28  deg.C (50  deg.F) below the 
average temperature of the vent stream during the most recent 
performance test at which compliance with Sec. 60.612(a) was determined. 
The owner or operator also shall record all 3-hour periods of operation 
during which the average temperature difference across the catalyst bed 
is less than 80 percent of the average temperature difference of the 
device during the most recent performance test at which compliance with 
Sec. 60.612(a) was determined.
    (3) All 3-hour periods of operation during which the average 
combustion temperature was more than 28  deg.C (50  deg.F) below the 
average combustion temperature during the most recent performance test 
at which compliance with Sec. 60.612(a) was determined for boilers or 
process heaters with a design heat input capacity of less than 44 MW 
(150 million Btu/hr).
    (4) For boilers or process heaters, whenever there is a change in 
the location at which the vent stream is introduced into the flame zone 
as required under Sec. 60.612(a).
    (d) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the flow 
indication specified under Sec. 60.613(a)(2), Sec. 60.613(b)(2), and 
Sec. 60.613(c)(1), as well as up-to-date, readily accessible records of 
all periods when the vent stream is diverted from the control device or 
has no flow rate.
    (e) Each owner or operator subject to the provisions of this subpart 
who uses a boiler or process heater with a design heat input capacity of 
44 MW or greater to comply with Sec. 60.612(a) shall keep an up-to-date, 
readily accessible record of all periods of operation of the boiler or 
process heater. (Examples of such records could include records of steam 
use, fuel use, or monitoring data collected pursuant to other State or 
Federal regulatory requirements).
    (f) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
flare pilot flame monitoring specified in Sec. 60.613(b), as well as up-
to-date, readily accessible records of all periods of operations in 
which the pilot flame is absent.
    (g) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
equipment operating parameters specified to be monitored under 
Sec. 60.613(c) as well as up-to-date, readily accessible records of 
periods of operation during which the parameter boundaries established 
during the most recent performance test are exceeded. The Administrator 
may at any time require a report of these data.

[[Page 454]]

Where the owner or operator seeks to demonstrate compliance with 
Sec. 60.612(c), periods of operation during which the parameter 
boundaries established during the most recent performance tests are 
exceeded are defined as follows:
    (1) Where an absorber is the final recovery device in a recovery 
system, and where an organic monitoring device is not used:
    (i) All 3-hour periods of operation during which the average 
absorbing liquid temperature was more than 11  deg.C (20  deg.F) above 
the average absorbing liquid temperature during the most recent 
performance test, or
    (ii) All 3-hour periods of operation during which the average 
absorbing liquid specific gravity was more than 0.1 unit above, or more 
than 0.1 unit below, the average absorbing liquid specific gravity 
during the most recent performance test (unless monitoring of an 
alternative parameter, which is a measure of the degree of absorbing 
liquid saturation, is approved by the Administrator, in which case he or 
she will define appropriate parameter boundaries and periods of 
operation during which they are exceeded).
    (2) When a condenser is the final recovery device in a recovery 
system, and where an organic monitoring device is not used, all 3-hour 
periods of operation during which the average exit (product side) 
condenser operating temperature was more than 6  deg.C (11  deg.F) above 
the average exit (product side) operating temperature during the most 
recent performance test.
    (3) Where a carbon adsorber is the final recovery device in a 
recovery system and where an organic monitoring device is not used:
    (i) All carbon bed regeneration cycles during which the total mass 
steam flow was more than 10 percent below the total mass steam flow 
during the most recent performance test, or
    (ii) All carbon bed regeneration cycles during which the temperature 
of the carbon bed after regeneration (and after completion of any 
cooling cycle(s)) was more than 10 percent greater than the carbon bed 
temperature (in degrees Celsius) during the most recent performance 
test.
    (4) Where an absorber, condenser, or carbon adsorber is the final 
recovery device in the recovery system and an organic monitoring device 
approved by the Administrator is used, all 3-hour periods of operation 
during which the average concentration level or reading of organic 
compounds in the exhaust gases is more than 20 percent greater than the 
exhaust gas organic compound concentration level or reading measured by 
the monitoring device during the most recent performance test.
    (h) Each owner or operator subject to the provisions of this subpart 
and seeking to demonstrate compliance with Sec. 60.612(c) shall keep up-
to-date, readily accessible records of:
    (1) Any changes in production capacity, feedstock type, or catalyst 
type, or of any replacement, removal or addition of recovery equipment 
or air oxidation reactors;
    (2) Any recalculation of the TRE index value performed pursuant to 
Sec. 60.614(f);
    (3) The results of any performance test performed pursuant to the 
methods and procedures required by Sec. 60.614(d).
    (i) Each owner and operator subject to the provisions of this 
subpart is exempt from the quarterly reporting requirements contained in 
Sec. 60.7(c) of the General Provisions.
    (j) Each owner or operator that seeks to comply with the 
requirements of this subpart by complying with the requirements of 
Sec. 60.612 shall submit to the Administrator semiannual reports of the 
following information. The initial report shall be submitted within 6 
months after the initial start-up-date.
    (1) Exceedances of monitored parameters recorded under 
Sec. 60.615(c) and (g).
    (2) All periods recorded under Sec. 60.615(d) when the vent stream 
is diverted from the control device or has no flow rate.
    (3) All periods recorded under Sec. 60.615(e) when the boiler or 
process heater was not operating.
    (4) All periods recorded under Sec. 60.615(f) in which the pilot 
flame of the flare was absent.
    (5) Any recalculation of the TRE index value, as recorded under 
Sec. 60.615(h).

[[Page 455]]

    (k) The requirements of Sec. 60.615(j) remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternative 
means of compliance surveillance adopted by such State. In that event, 
affected sources within the State will be relieved of the obligation to 
comply with Sec. 60.615(j), provided that they comply with the 
requirements established by the State.
    (l) The Administrator will specify appropriate reporting and 
recordkeeping requirements where the owner or operator of an affected 
facility seeks to demonstrate compliance with the standards specified 
under Sec. 60.612 other than as provided under Sec. 60.613(a), (b), (c), 
and (d).

[55 FR 26922, June 29, 1990; 55 FR 36932, Sept. 7, 1990]



Sec. 60.616  Reconstruction.

    For purposes of this subpart ``fixed capital cost of the new 
components,'' as used in Sec. 60.15, includes the fixed capital cost of 
all depreciable components which are or will be replaced pursuant to all 
continuous programs of component replacement which are commenced within 
any 2-year period following October 21, 1983. For purposes of this 
paragraph, ``commenced'' means that an owner or operator has undertaken 
a continuous program of component replacement or that an owner or 
operator has entered into a contractual obligation to undertake and 
complete, within a reasonable time, a continuous program of component 
replacement.



Sec. 60.617  Chemicals affected by subpart III.

------------------------------------------------------------------------
                        Chemical name                          CAS No.*
------------------------------------------------------------------------
Acetaldehyde................................................     75-07-0
Acetic acid.................................................     64-19-7
Acetone.....................................................     67-64-1
Acetonitrile................................................     75-05-8
Acetophenone................................................     98-86-2
Acrolein....................................................    107-02-8
Acrylic acid................................................     79-10-7
Acrylonitrile...............................................    107-13-1
Anthraquinone...............................................     84-65-1
Benzaldehyde................................................    100-52-7
Benzoic acid, tech..........................................     65-85-0
1,3-Butadiene...............................................    106-99-0
p-t-Butyl benzoic acid......................................     98-73-7
N-Butyric acid..............................................    107-92-6
Crotonic acid...............................................   3724-65-0
Cumene hydroperoxide........................................     80-15-9
Cyclohexanol................................................    108-93-0
Cyclohexanone...............................................    108-94-1
Dimethyl terephthalate......................................    120-61-6
Ethylene dichloride.........................................    107-06-2
Ethylene oxide..............................................     75-21-8
Formaldehyde................................................     50-00-0
Formic acid.................................................     64-18-6
Glyoxal.....................................................    107-22-2
Hydrogen cyanide............................................     74-90-8
Isobutyric acid.............................................     79-31-2
Isophthalic acid............................................    121-91-5
Maleic anhydride............................................    108-31-6
Methyl ethyl ketone.........................................     78-93-3
a-Methyl styrene............................................     98-83-9
Phenol......................................................    108-95-2
Phthalic anhydride..........................................     85-44-9
Propionic acid..............................................     79-09-4
Propylene oxide.............................................     75-56-9
Styrene.....................................................    100-42-5
Terephthalic acid...........................................    100-21-0
------------------------------------------------------------------------
*CAS numbers refer to the Chemical Abstracts Registry numbers assigned
  to specific chemicals, isomers, or mixtures of chemicals. Some isomers
  or mixtures that are covered by the standards do not have CAS numbers
  assigned to them. The standards apply to all of the chemicals listed,
  whether CAS numbers have been assigned or not.



Sec. 60.618  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to States: 
Sec. 60.613(e).



    Subpart JJJ--Standards of Performance for Petroleum Dry Cleaners

    Source: 49 FR 37331, Sept. 21, 1984, unless otherwise noted.



Sec. 60.620  Applicability and designation of affected facility.

    (a) The provisions of this subpart are applicable to the following 
affected facilities located at a petroleum dry cleaning plant with a 
total manufacturers' rated dryer capacity equal to or greater than 38 
kilograms (84 pounds): Petroleum solvent dry cleaning dryers, washers, 
filters, stills, and settling tanks.
    (1) When the affected facility is installed in an existing plant 
that is not expanding the manufacturers' rated capacity of its petroleum 
solvent dryer(s), the total manufacturers' rated dryer capacity is the 
summation of the manufacturers' rated capacity

[[Page 456]]

for each existing petroleum solvent dryer.
    (2) When the affected facility is installed in a plant that is 
expanding the manufacturers' rated capacity of its petroleum solvent 
dryers, the total manufacturers' rated dryer capacity is the summation 
of the manufacturers' rated dryer capacity for each existing and 
proposed new petroleum solvent dryer.
    (3) When the affected facilty is installed in a new plant, the total 
manufacturers' rated dryer capacity is the summation of the 
manufacturers' rated dryer capacity for each proposed new petroleum 
solvent dryer.
    (4) The petroleum solvent dryers considered in the determination of 
the total manufacturers' rated dryer capacity are those new and existing 
dryers in the plant that will be in service at any time after the 
proposed new source or modification commences operation.
    (b) Any facility under paragraph (a) of this section that commences 
construction or modification after December 14, 1982, is subject to the 
requirements of this subpart with the following exception. A dryer 
installed between December 14, 1982, and September 21, 1984, in a plant 
with an annual solvent consumption level of less than 4,700 gallons, is 
exempt from the requirements of this subpart.

[49 FR 37331, Sept. 21, 1984, as amended at 50 FR 49026, Nov. 27, 1985]



Sec. 60.621  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
same meaning given them in the Act and in subpart A of this part.
    Cartridge filter means a discrete filter unit containing both filter 
paper and activated carbon that traps and removes contaminants from 
petroleum solvent, together with the piping and ductwork used in the 
installation of this device.
    Dryer means a machine used to remove petroleum solvent from articles 
of clothing or other textile or leather goods, after washing and 
removing of excess petroleum solvent, together with the piping and 
ductwork used in the installation of this device.
    Manufacturers' rated dryer capacity means the dryer's rated capacity 
of articles, in pounds or kilograms of clothing articles per load, dry 
basis, that is typically found on each dryer on the manufacturer's name-
plate or in the manufacturer's equipment specifications.
    Perceptible leaks means any petroleum solvent vapor or liquid leaks 
that are conspicuous from visual observation or that bubble after 
application of a soap solution, such as pools or droplets of liquid, 
open containers or solvent, or solvent laden waste standing open to the 
atmosphere.
    Petroleum dry cleaner means a dry cleaning facility that uses 
petroleum solvent in a combination of washers, dryers, filters, stills, 
and settling tanks.
    Settling tank means a container that gravimetrically separates oils, 
grease, and dirt from petroleum solvent, together with the piping and 
ductwork used in the installation of this device.
    Solvent filter means a discrete solvent filter unit containing a 
porous medium that traps and removes contaminants from petroleum 
solvent, together with the piping and ductwork used in the installation 
of this device.
    Solvent recovery dryer means a class of dry cleaning dryers that 
employs a condenser to condense and recover solvent vapors evaporated in 
a closed-loop stream of heated air, together with the piping and 
ductwork used in the installation of this device.
    Still means a device used to volatilize, separate, and recover 
petroleum solvent from contaminated solvent, together with the piping 
and ductwork used in the installation of this device.
    Washer means a machine which agitates fabric articles in a petroleum 
solvent bath and spins the articles to remove the solvent, together with 
the piping and ductwork used in the installation of this device.



Sec. 60.622  Standards for volatile organic compounds.

    (a) Each affected petroleum solvent dry cleaning dryer that is 
installed at a petroleum dry cleaning plant after December 14, 1982, 
shall be a solvent recovery dryer. The solvent recovery

[[Page 457]]

dryer(s) shall be properly installed, operated, and maintained.
    (b) Each affected petroleum solvent filter that is installed at a 
petroleum dry cleaning plant after December 14, 1982, shall be a 
cartridge filter. Cartridge filters shall be drained in their sealed 
housings for at least 8 hours prior to their removal
    (c) Each manufacturer of an affected petroleum solvent dryer shall 
include leak inspection and leak repair cycle information in the 
operating manual and on a clearly visible label posted on each affected 
facility. Such information should state:

    To protect against fire hazards, loss of valuable solvents, and 
emissions of solvent to the atmosphere, periodic inspection of this 
equipment for evidence of leaks and prompt repair of any leaks is 
recommended. The U.S. Environmental Protection Agency recommends that 
the equipment be inspected every 15 days and all vapor or liquid leaks 
be repaired within the subsequent 15 day period.

[49 FR 37331, Sept. 21, 1984, as amended at 50 FR 49026, Nov. 27, 1985]



Sec. 60.623  Equivalent equipment and procedures.

    (a) Upon written application from any person, the Administrator may 
approve the use of equipment or procedures that have been demonstrated 
to his satisfaction to be equivalent, in terms of reducing VOC emissions 
to the atmosphere, to those prescribed for compliance within a specified 
paragraph of this subpart. The application must contain a complete 
description of the equipment or procedure; the testing method; the date, 
time and location of the test; and a description of the test results. 
Written applications shall be submitted to the Administrator, U.S. 
Environmental Protection Agency, 401 M Street SW., Washington, DC 20460.
    (b) The Administrator will make a preliminary determination of 
whether or not the application for equivalency is approvable and will 
publish a notice of these findings in the Federal Register. After notice 
and opportunity for public hearing, the Administrator will publish the 
final determination in the Federal Register.



Sec. 60.624  Test methods and procedures.

    Each owner or operator of an affected facility subject to the 
provisions of Sec. 60.622(a) shall perform an initial test to verify 
that the flow rate of recovered solvent from the solvent recovery dryer 
at the termination of the recovery cycle is no greater than 0.05 liters 
per minute. This test shall be conducted for a duration of no less than 
2 weeks during which no less than 50 percent of the dryer loads shall be 
monitored for their final recovered solvent flow rate. The suggested 
point for measuring the flow rate of recovered solvent is from the 
outlet of the solvent-water separator. Near the end of the recovery 
cycle, the entire flow of recovered solvent should be diverted to a 
graduated cylinder. As the recovered solvent collects in the graduated 
cylinder, the elapsed time is monitored and recorded in periods of 
greater than or equal to 1 minute. At the same time, the volume of 
solvent in the graduated cylinder is monitored and recorded to determine 
the volume of recovered solvent that is collected during each time 
period. The recovered solvent flow rate is calculated by dividing the 
volume of solvent collected per period by the length of time elapsed 
during the period and converting the result with appropriate factors 
into units of liters per minute. The recovery cycle and the monitoring 
procedure should continue until the flow rate of solvent is less than or 
equal to 0.05 liter per minute. The type of articles cleaned and the 
total length of the cycle should then be recorded.



Sec. 60.625  Recordkeeping requirements.

    Each owner or operator of an affected facility subject to the 
provisions of this subpart shall maintain a record of the performance 
test required under Sec. 60.624.



 Subpart KKK--Standards of Performance for Equipment Leaks of VOC From 
                 Onshore Natural Gas Processing Plants.

    Source: 50 FR 26124, June 24, 1985, unless otherwise noted.

[[Page 458]]



Sec. 60.630  Applicability and designation of affected facility.

    (a)(1) The provisions of this subpart apply to affected facilities 
in onshore natural gas processing plants.
    (2) A compressor in VOC service or in wet gas service is an affected 
facility.
    (3) The group of all equipment except compressors (definied in 
Sec. 60.631) within a process unit is an affected facility.
    (b) Any affected facility under paragraph (a) of this section that 
commences construction, reconstruction, or modification after January 
20, 1984, is subject to the requirements of this subpart.
    (c) Addition or replacement of equipment (defined in Sec. 60.631) 
for the purpose of process improvement that is accomplished without a 
capital expenditure shall not by itself be considered a modification 
under this subpart.
    (d) Facilities covered by subpart VV or subpart GGG of 40 CFR part 
60 are excluded from this subpart.
    (e) A compressor station, dehydration unit, sweetening unit, 
underground storage tank, field gas gathering system, or liquefied 
natural gas unit is covered by this subpart if it is located at an 
onshore natural gas processing plant. If the unit is not located at the 
plant site, then it is exempt from the provisions of this subpart.



Sec. 60.631  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act, in subpart A or subpart VV of part 60; 
and the following terms shall have the specific meanings given them.
    Alaskan North Slope means the approximately 69,000 square-mile area 
extending from the Brooks Range to the Arctic Ocean.
    Equipment means each pump, pressure relief device, open-ended valve 
or line, valve, compressor, and flange or other connector that is in VOC 
service or in wet gas service, and any device or system required by this 
subpart.
    Field gas means feedstock gas entering the natural gas processing 
plant.
    In light liquid service means that the piece of equipment contains a 
liquid that meets the conditions specified in Sec. 60.485(e) or 
Sec. 60.633(h)(2).
    In wet gas service means that a piece of equipment contains or 
contacts the field gas before the extraction step in the process.
    Natural gas liquids means the hydrocarbons, such as ethane, propane, 
butane, and pentane, that are extracted from field gas.
    Natural gas processing plant (gas plant) means any processing site 
engaged in the extraction of natural gas liquids from field gas, 
fractionation of mixed natural gas liquids to natural gas products, or 
both.
    Nonfractionating plant means any gas plant that does not fractionate 
mixed natural gas liquids into natural gas products.
    Onshore means all facilities except those that are located in the 
territorial seas or on the outer continental shelf.
    Process unit means equipment assembled for the extraction of natural 
gas liquids from field gas, the fractionation of the liquids into 
natural gas products, or other operations associated with the processing 
of natural gas products. A process unit can operate independently if 
supplied with sufficient feed or raw materials and sufficient storage 
facilities for the products.
    Reciprocating compressor means a piece of equipment that increases 
the pressure of a process gas by positive displacement, employing linear 
movement of the driveshaft.



Sec. 60.632  Standards.

    (a) Each owner or operator subject to the provisions of this subpart 
shall comply with the requirements of Secs. 60.482-1 (a), (b), and (d) 
and 60.482-2 through 60.482-10, except as provided in Sec. 60.633, as 
soon as practicable, but no later than 180 days after initial startup.
    (b) An owner or operator may elect to comply with the requirements 
of Secs. 60.483-1 and 60.483-2.
    (c) An owner or operator may apply to the Administrator for 
permission to use an alternative means of emission limitation that 
achieves a reduction in emissions of VOC at least equivalent to that 
achieved by the controls required in this subpart. In doing so, the 
owner or operator shall comply with requirements of Sec. 60.634 of this 
subpart.

[[Page 459]]

    (d) Each owner or operator subject to the provisions of this subpart 
shall comply with the provisions of Sec. 60.485 except as provided in 
Sec. 60.633(f) of this subpart.
    (e) Each owner or operator subject to the provisions of this subpart 
shall comply with the provisions of Secs. 60.486 and 60.487 except as 
provided in Secs. 60.633, 60.635, and 60.636 of this subpart.
    (f) An owner or operator shall use the following provision instead 
of Sec. 60.485(d)(1): Each piece of equipment is presumed to be in VOC 
service or in wet gas service unless an owner or operator demonstrates 
that the piece of equipment is not in VOC service or in wet gas service. 
For a piece of equipment to be considered not in VOC service, it must be 
determined that the percent VOC content can be reasonably expected never 
to exceed 10.0 percent by weight. For a piece of equipment to be 
considered in wet gas service, it must be determined that it contains or 
contacts the field gas before the extraction step in the process. For 
purposes of determining the percent VOC content of the process fluid 
that is contained in or contacts a piece of equipment, procedures that 
conform to the methods described in ASTM Methods E169, E168, or E260 
(incorporated by reference as specified in Sec. 60.17) shall be used.



Sec. 60.633  Exceptions.

    (a) Each owner or operator subject to the provisions of this subpart 
may comply with the following exceptions to the provisions of subpart 
VV.
    (b)(1) Each pressure relief device in gas/vapor service may be 
monitored quarterly and within 5 days after each pressure release to 
detect leaks by the methods specified in Sec. 60.485(b) except as 
provided in Sec. 60.632(c), paragraph (b)(4) of this section, and 
Sec. 60.482-4 (a) through (c) of subpart VV.
    (2) If an instrument reading of 10,000 ppm or greater is measured, a 
leak is detected.
    (3)(i) When a leak is detected, it shall be repaired as soon as 
practicable, but no later than 15 calendar days after it is detected, 
except as provided in Sec. 60.482-9.
    (ii) A first attempt at repair shall be made no later than 5 
calendar days after each leak is detected.
    (4)(i) Any pressure relief device that is located in a 
nonfractionating plant that is monitored only by nonplant personnel may 
be monitored after a pressure release the next time the monitoring 
personnel are on site, instead of within 5 days as specified in 
paragraph (b)(1) of this section and Sec. 60.482-(b)(1) of subpart VV.
    (ii) No pressure relief device described in paragraph (b)(4)(i) of 
this section shall be allowed to operate for more than 30 days after a 
pressure release without monitoring.
    (c) Sampling connection systems are exempt from the requirements of 
Sec. 60.482-5.
    (d) Pumps in light liquid service, valves in gas/vapor and light 
liquid service, and pressure relief devices in gas/vapor service that 
are located at a nonfractionating plant that does not have the design 
capacity to process 283,000 standard cubic meters per day (scmd) (10 
million standard cubic feet per day (scfd)) or more of field gas are 
exempt from the routine monitoring requirements of Secs. 60.482-2(a)(1) 
and 60.482-7(a), and paragraph (b)(1) of this section.
    (e) Pumps in light liquid service, valves in gas/vapor and light 
liquid service, and pressure relief devices in gas/vapor service within 
a process unit that is located in the Alaskan North Slope are exempt 
from the routine monitoring requirements of Secs. 60.482-2(a)(1), 
60.482-7(a), and paragraph (b)(1) of this section.
    (f) Reciprocating compressors in wet gas service are exempt from the 
compressor control requirements of Sec. 60.482-3.
    (g) Flares used to comply with this subpart shall comply with the 
requirements of Sec. 60.18.
    (h) An owner or operator may use the following provisions instead of 
Sec. 60.485(e):
    (1) Equipment is in heavy liquid service if the weight percent 
evaporated is 10 percent or less at 150  deg.C as determined by ASTM 
Method D86 (incorporated by reference as specified in Sec. 60.17).

[[Page 460]]

    (2) Equipment is in light liquid service if the weight percent 
evaporated is greater than 10 percent at 150  deg.C as determined by 
ASTM Method D86 (incorporated by reference as specified in Sec. 60.17).

[50 FR 26124, June 24, 1985, as amended at 51 FR 2702, Jan. 21, 1986]



Sec. 60.634  Alternative means of emission limitation.

    (a) If, in the Administrator's judgment, an alternative means of 
emission limitation will achieve a reduction in VOC emissions at least 
equivalent to the reduction in VOC emissions achieved under any design, 
equipment, work practice or operational standard, the Administrator will 
publish, in the Federal Register a notice permitting the use of that 
alternative means for the purpose of compliance with that standard. The 
notice may condition permission on requirements related to the operation 
and maintenance of the alternative means.
    (b) Any notice under paragraph (a) of this section shall be 
published only after notice and an opportunity for a public hearing.
    (c) The Administrator will consider applications under this section 
from either owners or operators of affected facilities, or manufacturers 
of control equipment.
    (d) The Administrator will treat applications under this section 
according to the following criteria, except in cases where he concludes 
that other criteria are appropriate:
    (1) The applicant must collect, verify and submit test data, 
covering a period of at least 12 months, necessary to support the 
finding in paragraph (a) of this section.
    (2) If the applicant is an owner or operator of an affected 
facility, he must commit in writing to operate and maintain the 
alternative means so as to achieve a reduction in VOC emissions at least 
equivalent to the reduction in VOC emissions achieved under the design, 
equipment, work practice or operational standard.



Sec. 60.635  Recordkeeping requirements.

    (a) Each owner or operator subject to the provisions of this subpart 
shall comply with the requirements of paragraphs (b) and (c) of this 
section in addition to the requirements of Sec. 60.486.
    (b) The following recordkeeping requirements shall apply to pressure 
relief devices subject to the requirements of Sec. 60.633(b)(1) of this 
subpart.
    (1) When each leak is detected as specified in Sec. 60.633(b)(2), a 
weatherproof and readily visible identification, marked with the 
equipment identification number, shall be attached to the leaking 
equipment. The identification on the pressure relief device may be 
removed after it has been repaired.
    (2) When each leak is detected as specified in Sec. 60.633(b)(2), 
the following information shall be recorded in a log and shall be kept 
for 2 years in a readily accessible location:
    (i) The instrument and operator identification numbers and the 
equipment identification number.
    (ii) The date the leak was detected and the dates of each attempt to 
repair the leak.
    (iii) Repair methods applied in each attempt to repair the leak.
    (iv) ``Above 10,000 ppm'' if the maximum instrument reading measured 
by the methods specified in paragraph (a) of this section after each 
repair attempt is 10,000 ppm or greater.
    (v) ``Repair delayed'' and the reason for the delay if a leak is not 
repaired within 15 calendar days after discovery of the leak.
    (vi) The signature of the owner or operator (or designate) whose 
decision it was that repair could not be effected without a process 
shutdown.
    (vii) The expected date of successful repair of the leak if a leak 
is not repaired within 15 days.
    (viii) Dates of process unit shutdowns that occur while the 
equipment is unrepaired.
    (ix) The date of successful repair of the leak.
    (x) A list of identification numbers for equipment that are 
designated for no detectable emissions under the provisions of 
Sec. 60.482-4(a). The designation of equipment subject to the provisions 
of Sec. 60.482-4(a) shall be signed by the owner or operator.
    (c) An owner or operator shall comply with the following requirement 
in addition to the requirement of Sec. 60.486(j): Information and data 
used to

[[Page 461]]

demonstrate that a reciprocating compressor is in wet gas service to 
apply for the exemption in Sec. 60.633(f) shall be recorded in a log 
that is kept in a readily accessible location.



Sec. 60.636  Reporting requirements.

    (a) Each owner or operator subject to the provisions of this subpart 
shall comply with the requirements of paragraphs (b) and (c) of this 
section in addition to the requirements of Sec. 60.487.
    (b) An owner or operator shall include the following information in 
the initial semiannual report in addition to the information required in 
Sec. 60.487(b) (1)--(4): Number of pressure relief devices subject to 
the requirements of Sec. 60.633(b) except for those pressure relief 
devices designated for no detectable emissions under the provisions of 
Sec. 60.482-4(a) and those pressure relief devices complying with 
Sec. 60.482-4(c).
    (c) An owner or operator shall include the following information in 
all semiannual reports in addition to the information required in 
Sec. 60.487(c)(2) (i) through (vi):
    (1) Number of pressure relief devices for which leaks were detected 
as required in Sec. 60.633(b)(2) and
    (2) Number of pressure relief devices for which leaks were not 
repaired as required in Sec. 60.633(b)(3).



     Subpart LLL--Standards of Performance for Onshore Natural Gas 
                  Processing: SO2 Emissions

    Source: 50 FR 40160, Oct. 1, 1985, unless otherwise noted.



Sec. 60.640  Applicability and designation of affected facilities.

    (a) The provisions of this subpart are applicable to the following 
affected facilities that process natural gas: each sweetening unit, and 
each sweetening unit followed by a sulfur recovery unit.
    (b) Facilities that have a design capacity less than 2 long tons per 
day (LT/D) of hydrogen sulfide (H2S) in the acid gas 
(expressed as sulfur) are required to comply with Sec. 60.647(c) but are 
not required to comply with Secs. 60.642 through 60.646.
    (c) The provisions of this subpart are applicable to facilities 
located on land and include facilities located onshore which process 
natural gas produced from either onshore or offshore wells.
    (d) The provisions of this subpart apply to each affected facility 
identified in paragraph (a) of this section which commences construction 
or modification after January 20, 1984.
    (e) The provisions of this subpart do not apply to sweetening 
facilities producing acid gas that is completely reinjected into oil-or-
gas-bearing geologic strata or that is otherwise not released to the 
atmosphere.



Sec. 60.641  Definitions.

    All terms used in this subpart not defined below are given the 
meaning in the Act and in subpart A of this part.
    Acid gas means a gas stream of hydrogen sulfide (H2S) and 
carbon dioxide (CO2) that has been separated from sour 
natural gas by a sweetening unit.
    Natural gas means a naturally occurring mixture of hydrocarbon and 
nonhydrocarbon gases found in geologic formations beneath the earth's 
surface. The principal hydrocarbon constituent is methane.
    Onshore means all facilities except those that are located in the 
territorial seas or on the outercontinental shelf.
    Reduced sulfur compounds means H2S, carbonyl sulfide 
(COS), and carbon disulfide (CS2).
    Sulfur production rate means the rate of liquid sulfur accumulation 
from the sulfur recovery unit.
    Sulfur recovery unit means a process device that recovers element 
sulfur from acid gas.
    Sweetening unit means a process device that separates the 
H2S and CO2 contents from the sour natural gas 
stream.
    Total SO2 equivalents means the sum of volumetric or mass 
concentrations of the sulfur compounds obtained by adding the quantity 
existing as SO2 to the quantity of SO2 that would 
be obtained if all reduced sulfur compounds were converted to 
SO2 (ppmv or kg/DSCM).

E=the sulfur emission rate expressed as elemental sulfur, kilograms per 
          hour (kg/hr) rounded to one decimal place.
R=the sulfur emission reduction efficiency achieved in percent, carried 
          to one decimal place.

[[Page 462]]

S=the sulfur production rate in kilograms per hour (kg/hr) rounded to 
          one decimal place.
X=the sulfur feed rate, i.e., the H2S in the acid gas 
          (expressed as sulfur) from the sweetening unit, expressed in 
          long tons per day (LT/D) of sulfur rounded to one decimal 
          place.
Y=the sulfur content of the acid gas from the sweetening unit, expressed 
          as mole percent H2S (dry basis) rounded to one 
          decimal place.
Z=the minimum required sulfur dioxide (SO2) emission 
          reduction efficiency, expressed as percent carried to one 
          decimal place. Zi refers to the reduction 
          efficiency required at the initial performance test. 
          Zc refers to the reduction efficiency required on a 
          continuous basis after compliance with Zi has been 
          demonstrated.



Sec. 60.642  Standards for sulfur dioxide.

    (a) During the initial performance test required by Sec. 60.8(b), 
each owner or operator shall achieve at a minimum, an SO2 
emission reduction efficiency (Zi) to be determined from 
Table 1 based on the sulfur feed rate (X) and the sulfur content of the 
acid gas (Y) of the affected facility.
    (b) After demonstrating compliance with the provisions of paragraph 
(a) of this section, the owner or operator shall achieve at a minimum, 
an SO2 emission reduction efficiency (Zc) to be 
determined from Table 2 based on the sulfur feed rate (X) and the sulfur 
content of the acid gas (Y) of the affected facility.

[[Page 463]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.054



Sec. 60.643  Compliance provisions.

    (a)(1) To determine compliance with the standards for sulfur dioxide 
specified in Sec. 60.642(a), during the initial performance test as 
required by Sec. 60.8, the

[[Page 464]]

minimum required sulfur dioxide emission reduction efficiency (Z) is 
compared to the emission reduction efficiency (R) achieved by the sulfur 
recovery technology.
    (i) If R  Zi, the affected facility is in 
compliance.
    (ii) If R < Zi, the affected facility is not in 
compliance.
    (2) Following the initial determination of compliance as required by 
Sec. 60.8, any subsequent compliance determinations that may be required 
by the Administrator would compare R to Zc.
    (b) The emission reduction efficiency (R) achieved by the sulfur 
reduction technology shall be determined using the procedures in 
Sec. 60.644(c)(1).

[50 FR 40160, Oct. 1, 1985, as amended at 54 FR 6679, Feb. 14, 1989]



Sec. 60.644  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in paragraph Sec. 60.8(b).
    (b) During a performance test required by Sec. 60.8, the owner or 
operator shall determine the minimum required reduction efficiencies (Z) 
of SO2 emissions as required in Sec. 60.642 (a) and (b) as 
follows:
    (1) The average sulfur feed rate (X) shall be computed as follows:

                X=K Qa Y
where:
X=average sulfur feed rate, long ton/day.
Qa=average volumetric flow rate of acid gas from sweetening 
          unit, dscf/day.
Y=average H2S concentration in acid gas feed from sweetening 
          unit, percent by volume.
K=(32 lb S/lb-mole)/[(100%)(385.36 dscf/lb-mole)(2240 lb/long ton)]
=3.707 x 10-7

    (2) The continuous readings from the process flowmeter shall be used 
to determine the average volumetric flow rate (Qa) in dscf/
day of the acid gas from the sweetening unit for each run.
    (3) The Tutwiler procedure in Sec. 60.648 or a chromatographic 
procedure following ASTM E-260 (incorporated by reference--see 
Sec. 60.17) shall be used to determine the H2S concentration 
in the acid gas feed from the sweetening unit. At least one sample per 
hour (at equally spaced intervals) shall be taken during each 4-hour 
run. The arithmetic mean of all samples shall be the average 
H2S concentration (Y) on a dry basis for the run. By 
multiplying the result from the Tutwiler procedure by 1.62  x  
10-3, the units gr/100 scf are converted to volume percent.
    (4) Using the information from paragraphs (b) (1) and (3), Tables 1 
and 2 shall be used to determine the required initial (Zi) 
and continuous (Zc) reduction efficiencies of SO2 
emissions.
    (c) The owner or operator shall determine compliance with the 
SO2 standards in Sec. 60.642 (a) or (b) as follows:
    (1) The emission reduction efficiency (R) achieved by the sulfur 
recovery technology shall be computed for each run using the following 
equation:

R=(100 S)/(S+E)

    (2) The level indicators or manual soundings shall be used to 
measure the liquid sulfur accumulation rate in the product storage 
tanks. Readings taken at the beginning and end of each run, the tank 
geometry, sulfur density at the storage temperature, and sample duration 
shall be used to determine the sulfur production rate (S) in kg/hr for 
each run.
    (3) The emission rate (E) of sulfur shall be computed for each run 
as follows:

E=Ce Qsd/K

where:
Ce=concentration of sulfur equivalent (SO2+TRS), 
          g/dscm.
Qsd=volumetric flow rate of effluent gas, dscm/hr.
K=conversion factor, 1000 g/kg.

    (4) The concentration (Ce) of sulfur equivalent shall be 
the sum of the SO2 and TRS concentrations, after being 
converted to sulfur equivalents. For each run and each of the test 
methods specified in this paragraph (c) of this section, the sampling 
time shall be at least 4 hours. Method 1 shall be used to select the 
sampling site. The sampling point in the duct shall be at the centroid 
of the cross-section if the area is less than 5 m2 (54 
ft2) or at a point no closer to the walls than 1 m (39 in.) 
if the cross-sectional area is 5 m2 or

[[Page 465]]

more, and the centroid is more than 1 m (39 in.) from the wall.
    (i) Method 6 shall be used to determine the SO2 
concentration. Eight samples of 20 minutes each shall be taken at 30-
minute intervals. The arithmetic average in mg/dscm shall be the 
concentration for the run. The concentration in mg/dscm shall be 
multiplied by 0.5 to convert the results to sulfur equivalent.
    (ii) Method 15 shall be used to determine the TRS concentration from 
reduction-type devices or where the oxygen content of the effluent gas 
is less than 1.0 percent by volume. The sampling rate shall be at least 
3 liters/min (0.1 ft3/min) to insure minimum residence time 
in the sample line. Sixteen samples shall be taken at 15-minute 
intervals. The arithmetic average of all the samples shall be the 
concentration for the run. The concentration in ppm TRS as 
H2S shall be multiplied by 1.352  x  10-6 to 
convert the results to sulfur equivalent.
    (iii) Method 16A shall be used to determine the TRS concentration 
from oxidation-type devices or where the oxygen content of the effluent 
gas is greater than 1.0 percent by volume. Eight samples of 20 minutes 
each shall be taken at 30-minute intervals. The arithmetic average shall 
be the concentration for the run. The concentration in ppm TRS as 
H2S shall be multiplied by 1.352  x  10-6 to 
convert the results to sulfur equivalent.
    (iv) Method 2 shall be used to determine the volumetric flow rate of 
the effluent gas. A velocity traverse shall be conducted at the 
beginning and end of each run. The arithmetic average of the two 
measurements shall be used to calculate the volumetric flow rate 
(Qsd) for the run. For the determination of the effluent gas 
molecular weight, a single integrated sample over the 4-hour period may 
be taken and analyzed or grab samples at 1-hour intervals may be taken, 
analyzed, and averaged. For the moisture content, two samples of at 
least 0.10 dscm (0.35 dscf) and 10 minutes shall be taken at the 
beginning of the 4-hour run and near the end of the time period. The 
arithmetic average of the two runs shall be the moisture content for the 
run.
    (d) To comply with Sec. 60.646(d), the owner or operator shall 
obtain the information required by using the monitoring devices in 
paragraph (b) of (c) of this section.

[54 FR 6679, Feb. 14, 1989]



Sec. 60.645  [Reserved]



Sec. 60.646  Monitoring of emissions and operations.

    (a) The owner or operator subject to the provisions of Sec. 60.642 
(a) or (b) shall install, calibrate, maintain, and operate monitoring 
devices or perform measurements to determine the following operations 
information on a daily basis:
    (1) The accumulation of sulfur product over each 24-hour period: The 
monitoring method may incorporate the use of an instrument to measure 
and record the liquid sulfur production rate, or may be a procedure for 
measuring and recording the sulfur liquid levels in the storage tanks 
with a level indicator or by manual soundings, with subsequent 
calculation of the sulfur production rate based on the tank geometry, 
stored sulfur density, and elapsed time between readings. The method 
shall be designed to be accurate within 2 percent of the 24-
hour sulfur accumulation.
    (2) The H2S concentration in the acid gas from the 
sweetening unit for each 24-hour period: At least one sample per 24-hour 
period shall be collected and analyzed using the method specified in 
Sec. 60.644(b)(1). The Administrator may require the owner or operator 
to demonstrate that the H2S concentration obtained from one 
or more samples over a 24-hour period is within 20 percent 
of the average of 12 samples collected at equally spaced intervals 
during the 24-hour period. In instances where the H2S 
concentration of a single sample is not within 20 percent of 
the average of the 12 equally spaced samples, the Administrator may 
require a more frequent sampling schedule.
    (3) The average acid gas flow rate from the sweetening unit: The 
owner or operator shall install and operate a monitoring device to 
continuously measure the flow rate of acid gas. The monitoring device 
reading shall be recorded at least once per hour during

[[Page 466]]

each 24-hour period. The average acid gas flow rate shall be computed 
from the individual readings.
    (4) The sulfur feed rate (X): For each 24-hour period, X shall be 
computed using the equation in Sec. 60.644(b)(3).
    (5) The required sulfur dioxide emission reduction efficiency for 
the 24-hour period: The sulfur feed rate and the H2S 
concentration in the acid gas for the 24-hour period as applicable, 
shall be used to determine the required reduction efficiency in 
accordance with the provisions of Sec. 60.642(b).
    (b) Where compliance is achieved through the use of an oxidation 
control system or a reduction control system followed by a continually 
operated incineration device, the owner or operator shall install, 
calibrate, maintain, and operate monitoring devices and continuous 
emission monitors as follows:
    (1) A continuous monitoring system to measure the total sulfur 
emission rate (E) of SO2 in the gases discharged to the 
atmosphere. The SO2 emission rate shall be expressed in terms 
of equivalent sulfur mass flow rates (kg/hr). The span of this 
monitoring system shall be set so that the equivalent emission limit of 
Sec. 60.642(b) will be between 30 percent and 70 percent of the 
measurement range of the instrument system.
    (2) Except as provided in paragraph (b)(3) of this section: A 
monitoring device to measure the temperature of the gas leaving the 
combustion zone of the incinerator, if compliance with Sec. 60.642(a) is 
achieved through the use of an oxidation control system or a reduction 
control system followed by a continually operated incineration device. 
The monitoring device shall be certified by the manufacturer to be 
accurate to within 1 percent of the temperature being 
measured.

When performance tests are conducted under the provision of Sec. 60.8 to 
demonstrate compliance with the standards under Sec. 60.642, the 
temperature of the gas leaving the incinerator combustion zone shall be 
determined using the monitoring device. If the volumetric ratio of 
sulfur dioxide to sulfur dioxide plus total reduced sulfur (expressed as 
SO2) in the gas leaving the incinerator is 0.98, 
then temperature monitoring may be used to demonstrate that sulfur 
dioxide emission monitoring is sufficient to determine total sulfur 
emissions. At all times during the operation of the facility, the owner 
or operator shall maintain the average temperature of the gas leaving 
the combustion zone of the incinerator at or above the appropriate level 
determined during the most recent performance test to ensure the sulfur 
compound oxidation criteria are met. Operation at lower average 
temperatures may be considered by the Administrator to be unacceptable 
operation and maintenance of the affected facility. The owner or 
operator may request that the minimum incinerator temperature be 
reestablished by conducting new performance tests under Sec. 60.8.
    (3) Upon promulgation of a performance specification of continuous 
monitoring systems for total reduced sulfur compounds at sulfur recovery 
plants, the owner or operator may, as an alternative to paragraph (b)(2) 
of this section, install, calibrate, maintain, and operate a continuous 
emission monitoring system for total reduced sulfur compounds as 
required in paragraph (d) of this section in addition to a sulfur 
dioxide emission monitoring system. The sum of the equivalent sulfur 
mass emission rates from the two monitoring systems shall be used to 
compute the total sulfur emission rate (E).
    (c) Where compliance is achieved through the use of a reduction 
control system not followed by a continually operated incineration 
device, the owner or operator shall install, calibrate, maintain, and 
operate a continuous monitoring system to measure the emission rate of 
reduced sulfur compounds as SO2 equivalent in the gases 
discharged to the atmosphere. The SO2 equivalent compound 
emission rate shall be expressed in terms of equivalent sulfur mass flow 
rates (kg/hr). The span of this monitoring system shall be set so that 
the equivalent

[[Page 467]]

emission limit of Sec. 60.642(b) will be between 30 and 70 percent of 
the measurement range of the system. This requirement becomes effective 
upon promulgation of a performance specification for continuous 
monitoring systems for total reduced sulfur compounds at sulfur recovery 
plants.
    (d) For those sources required to comply with paragraph (b) or (c) 
of this section, the average sulfur emission reduction efficiency 
achieved (R) shall be calculated for each 24-hour clock internal. The 
24-hour interval may begin and end at any selected clock time, but must 
be consistent. The 24-hour average reduction efficiency (R) shall be 
computed based on the 24-hour average sulfur production rate (S) and 
sulfur emission rate (E), using the equation in Sec. 60.644(c)(1).
    (1) Data obtained from the sulfur production rate monitoring device 
specified in paragraph (a) of this section shall be used to determine S.
    (2) Data obtained from the sulfur emission rate monitoring systems 
specified in paragraphs (b) or (c) of this section shall be used to 
calculate a 24-hour average for the sulfur emission rate (E). The 
monitoring system must provide at least one data point in each 
successive 15-minute interval. At least two data points must be used to 
calculate each 1-hour average. A minimum of 18 1-hour averages must be 
used to compute each 24-hour average.
    (e) In lieu of complying with (b) or (c) of this section, those 
sources with a design capacity of less than 150 LT/D of H2S 
expressed as sulfur may calculate the sulfur emission reduction 
efficiency achieved for each 24-hour period by:
[GRAPHIC] [TIFF OMITTED] TC16NO91.095

Where:
R= the sulfur dioxide removal efficiency achieved during the 24-hour 
          period, percent;
S= the sulfur production rate during the 24-hour period, kg/hr;
X= the sulfur feed rate in the acid gas, LT/D; and 0.0236= conversion 
          factor, LT/D per kg/hr.

    (f) The monitoring devices required in paragraphs (b)(1), (b)(3) and 
(c) of this section shall be calibrated at least annually according to 
the manufacturer's specifications, as required by Sec. 60.13(b).
    (g) The continuous emission monitoring systems required in 
paragraphs (b)(1), (b)(3), and (c) of this section shall be subject to 
the emission monitoring requirements of Sec. 60.13 of the General 
Provisions. For conducting the continuous emission monitoring system 
performance evaluation required by Sec. 60.13(c), Performance 
Specification 2 shall apply, and Method 6 shall be used for systems 
required by paragraph (b) of this section.

[50 FR 40160, Oct. 1, 1985, as amended at 54 FR 6680, Feb. 14, 1989]



Sec. 60.647  Recordkeeping and reporting requirements.

    (a) Records of the calculations and measurements required in 
Sec. 60.642 (a) and (b) and Sec. 60.646 (a) through (g) must be retained 
for at least 2 years following the date of the measurements by owners 
and operators subject to this subpart. This requirement is included 
under Sec. 60.7(d) of the General Provisions.
    (b) Each owner or operator shall submit a written report of excess 
emissions to the Administrator semiannually. For the purpose of these 
reports, excess emissions are defined as:
    (1) Any 24-hour period (at consistent intervals) during which the 
average sulfur emission reduction efficiency (R) is less than the 
minimum required efficiency (Z).
    (2) For any affected facility electing to comply with the provisions 
of Sec. 60.646(b)(2), any 24-hour period during which the average 
temperature of the gases leaving the combustion zone of an incinerator 
is less than the appropriate operating temperature as determined during 
the most recent performance test in accordance with the provisions of 
Sec. 60.646(b)(2). Each 24-hour period must consist of at least 96 
temperature measurements equally spaced over the 24 hours.
    (c) To certify that a facility is exempt from the control 
requirements of these standards, each owner or operator of a facility 
with a design capacity less that 2 LT/D of H2S in the acid 
gas (expresssed as sulfur) shall keep, for the life of the facility, an 
analysis

[[Page 468]]

demonstrating that the facility's design capacity is less than 2 LT/D of 
H2S expressed as sulfur.
    (d) Each owner or operator who elects to comply with Sec. 60.646(e) 
shall keep, for the life of the facility, a record demonstrating that 
the facility's design capacity is less than 150 LT/D of H2S 
expressed as sulfur.
    (e) The requirements of paragraph (b) of this section remain in 
force until and unless EPA, in delegating enforcement authority to a 
State under section 111(c) of the Act, approves reporting requirements 
or an alternative means of compliance surveillance adopted by such 
State. In that event, affected sources within the State will be relieved 
of obligation to comply with paragraph (b) of this section, provided 
that they comply with the requirements established by the State.



Sec. 60.648  Optional procedure for measuring hydrogen sulfide in acid gas--Tutwiler Procedure.1
---------------------------------------------------------------------------

    \1\ Gas Engineers Handbook, Fuel Gas Engineering Practices, The 
Industrial Press, 93 Worth Street, New York, NY, 1966, First Edition, 
Second Printing, page 6/25 (Docket A-80-20-A, Entry II-I-67).
---------------------------------------------------------------------------

    (a) When an instantaneous sample is desired and H2S 
concentration is ten grains per 1000 cubic foot or more, a 100 ml 
Tutwiler burette is used. For concentrations less than ten grains, a 500 
ml Tutwiler burette and more dilute solutions are used. In principle, 
this method consists of titrating hydrogen sulfide in a gas sample 
directly with a standard solution of iodine.
    (b) Apparatus. (See Figure 1.) A 100 or 500 ml capacity Tutwiler 
burette, with two-way glass stopcock at bottom and three-way stopcock at 
top which connect either with inlet tubulature or glass-stoppered 
cylinder, 10 ml capacity, graduated in 0.1 ml subdivision; rubber tubing 
connecting burette with leveling bottle.
    (c) Reagents. (1) Iodine stock solution, 0.1N. Weight 12.7 g iodine, 
and 20 to 25 g cp potassium iodide for each liter of solution. Dissolve 
KI in as little water as necessary; dissolve iodine in concentrated KI 
solution, make up to proper volume, and store in glass-stoppered brown 
glass bottle.
    (2) Standard iodine solution, 1 ml=0.001771 g I. Transfer 33.7 ml of 
above 0.1N stock solution into a 250 ml volumetric flask; add water to 
mark and mix well. Then, for 100 ml sample of gas, 1 ml of standard 
iodine solution is equivalent to 100 grains H2S per cubic 
feet of gas.
    (3) Starch solution. Rub into a thin paste about one teaspoonful of 
wheat starch with a little water; pour into about a pint of boiling 
water; stir; let cool and decant off clear solution. Make fresh solution 
every few days.
    (d) Procedure. Fill leveling bulb with starch solution. Raise (L), 
open cock (G), open (F) to (A), and close (F) when solutions starts to 
run out of gas inlet. Close (G). Purge gas sampling line and connect 
with (A). Lower (L) and open (F) and (G). When liquid level is several 
ml past the 100 ml mark, close (G) and (F), and disconnect sampling 
tube. Open (G) and bring starch solution to 100 ml mark by raising (L); 
then close (G). Open (F) momentarily, to bring gas in burette to 
atmospheric pressure, and close (F). Open (G), bring liquid level down 
to 10 ml mark by lowering (L). Close (G), clamp rubber tubing near (E) 
and disconnect it from burette. Rinse graduated cylinder with a standard 
iodine solution (0.00171 g I per ml); fill cylinder and record reading. 
Introduce successive small amounts of iodine thru (F); shake well after 
each addition; continue until a faint permanent blue color is obtained. 
Record reading; subtract from previous reading, and call difference D.
    (e) With every fresh stock of starch solution perform a blank test 
as follows: introduce fresh starch solution into burette up to 100 ml 
mark. Close (F) and (G). Lower (L) and open (G). When liquid level 
reaches the 10 ml mark, close (G). With air in burette, titrate as 
during a test and up to same end point. Call ml of iodine used C. Then,

Grains H2S per 100 cubic foot of gas=100      (D--C)

    (f) Greater sensitivity can be attained if a 500 ml capacity 
Tutwiler burette is used with a more dilute (0.001N) iodine solution. 
Concentrations less than 1.0 grains per 100 cubic foot can be determined 
in this way. Usually, the

[[Page 469]]

starch-iodine end point is much less distinct, and a blank determination 
of end point, with H2S-free gas or air, is required.
[GRAPHIC] [TIFF OMITTED] TC01JN92.055

     Figure 1. Tutwiler burette (lettered items mentioned in text).

Subpart MMM [Reserved]



  Subpart NNN--Standards of Performance for Volatile Organic Compound 
 (VOC) Emissions From Synthetic Organic Chemical Manufacturing Industry 
                     (SOCMI) Distillation Operations

    Source: 55 FR 26942, June 29, 1990, unless otherwise noted.



Sec. 60.660  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to each affected facility 
designated in paragraph (b) of this section that is part of a process 
unit that produces any of the chemicals listed in Sec. 60.667 as a 
product, co-product, by-product, or intermediate, except as provided in 
paragraph (c).
    (b) The affected facility is any of the following for which 
construction, modification, or reconstruction commenced after December 
30, 1983:
    (1) Each distillation unit not discharging its vent stream into a 
recovery system.
    (2) Each combination of a distillation unit and the recovery system 
into which its vent stream is discharged.
    (3) Each combination of two or more distillation units and the 
common recovery system into which their vent streams are discharged.
    (c) Exemptions from the provisions of paragraph (a) of this section 
are as follows:
    (1) Any distillation unit operating as part of a process unit which 
produces coal tar or beverage alcohols, or which uses, contains, and 
produces no VOC is not an affected facility.
    (2) Any distillation unit that is subject to the provisions of 
Subpart DDD is not an affected facility.
    (3) Any distillation unit that is designed and operated as a batch 
operation is not an affected facility.
    (4) Each affected facility that has a total resource effectiveness 
(TRE) index value greater than 8.0 is exempt from all provisions of this 
subpart except for Secs. 60.662; 60.664 (d), (e), and (f); and 60.665 
(h) and (l).
    (5) Each affected facility in a process unit with a total design 
capacity for all chemicals produced within that unit of less than one 
gigagram per year is exempt from all provisions of this subpart except 
for the recordkeeping and reporting requirements in paragraphs (j), 
(l)(6), and (n) of Sec. 60.665.
    (6) Each affected facility operated with a vent stream flow rate 
less than 0.008 scm/min is exempt from all provisions of this subpart 
except for the test method and procedure and the recordkeeping and 
reporting requirements in Sec. 60.664(g) and paragraphs (i), (l)(5), and 
(o) of Sec. 60.665.
    [Note: The intent of these standards is to minimize the emissions of 
VOC through the application of best demonstrated technology (BDT). The 
numerical emission limits in these standards are expressed in terms of 
total organic compounds (TOC), measured as

[[Page 470]]

TOC less methane and ethane. This emission limit reflects the 
performance of BDT.]



Sec. 60.661  Definitions.

    As used in this subpart, all terms not defined here shall have the 
meaning given them in the Act and in subpart A of part 60, and the 
following terms shall have the specific meanings given them.
    Batch distillation operation means a noncontinuous distillation 
operation in which a discrete quantity or batch of liquid feed is 
charged into a distillation unit and distilled at one time. After the 
initial charging of the liquid feed, no additional liquid is added 
during the distillation operation.
    Boiler means any enclosed combustion device that extracts useful 
energy in the form of steam.
    By compound means by individual stream components, not carbon 
equivalents.
    Continuous recorder means a data recording device recording an 
instantaneous data value at least once every 15 minutes.
    Distillation operation means an operation separating one or more 
feed stream(s) into two or more exit stream(s), each exit stream having 
component concentrations different from those in the feed stream(s). The 
separation is achieved by the redistribution of the components between 
the liquid and vapor-phase as they approach equilibrium within the 
distillation unit.
    Distillation unit means a device or vessel in which distillation 
operations occur, including all associated internals (such as trays or 
packing) and accessories (such as reboiler, condenser, vacuum pump, 
steam jet, etc.), plus any associated recovery system.
    Flame zone means the portion of the combustion chamber in a boiler 
occupied by the flame envelope.
    Flow indicator means a device which indicates whether gas flow is 
present in a vent stream.
    Halogenated vent stream means any vent stream determined to have a 
total concentration (by volume) of compounds containing halogens of 20 
ppmv (by compound) or greater.
    Incinerator means any enclosed combustion device that is used for 
destroying organic compounds and does not extract energy in the form of 
steam or process heat.
    Process heater means a device that transfers heat liberated by 
burning fuel to fluids contained in tubes, including all fluids except 
water that is heated to produce steam.
    Process unit means equipment assembled and connected by pipes or 
ducts to produce, as intermediates or final products, one or more of the 
chemicals in Sec. 60.667. A process unit can operate independently if 
supplied with sufficient fuel or raw materials and sufficient product 
storage facilities.
    Product means any compound or chemical listed in Sec. 60.667 that is 
produced for sale as a final product as that chemical, or for use in the 
production of other chemicals or compounds. By-products, co-products, 
and intermediates are considered to be products.
    Recovery device means an individual unit of equipment, such as an 
absorber, carbon adsorber, or condenser, capable of and used for the 
purpose of recovering chemicals for use, reuse, or sale.
    Recovery system means an individual recovery device or series of 
such devices applied to the same vent stream.
    Total organic compounds (TOC) means those compounds measured 
according to the procedures in Sec. 60.664(b)(4). For the purposes of 
measuring molar composition as required in Sec. 60.664(d)(2)(i); hourly 
emissions rate as required in Sec. 60.664(d)(5) and Sec. 60.664(e); and 
TOC concentration as required in Sec. 60.665(b)(4) and 
Sec. 60.665(g)(4), those compounds which the Administrator has 
determined do not contribute appreciably to the formation of ozone are 
to be excluded. The compounds to be excluded are identified in 
Environmental Protection Agency's statements on ozone abatement policy 
for State Implementation Plans (SIP) revisions (42 FR 35314; 44 FR 
32042; 45 FR 32424; 45 FR 48942).
    TRE index value means a measure of the supplemental total resource 
requirement per unit reduction of TOC associated with an individual 
distillation vent stream, based on vent stream flow rate, emission rate 
of TOC net heating value, and corrosion properties

[[Page 471]]

(whether or not the vent stream is halogenated), as quantified by the 
equation given under Sec. 60.664(e).
    Vent stream means any gas stream discharged directly from a 
distillation facility to the atmosphere or indirectly to the atmosphere 
after diversion through other process equipment. The vent stream 
excludes relief valve discharges and equipment leaks including, but not 
limited to, pumps, compressors, and valves.



Sec. 60.662  Standards.

    Each owner or operator of any affected facility shall comply with 
paragraph (a), (b), or (c) of this section for each vent stream on and 
after the date on which the initial performance test required by 
Sec. 60.8 and Sec. 60.664 is completed, but not later than 60 days after 
achieving the maximum production rate at which the affected facility 
will be operated, or 180 days after the initial start-up, whichever date 
comes first. Each owner or operator shall either:
    (a) Reduce emissions of TOC (less methane and ethane) by 98 weight-
percent, or to a TOC (less methane and ethane) concentration of 20 ppmv, 
on a dry basis corrected to 3 percent oxygen, whichever is less 
stringent. If a boiler or process heater is used to comply with this 
paragraph, then the vent stream shall be introduced into the flame zone 
of the boiler or process heater; or
    (b) Combust the emissions in a flare that meets the requirements of 
Sec. 60.18; or
    (c) Maintain a TRE index value greater than 1.0 without use of VOC 
emission control devices.



Sec. 60.663  Monitoring of emissions and operations.

    (a) The owner or operator of an affected facility that uses an 
incinerator to seek to comply with the TOC emission limit specified 
under Sec. 60.662(a) shall install, calibrate, maintain, and operate 
according to manufacturer's specifications the following equipment:
    (1) A temperature monitoring device equipped with a continuous 
recorder and having an accuracy of 1 percent of the 
temperature being monitored expressed in degrees Celsius or 
0.5  deg.C, whichever is greater.
    (i) Where an incinerator other than a catalytic incinerator is used, 
a temperature monitoring device shall be installed in the firebox.
    (ii) Where a catalytic incinerator is used, temperature monitoring 
devices shall be installed in the gas stream immediately before and 
after the catalyst bed.
    (2) A flow indicator that provides a record of vent stream flow to 
the incinerator at least once every hour for each affected facility. The 
flow indicator shall be installed in the vent stream from each affected 
facility at a point closest to the inlet of each incinerator and before 
being joined with any other vent stream.
    (b) The owner or operator of an affected facility that uses a flare 
to seek to comply with Sec. 60.662(b) shall install, calibrate, maintain 
and operate according to manufacturer's specifications the following 
equipment:
    (1) A heat sensing device, such as a ultra-violet beam sensor or 
thermocouple, at the pilot light to indicate the continuous presence of 
a flame.
    (2) A flow indicator that provides a record of vent stream flow to 
the flare at least once every hour for each affected facility. The flow 
indicator shall be installed in the vent stream from each affected 
facility at a point closest to the flare and before being joined with 
any other vent stream.
    (c) The owner or operator of an affected facility that uses a boiler 
or process heater to seek to comply with Sec. 60.662(a) shall install, 
calibrate, maintain and operate according to the manufacturer's 
specifications in the following equipment:
    (1) A flow indicator that provides a record of vent stream flow to 
the boiler or process heater at least once every hour for each affected 
facility. The flow indicator shall be installed in the vent stream from 
each distillation unit within an affected facility at a point closest to 
the inlet of each boiler or process heater and before being joined with 
any other vent stream.
    (2) A temperature monitoring device in the firebox equipped with a 
continuous recorder and having an accuracy of 1 percent of 
the temperature being

[[Page 472]]

measured expressed in degrees Celsius or 0.5  deg.C, 
whichever is greater, for boilers or process heaters of less than 44 MW 
(150 million Btu/hr) heat input design capacity.
    (3) Monitor and record the periods of operation of the boiler or 
process heater if the design heat input capacity of the boiler or 
process heater is 44 MW (150 million Btu/hr) or greater. The records 
must be readily available for inspection.
    (d) The owner or operator of an affected facility that seeks to 
comply with the TRE index value limit specified under Sec. 60.662(c) 
shall install, calibrate, maintain, and operate according to 
manufacturer's specifications the following equipment, unless 
alternative monitoring procedures or requirements are approved for that 
facility by the Administrator:
    (1) Where an absorber is the final recovery device in the recovery 
system:
    (i) A scrubbing liquid temperature monitoring device having an 
accuracy of 1 percent of the temperature being monitored 
expressed in degrees Celsius or 0.5  deg.C, whichever is 
greater, and a specific gravity monitoring device having an accuracy of 
0.02 specific gravity units, each equipped with a continuous 
recorder, or
    (ii) An organic monitoring device used to indicate the concentration 
level of organic compounds exiting the recovery device based on a 
detection principle such as infrared, photoionization, or thermal 
conductivity, each equipped with a continuous recorder.
    (2) Where a condenser is the final recovery device in the recovery 
system:
    (i) A condenser exit (product side) temperature monitoring device 
equipped with a continuous recorder and having an accuracy of 
1 percent of the temperature being monitored expressed in 
degrees Celsius or 0.5  deg.C, whichever is greater, or
    (ii) An organic monitoring device used to monitor organic compounds 
exiting the recovery device based on a detection principle such as 
infra-red, photoionization, or thermal conductivity, each equipped with 
a continuous recorder.
    (3) Where a carbon adsorber is the final recovery device unit in the 
recovery system:
    (i) An integrating steam flow monitoring device having an accuracy 
of 10 percent, and a carbon bed temperature monitoring 
device having an accuracy of 1 percent of the temperature 
being monitored expressed in degrees Celsius or 0.5  deg.C, 
whichever is greater, both equipped with a continuous recorder, or
    (ii) An organic monitoring device used to indicate the concentration 
level of organic compounds exiting the recovery device based on a 
detection principle such as infra-red, photoionization, or thermal 
conductivity, each equipped with a continuous recorder.
    (e) An owner or operator of an affected facility seeking to 
demonstrate compliance with the standards specified under Sec. 60.662 
with control devices other than incinerator, boiler, process heater, or 
flare; or recovery device other than an absorber, condenser, or carbon 
absorber shall provide to the Administrator information describing the 
operation of the control device or recovery device and the process 
parameter(s) which would indicate proper operation and maintenance of 
the device. The Administrator may request further information and will 
specify appropriate monitoring procedures or requirements.



Sec. 60.664  Test methods and procedures.

    (a) For the purpose of demonstrating compliance with Sec. 60.662, 
all affected facilities shall be run at full operating conditions and 
flow rates during any performance test.
    (b) The following methods in appendix A to this part, except as 
provided under Sec. 60.8(b), shall be used as reference methods to 
determine compliance with the emission limit or percent reduction 
efficiency specified under Sec. 60.662(a).
    (1) Method 1 or 1A, as appropriate, for selection of the sampling 
sites. The control device inlet sampling site for determination of vent 
stream molar composition or TOC (less methane and ethane) reduction 
efficiency shall be prior to the inlet of the control device and after 
the recovery system.
    (2) Method 2, 2A, 2C, or 2D, as appropriate, for determination of 
the gas volumetric flow rates.

[[Page 473]]

    (3) The emission rate correction factor, integrated sampling and 
analysis procedure of Method 3 shall be used to determine the oxygen 
concentration (%O2d) for the purposes of determining 
compliance with the 20 ppmv limit. The sampling site shall be the same 
as that of the TOC samples, and the samples shall be taken during the 
same time that the TOC samples are taken.
    The TOC concentration corrected to 3 percent 02 
(Cc) shall be computed using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.096

where:

Cc=Concentration of TOC corrected to 3 percent O2, 
          dry basis, ppm by volume.
CTOC=Concentration of TOC (minus methane and ethane), dry 
          basis, ppm by volume.
%O2d=Concentration of O2, dry basis, percent by 
          volume.

    (4) Method 18 to determine the concentration of TOC in the control 
device outlet and the concentration of TOC in the inlet when the 
reduction efficiency of the control device is to be determined.
    (i) The sampling time for each run shall be 1 hour in which either 
an integrated sample or four grab samples shall be taken. If grab 
sampling is used then the samples shall be taken at 15-minute intervals.
    (ii) The emission reduction (R) of TOC (minus methane and ethane) 
shall be determined using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.097

where:

R=Emission reduction, percent by weight.
Ei=Mass rate of TOC entering the control device, kg TOC/hr.
Eo=Mass rate of TOC discharged to the atmosphere, kg TOC/hr.

    (iii) The mass rates of TOC (Ei, Eo) shall be 
computed using the following equations:
[GRAPHIC] [TIFF OMITTED] TC16NO91.098

where:

Cij, Coj=Concentration of sample component ``j'' 
          of the gas stream at the inlet and outlet of the control 
          device, respectively, dry basis, ppm by volume.
Mij, Moj=Molecular weight of sample component 
          ``j'' of the gas stream at the inlet and outlet of the control 
          device, respectively, g/g-mole (lb/lb-mole).
Qi, Qo=Flow rate of gas stream at the inlet and 
          outlet of the control device, respectively, dscm/min (dscf/
          hr).
K2=Constant, 2.494 x 10-6 (1/ppm) (g-mole/scm) 
          (kg/g) (min/hr), where standard temperature for (g-mole/scm) 
          is 20  deg.C.

    (iv) The TOC concentration (CTOC) is the sum of the 
individual components and shall be computed for each run using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.099

where:

CTOC=Concentration of TOC (minus methane and ethane), dry 
          basis, ppm by volume.
Cj=Concentration of sample components ``j'', dry basis, ppm 
          by volume.
n=Number of components in the sample.

    (5) When a boiler or process heater with a design heat input 
capacity of 44 MW (150 million Btu/hour) or greater is used to seek to 
comply with Sec. 60.662(a), the requirement for an initial performance 
test is waived, in accordance with Sec. 60.8(b). However, the 
Administrator reserves the option to require testing at such other times 
as may be required, as provided for in section 114 of the Act.
    (c) When a flare is used to seek to comply with Sec. 60.662(b), the 
flare shall comply with the requirements of Sec. 60.18.
    (d) The following test methods in appendix A to this part, except as 
provided under Sec. 60.8(b), shall be used for determining the net 
heating value of

[[Page 474]]

the gas combusted to determine compliance under Sec. 60.662(b) and for 
determining the process vent stream TRE index value to determine 
compliance under Sec. 60.662(c).
    (1)(i) Method 1 or 1A, as appropriate, for selection of the sampling 
site. The sampling site for the vent stream flow rate and molar 
composition determination prescribed in Sec. 60.664(d) (2) and (3) shall 
be, except for the situations outlined in paragraph (d)(1)(ii) of this 
section, prior to the inlet of any control device, prior to any post-
distillation dilution of the stream with air, and prior to any post-
distillation introduction of halogenated compounds into the process vent 
stream. No transverse site selection method is needed for vents smaller 
than 4 inches in diameter.
    (ii) If any gas stream other than the distillation vent stream from 
the affected facility is normally conducted through the final recovery 
device.
    (A) The sampling site for vent stream flow rate and molar 
composition shall be prior to the final recovery device and prior to the 
point at which the nondistillation stream is introduced.
    (B) The efficiency of the final recovery device is determined by 
measuring the TOC concentration using Method 18 at the inlet to the 
final recovery device after the introduction of any nondistillation vent 
stream and at the outlet of the final recovery device.
    (C) This efficiency is applied to the TOC concentration measured 
prior to the final recovery device and prior to the introduction of the 
nondistillation stream to determine the concentration of TOC in the 
distillation vent stream from the final recovery device. This 
concentration of TOC is then used to perform the calculations outlined 
in Sec. 60.664(d) (4) and (5).
    (2) The molar composition of the process vent stream shall be 
determined as follows:
    (i) Method 18 to measure the concentration of TOC including those 
containing halogens.
    (ii) ASTM D1946-77 (incorporation by reference as specified in 
Sec. 60.17 of this part) to measure the concentration of carbon monoxide 
and hydrogen.
    (iii) Method 4 to measure the content of water vapor.
    (3) The volumetric flow rate shall be determined using Method 2, 2A, 
2C, or 2D, as appropriate.
    (4) The net heating value of the vent stream shall be calculated 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.100

where:

HT=Net heating value of the sample, MJ/scm, where the net 
          enthalpy per mole of vent stream is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to one mole is 20  deg.C, 
          as in the definition of Qs (vent stream flow rate).
K1=Constant, 1.740 x 10-7
[GRAPHIC] [TIFF OMITTED] TC16NO91.101

    where standard temperature for
[GRAPHIC] [TIFF OMITTED] TC16NO91.102

    is 20  deg.C.
Cj=Concentration on a wet basis of compound j in ppm, as 
          measured for organics by Method 18 and measured for hydrogen 
          and carbon monoxide by ASTM D1946-77 (incorporation by 
          reference as specified in Sec. 60.17 of this part) as 
          indicated in Sec. 60.664(d)(2).
Hj=Net heat of combustion of compound j, kcal/g-mole, based 
          on combustion at 25  deg.C and 760 mm Hg.

    The heats of combustion of vent stream components would be required 
to be determined using ASTM D2382-76 (incorporation by reference as 
specified in Sec. 60.17 of this part) if published values are not 
available or cannot be calculated.
    (5) The emission rate of TOC in the vent stream shall be calculated 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.103

where:

ETOC=Emission rate of TOC in the sample, kg/hr.
K2=Constant, 2.494x10-6 (l/ppm) (g-mole/scm) (kg/
          g) (min/hr), where standard temperature for (g-mole/scm) is 20 
           deg.C.

[[Page 475]]

Cj=Concentration on a basis of compound j in ppm as measured 
          by Method 18 as indicated in Sec. 60.664(d)(2).
Mj=Molecular weight of sample j, g/g-mole.
Qs=Vent stream flow rate (scm/min) at a temperature of 20 
          deg.C.

    (6) The total process vent stream concentration (by volume) of 
compounds containing halogens (ppmv, by compound) shall be summed from 
the individual concentrations of compounds containing halogens which 
were measured by Method 18.
    (e) For purposes of complying with Sec. 60.662(c) the owner or 
operator of a facility affected by this subpart shall calculate the TRE 
index value of the vent stream using the equation for incineration in 
paragraph (e)(1) of this section for halogenated vent streams. The owner 
or operator of an affected facility with a nonhalogenated vent stream 
shall determine the TRE index value by calculating values using both the 
incinerator equation in (e)(1) and the flare equation in (e)(2) of this 
section and selecting the lower of the two values.
    (1) The equation for calculating the TRE index value of a vent 
stream controlled by an incinerator is as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.104

    (i) where for a vent stream flow rate (scm/min) at a standard 
temperature of 20  deg.C that is greater than or equal to 14.2 scm/min:

TRE=TRE index value.
Qs=Vent stream flow rate (scm/min) at a standard temperature 
          of 20  deg.C.
HT=Vent stream net heating value (MJ/scm), where the net 
          enthalpy per mole of vent stream is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to one mole is 20  deg.C 
          as in the definition of Qs.
Ys=Qs for all vent stream categories listed in 
          Table 1 except for Category E vent streams where 
          Ys=(Qs) (HT)/3.6.
ETOC=Hourly emissions of TOC reported in kg/hr.
a, b, c, d, e, and f are coefficients.

    The set of coefficients that apply to a vent stream can be obtained 
from Table 1.

[[Page 476]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.056

    (ii) where for a vent stream flow rate (scm/min) at a standard 
temperature of 20  deg.C that is less than 14.2 scm/min:

TRE=TRE index value.
Qs=14.2 scm/min.
HT=(FLOW)(HVAL)/14.2.

where by the following inputs are used:


[[Page 477]]


FLOW=Vent stream flow rate (scm/min), at a standard temperature of 20 
          deg.C.
HVAL=Vent stream net heating value (MJ/scm), where the net enthalpy per 
          mole of vent stream is based on combustion at 25  deg.C and 
          760 mm Hg, but the standard temperature for determining the 
          volume corresponding to one mole is 20  deg.C as in definition 
          of Qs.
Ys=14.2 scm/min for all vent stream categories listed in 
          Table 1 except for Category E vent streams, where 
          Ys=(14.2)(HT)/3.6.
ETOC=Hourly emissions of TOC reported in kg/hr.
a, b, c, d, e, and f are coefficients.

    The set of coefficients that apply to a vent stream can be obtained 
from Table 1.
    (2) The equation for calculating the TRE index value of a vent 
stream controlled by a flare is as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.105

where:

TRE=TRE index value.
ETOC=Hourly emission rate of TOC reported in kg/hr.
Qs=Vent stream flow rate (scm/min) at a standard temperature 
          of 20  deg.C.
HT=Vent stream net heating value (MJ/scm) where the net 
          enthalpy per mole of offgas is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to one mole is 20  deg.C 
          as in the definition of Qs.
a, b, c, d, and e are coefficients.

    The set of coefficients that apply to a vent stream shall be 
obtained from Table 2.

               Table 2--Distillation NSPS TRE Coefficients for Vent Streams Controlled by a Flare
----------------------------------------------------------------------------------------------------------------
                                                    a             b             c            d            e
----------------------------------------------------------------------------------------------------------------
HT <11.2 MJ/scm..............................        2.25         0.288        -0.193       -0.0051         2.08
HT >11.2 MJ/scm..............................        0.309        0.0619       -0.0043      -0.0034         2.08
----------------------------------------------------------------------------------------------------------------

    (f) Each owner or operator of an affected facility seeking to comply 
with Sec. 60.660(c)(4) or Sec. 60.662(c) shall recalculate the TRE index 
value for that affected facility whenever process changes are made. 
Examples of process changes include changes in production capacity, 
feedstock type, or catalyst type, or whenever there is replacement, 
removal, or addition of recovery equipment. The TRE index value shall be 
recalculated based on test data, or on best engineering estimates of the 
effects of the change to the recovery system.
    (1) Where the recalculated TRE index value is less than or equal to 
1.0, the owner or operator shall notify the Administrator within 1 week 
of the recalculation and shall conduct a performance test according to 
the methods and procedures required by Sec. 60.664 in order to determine 
compliance with Sec. 60.662(a). Performance tests must be conducted as 
soon as possible after the process change but no later than 180 days 
from the time of the process change.
    (2) Where the initial TRE index value is greater than 8.0 and the 
recalculated TRE index value is less than or equal to 8.0 but greater 
than 1.0, the owner or operator shall conduct a performance test in 
accordance with Secs. 60.8 and 60.664 and shall comply with 
Secs. 60.663, 60.664 and 60.665. Performance tests must be conducted as 
soon as possible after the process change but no later than 180 days 
from the time of the process change.
    (g) Any owner or operator subject to the provisions of this subpart 
seeking to demonstrate compliance with Sec. 60.660(c)(6) shall use 
Method 2, 2A, 2C, or 2D as appropriate, for determination of volumetric 
flow rate.

[[Page 478]]



Sec. 60.665  Reporting and recordkeeping requirements.

    (a) Each owner or operator subject to Sec. 60.662 shall notify the 
Administrator of the specific provisions of Sec. 60.662 (Sec. 60.662 
(a), (b), or (c)) with which the owner or operator has elected to 
comply. Notification shall be submitted with the notification of initial 
start-up required by Sec. 60.7(a)(3). If an owner or operator elects at 
a later date to use an alternative provision of Sec. 60.662 with which 
he or she will comply, then the Administrator shall be notified by the 
owner or operator 90 days before implementing a change and, upon 
implementing the change, a performance test shall be performed as 
specified by Sec. 60.664 within 180 days.
    (b) Each owner or operator subject to the provisions of this subpart 
shall keep an up-to-date, readily accessible record of the following 
data measured during each performance test, and also include the 
following data in the report of the initial performance test required 
under Sec. 60.8. Where a boiler or process heater with a design heat 
input capacity of 44 MW (150 million Btu/hour) or greater is used to 
comply with Sec. 60.662(a), a report containing performance test data 
need not be submitted, but a report containing the information in 
Sec. 60.665(b)(2)(i) is required. The same data specified in this 
section shall be submitted in the reports of all subsequently required 
performance tests where either the emission control efficiency of a 
control device, outlet concentration of TOC, or the TRE index value of a 
vent stream from a recovery system is determined.
    (1) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.662(a) through use 
of either a thermal or catalytic incinerator:
    (i) The average firebox temperature of the incinerator (or the 
average temperature upstream and downstream of the catalyst bed for a 
catalytic incinerator), measured at least every 15 minutes and averaged 
over the same time period of the performance testing, and
    (ii) The percent reduction of TOC determined as specified in 
Sec. 60.664(b) achieved by the incinerator, or the concentration of TOC 
(ppmv, by compound) determined as specified in Sec. 60.664(b) at the 
outlet of the control device on a dry basis corrected to 3 percent 
oxygen.
    (2) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.662(a) through use 
of a boiler or process heater:
    (i) A description of the location at which the vent stream is 
introduced into the boiler or process heater, and
    (ii) The average combustion temperature of the boiler or process 
heater with a design heat input capacity of less than 44 MW (150 million 
Btu/hr) measured at least every 15 minutes and averaged over the same 
time period of the performance testing.
    (3) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.662(b) through use 
of a smokeless flare, flare design (i.e., steam-assisted, air-assisted 
or nonassisted), all visible emission readings, heat content 
determinations, flow rate measurements, and exit velocity determinations 
made during the performance test, continuous records of the flare pilot 
flame monitoring, and records of all periods of operations during which 
the pilot flame is absent.
    (4) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.662(c):
    (i) Where an absorber is the final recovery device in the recovery 
system, the exit specific gravity (or alternative parameter which is a 
measure of the degree of absorbing liquid saturation, if approved by the 
Administrator), and average exit temperature, of the adsorbing liquid 
measured at least every 15 minutes and averaged over the same time 
period of the performance testing (both measured while the vent stream 
is normally routed and constituted), or
    (ii) Where a condenser is the final recovery device in the recovery 
system, the average exit (product side) temperature measured at least 
every 15 minutes and averaged over the same time period of the 
performance testing while the vent stream is routed and constituted 
normally, or
    (iii) Where a carbon adsorber is the final recovery device in the 
recovery system, the total steam mass flow

[[Page 479]]

measured at least every 15 minutes and averaged over the same time 
period of the performance test (full carbon bed cycle), temperature of 
the carbon bed after regeneration (and within 15 minutes of completion 
of any cooling cycle(s)), and duration of the carbon bed steaming cycle 
(all measured while the vent stream is routed and constituted normally), 
or
    (iv) As an alternative to Sec. 60.665(b)(4) ((i), (ii) or (iii), the 
concentration level or reading indicated by the organics monitoring 
device at the outlet of the absorber, condenser, or carbon adsorber, 
measured at least every 15 minutes and averaged over the same time 
period of the performance testing while the vent stream is normally 
routed and constituted.
    (v) All measurements and calculations performed to determine the TRE 
index value of the vent stream.
    (c) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
equipment operating parameters specified to be monitored under 
Sec. 60.663 (a) and (c) as well as up-to-date, readily accessible 
records of periods of operation during which the parameter boundaries 
established during the most recent performance test are exceeded. The 
Administrator may at any time require a report of these data. Where a 
combustion device is used to comply with Sec. 60.662(a), periods of 
operation during which the parameter boundaries established during the 
most recent performance tests are exceeded are defined as follows:
    (1) For thermal incinerators, all 3-hour periods of operation during 
which the average combustion temperature was more than 28  deg. C (50 
deg. F) below the average combustion temperature during the most recent 
performance test at which compliance with Sec. 60.662(a) was determined.
    (2) For catalytic incinerators, all 3-hour periods of operation 
during which the average temperature of the vent stream immediately 
before the catalyst bed is more than 28  deg. C (50  deg. F) below the 
average temperature of the vent stream during the most recent 
performance test at which compliance with Sec. 60.662(a) was determined. 
The owner or operator also shall record all 3-hour periods of operation 
during which the average temperature difference across the catalyst bed 
is less than 80 percent of the average temperature difference of the 
device during the most recent performance test at which compliance with 
Sec. 60.662(a) was determined.
    (3) All 3-hour periods of operation during which the average 
combustion temperature was more than 28  deg. C (50  deg. F) below the 
average combustion temperature during the most recent performance test 
at which compliance with Sec. 60.662(a) was determined for boilers or 
process heaters with a design heat input capacity of less than 44 MW 
(150 million Btu/hr).
    (4) For boilers or process heaters, whenever there is a change in 
the location at which the vent stream is introduced into the flame zone 
as required under Sec. 60.662(a).
    (d) Each owner or operator subject to the provisions of this subpart 
shall keep up to date, readily accessible continuous records of the flow 
indication specified under Sec. 60.663(a)(2), Sec. 60.663(b)(2) and 
Sec. 60.663(c)(1), as well as up-to-date, readily accessible records of 
all periods when the vent stream is diverted from the control device or 
has no flow rate.
    (e) Each owner or operator subject to the provisions of this subpart 
who uses a boiler or process heater with a design heat input capacity of 
44 MW or greater to comply with Sec. 60.662(a) shall keep an up-to-date, 
readily accessible record of all periods of operation of the boiler or 
process heater. (Examples of such records could include records of steam 
use, fuel use, or monitoring data collected pursuant to other State or 
Federal regulatory requirements.)
    (f) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
flare pilot flame monitoring specified under Sec. 60.663(b), as well as 
up-to-date, readily accessible records of all periods of operations in 
which the pilot flame is absent.
    (g) Each owner or operator subject to the provisions of this subpart 
shall

[[Page 480]]

keep up-to-date, readily accessible continuous records of the equipment 
operating parameters specified to be monitored under Sec. 60.663(d), as 
well as up-to-date, readily accessible records of periods of operation 
during which the parameter boundaries established during the most recent 
performance test are exceeded. The Administrator may at any time require 
a report of these data. Where an owner or operator seeks to comply with 
Sec. 60.662(c), periods of operation during which the parameter 
boundaries established during the most recent performance tests are 
exceeded are defined as follows:
    (1) Where an absorber is the final recovery device in a recovery 
system, and where an organic compound monitoring device is not used:
    (i) All 3-hour periods of operation during which the average 
absorbing liquid temperature was more than 11  deg.C (20  deg.F) above 
the average absorbing liquid temperature during the most recent 
performance test, or
    (ii) All 3-hour periods of operation during which the average 
absorbing liquid specific gravity was more than 0.1 unit above, or more 
than 0.1 unit below, the average absorbing liquid specific gravity 
during the most recent performance test (unless monitoring of an 
alternative parameter, which is a measure of the degree of absorbing 
liquid saturation, is approved by the Administrator, in which case he 
will define appropriate parameter boundaries and periods of operation 
during which they are exceeded).
    (2) Where a condenser is the final recovery device in a system, and 
where an organic compound monitoring device is not used, all 3-hour 
periods of operation during which the average exit (product side) 
condenser operating temperature was more than 6  deg.C (1 1  deg.F) 
above the average exit (product side) operating temperature during the 
most recent performance test.
    (3) Where a carbon adsorber is the final recovery device in a 
system, and where an organic compound monitoring device is not used:
    (i) All carbon bed regeneration cycles during which the total mass 
steam flow was more than 10 percent below the total mass steam flow 
during the most recent performance test, or
    (ii) All carbon bed regeneration cycles during which the temperature 
of the carbon bed after regeneration (and after completion of any 
cooling cycle(s)) was more than 10 percent greater than the carbon bed 
temperature (in degrees Celsius) during the most recent performance 
test.
    (4) Where an absorber, condenser, or carbon adsorber is the final 
recovery device in the recovery system and where an organic compound 
monitoring device is used, all 3-hour periods of operation during which 
the average organic compound concentration level or reading of organic 
compounds in the exhaust gases is more than 20 percent greater than the 
exhaust gas organic compound concentration level or reading measured by 
the monitoring device during the most recent performance test.
    (h) Each owner or operator of an affected facility subject to the 
provisions of this subpart and seeking to demonstrate compliance with 
Sec. 60.662(c) shall keep up-to-date, readily accessible records of:
    (1) Any changes in production capacity, feedstock type, or catalyst 
type, or of any replacement, removal or addition of recovery equipment 
or a distillation unit;
    (2) Any recalculation of the TRE index value performed pursuant to 
Sec. 60.664(f); and
    (3) The results of any performance test performed pursuant to the 
methods and procedures required by Sec. 60.664(d).
    (i) Each owner or operator of an affected facility that seeks to 
comply with the requirements of this subpart by complying with the flow 
rate cutoff in Sec. 60.660(c)(6) shall keep up-to-date, readily 
accessible records to indicate that the vent stream flow rate is less 
than 0.008 m\3\/min and of any change in equipment or process operation 
that increases the operating vent stream flow rate, including a 
measurement of the new vent stream flow rate.
    (j) Each owner or operator of an affected facility that seeks to 
comply with the requirements of this subpart by complying with the 
design production capacity provision in Sec. 60.660(c)(5)

[[Page 481]]

shall keep up-to-date, readily accessible records of any change in 
equipment or process operation that increases the design production 
capacity of the process unit in which the affected facility is located.
    (k) Each owner and operator subject to the provisions of this 
subpart is exempt from the quarterly reporting requirements contained in 
Sec. 60.7(c) of the General Provisions.
    (l) Each owner or operator that seeks to comply with the 
requirements of this subpart by complying with the requirements of 
Sec. 60.660 (c)(4), (c)(5), or (c)(6) or Sec. 60.662 shall submit to the 
Administrator semiannual reports of the following recorded information. 
The initial report shall be submitted within 6 months after the initial 
start-up date.
    (1) Exceedances of monitored parameters recorded under Sec. 60.665 
(c) and (g).
    (2) All periods recorded under Sec. 60.665(d) when the vent stream 
is diverted from the control device or has no flow rate.
    (3) All periods recorded under Sec. 60.665(e) when the boiler or 
process heater was not operating.
    (4) All periods recorded under Sec. 60.665(f) in which the pilot 
flame of the flare was absent.
    (5) Any change in equipment or process operation that increases the 
operating vent stream flow rate above the low flow exemption level in 
Sec. 60.660(c)(6), including a measurement of the new vent stream flow 
rate, as recorded under Sec. 60.665(i). These must be reported as soon 
as possible after the change and no later than 180 days after the 
change. These reports may be submitted either in conjunction with 
semiannual reports or as a single separate report. A performance test 
must be completed with the same time period to verify the recalculated 
flow value and to obtain the vent stream characteristics of heating 
value and ETOC. The performance test is subject to the 
requirements of Sec. 60.8 of the General Provisions. Unless the facility 
qualifies for an exemption under the low capacity exemption status in 
Sec. 60.660(c)(5), the facility must begin compliance with the 
requirements set forth in Sec. 60.662.
    (6) Any change in equipment or process operation, as recorded under 
Sec. 60.665(j), that increases the design production capacity above the 
low capacity exemption level in Sec. 60.660(c)(5) and the new capacity 
resulting from the change for the distillation process unit containing 
the affected facility. These must be reported as soon as possible after 
the change and no later than 180 days after the change. These reports 
may be submitted either in conjunction with semiannual reports or as a 
single seperate report. A performance test must be completed within the 
same time period to obtain the vent stream flow rate, heating value, 
ETOC. The performance test is subject to the requirements of 
Sec. 60.8 of the General Provisions. Unless the facility qualifies for 
an exemption under the low flow exemption in Sec. 60.660(c)(6), the 
facility must begin compliance with the requirements set forth in 
Sec. 60.662.
    (7) Any recalculation of the TRE index value, as recorded under 
Sec. 60.665(h).
    (m) The requirements of Sec. 60.665(l) remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternative 
means of compliance surveillance adopted by such State. In that event, 
affected sources within the State will be relieved of the obligation to 
comply with Sec. 60.665(l), provided that they comply with the 
requirements established by the State.
    (n) Each owner or operator that seeks to demonstrate compliance with 
Sec. 60.660(c)(5) must submit to the Administrator an initial report 
detailing the design production capcity of the process unit.
    (o) Each owner or operator that seeks to demonstrate compliance with 
Sec. 60.660(c)(6) must submit to the Administrator an initial report 
including a flow rate measurement using the test methods specified in 
Sec. 60.664.
    (p) The Administrator will specify appropriate reporting and 
recordkeeping requirements where the owner or operator of an affected 
facility complies with the standards specified under

[[Page 482]]

Sec. 60.662 other than as provided under Sec. 60.663(a), (b), (c) and 
(d).

[55 FR 26922, June 29, 1990; 55 FR 36932, Sept. 7, 1990, as amended at 
60 FR 58237, Nov. 27, 1995]



Sec. 60.666  Reconstruction.

    For purposes of this subpart ``fixed capital cost of the new 
components,'' as used in Sec. 60.15, includes the fixed capital cost of 
all depreciable components which are or will be replaced pursuant to all 
continuous programs of component replacement which are commenced within 
any 2-year period following December 30, 1983. For purposes of this 
paragraph, ``commenced'' means that an owner or operator has undertaken 
a continuous program of component replacement or that an owner or 
operator has entered into a contractual obligation to undertake and 
complete, within a reasonable time, a continuous program of component 
replacement.



Sec. 60.667  Chemicals affected by subpart NNN.

------------------------------------------------------------------------
                       Chemical name                           CAS No.*
------------------------------------------------------------------------
Acetaldehyde...............................................      75-07-0
Acetaldol..................................................     107-89-1
Acetic acid................................................      64-19-7
Acetic anhydride...........................................     108-24-7
Acetone....................................................      67-64-1
Acetone cyanohydrin........................................      75-86-5
Acetylene..................................................      74-86-2
Acrylic acid...............................................      79-10-7
Acrylonitrile..............................................     107-13-1
Adipic acid................................................     124-04-9
Adiponitrile...............................................     111-69-3
Alcohols, C-11 or lower, mixtures..........................  ...........
Alcohols, C-12 or higher, mixtures.........................  ...........
Allyl chloride.............................................     107-05-1
Amylene....................................................     513-35-9
Amylenes, mixed............................................  ...........
Aniline....................................................      62-53-3
Benzene....................................................      71-43-2
Benzenesulfonic acid.......................................      98-11-3
Benzenesulfonic acid C10-16-alkyl derivatives, sodium salts   68081-81-2
Benzoic acid, tech.........................................      65-85-0
Benzyl chloride............................................     100-44-7
Biphenyl...................................................      92-52-4
Bisphenol A................................................      80-05-7
Brometone..................................................      76-08-4
1,3-Butadiene..............................................     106-99-0
Butadiene and butene fractions.............................  ...........
n-Butane...................................................     106-97-8
1,4-Butanediol.............................................     110-63-4
Butanes, mixed.............................................  ...........
1-Butene...................................................     106-98-9
2-Butene...................................................   25167-67-3
Butenes, mixed.............................................  ...........
n-Butyl acetate............................................     123-86-4
Butyl acrylate.............................................     141-32-2
n-Butyl alcohol............................................      71-36-3
sec-Butyl alcohol..........................................      78-92-2
tert-Butyl alcohol.........................................      75-65-0
Butylbenzyl phthalate......................................      85-68-7
Butylene glycol............................................     107-88-0
tert-Butyl hydroperoxide...................................      75-91-2
2-Butyne-1,4-diol..........................................     110-65-6
Butyraldehyde..............................................     123-72-8
Butyric anhydride..........................................     106-31-0
Caprolactam................................................     105-60-2
Carbon disulfide...........................................      75-15-0
Carbon tetrabromide........................................     558-13-4
Carbon tetrachloride.......................................      56-23-5
Chlorobenzene..............................................     108-90-7
2-Chloro-4-(ethylamino)-6-(isopropylamino)-s-triazine......    1912-24-9
Chloroform.................................................      67-66-3
p-Chloronitrobenzene.......................................     100-00-5
Chloroprene................................................     126-99-8
Citric acid................................................      77-92-9
Crotonaldehyde.............................................    4170-30-0
Crotonic acid..............................................    3724-65-0
Cumene.....................................................      98-82-8
Cumene hydroperoxide.......................................      80-15-9
Cyanuric chloride..........................................     108-77-0
Cyclohexane................................................     110-82-7
Cyclohexane, oxidized......................................   68512-15-2
Cyclohexanol...............................................     108-93-0
Cyclohexanone..............................................     108-94-1
Cyclohexanone oxime........................................     100-64-1
Cyclohexene................................................     110-83-8
1,3-Cyclopentadiene........................................     542-92-7
Cyclopropane...............................................      75-19-4
Diacetone alcohol..........................................     123-42-2
Dibutanized aromatic concentrate...........................  ...........
1,4-Dichlorobutene.........................................     110-57-6
3,4-Dichloro-1-butene......................................   64037-54-3
Dichlorodifluoromethane....................................      75-71-8
Dichlorodimethylsilane.....................................      75-78-5
Dichlorofluoromethane......................................      75-43-4
    -Dichlorohydrin........................................      96-23-1
Diethanolamine.............................................     111-42-2
Diethylbenzene.............................................   25340-17-4
Diethylene glycol..........................................     111-46-6
Di-n-heptyl-n-nonyl undecyl phthalate......................      85-68-7
Di-isodecyl phthalate......................................   26761-40-0
Diisononyl phthalate.......................................   28553-12-0
Dimethylamine..............................................     124-40-3
Dimethyl terephthalate.....................................     120-61-6
2,4-Dinitrotoluene.........................................     121-14-2
2,4-(and 2,6)-dinitrotoluene...............................     121-14-2
                                                                606-20-2
Dioctyl phthalate..........................................     117-81-7
Dodecene...................................................   25378-22-7
Dodecylbenzene, non linear.................................  ...........
Dodecylbenzenesulfonic acid................................   27176-87-0
Dodecylbenzenesulfonic acid, sodium salt...................   25155-30-0
Epichlorohydrin............................................     106-89-8
Ethanol....................................................      64-17-5
Ethanolamine...............................................     141-43-5
Ethyl acetate..............................................     141-78-6
Ethyl acrylate.............................................     140-88-5
Ethylbenzene...............................................     100-41-4
Ethyl chloride.............................................      75-00-3
Ethyl cyanide..............................................     107-12-0
Ethylene...................................................      74-85-1
Ethylene dibromide.........................................     106-93-4
Ethylene dichloride........................................     107-06-2
Ethylene glycol............................................     107-21-1
Ethylene glycol monobutyl..................................     111-76-2
Ethylene glycol monoethyl ether............................     110-80-5
Ethylene glycol monoethyl ether acetate....................     111-15-9
Ethylene glycol monomethyl ether...........................     109-86-4
Ethylene oxide.............................................      75-21-8
2-Ethylhexanal.............................................   26266-68-2
2-Ethylhexyl alcohol.......................................     104-76-7
(2-Ethylhexyl) amine.......................................     104-75-6

[[Page 483]]

 
Ethylmethylbenzene.........................................   25550-14-5
6-Ethyl-1,2,3,4-tetrahydro 9,10-anthracenedione............   15547-17-8
Formaldehyde...............................................      50-00-0
Glycerol...................................................      56-81-5
n-Heptane..................................................     142-82-5
Heptenes (mixed)...........................................  ...........
Hexadecyl chloride.........................................  ...........
Hexamethylene diamine......................................     124-09-4
Hexamethylene diamine adipate..............................    3323-53-3
Hexamethylenetetramine.....................................     100-97-0
Hexane.....................................................     110-54-3
2-Hexenedinitrile..........................................   13042-02-9
3-Hexenedinitrile..........................................    1119-85-3
Hydrogen cyanide...........................................      74-90-8
Isobutane..................................................      75-28-5
Isobutanol.................................................      78-83-1
Isobutylene................................................     115-11-7
Isobutyraldehyde...........................................      78-84-2
Isodecyl alcohol...........................................   25339-17-7
Isooctyl alcohol...........................................   26952-21-6
Isopentane.................................................      78-78-4
Isophthalic acid...........................................     121-91-5
Isoprene...................................................      78-79-5
Isopropanol................................................      67-63-0
Ketene.....................................................     463-51-4
Linear alcohols, ethoxylated, mixed........................  ...........
Linear alcohols, ethoxylated, and sulfated, sodium salt,     ...........
 mixed.....................................................
Linear alcohols, sulfated, sodium salt, mixed..............  ...........
Linear alkylbenzene........................................     123-01-3
Magnesium acetate..........................................     142-72-3
Maleic anhydride...........................................     108-31-6
Melamine...................................................     108-78-1
Mesityl oxide..............................................     141-79-7
Methacrylonitrile..........................................     126-98-7
Methanol...................................................      67-56-1
Methylamine................................................      74-89-5
ar-Methylbenzenediamine....................................   25376-45-8
Methyl chloride............................................      74-87-3
Methylene chloride.........................................      75-09-2
Methyl ethyl ketone........................................      78-93-3
Methyl iodide..............................................      74-88-4
Methyl isobutyl ketone.....................................     108-10-1
Methyl methacrylate........................................      80-62-6
2-Methylpentane............................................     107-83-5
1-Methyl-2-pyrrolidone.....................................     872-50-4
Methyl tert-butyl ether....................................  ...........
Naphthalene................................................      91-20-3
Nitrobenzene...............................................      98-95-3
1-Nonene...................................................   27215-95-8
Nonyl alcohol..............................................     143-08-8
Nonylphenol................................................   25154-52-3
Nonylphenol, ethoxylated...................................    9016-45-9
Octene.....................................................   25377-83-7
Oil-soluble petroleum sulfonate, calcium salt..............  ...........
Oil-soluble petroleum sulfonate, sodium salt...............  ...........
Pentaerythritol............................................     115-77-5
n-Pentane..................................................     109-66-0
3-Pentenenitrile...........................................    4635-87-4
Pentenes, mixed............................................     109-67-1
Perchloroethylene..........................................     127-18-4
Phenol.....................................................     108-95-2
1-Phenylethyl hydroperoxide................................    3071-32-7
Phenylpropane..............................................     103-65-1
Phosgene...................................................      75-44-5
Phthalic anhydride.........................................      85-44-9
Propane....................................................      74-98-6
Propionaldehyde............................................     123-38-6
Propionic acid.............................................      79-09-4
Propyl alcohol.............................................      71-23-8
Propylene..................................................     115-07-1
Propylene chlorohydrin.....................................      78-89-7
Propylene glycol...........................................      57-55-6
Propylene oxide............................................      75-56-9
Sodium cyanide.............................................     143-33-9
Sorbitol...................................................      50-70-4
Styrene....................................................     100-42-5
Terephthalic acid..........................................     100-21-0
1,1,2,2-Tetrachloroethane..................................      79-34-5
Tetraethyl lead............................................      78-00-2
Tetrahydrofuran............................................     109-99-9
Tetra (methyl-ethyl) lead..................................  ...........
Tetramethyl lead...........................................      75-74-1
Toluene....................................................     108-88-3
Toluene-2,4-diamine........................................      95-80-7
Toluene-2,4-(and, 2,6)-diisocyanate (80/20 mixture)........   26471-62-5
Tribromomethane............................................      75-25-2
1,1,1-Trichloroethane......................................      71-55-6
1,1,2-Trichloroethane......................................      79-00-5
Trichloroethylene..........................................      79-01-6
Trichlorofluoromethane.....................................      75-69-4
1,1,2-Trichloro-1,2,2-trifluoroethane......................      76-13-1
Triethanolamine............................................     102-71-6
Triethylene glycol.........................................     112-27-6
Vinyl acetate..............................................     108-05-4
Vinyl chloride.............................................      75-01-4
Vinylidene chloride........................................      75-35-4
m-Xylene...................................................     108-38-3
o-Xylene...................................................      95-47-6
p-Xylene...................................................     106-42-3
Xylenes (mixed)............................................    1330-20-7
m-Xylenol..................................................     576-26-1
------------------------------------------------------------------------
* CAS numbers refer to the Chemical Abstracts Registry numbers assigned
  to specific chemicals, isomers, or mixtures of chemicals. Some isomers
  or mixtures that are covered by the standards do not have CAS numbers
  assigned to them. The standards apply to all of the chemicals listed,
  whether CAS numbers have been assigned or not.


[55 FR 26942, June 29, 1990, as amended at 60 FR 58237, 58238, Nov. 27, 
1995]



Sec. 60.668  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under Sec. 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to States: 
Sec. 60.663(e).



Subpart OOO--Standards of Performance for Nonmetallic Mineral Processing 
                                 Plants

    Source: 51 FR 31337, Aug. 1, 1985, unless otherwise noted.



Sec. 60.670  Applicability and designation of affected facility.

    (a)(1) Except as provided in paragraphs (a)(2), (b), (c), and (d) of 
this section, the provisions of this subpart are applicable to the 
following affected facilities in fixed or portable nonmetallic mineral 
processing plants: each

[[Page 484]]

crusher, grinding mill, screening operation, bucket elevator, belt 
conveyor, bagging operation, storage bin, enclosed truck or railcar 
loading station. Also, crushers and grinding mills at hot mix asphalt 
facilities that reduce the size of nonmetallic minerals embedded in 
recycled asphalt pavement and subsequent affected facilities up to, but 
not including, the first storage silo or bin are subject to the 
provisions of this subpart.
    (2) The provisions of this subpart do not apply to the following 
operations: All facilities located in underground mines; and stand-alone 
screening operations at plants without crushers or grinding mills.
    (b) An affected facility that is subject to the provisions of 
subpart F or I or that follows in the plant process any facility subject 
to the provisions of subparts F or I of this part is not subject to the 
provisions of this subpart.
    (c) Facilities at the following plants are not subject to the 
provisions of this subpart:
    (1) Fixed sand and gravel plants and crushed stone plants with 
capacities, as defined in Sec. 60.671, of 23 megagrams per hour (25 tons 
per hour) or less;
    (2) Portable sand and gravel plants and crushed stone plants with 
capacities, as defined in Sec. 60.671, of 136 megagrams per hour (150 
tons per hour) or less; and
    (3) Common clay plants and pumice plants with capacities, as defined 
in Sec. 60.671, of 9 megagrams per hour (10 tons per hour) or less.
    (d)(1) When an existing facility is replaced by a piece of equipment 
of equal or smaller size, as defined in Sec. 60.671, having the same 
function as the existing facility, the new facility is exempt from the 
provisions of Secs. 60.672, 60.674, and 60.675 except as provided for in 
paragraph (d)(3) of this section.
    (2) An owner or operator complying with paragraph (d)(1) of this 
section shall submit the information required in Sec. 60.676(a).
    (3) An owner or operator replacing all existing facilities in a 
production line with new facilities does not qualify for the exemption 
described in paragraph (d)(1) of this section and must comply with the 
provisions of Secs. 60.672, 60.674 and 60.675.
    (e) An affected facility under paragraph (a) of this section that 
commences construction, reconstruction, or modification after August 31, 
1983 is subject to the requirements of this part.
    (f) Table 1 of this subpart specifies the provisions of subpart A of 
this part 60 that apply and those that do not apply to owners and 
operators of affected facilities subject to this subpart.

                               Table 1--Applicability of Subpart A To Subpart OOO
----------------------------------------------------------------------------------------------------------------
          Subpart A reference               Applies to Subpart OOO                       Comment
----------------------------------------------------------------------------------------------------------------
60.1, Applicability...................  Yes...........................
60.2, Definitions.....................  Yes...........................
60.3, Units and abbreviations.........  Yes...........................
60.4, Address:
    (a)...............................  Yes...........................
    (b)...............................  Yes...........................
60.5, Determination of construction or  Yes...........................
 modification.
60.6, Review of plans.................  Yes...........................
60.7, Notification and recordkeeping..  Yes...........................  Except in (a)(2) report of anticipated
                                                                         date of initial startup is not required
                                                                         (Sec.  60.676(h)).
60.8, Performance tests...............  Yes...........................  Except in (d), after 30 days notice for
                                                                         an initially scheduled performance
                                                                         test, any rescheduled performance test
                                                                         requires 7 days notice, not 30 days
                                                                         (Sec.  60.675(g)).
60.9, Availability of information.....  Yes...........................
60.10, State authority................  Yes...........................
60.11, Compliance with standards and    Yes...........................  Except in (b) under certain conditions
 maintenance requirements.                                               (Secs.  60.675 (c)(3) and (c)(4)),
                                                                         Method 9 observation may be reduced
                                                                         from 3 hours to 1 hour. Some affected
                                                                         facilities exempted from Method 9 tests
                                                                         (Sec.  60.675(h)).
60.12, Circumvention..................  Yes...........................
60.13, Monitoring requirements........  Yes...........................
60.14, Modification...................  Yes...........................
60.15, Reconstruction.................  Yes...........................

[[Page 485]]

 
60.16, Priority list..................  Yes...........................
60.17, Incorporations by reference....  Yes...........................
60.18, General control device.........  No............................  Flares will not be used to comply with
                                                                         the emission limits.
60.19, General notification and         Yes...........................
 reporting requirements.
----------------------------------------------------------------------------------------------------------

[51 FR 31337, Aug. 1, 1985, as amended at 62 FR 31359, June 9, 1997]



Sec. 60.671  Definitions.

    All terms used in this subpart, but not specifically defined in this 
section, shall have the meaning given them in the Act and in subpart A 
of this part.
    Bagging operation means the mechanical process by which bags are 
filled with nonmetallic minerals.
    Belt conveyor means a conveying device that transports material from 
one location to another by means of an endless belt that is carried on a 
series of idlers and routed around a pulley at each end.
    Bucket elevator means a conveying device of nonmetallic minerals 
consisting of a head and foot assembly which supports and drives an 
endless single or double strand chain or belt to which buckets are 
attached.
    Building means any frame structure with a roof.
    Capacity means the cumulative rated capacity of all initial crushers 
that are part of the plant.
    Capture system means the equipment (including enclosures, hoods, 
ducts, fans, dampers, etc.) used to capture and transport particulate 
matter generated by one or more process operations to a control device.
    Control device means the air pollution control equipment used to 
reduce particulate matter emissions released to the atmosphere from one 
or more process operations at a nonmetallic mineral processing plant.
    Conveying system means a device for transporting materials from one 
piece of equipment or location to another location within a plant. 
Conveying systems include but are not limited to the following: Feeders, 
belt conveyors, bucket elevators and pneumatic systems.
    Crusher means a machine used to crush any nonmetallic minerals, and 
includes, but is not limited to, the following types: jaw, gyratory, 
cone, roll, rod mill, hammermill, and impactor.
    Enclosed truck or railcar loading station means that portion of a 
nonmetallic mineral processing plant where nonmetallic minerals are 
loaded by an enclosed conveying system into enclosed trucks or railcars.
    Fixed plant means any nonmetallic mineral processing plant at which 
the processing equipment specified in Sec. 60.670(a) is attached by a 
cable, chain, turnbuckle, bolt or other means (except electrical 
connections) to any anchor, slab, or structure including bedrock.
    Fugitive emission means particulate matter that is not collected by 
a capture system and is released to the atmosphere at the point of 
generation.
    Grinding mill means a machine used for the wet or dry fine crushing 
of any nonmetallic mineral. Grinding mills include, but are not limited 
to, the following types: hammer, roller, rod, pebble and ball, and fluid 
energy. The grinding mill includes the air conveying system, air 
separator, or air classifier, where such systems are used.
    Initial crusher means any crusher into which nonmetallic minerals 
can be fed without prior crushing in the plant.
    Nonmetallic mineral means any of the following minerals or any 
mixture of which the majority is any of the following minerals:
    (a) Crushed and Broken Stone, including Limestone, Dolomite, 
Granite, Traprock, Sandstone, Quartz, Quartzite, Marl, Marble, Slate, 
Shale, Oil Shale, and Shell.
    (b) Sand and Gravel.
    (c) Clay including Kaolin, Fireclay, Bentonite, Fuller's Earth, Ball 
Clay, and Common Clay.
    (d) Rock Salt.
    (e) Gypsum.

[[Page 486]]

    (f) Sodium Compounds, including Sodium Carbonate, Sodium Chloride, 
and Sodium Sulfate.
    (g) Pumice.
    (h) Gilsonite.
    (i) Talc and Pyrophyllite.
    (j) Boron, including Borax, Kernite, and Colemanite.
    (k) Barite.
    (l) Fluorospar.
    (m) Feldspar.
    (n) Diatomite.
    (o) Perlite.
    (p) Vermiculite.
    (q) Mica.
    (r) Kyanite, including Andalusite, Sillimanite, Topaz, and 
Dumortierite.
    Nonmetallic mineral processing plant means any combination of 
equipment that is used to crush or grind any nonmetallic mineral 
wherever located, including lime plants, power plants, steel mills, 
asphalt concrete plants, portland cement plants, or any other facility 
processing nonmetallic minerals except as provided in Sec. 60.670 (b) 
and (c).
    Portable plant means any nonmetallic mineral processing plant that 
is mounted on any chassis or skids and may be moved by the application 
of a lifting or pulling force. In addition, there shall be no cable, 
chain, turnbuckle, bolt or other means (except electrical connections) 
by which any piece of equipment is attached or clamped to any anchor, 
slab, or structure, including bedrock that must be removed prior to the 
application of a lifting or pulling force for the purpose of 
transporting the unit.
    Production line means all affected facilities (crushers, grinding 
mills, screening operations, bucket elevators, belt conveyors, bagging 
operations, storage bins, and enclosed truck and railcar loading 
stations) which are directly connected or are connected together by a 
conveying system.
    Screening operation means a device for separating material according 
to size by passing undersize material through one or more mesh surfaces 
(screens) in series, and retaining oversize material on the mesh 
surfaces (screens).
    Size means the rated capacity in tons per hour of a crusher, 
grinding mill, bucket elevator, bagging operation, or enclosed truck or 
railcar loading station; the total surface area of the top screen of a 
screening operation; the width of a conveyor belt; and the rated 
capacity in tons of a storage bin.
    Stack emission means the particulate matter that is released to the 
atmosphere from a capture system.
    Storage bin means a facility for storage (including surge bins) or 
nonmetallic minerals prior to further processing or loading.
    Transfer point means a point in a conveying operation where the 
nonmetallic mineral is transferred to or from a belt conveyor except 
where the nonmetallic mineral is being transferred to a stockpile.
    Truck dumping means the unloading of nonmetallic minerals from 
movable vehicles designed to transport nonmetallic minerals from one 
location to another. Movable vehicles include but are not limited to: 
trucks, front end loaders, skip hoists, and railcars.
    Vent means an opening through which there is mechanically induced 
air flow for the purpose of exhausting from a building air carrying 
particulate matter emissions from one or more affected facilities.
    Wet mining operation means a mining or dredging operation designed 
and operated to extract any nonmetallic mineral regulated under this 
subpart from deposits existing at or below the water table, where the 
nonmetallic mineral is saturated with water.
    Wet screening operation means a screening operation at a nonmetallic 
mineral processing plant which removes unwanted material or which 
separates marketable fines from the product by a washing process which 
is designed and operated at all times such that the product is saturated 
with water.

[51 FR 31337, Aug. 1, 1985, as amended at 62 FR 31359, June 9, 1997]



Sec. 60.672  Standard for particulate matter.

    (a) On and after the date on which the performance test required to 
be conducted by Sec. 60.8 is completed, no owner or operator subject to 
the provisions of this subpart shall cause to be discharged into the 
atmosphere from any transfer point on belt conveyors or from any other 
affected facility any stack emissions which:

[[Page 487]]

    (1) Contain particulate matter in excess of 0.05 g/dscm; and
    (2) Exhibit greater than 7 percent opacity, unless the stack 
emissions are discharged from an affected facility using a wet scrubbing 
control device. Facilities using a wet scrubber must comply with the 
reporting provisions of Sec. 60.676 (c), (d), and (e).
    (b) On and after the sixtieth day after achieving the maximum 
production rate at which the affected facility will be operated, but not 
later than 180 days after initial startup as required under Sec. 60.11 
of this part, no owner or operator subject to the provisions of this 
subpart shall cause to be discharged into the atmosphere from any 
transfer point on belt conveyors or from any other affected facility any 
fugitive emissions which exhibit greater than 10 percent opacity, except 
as provided in paragraphs (c), (d), and (e) of this section.
    (c) On and after the sixtieth day after achieving the maximum 
production rate at which the affected facility will be operated, but not 
later than 180 days after initial startup as required under Sec. 60.11 
of this part, no owner or operator shall cause to be discharged into the 
atmosphere from any crusher, at which a capture system is not used, 
fugitive emissions which exhibit greater than 15 percent opacity.
    (d) Truck dumping of nonmetallic minerals into any screening 
operation, feed hopper, or crusher is exempt from the requirements of 
this section.
    (e) If any transfer point on a conveyor belt or any other affected 
facility is enclosed in a building, then each enclosed affected facility 
must comply with the emission limits in paragraphs (a), (b) and (c) of 
this section, or the building enclosing the affected facility or 
facilities must comply with the following emission limits:
    (1) No owner or operator shall cause to be discharged into the 
atmosphere from any building enclosing any transfer point on a conveyor 
belt or any other affected facility any visible fugitive emissions 
except emissions from a vent as defined in Sec. 60.671.
    (2) No owner or operator shall cause to be discharged into the 
atmosphere from any vent of any building enclosing any transfer point on 
a conveyor belt or any other affected facility emissions which exceed 
the stack emissions limits in paragraph (a) of this section.
    (f) On and after the sixtieth day after achieving the maximum 
production rate at which the affected facility will be operated, but not 
later than 180 days after initial startup as required under Sec. 60.11 
of this part, no owner or operator shall cause to be discharged into the 
atmosphere from any baghouse that controls emissions from only an 
individual, enclosed storage bin, stack emissions which exhibit greater 
than 7 percent opacity.
    (g) Owners or operators of multiple storage bins with combined stack 
emissions shall comply with the emission limits in paragraph (a)(1) and 
(a)(2) of this section.
    (h) On and after the sixtieth day after achieving the maximum 
production rate at which the affected facility will be operated, but not 
later than 180 days after initial startup, no owner or operator shall 
cause to be discharged into the atmosphere any visible emissions from:
    (1) Wet screening operations and subsequent screening operations, 
bucket elevators, and belt conveyors that process saturated material in 
the production line up to the next crusher, grinding mill or storage 
bin.
    (2) Screening operations, bucket elevators, and belt conveyors in 
the production line downstream of wet mining operations, where such 
screening operations, bucket elevators, and belt conveyors process 
saturated materials up to the first crusher, grinding mill, or storage 
bin in the production line.

[51 FR 31337, Aug. 1, 1985, as amended at 62 FR 31359, June 9, 1997]



Sec. 60.673  Reconstruction.

    (a) The cost of replacement of ore-contact surfaces on processing 
equipment shall not be considered in calculating either the ``fixed 
capital cost of the new components'' or the ``fixed capital cost that 
would be required to construct a comparable new facility'' under 
Sec. 60.15. Ore-contact surfaces are crushing surfaces; screen meshes, 
bars, and plates; conveyor belts; and elevator buckets.
    (b) Under Sec. 60.15, the ``fixed capital cost of the new 
components'' includes

[[Page 488]]

the fixed capital cost of all depreciable components (except components 
specified in paragraph (a) of this section) which are or will be 
replaced pursuant to all continuous programs of component replacement 
commenced within any 2-year period following August 31, 1983.



Sec. 60.674  Monitoring of operations.

    The owner or operator of any affected facility subject to the 
provisions of this subpart which uses a wet scrubber to control 
emissions shall install, calibrate, maintain and operate the following 
monitoring devices:
    (a) A device for the continuous measurement of the pressure loss of 
the gas stream through the scrubber. The monitoring device must be 
certified by the manufacturer to be accurate within 250 
pascals 1 inch water gauge pressure and must be calibrated 
on an annual basis in accordance with manufacturer's instructions.
    (b) A device for the continuous measurement of the scrubbing liquid 
flow rate to the wet scrubber. The monitoring device must be certified 
by the manufacturer to be accurate within 5 percent of 
design scrubbing liquid flow rate and must be calibrated on an annual 
basis in accordance with manufacturer's instructions.



Sec. 60.675  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b). 
Acceptable alternative methods and procedures are given in paragraph (e) 
of this section.
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.672(a) as follows:
    (1) Method 5 or Method 17 shall be used to determine the particulate 
matter concentration. The sample volume shall be at least 1.70 dscm (60 
dscf). For Method 5, if the gas stream being sampled is at ambient 
temperature, the sampling probe and filter may be operated without 
heaters. If the gas stream is above ambient temperature, the sampling 
probe and filter may be operated at a temperature high enough, but no 
higher than 121  deg.C (250  deg.F), to prevent water condensation on 
the filter.
    (2) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity.
    (c)(1) In determining compliance with the particulate matter 
standards in Sec. 60.672 (b) and (c), the owner or operator shall use 
Method 9 and the procedures in Sec. 60.11, with the following additions:
    (i) The minimum distance between the observer and the emission 
source shall be 4.57 meters (15 feet).
    (ii) The observer shall, when possible, select a position that 
minimizes interference from other fugitive emission sources (e.g., road 
dust). The required observer position relative to the sun (Method 9, 
Section 2.1) must be followed.
    (iii) For affected facilities using wet dust suppression for 
particulate matter control, a visible mist is sometimes generated by the 
spray. The water mist must not be confused with particulate matter 
emissions and is not to be considered a visible emission. When a water 
mist of this nature is present, the observation of emissions is to be 
made at a point in the plume where the mist is no longer visible.
    (2) In determining compliance with the opacity of stack emissions 
from any baghouse that controls emissions only from an individual 
enclosed storage bin under Sec. 60.672(f) of this subpart, using Method 
9, the duration of the Method 9 observations shall be 1 hour (ten 6-
minute averages).
    (3) When determining compliance with the fugitive emissions standard 
for any affected facility described under Sec. 60.672(b) of this 
subpart, the duration of the Method 9 observations may be reduced from 3 
hours (thirty 6-minute averages) to 1 hour (ten 6-minute averages) only 
if the following conditions apply:
    (i) There are no individual readings greater than 10 percent 
opacity; and
    (ii) There are no more than 3 readings of 10 percent for the 1-hour 
period.
    (4) When determining compliance with the fugitive emissions standard 
for any crusher at which a capture system is not used as described under

[[Page 489]]

Sec. 60.672(c) of this subpart, the duration of the Method 9 
observations may be reduced from 3 hours (thirty 6-minute averages) to 1 
hour (ten 6-minute averages) only if the following conditions apply:
    (i) There are no individual readings greater than 15 percent 
opacity; and
    (ii) There are no more than 3 readings of 15 percent for the 1-hour 
period.
    (d) In determining compliance with Sec. 60.672(e), the owner or 
operator shall use Method 22 to determine fugitive emissions. The 
performance test shall be conducted while all affected facilities inside 
the building are operating. The performance test for each building shall 
be at least 75 minutes in duration, with each side of the building and 
the roof being observed for at least 15 minutes.
    (e) The owner or operator may use the following as alternatives to 
the reference methods and procedures specified in this section:
    (1) For the method and procedure of paragraph (c) of this section, 
if emissions from two or more facilities continuously interfere so that 
the opacity of fugitive emissions from an individual affected facility 
cannot be read, either of the following procedures may be used:
    (i) Use for the combined emission stream the highest fugitive 
opacity standard applicable to any of the individual affected facilities 
contributing to the emissions stream.
    (ii) Separate the emissions so that the opacity of emissions from 
each affected facility can be read.
    (f) To comply with Sec. 60.676(d), the owner or operator shall 
record the measurements as required in Sec. 60.676(c) using the 
monitoring devices in Sec. 60.674 (a) and (b) during each particulate 
matter run and shall determine the averages.
    (g) If, after 30 days notice for an initially scheduled performance 
test, there is a delay (due to operational problems, etc.) in conducting 
any rescheduled performance test required in this section, the owner or 
operator of an affected facility shall submit a notice to the 
Administrator at least 7 days prior to any rescheduled performance test.
    (h) Initial Method 9 performance tests under Sec. 60.11 of this part 
and Sec. 60.675 of this subpart are not required for:
    (1) Wet screening operations and subsequent screening operations, 
bucket elevators, and belt conveyors that process saturated material in 
the production line up to, but not including the next crusher, grinding 
mill or storage bin.
    (2) Screening operations, bucket elevators, and belt conveyors in 
the production line downstream of wet mining operations, that process 
saturated materials up to the first crusher, grinding mill, or storage 
bin in the production line.

[54 FR 6680, Feb. 14, 1989, as amended at 62 FR 31360, June 9, 1997]



Sec. 60.676  Reporting and recordkeeping.

    (a) Each owner or operator seeking to comply with Sec. 60.670(d) 
shall submit to the Administrator the following information about the 
existing facility being replaced and the replacement piece of equipment.
    (1) For a crusher, grinding mill, bucket elevator, bagging 
operation, or enclosed truck or railcar loading station:
    (i) The rated capacity in tons per hour of the existing facility 
being replaced and
    (ii) The rated capacity in tons per hour of the replacement 
equipment.
    (2) For a screening operation:
    (i) The total surface area of the top screen of the existing 
screening operation being replaced and
    (ii) The total surface area of the top screen of the replacement 
screening operation.
    (3) For a conveyor belt:
    (i) The width of the existing belt being replaced and
    (ii) The width of the replacement conveyor belt.
    (4) For a storage bin:
    (i) The rated capacity in tons of the existing storage bin being 
replaced and
    (ii) The rated capacity in tons of replacement storage bins.
    (b) [Reserved]
    (c) During the initial performance test of a wet scrubber, and daily 
thereafter, the owner or operator shall record the measurements of both 
the

[[Page 490]]

change in pressure of the gas stream across the scrubber and the 
scrubbing liquid flow rate.
    (d) After the initial performance test of a wet scrubber, the owner 
or operator shall submit semiannual reports to the Administrator of 
occurrences when the measurements of the scrubber pressure loss (or 
gain) and liquid flow rate differ by more than 30 percent 
from the averaged determined during the most recent performance test.
    (e) The reports required under paragraph (d) shall be postmarked 
within 30 days following end of the second and fourth calendar quarters.
    (f) The owner or operator of any affected facility shall submit 
written reports of the results of all performance tests conducted to 
demonstrate compliance with the standards set forth in Sec. 60.672 of 
this subpart, including reports of opacity observations made using 
Method 9 to demonstrate compliance with Sec. 60.672(b), (c), and (f), 
and reports of observations using Method 22 to demonstrate compliance 
with Sec. 60.672(e).
    (g) The owner or operator of any screening operation, bucket 
elevator, or belt conveyor that processes saturated material and is 
subject to Sec. 60.672(h) and subsequently processes unsaturated 
materials, shall submit a report of this change within 30 days following 
such change. This screening operation, bucket elevator, or belt conveyor 
is then subject to the 10 percent opacity limit in Sec. 60.672(b) and 
the emission test requirements of Sec. 60.11 and this subpart. Likewise 
a screening operation, bucket elevator, or belt conveyor that processes 
unsaturated material but subsequently processes saturated material shall 
submit a report of this change within 30 days following such change. 
This screening operation, bucket elevator, or belt conveyor is then 
subject to the no visible emission limit in Sec. 60.672(h).
    (h) The subpart A requirement under Sec. 60.7(a)(2) for notification 
of the anticipated date of initial startup of an affected facility shall 
be waived for owners or operators of affected facilities regulated under 
this subpart.
    (i) A notification of the actual date of initial startup of each 
affected facility shall be submitted to the Administrator.
    (1) For a combination of affected facilities in a production line 
that begin actual initial startup on the same day, a single notification 
of startup may be submitted by the owner or operator to the 
Administrator. The notification shall be postmarked within 15 days after 
such date and shall include a description of each affected facility, 
equipment manufacturer, and serial number of the equipment, if 
available.
    (2) For portable aggregate processing plants, the notification of 
the actual date of initial startup shall include both the home office 
and the current address or location of the portable plant.
    (j) The requirements of this section remain in force until and 
unless the Agency, in delegating enforcement authority to a State under 
section 111(c) of the Act, approves reporting requirements or an 
alternative means of compliance surveillance adopted by such States. In 
that event, affected facilities within the State will be relieved of the 
obligation to comply with the reporting requirements of this section, 
provided that they comply with requirements established by the State.

[51 FR 31337, Aug. 1, 1985, as amended at 54 FR 6680, Feb. 14, 1989; 62 
FR 31360, June 9, 1997]



  Subpart PPP--Standard of Performance for Wool Fiberglass Insulation 
                        Manufacturing      Plants

    Source: 50 FR 7699, Feb. 25, 1985, unless otherwise noted.



Sec. 60.680  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each rotary spin wool fiberglass insulation manufacturing line.
    (b) The owner or operator of any facility under paragraph (a) of 
this section that commences construction, modification, or 
reconstruction after February 7, 1984, is subject to the requirements of 
this subpart.

[[Page 491]]



Sec. 60.681  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act and in subpart A of this part.
    Glass pull rate means the mass of molten glass utilized in the 
manufacture of wool fiberglass insulation at a single manufacturing line 
in a specified time period.
    Manufacturing line means the manufacturing equipment comprising the 
forming section, where molten glass is fiberized and a fiberglass mat is 
formed; the curing section, where the binder resin in the mat is 
thermally ``set;'' and the cooling section, where the mat is cooled.
    Rotary spin means a process used to produce wool fiberglass 
insulation by forcing molten glass through numerous small orifices in 
the side wall of a spinner to form continuous glass fibers that are then 
broken into discrete lengths by high velocity air flow.
    Wool fiberglass insulation means a thermal insulation material 
composed of glass fibers and made from glass produced or melted at the 
same facility where the manufacturing line is located.



Sec. 60.682  Standard for particulate matter.

    On and after the date on which the performance test required to be 
conducted by Sec. 60.8 is completed, no owner or operator subject to the 
provisions of this subpart shall cause to be discharged into the 
atmosphere from any affected facility any gases which contain 
particulate matter in excess of 5.5 kg/Mg (11.0 1b/ton) of glass pulled.



Sec. 60.683  Monitoring of operations.

    (a) An owner or operator subject to the provisions of this subpart 
who uses a wet scrubbing control device to comply with the mass emission 
standard shall install, calibrate, maintain, and operate monitoring 
devices that measure the gas pressure drop across each scrubber and the 
scrubbing liquid flow rate to each scrubber. The pressure drop monitor 
is to be certified by its manufacturer to be accurate within 
250 pascals (1 inch water gauge) over its 
operating range, and the flow rate monitor is to be certified by its 
manufacturer to be accurate within 5 percent over its 
operating range.
    (b) An owner or operator subject to the provisions of this subpart 
who uses a wet electrostatic precipitator control device to comply with 
the mass emission standard shall install, calibrate, maintain, and 
operate monitoring devices that measure the primary and secondary 
current (amperes) and voltage in each electrical field and the inlet 
water flow rate. In addition, the owner or operator shall determine the 
total residue (total solids) content of the water entering the control 
device once per day using Method 209A, ``Total Residue Dried at 103-105 
deg. C,'' in Standard Methods for the Examination of Water and 
Wastewater, 15th Edition, 1980 (incorporated by reference--see 
Sec. 60.17). Total residue shall be reported as percent by weight. All 
monitoring devices required under this paragraph are to be certified by 
their manufacturers to be accurate within 5 percent over 
their operating range.
    (c) All monitoring devices required under this section are to be 
recalibrated quarterly in accordance with procedures under 
Sec. 60.13(b).



Sec. 60.684  Recordkeeping and reporting requirements.

    (a) At 30-minute intervals during each 2-hour test run of each 
performance test of a wet scrubber control device and at least once 
every 4 hours thereafter, the owner or operator shall record the 
measurements required by Sec. 60.683(a).
    (b) At 30-minute intervals during each 2-hour test run of each 
performance test of a wet electrostatic precipitator control device and 
at least once every 4 hours thereafter, the owner or operator shall 
record the measurements required by Sec. 60.683(b), except that the 
concentration of total residue in the water shall be recorded once 
during each performance test and once per day thereafter.
    (c) Records of the measurements required in paragraphs (a) and (b) 
of this section must be retained for at least 2 years.
    (d) Each owner or operator shall submit written semiannual reports 
of exceedances of control device operating parameters required to be 
monitored

[[Page 492]]

by paragraphs (a) and (b) of this section and written documentation of, 
and a report of corrective maintenance required as a result of, 
quarterly calibrations of the monitoring devices required in 
Sec. 60.683(c). For the purpose of these reports, exceedances are 
defined as any monitoring data that are less than 70 percent of the 
lowest value or greater than 130 percent of the highest value of each 
operating parameter recorded during the most recent performance test.
    (e) The requirements of this section remain in force until and 
unless the Agency, in delegating enforcement authority to a State under 
section 111(c) of the Act, approves reporting requirements or an 
alternative means of compliance surveillance adopted by such State. In 
that event, affected facilities within the State will be relieved of the 
obligation to comply with this section, provided that they comply with 
the requirements established by the State.



Sec. 60.685  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use as reference methods and procedures the test 
methods in appendix A of this part or other methods and procedures as 
specified in this section, except as provided in Sec. 60.8(b).
    (b) The owner or operator shall conduct performance tests while the 
product with the highest loss on ignition (LOI) expected to be produced 
by the affected facility is being manufactured.
    (c) The owner or operator shall determine compliance with the 
particulate matter standard in Sec. 60.682 as follows:
    (1) The emission rate (E) of particulate matter shall be computed 
for each run using the following equation:

E=(Ct Qsd)/(Pavg K)

where:

E=emission rate of particulate matter, kg/Mg (lb/ton).
Ct=concentration of particulate matter, g/dscm (g/dscf).
Qsd=volumetric flow rate of effluent gas, dscm/hr (dscf/hr).
Pavg=average glass pull rate, Mg/hr (ton/hr).
K=conversion factor, 1000 g/kg (453.6 g/lb).

    (2) Method 5E shall be used to determine the particulate matter 
concentration (Ct) and the volumetric flow rate 
(Qsd) of the effluent gas. The sampling time and sample 
volume shall be at least 120 minutes and 2.55 dscm (90 dscf).
    (3) The average glass pull rate (Pavg) for the 
manufacturing line shall be the arithmetic average of three glass pull 
rate (Pi) determinations taken at intervals of at least 30 
minutes during each run.

The individual glass pull rates (Pi) shall be computed using 
the following equation:

Pi=K' Ls Wm M [1.0-(LOI/100)]

where:

Pi=glass pull rate at interval ``i'', Mg/hr (ton/hr).
Ls=line speed, m/min (ft/min).
Wm=trimmed mat width, m (ft).
M=mat gram weight, g/m2 (lb/ft2).
LOI=loss on ignition, weight percent.
K'=conversion factor, 6 x 10-5 (min-Mg)/ (hr-g) 
          [3 x 10-2 (min-ton)/(hr-lb)].

    (i) ASTM Standard Test Method D2584-68 (Reapproved 1979) 
(incorporated by reference--see Sec. 60.17), shall be used to determine 
the LOI for each run.
    (ii) Line speed (Ls), trimmed mat width (Wm), 
and mat gram weight (M) shall be determined for each run from the 
process information or from direct measurements.
    (d) To comply with Sec. 60.684(d), the owner or operator shall 
record measurements as required in Sec. 60.684 (a) and (b) using the 
monitoring devices in Sec. 60.683 (a) and (b) during the particulate 
matter runs.

[54 FR 6680, Feb. 14, 1989]



 Subpart QQQ--Standards of Performance for VOC Emissions From Petroleum 
                     Refinery     Wastewater Systems

    Source: 53 FR 47623, Nov. 23, 1988, unless otherwise noted.



Sec. 60.690  Applicability and designation of affected facility.

    (a)(1) The provisions of this subpart apply to affected facilities 
located in petroleum refineries for which construction, modification, or 
reconstruction is commenced after May 4, 1987.
    (2) An individual drain system is a separate affected facility.

[[Page 493]]

    (3) An oil-water separator is a separate affected facility.
    (4) An aggregate facility is a separate affected facility.
    (b) Notwithstanding the provisions of 40 CFR 60.14(e)(2), the 
construction or installation of a new individual drain system shall 
constitute a modification to an affected facility described in 
Sec. 60.690(a)(4). For purposes of this paragraph, a new individual 
drain system shall be limited to all process drains and the first common 
junction box.



Sec. 60.691  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act or in subpart A of 40 CFR part 60, and the 
following terms shall have the specific meanings given them.
    Active service means that a drain is receiving refinery wastewater 
from a process unit that will continuously maintain a water seal.
    Aggregate facility means an individual drain system together with 
ancillary downstream sewer lines and oil-water separators, down to and 
including the secondary oil-water separator, as applicable.
    Catch basin means an open basin which serves as a single collection 
point for stormwater runoff received directly from refinery surfaces and 
for refinery wastewater from process drains.
    Closed vent system means a system that is not open to the atmosphere 
and that is composed of piping, connections, and, if necessary, flow-
inducing devices that transport gas or vapor from an emission source to 
a control device. If gas or vapor from regulated equipment are routed to 
a process (e.g., to a petroleum refinery fuel gas system), the process 
shall not be considered a closed vent system and is not subject to the 
closed vent system standards.
    Completely closed drain system means an individual drain system that 
is not open to the atmosphere and is equipped and operated with a closed 
vent system and control device complying with the requirements of 
Sec. 60.692-5.
    Control device means an enclosed combustion device, vapor recovery 
system or flare.
    Fixed roof means a cover that is mounted to a tank or chamber in a 
stationary manner and which does not move with fluctuations in 
wastewater levels.
    Floating roof means a pontoon-type or double-deck type cover that 
rests on the liquid surface.
    Gas-tight means operated with no detectable emissions.
    Individual drain system means all process drains connected to the 
first common downstream junction box. The term includes all such drains 
and common junction box, together with their associated sewer lines and 
other junction boxes, down to the receiving oil-water separator.
    Junction box means a manhole or access point to a wastewater sewer 
system line.
    No detectable emissions means less than 500 ppm above background 
levels, as measured by a detection instrument in accordance with Method 
21 in appendix A of 40 CFR part 60.
    Non-contact cooling water system means a once-through drain, 
collection and treatment system designed and operated for collecting 
cooling water which does not come into contact with hydrocarbons or oily 
wastewater and which is not recirculated through a cooling tower.
    Oil-water separator means wastewater treatment equipment used to 
separate oil from water consisting of a separation tank, which also 
includes the forebay and other separator basins, skimmers, weirs, grit 
chambers, and sludge hoppers. Slop oil facilities, including tanks, are 
included in this term along with storage vessels and auxiliary equipment 
located between individual drain systems and the oil-water separator. 
This term does not include storage vessels or auxiliary equipment which 
do not come in contact with or store oily wastewater.
    Oily wastewater means wastewater generated during the refinery 
process which contains oil, emulsified oil, or other hydrocarbons. Oily 
wastewater originates from a variety of refinery processes including 
cooling water, condensed stripping steam, tank draw-off, and contact 
process water.

[[Page 494]]

    Petroleum means the crude oil removed from the earth and the oils 
derived from tar sands, shale, and coal.
    Petroleum refinery means any facility engaged in producing gasoline, 
kerosene, distillate fuel oils, residual fuel oils, lubricants, or other 
products through the distillation of petroleum, or through the 
redistillation of petroleum, cracking, or reforming unfinished petroleum 
derivatives.
    Sewer line means a lateral, trunk line, branch line, ditch, channel, 
or other conduit used to convey refinery wastewater to downstream 
components of a refinery wastewater treatment system. This term does not 
include buried, below-grade sewer lines.
    Slop oil means the floating oil and solids that accumulate on the 
surface of an oil-water separator.
    Storage vessel means any tank, reservoir, or container used for the 
storage of petroleum liquids, including oily wastewater.
    Stormwater sewer system means a drain and collection system designed 
and operated for the sole purpose of collecting stormwater and which is 
segregated from the process wastewater collection system.
    Wastewater system means any component, piece of equipment, or 
installation that receives, treats, or processes oily wastewater from 
petroleum refinery process units.
    Water seal controls means a seal pot, p-leg trap, or other type of 
trap filled with water that has a design capability to create a water 
barrier between the sewer and the atmosphere.

[53 FR 47623, Nov. 23, 1985, as amended at 60 FR 43259, Aug. 18, 1995]



Sec. 60.692-1  Standards: General.

    (a) Each owner or operator subject to the provisions of this subpart 
shall comply with the requirements of Secs. 60.692-1 to 60.692-5 and 
with Secs. 60.693-1 and 60.693-2, except during periods of startup, 
shutdown, or malfunction.
    (b) Compliance with Secs. 60.692-1 to 60.692-5 and with 
Secs. 60.693-1 and 60.693-2 will be determined by review of records and 
reports, review of performance test results, and inspection using the 
methods and procedures specified in Sec. 60.696.
    (c) Permission to use alternative means of emission limitation to 
meet the requirements of Secs. 60.692-2 through 60.692-4 may be granted 
as provided in Sec. 60.694.
    (d)(1) Stormwater sewer systems are not subject to the requirements 
of this subpart.
    (2) Ancillary equipment, which is physically separate from the 
wastewater system and does not come in contact with or store oily 
wastewater, is not subject to the requirements of this subpart.
    (3) Non-contact cooling water systems are not subject to the 
requirements of this subpart.
    (4) An owner or operator shall demonstrate compliance with the 
exclusions in paragraphs (d)(1), (2), and (3) of this section as 
provided in Sec. 60.697 (h), (i), and (j).



Sec. 60.692-2  Standards: Individual drain systems.

    (a)(1) Each drain shall be equipped with water seal controls.
    (2) Each drain in active service shall be checked by visual or 
physical inspection initially and monthly thereafter for indications of 
low water levels or other conditions that would reduce the effectiveness 
of the water seal controls.
    (3) Except as provided in paragraph (a)(4) of this section, each 
drain out of active service shall be checked by visual or physical 
inspection initially and weekly thereafter for indications of low water 
levels or other problems that could result in VOC emissions.
    (4) As an alternative to the requirements in paragraph (a)(3) of 
this section, if an owner or operator elects to install a tightly sealed 
cap or plug over a drain that is out of service, inspections shall be 
conducted initially and semiannually to ensure caps or plugs are in 
place and properly installed.
    (5) Whenever low water levels or missing or improperly installed 
caps or plugs are identified, water shall be added or first efforts at 
repair shall be made as soon as practicable, but not later than 24 hours 
after detection, except as provided in Sec. 60.692-6.
    (b)(1) Junction boxes shall be equipped with a cover and may have an 
open vent pipe. The vent pipe shall be at least 90 cm (3 ft) in length 
and shall not exceed 10.2 cm (4 in) in diameter.

[[Page 495]]

    (2) Junction box covers shall have a tight seal around the edge and 
shall be kept in place at all times, except during inspection and 
maintenance.
    (3) Junction boxes shall be visually inspected initially and 
semiannually thereafter to ensure that the cover is in place and to 
ensure that the cover has a tight seal around the edge.
    (4) If a broken seal or gap is identified, first effort at repair 
shall be made as soon as practicable, but not later than 15 calendar 
days after the broken seal or gap is identified, except as provided in 
Sec. 60.692-6.
    (c)(1) Sewer lines shall not be open to the atmosphere and shall be 
covered or enclosed in a manner so as to have no visual gaps or cracks 
in joints, seals, or other emission interfaces.
    (2) The portion of each unburied sewer line shall be visually 
inspected initially and semiannually thereafter for indication of 
cracks, gaps, or other problems that could result in VOC emissions.
    (3) Whenever cracks, gaps, or other problems are detected, repairs 
shall be made as soon as practicable, but not later than 15 calendar 
days after identification, except as provided in Sec. 60.692-6.
    (d) Except as provided in paragraph (e) of this section, each 
modified or reconstructed individual drain system that has a catch basin 
in the existing configuration prior to May 4, 1987 shall be exempt from 
the provisions of this section.
    (e) Refinery wastewater routed through new process drains and a new 
first common downstream junction box, either as part of a new individual 
drain system or an existing individual drain system, shall not be routed 
through a downstream catch basin.



Sec. 60.692-3  Standards: Oil-water separators.

    (a) Each oil-water separator tank, slop oil tank, storage vessel, or 
other auxiliary equipment subject to the requirements of this subpart 
shall be equipped and operated with a fixed roof, which meets the 
following specifications, except as provided in paragraph (d) of this 
section or in Sec. 60.693-2.
    (1) The fixed roof shall be installed to completely cover the 
separator tank, slop oil tank, storage vessel, or other auxiliary 
equipment with no separation between the roof and the wall.
    (2) The vapor space under a fixed roof shall not be purged unless 
the vapor is directed to a control device.
    (3) If the roof has access doors or openings, such doors or openings 
shall be gasketed, latched, and kept closed at all times during 
operation of the separator system, except during inspection and 
maintenance.
    (4) Roof seals, access doors, and other openings shall be checked by 
visual inspection initially and semiannually thereafter to ensure that 
no cracks or gaps occur between the roof and wall and that access doors 
and other openings are closed and gasketed properly.
    (5) When a broken seal or gasket or other problem is identified, 
first efforts at repair shall be made as soon as practicable, but not 
later than 15 calendar days after it is identified, except as provided 
in Sec. 60.692-6.
    (b) Each oil-water separator tank or auxiliary equipment with a 
design capacity to treat more than 16 liters per second (250 gpm) of 
refinery wastewater shall, in addition to the requirements in paragraph 
(a) of this section, be equipped and operated with a closed vent system 
and control device, which meet the requirements of Sec. 60.692-5, except 
as provided in paragraph (c) of this section or in Sec. 60.693-2.
    (c)(1) Each modified or reconstructed oil-water separator tank with 
a maximum design capacity to treat less than 38 liters per second (600 
gpm) of refinery wastewater which was equipped and operated with a fixed 
roof covering the entire separator tank or a portion of the separator 
tank prior to May 4, 1987 shall be exempt from the requirements of 
paragraph (b) of this section, but shall meet the requirements of 
paragraph (a) of this section, or may elect to comply with paragraph 
(c)(2) of this section.
    (2) The owner or operator may elect to comply with the requirements 
of paragraph (a) of this section for the existing fixed roof covering a 
portion of the separator tank and comply with the requirements for 
floating roofs in Sec. 60.693-2 for the remainder of the separator tank.

[[Page 496]]

    (d) Storage vessels, including slop oil tanks and other auxiliary 
tanks that are subject to the standards in Secs. 60.112, 60.112a, and 
60.112b and associated requirements, 40 CFR part 60, subparts K, Ka, or 
Kb are not subject to the requirements of this section.
    (e) Slop oil from an oil-water separator tank and oily wastewater 
from slop oil handling equipment shall be collected, stored, 
transported, recycled, reused, or disposed of in an enclosed system. 
Once slop oil is returned to the process unit or is disposed of, it is 
no longer within the scope of this subpart. Equipment used in handling 
slop oil shall be equipped with a fixed roof meeting the requirements of 
paragraph (a) of this section.
    (f) Each oil-water separator tank, slop oil tank, storage vessel, or 
other auxiliary equipment that is required to comply with paragraph (a) 
of this section, and not paragraph (b) of this section, may be equipped 
with a pressure control valve as necessary for proper system operation. 
The pressure control valve shall be set at the maximum pressure 
necessary for proper system operation, but such that the value will not 
vent continuously.

[53 FR 47623, Nov. 23, 1985, as amended at 60 FR 43259, Aug. 18, 1995]



Sec. 60.692-4  Standards: Aggregate facility.

    A new, modified, or reconstructed aggregate facility shall comply 
with the requirements of Secs. 60.692-2 and 60.692-3.



Sec. 60.692-5  Standards: Closed vent systems and control devices.

    (a) Enclosed combustion devices shall be designed and operated to 
reduce the VOC emissions vented to them with an efficiency of 95 percent 
or greater or to provide a minimum residence time of 0.75 seconds at a 
minimum temperature of 816  deg.C (1,500  deg.F).
    (b) Vapor recovery systems (for example, condensers and adsorbers) 
shall be designed and operated to recover the VOC emissions vented to 
them with an efficiency of 95 percent or greater.
    (c) Flares used to comply with this subpart shall comply with the 
requirements of 40 CFR 60.18.
    (d) Closed vent systems and control devices used to comply with 
provisions of this subpart shall be operated at all times when emissions 
may be vented to them.
    (e)(1) Closed vent systems shall be designed and operated with no 
detectable emissions, as indicated by an instrument reading of less than 
500 ppm above background, as determined during the initial and 
semiannual inspections by the methods specified in Sec. 60.696.
    (2) Closed vent systems shall be purged to direct vapor to the 
control device.
    (3) A flow indicator shall be installed on a vent stream to a 
control device to ensure that the vapors are being routed to the device.
    (4) All gauging and sampling devices shall be gas-tight except when 
gauging or sampling is taking place.
    (5) When emissions from a closed system are detected, first efforts 
at repair to eliminate the emissions shall be made as soon as 
practicable, but not later than 30 calendar days from the date the 
emissions are detected, except as provided in Sec. 60.692-6.



Sec. 60.692-6  Standards: Delay of repair.

    (a) Delay of repair of facilities that are subject to the provisions 
of this subpart will be allowed if the repair is technically impossible 
without a complete or partial refinery or process unit shutdown.
    (b) Repair of such equipment shall occur before the end of the next 
refinery or process unit shutdown.



Sec. 60.692-7  Standards: Delay of compliance.

    (a) Delay of compliance of modified individual drain systems with 
ancillary downstream treatment components will be allowed if compliance 
with the provisions of this subpart cannot be achieved without a 
refinery or process unit shutdown.
    (b) Installation of equipment necessary to comply with the 
provisions of this subpart shall occur no later than the next scheduled 
refinery or process unit shutdown.

[[Page 497]]



Sec. 60.693-1  Alternative standards for individual drain systems.

    (a) An owner or operator may elect to construct and operate a 
completely closed drain system.
    (b) Each completely closed drain system shall be equipped and 
operated with a closed vent system and control device complying with the 
requirements of Sec. 60.692-5.
    (c) An owner or operator must notify the Administrator in the report 
required in 40 CFR 60.7 that the owner or operator has elected to 
construct and operate a completely closed drain system.
    (d) If an owner or operator elects to comply with the provisions of 
this section, then the owner or operator does not need to comply with 
the provisions of Sec. 60.692-2 or Sec. 60.694.
    (e)(1) Sewer lines shall not be open to the atmosphere and shall be 
covered or enclosed in a manner so as to have no visual gaps or cracks 
in joints, seals, or other emission interfaces.
    (2) The portion of each unburied sewer line shall be visually 
inspected initially and semiannually thereafter for indication of 
cracks, gaps, or other problems that could result in VOC emissions.
    (3) Whenever cracks, gaps, or other problems are detected, repairs 
shall be made as soon as practicable, but not later than 15 calendar 
days after identification, except as provided in Sec. 60.692-6.



Sec. 60.693-2  Alternative standards for oil-water separators.

    (a) An owner or operator may elect to construct and operate a 
floating roof on an oil-water separator tank, slop oil tank, storage 
vessel, or other auxiliary equipment subject to the requirements of this 
subpart which meets the following specifications.
    (1) Each floating roof shall be equipped with a closure device 
between the wall of the separator and the roof edge. The closure device 
is to consist of a primary seal and a secondary seal.
    (i) The primary seal shall be a liquid-mounted seal or a mechanical 
shoe seal.
    (A) A liquid-mounted seal means a foam- or liquid-filled seal 
mounted in contact with the liquid between the wall of the separator and 
the floating roof. A mechanical shoe seal means a metal sheet held 
vertically against the wall of the separator by springs or weighted 
levers and is connected by braces to the floating roof. A flexible 
coated fabric (envelope) spans the annular space between the metal sheet 
and the floating roof.
    (B) The gap width between the primary seal and the separator wall 
shall not exceed 3.8 cm (1.5 in.) at any point.
    (C) The total gap area between the primary seal and the separator 
wall shall not exceed 67 cm2/m (3.2 in.2/ft) of 
separator wall perimeter.
    (ii) The secondary seal shall be above the primary seal and cover 
the annular space between the floating roof and the wall of the 
separator.
    (A) The gap width between the secondary seal and the separator wall 
shall not exceed 1.3 cm (0.5 in.) at any point.
    (B) The total gap area between the secondary seal and the separator 
wall shall not exceed 6.7 cm2/m (0.32 in.2/ft) of 
separator wall perimeter.
    (iii) The maximum gap width and total gap area shall be determined 
by the methods and procedures specified in Sec. 60.696(d).
    (A) Measurement of primary seal gaps shall be performed within 60 
calendar days after initial installation of the floating roof and 
introduction of refinery wastewater and once every 5 years thereafter.
    (B) Measurement of secondary seal gaps shall be performed within 60 
calendar days of initial introduction of refinery wastewater and once 
every year thereafter.
    (iv) The owner or operator shall make necessary repairs within 30 
calendar days of identification of seals not meeting the requirements 
listed in paragraphs (a)(1) (i) and (ii) of this section.
    (2) Except as provided in paragraph (a)(4) of this section, each 
opening in the roof shall be equipped with a gasketed cover, seal, or 
lid, which shall be maintained in a closed position at all times, except 
during inspection and maintenance.
    (3) The roof shall be floating on the liquid (i.e., off the roof 
supports) at all

[[Page 498]]

times except during abnormal conditions (i.e., low flow rate).
    (4) The floating roof may be equipped with one or more emergency 
roof drains for removal of stormwater. Each emergency roof drain shall 
be fitted with a slotted membrane fabric cover that covers at least 90 
percent of the drain opening area or a flexible fabric sleeve seal.
    (5)(i) Access doors and other openings shall be visually inspected 
initially and semiannually thereafter to ensure that there is a tight 
fit around the edges and to identify other problems that could result in 
VOC emissions.
    (ii) When a broken seal or gasket on an access door or other opening 
is identified, it shall be repaired as soon as practicable, but not 
later than 30 calendar days after it is identified, except as provided 
in Sec. 60.692-6.
    (b) An owner or operator must notify the Administrator in the report 
required by 40 CFR 60.7 that the owner or operator has elected to 
construct and operate a floating roof under paragraph (a) of this 
section.
    (c) For portions of the oil-water separator tank where it is 
infeasible to construct and operate a floating roof, such as the skimmer 
mechanism and weirs, a fixed roof meeting the requirements of 
Sec. 60.692-3(a) shall be installed.
    (d) Except as provided in paragraph (c) of this section, if an owner 
or operator elects to comply with the provisions of this section, then 
the owner or operator does not need to comply with the provisions of 
Secs. 60.692-3 or 60.694 applicable to the same facilities.

[53 FR 47623, Nov. 23, 1985, as amended at 60 FR 43259, Aug. 18, 1995]



Sec. 60.694  Permission to use alternative means of emission limitation.

    (a) If, in the Administrator's judgment, an alternative means of 
emission limitation will achieve a reduction in VOC emissions at least 
equivalent to the reduction in VOC emissions achieved by the applicable 
requirement in Sec. 60.692, the Administrator will publish in the 
Federal Register a notice permitting the use of the alternative means 
for purposes of compliance with that requirement. The notice may 
condition the permission on requirements related to the operation and 
maintenance of the alternative means.
    (b) Any notice under paragraph (a) of this section shall be 
published only after notice and an opportunity for a hearing.
    (c) Any person seeking permission under this section shall collect, 
verify, and submit to the Administrator information showing that the 
alternative means achieves equivalent emission reductions.



Sec. 60.695  Monitoring of operations.

    (a) Each owner or operator subject to the provisions of this subpart 
shall install, calibrate, maintain, and operate according to 
manufacturer's specifications the following equipment, unless 
alternative monitoring procedures or requirements are approved for that 
facility by the Administrator.
    (1) Where a thermal incinerator is used for VOC emission reduction, 
a temperature monitoring device equipped with a continuous recorder 
shall be used to measure the temperature of the gas stream in the 
combustion zone of the incinerator. The temperature monitoring device 
shall have an accuracy of 1 percent of the temperature being measured in 
 deg.C or 0.5  deg.C (1.0  deg.F), whichever is 
greater.
    (2) Where a catalytic incinerator is used for VOC emission 
reduction, temperature monitoring devices, each equipped with a 
continuous recorder shall be used to measure the temperature in the gas 
stream immediately before and after the catalyst bed of the incinerator. 
The temperature monitoring devices shall have an accuracy of 1 percent 
of the temperature being measured in  deg.C or 0.5  deg.C 
(1.0  deg.F), whichever is greater.
    (3) Where a carbon adsorber is used for VOC emissions reduction, a 
monitoring device that continuously indicates and records the VOC 
concentration level or reading of organics in the exhaust gases of the 
control device outlet gas stream or inlet and outlet gas stream shall be 
used.
    (i) For a carbon adsorption system that regenerates the carbon bed 
directly onsite, a monitoring device that continuously indicates and 
records the volatile organic compound concentration level or reading of 
organics in the

[[Page 499]]

exhaust gases of the control device outlet gas stream or inlet and 
outlet gas stream shall be used.
    (ii) For a carbon adsorption system that does not regenerate the 
carbon bed directly onsite in the control device (e.g., a carbon 
canister), the concentration level of the organic compounds in the 
exhaust vent stream from the carbon adsorption system shall be monitored 
on a regular schedule, and the existing carbon shall be replaced with 
fresh carbon immediately when carbon breakthrough is indicated. The 
device shall be monitored on a daily basis or at intervals no greater 
than 20 percent of the design carbon replacement interval, whichever is 
greater. As an alternative to conducting this monitoring, an owner or 
operator may replace the carbon in the carbon adsorption system with 
fresh carbon at a regular predetermined time interval that is less than 
the carbon replacement interval that is determined by the maximum design 
flow rate and organic concentration in the gas stream vented to the 
carbon adsorption system.
    (4) Where a flare is used for VOC emission reduction, the owner or 
operator shall comply with the monitoring requirements of 40 CFR 
60.18(f)(2).
    (b) Where a VOC recovery device other than a carbon adsorber is used 
to meet the requirements specified in Sec. 60.692-5(a), the owner or 
operator shall provide to the Administrator information describing the 
operation of the control device and the process parameter(s) that would 
indicate proper operation and maintenance of the device. The 
Administrator may request further information and will specify 
appropriate monitoring procedures or requirements.
    (c) An alternative operational or process parameter may be monitored 
if it can be demonstrated that another parameter will ensure that the 
control device is operated in conformance with these standards and the 
control device's design specifications.

[53 FR 47623, Nov. 23, 1985, as amended at 60 FR 43259, Aug. 18, 1995]



Sec. 60.696  Performance test methods and procedures and compliance provisions.

    (a) Before using any equipment installed in compliance with the 
requirements of Sec. 60.692-2, Sec. 60.692-3, Sec. 60.692-4, 
Sec. 60.692-5, or Sec. 60.693, the owner or operator shall inspect such 
equipment for indications of potential emissions, defects, or other 
problems that may cause the requirements of this subpart not to be met. 
Points of inspection shall include, but are not limited to, seals, 
flanges, joints, gaskets, hatches, caps, and plugs.
    (b) The owner or operator of each source that is equipped with a 
closed vent system and control device as required in Sec. 60.692-5 
(other than a flare) is exempt from Sec. 60.8 of the General Provisions 
and shall use Method 21 to measure the emission concentrations, using 
500 ppm as the no detectable emission limit. The instrument shall be 
calibrated each day before using. The calibration gases shall be:
    (1) Zero air (less than 10 ppm of hydrocarbon in air), and
    (2) A mixture of either methane or n-hexane and air at a 
concentration of approximately, but less than, 10,000 ppm methane or n-
hexane.
    (c) The owner or operator shall conduct a performance test 
initially, and at other times as requested by the Administrator, using 
the test methods and procedures in Sec. 60.18(f) to determine compliance 
of flares.
    (d) After installing the control equipment required to meet 
Sec. 60.693-2(a) or whenever sources that have ceased to treat refinery 
wastewater for a period of 1 year or more are placed back into service, 
the owner or operator shall determine compliance with the standards in 
Sec. 60.693-2(a) as follows:
    (1) The maximum gap widths and maximum gap areas between the primary 
seal and the separator wall and between the secondary seal and the 
separator wall shall be determined individually within 60 calendar days 
of the initial installation of the floating roof and introduction of 
refinery wastewater or 60 calendar days after the equipment is placed 
back into service using the following procedure when

[[Page 500]]

the separator is filled to the design operating level and when the roof 
is floating off the roof supports.
    (i) Measure seal gaps around the entire perimeter of the separator 
in each place where a 0.32 cm (0.125 in.) diameter uniform probe passes 
freely (without forcing or binding against seal) between the seal and 
the wall of the separator and measure the gap width and perimetrical 
distance of each such location.
    (ii) The total surface area of each gap described in (d)(1)(i) of 
this section shall be determined by using probes of various widths to 
measure accurately the actual distance from the wall to the seal and 
multiplying each such width by its respective perimetrical distance.
    (iii) Add the gap surface area of each gap location for the primary 
seal and the secondary seal individually, divide the sum for each seal 
by the nominal perimeter of the separator basin and compare each to the 
maximum gap area as specified in Sec. 60.693-2.
    (2) The gap widths and total gap area shall be determined using the 
procedure in paragraph (d)(1) of this section according to the following 
frequency:
    (i) For primary seals, once every 5 years.
    (ii) For secondary seals, once every year.



Sec. 60.697  Recordkeeping requirements.

    (a) Each owner or operator of a facility subject to the provisions 
of this subpart shall comply with the recordkeeping requirements of this 
section. All records shall be retained for a period of 2 years after 
being recorded unless otherwise noted.
    (b)(1) For individual drain systems subject to Sec. 60.692-2, the 
location, date, and corrective action shall be recorded for each drain 
when the water seal is dry or otherwise breached, when a drain cap or 
plug is missing or improperly installed, or other problem is identified 
that could result in VOC emissions, as determined during the initial and 
periodic visual or physical inspection.
    (2) For junction boxes subject to Sec. 60.692-2, the location, date, 
and corrective action shall be recorded for inspections required by 
Sec. 60.692-2(b) when a broken seal, gap, or other problem is identified 
that could result in VOC emissions.
    (3) For sewer lines subject to Secs. 60.692-2 and 60.693-1(e), the 
location, date, and corrective action shall be recorded for inspections 
required by Secs. 60.692-2(c) and 60.693-1(e) when a problem is 
identified that could result in VOC emissions.
    (c) For oil-water separators subject to Sec. 60.692-3, the location, 
date, and corrective action shall be recorded for inspections required 
by by Sec. 60.692-3(a) when a problem is identified that could result in 
VOC emissions.
    (d) For closed vent systems subject to Sec. 60.692-5 and completely 
closed drain systems subject to Sec. 60.693-1, the location, date, and 
corrective action shall be recorded for inspections required by 
Sec. 60.692-5(e) during which detectable emissions are measured or a 
problem is identified that could result in VOC emissions.
    (e)(1) If an emission point cannot be repaired or corrected without 
a process unit shutdown, the expected date of a successful repair shall 
be recorded.
    (2) The reason for the delay as specified in Sec. 60.692-6 shall be 
recorded if an emission point or equipment problem is not repaired or 
corrected in the specified amount of time.
    (3) The signature of the owner or operator (or designee) whose 
decision it was that repair could not be effected without refinery or 
process shutdown shall be recorded.
    (4) The date of successful repair or corrective action shall be 
recorded.
    (f)(1) A copy of the design specifications for all equipment used to 
comply with the provisions of this subpart shall be kept for the life of 
the source in a readily accessible location.
    (2) The following information pertaining to the design 
specifications shall be kept.
    (i) Detailed schematics, and piping and instrumentation diagrams.
    (ii) The dates and descriptions of any changes in the design 
specifications.
    (3) The following information pertaining to the operation and 
maintenance of closed drain systems and closed vent systems shall be 
kept in a readily accessible location.

[[Page 501]]

    (i) Documentation demonstrating that the control device will achieve 
the required control efficiency during maximum loading conditions shall 
be kept for the life of the facility. This documentation is to include a 
general description of the gas streams that enter the control device, 
including flow and volatile organic compound content under varying 
liquid level conditions (dynamic and static) and manufacturer's design 
specifications for the control device. If an enclosed combustion device 
with a minimum residence time of 0.75 seconds and a minimum temperature 
of 816  deg.C (1,500  deg.F) is used to meet the 95-percent requirement, 
documentation that those conditions exist is sufficient to meet the 
requirements of this paragraph.
    (ii) For a carbon adsorption system that does not regenerate the 
carbon bed directly onsite in the control device such as a carbon 
canister, the design analysis shall consider the vent stream 
composition, constituent concentrations, flow rate, relative humidity, 
and temperature. The design analysis shall also establish the design 
exhaust vent stream organic compound concentration level, capacity of 
carbon bed, type and working capacity of activated carbon used for 
carbon bed, and design carbon replacement interval based on the total 
carbon working capacity of the control device and source operating 
schedule.
    (iii) Periods when the closed vent systems and control devices 
required in Sec. 60.692 are not operated as designed, including periods 
when a flare pilot does not have a flame shall be recorded and kept for 
2 years after the information is recorded.
    (iv) Dates of startup and shutdown of the closed vent system and 
control devices required in Sec. 60.692 shall be recorded and kept for 2 
years after the information is recorded.
    (v) The dates of each measurement of detectable emissions required 
in Secs. 60.692, 60.693, or 60.692-5 shall be recorded and kept for 2 
years after the information is recorded.
    (vi) The background level measured during each detectable emissions 
measurement shall be recorded and kept for 2 years after the information 
is recorded.
    (vii) The maximum instrument reading measured during each detectable 
emission measurement shall be recorded and kept for 2 years after the 
information is recorded.
    (viii) Each owner or operator of an affected facility that uses a 
thermal incinerator shall maintain continuous records of the temperature 
of the gas stream in the combustion zone of the incinerator and records 
of all 3-hour periods of operation during which the average temperature 
of the gas stream in the combustion zone is more than 28  deg.C (50 
deg.F) below the design combustion zone temperature, and shall keep such 
records for 2 years after the information is recorded.
    (ix) Each owner or operator of an affected facility that uses a 
catalytic incinerator shall maintain continuous records of the 
temperature of the gas stream both upstream and downstream of the 
catalyst bed of the incinerator, records of all 3-hour periods of 
operation during which the average temperature measured before the 
catalyst bed is more than 28  deg.C (50  deg.F) below the design gas 
stream temperature, and records of all 3-hour periods during which the 
average temperature difference across the catalyst bed is less than 80 
percent of the design temperature difference, and shall keep such 
records for 2 years after the information is recorded.
    (x) Each owner or operator of an affected facility that uses a 
carbon adsorber shall maintain continuous records of the VOC 
concentration level or reading of organics of the control device outlet 
gas stream or inlet and outlet gas stream and records of all 3-hour 
periods of operation during which the average VOC concentration level or 
reading of organics in the exhaust gases, or inlet and outlet gas 
stream, is more than 20 percent greater than the design exhaust gas 
concentration level, and shall keep such records for 2 years after the 
information is recorded.
    (A) Each owner or operator of an affected facility that uses a 
carbon adsorber which is regenerated directly onsite shall maintain 
continuous records of the volatile organic compound concentration level 
or reading of organics of the control device outlet gas stream or inlet 
and outlet gas

[[Page 502]]

stream and records of all 3-hour periods of operation during which the 
average volatile organic compound concentration level or reading of 
organics in the exhaust gases, or inlet and outlet gas stream, is more 
than 20 percent greater than the design exhaust gas concentration level, 
and shall keep such records for 2 years after the information is 
recorded.
    (B) If a carbon adsorber that is not regenerated directly onsite in 
the control device is used, then the owner or operator shall maintain 
records of dates and times when the control device is monitored, when 
breakthrough is measured, and shall record the date and time that the 
existing carbon in the control device is replaced with fresh carbon.
    (g) If an owner or operator elects to install a tightly sealed cap 
or plug over a drain that is out of active service, the owner or 
operator shall keep for the life of a facility in a readily accessible 
location, plans or specifications which indicate the location of such 
drains.
    (h) For stormwater sewer systems subject to the exclusion in 
Sec. 60.692-1(d)(1), an owner or operator shall keep for the life of the 
facility in a readily accessible location, plans or specifications which 
demonstrate that no wastewater from any process units or equipment is 
directly discharged to the stormwater sewer system.
    (i) For ancillary equipment subject to the exclusion in Sec. 60.692-
1(d)(2), an owner or operator shall keep for the life of a facility in a 
readily accessible location, plans or specifications which demonsrate 
that the ancillary equipment does not come in contact with or store oily 
wastewater.
    (j) For non-contact cooling water systems subject to the exclusion 
in Sec. 60.692-1(d)(3), an owner or operator shall keep for the life of 
the facility in a readily accessible location, plans or specifications 
which demonstrate that the cooling water does not contact hydrocarbons 
or oily wastewater and is not recirculated through a cooling tower.

[53 FR 47623, Nov. 23, 1985, as amended at 60 FR 43259, Aug. 18, 1995]



Sec. 60.698  Reporting requirements.

    (a) An owner or operator electing to comply with the provisions of 
Sec. 60.693 shall notify the Administrator of the alternative standard 
selected in the report required in Sec. 60.7.
    (b)(1) Each owner or operator of a facility subject to this subpart 
shall submit to the Administrator within 60 days after initial startup a 
certification that the equipment necessary to comply with these 
standards has been installed and that the required initial inspections 
or tests of process drains, sewer lines, junction boxes, oil-water 
separators, and closed vent systems and control devices have been 
carried out in accordance with these standards. Thereafter, the owner or 
operator shall submit to the Administrator semiannually a certification 
that all of the required inspections have been carried out in accordance 
with these standards.
    (2) Each owner or operator of an affected facility that uses a flare 
shall submit to the Administrator within 60 days after initial startup, 
as required under Sec. 60.8(a), a report of the results of the 
performance test required in Sec. 60.696(c).
    (c) A report that summarizes all inspections when a water seal was 
dry or otherwise breached, when a drain cap or plug was missing or 
improperly installed, or when cracks, gaps, or other problems were 
identified that could result in VOC emissions, including information 
about the repairs or corrective action taken, shall be submitted 
initially and semiannually thereafter to the Administrator.
    (d) As applicable, a report shall be submitted semiannually to the 
Administrator that indicates:
    (1) Each 3-hour period of operation during which the average 
temperature of the gas stream in the combustion zone of a thermal 
incinerator, as measured by the temperature monitoring device, is more 
than 28  deg.C (50  deg.F) below the design combustion zone temperature,
    (2) Each 3-hour period of operation during which the average 
temperature of the gas stream immediately before the catalyst bed of a 
catalytic incinerator, as measured by the temperature monitoring device, 
is more than 28  deg.C

[[Page 503]]

(50  deg.F) below the design gas stream temperature, and any 3-hour 
period during which the average temperature difference across the 
catalyst bed (i.e., the difference between the temperatures of the gas 
stream immediately before and after the catalyst bed), as measured by 
the temperature monitoring device, is less than 80 percent of the design 
temperature difference, or,
    (3) Each 3-hour period of operation during which the average VOC 
concentration level or reading of organics in the exhaust gases from a 
carbon adsorber is more than 20 percent greater than the design exhaust 
gas concentration level or reading.
    (i) Each 3-hour period of operation during which the average 
volatile organic compound concentration level or reading of organics in 
the exhaust gases from a carbon adsorber which is regenerated directly 
onsite is more than 20 percent greater than the design exhaust gas 
concentration level or reading.
    (ii) Each occurrence when the carbon in a carbon adsorber system 
that is not regenerated directly onsite in the control device is not 
replaced at the predetermined interval specified in 
Sec. 60.695(a)(3)(ii).
    (e) If compliance with the provisions of this subpart is delayed 
pursuant to Sec. 60.692-7, the notification required under 40 CFR 
60.7(a)(4) shall include the estimated date of the next scheduled 
refinery or process unit shutdown after the date of notification and the 
reason why compliance with the standards is technically impossible 
without a refinery or process unit shutdown.

[53 FR 47623, Nov. 23, 1985, as amended at 60 FR 43260, Aug. 18, 1995]



Sec. 60.699  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to States:
    Sec. 60.694 Permission to use alternative means of emission 
limitations.

[53 FR 47623, Nov. 23, 1985]



  Subpart RRR--Standards of Performance for Volatile Organic Compound 
Emissions From Synthetic Organic Chemical Manufacturing Industry (SOCMI) 
                            Reactor Processes

    Source: 58 FR 45962, Aug. 31, 1993, unless otherwise noted.

    Effective Date Note: At 58 FR 45962, Aug. 31, 1993, subpart RRR was 
added. This subpart contains information collection and recordkeeping 
requirements which will not become effective until approval has been 
given by the Office of Management and Budget. A document will be 
published in the Federal Register once approval has been obtained.



Sec. 60.700  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to each affected facility 
designated in paragraph (b) of this section that is part of a process 
unit that produces any of the chemicals listed in Sec. 60.707 as a 
product, co-product, by-product, or intermediate, except as provided in 
paragraph (c) of this section.
    (b) The affected facility is any of the following for which 
construction, modification, or reconstruction commenced after June 29, 
1990:
    (1) Each reactor process not discharging its vent stream into a 
recovery system.
    (2) Each combination of a reactor process and the recovery system 
into which its vent stream is discharged.
    (3) Each combination of two or more reactor processes and the common 
recovery system into which their vent streams are discharged.
    (c) Exemptions from the provisions of paragraph (a) of this section 
are as follows:
    (1) Any reactor process that is designed and operated as a batch 
operation is not an affected facility.
    (2) Each affected facility that has a total resource effectiveness 
(TRE) index value greater than 8.0 is exempt from all provisions of this 
subpart except for Secs. 60.702(c); 60.704 (d), (e), and (f); and 60.705 
(g), (l)(1), (l)(6), and (t).
    (3) Each affected facility in a process unit with a total design 
capacity for all chemicals produced within that unit of less than 1 
gigagram per year (1,100

[[Page 504]]

tons per year) is exempt from all provisions of this subpart except for 
the recordkeeping and reporting requirements in Sec. 60.705 (i), (l)(5), 
and (n).
    (4) Each affected facility operated with a vent stream flow rate 
less than 0.011 scm/min is exempt from all provisions of this subpart 
except for the test method and procedure and the recordkeeping and 
reporting requirements in Sec. 60.704(g) and Sec. 70.705 (h), (l)(4), 
and (o).
    (5) If the vent stream from an affected facility is routed to a 
distillation unit subject to subpart NNN and has no other releases to 
the air except for a pressure relief valve, the facility is exempt from 
all provisions of this subpart except for Sec. 60.705(r).
    (6) Any reactor process operating as part of a process unit which 
produces beverage alcohols, or which uses, contains, and produces no VOC 
is not an affected facility.
    (7) Any reactor process that is subject to the provisions of subpart 
DDD is not an affected facility.
    (8) Each affected facility operated with a concentration of total 
organic compounds (TOC) (less methane and ethane) in the vent stream 
less than 300 ppmv as measured by Method 18 or a concentration of TOC in 
the vent stream less than 150 ppmv as measured by Method 25A is exempt 
from all provisions of this subpart except for the test method and 
procedure and the reporting and recordkeeping requirements in 
Sec. 60.704(h) and paragraphs (j), (l)(8), and (p) of Sec. 60.705.
    (Note: The intent of these standards is to minimize emissions of VOC 
through the application of best demonstrated technology (BDT). The 
numerical emission limits in these standards are expressed in terms of 
TOC, measured as TOC less methane and ethane. This emission limit 
reflects the performance of BDT.)

[58 FR 45962, Aug. 31, 1993, as amended at 60 FR 58238, Nov. 27, 1995]



Sec. 60.701  Definitions.

    As used in this subpart, all terms not defined here shall have the 
meaning given them in the Act and in subpart A of part 60, and the 
following terms shall have the specific meanings given them.
    Batch operation means any noncontinuous reactor process that is not 
characterized by steady-state conditions and in which reactants are not 
added and products are not removed simultaneously.
    Boiler means any enclosed combustion device that extracts useful 
energy in the form of steam and is not an incinerator.
    By compound means by individual stream components, not carbon 
equivalents.
    Car-seal means a seal that is placed on a device that is used to 
change the position of a valve (e.g., from opened to closed) in such a 
way that the position of the valve cannot be changed without breaking 
the seal.
    Combustion device means an individual unit of equipment, such as an 
incinerator, flare, boiler, or process heater, used for combustion of a 
vent stream discharged from the process vent.
    Continuous recorder means a data recording device recording an 
instantaneous data value at least once every 15 minutes.
    Flame zone means the portion of the combustion chamber in a boiler 
occupied by the flame envelope.
    Flow indicator means a device which indicates whether gas flow is 
present in a line.
    Halogenated vent stream means any vent stream determined to have a 
total concentration (by volume) of compounds containing halogens of 20 
ppmv (by compound) or greater.
    Incinerator means an enclosed combustion device that is used for 
destroying organic compounds. If there is energy recovery, the energy 
recovery section and the combustion chambers are not of integral design. 
That is, the energy recovery section and the combustion section are not 
physically formed into one manufactured or assembled unit but are joined 
by ducts or connections carrying flue gas.
    Primary fuel means the fuel fired through a burner or a number of 
similar burners. The primary fuel provides the principal heat input to 
the device, and the amount of fuel is sufficient to sustain operation 
without the addition of other fuels.
    Process heater means a device that transfers heat liberated by 
burning fuel directly to process streams or to heat transfer liquids 
other than water.

[[Page 505]]

    Process unit means equipment assembled and connected by pipes or 
ducts to produce, as intermediates or final products, one or more of the 
chemicals in Sec. 60.707. A process unit can operate independently if 
supplied with sufficient feed or raw materials and sufficient product 
storage facilities.
    Product means any compound or chemical listed in Sec. 60.707 which 
is produced for sale as a final product as that chemical, or for use in 
the production of other chemicals or compounds. By-products, co-
products, and intermediates are considered to be products.
    Reactor processes are unit operations in which one or more 
chemicals, or reactants other than air, are combined or decomposed in 
such a way that their molecular structures are altered and one or more 
new organic compounds are formed.
    Recovery device means an individual unit of equipment, such as an 
absorber, carbon adsorber, or condenser, capable of and used for the 
purpose of recovering chemicals for use, reuse, or sale.
    Recovery system means an individual recovery device or series of 
such devices applied to the same vent stream.
    Relief valve means a valve used only to release an unplanned, 
nonroutine discharge. A relief valve discharge results from an operator 
error, a malfunction such as a power failure or equipment failure, or 
other unexpected cause that requires immediate venting of gas from 
process equipment in order to avoid safety hazards or equipment damage.
    Secondary fuel means a fuel fired through a burner other than a 
primary fuel burner. The secondary fuel may provide supplementary heat 
in addition to the heat provided by the primary fuel.
    Total organic compounds or TOC means those compounds measured 
according to the procedures in Sec. 60.704(b)(4). For the purposes of 
measuring molar composition as required in Sec. 60.704(d)(2)(i) and 
Sec. 60.704(d)(2)(ii), hourly emission rate as required in 
Sec. 60.704(d)(5) and Sec. 60.704(e), and TOC concentration as required 
in Sec. 60.705(b)(4) and Sec. 60.705(f)(4), those compounds which the 
Administrator has determined do not contribute appreciably to the 
formation of ozone are to be excluded.
    Total resource effectiveness or TRE index value means a measure of 
the supplemental total resource requirement per unit reduction of TOC 
associated with a vent stream from an affected reactor process facility, 
based on vent stream flow rate, emission rate of TOC, net heating value, 
and corrosion properties (whether or not the vent stream contains 
halogenated compounds), as quantified by the equation given under 
Sec. 60.704(e).
    Vent stream means any gas stream discharged directly from a reactor 
process to the atmosphere or indirectly to the atmosphere after 
diversion through other process equipment. The vent stream excludes 
relief valve discharges and equipment leaks.



Sec. 60.702  Standards.

    Each owner or operator of any affected facility shall comply with 
paragraph (a), (b), or (c) of this section for each vent stream on and 
after the date on which the initial performance test required by 
Sec. 60.8 and Sec. 60.704 is completed, but not later than 60 days after 
achieving the maximum production rate at which the affected facility 
will be operated, or 180 days after the initial start-up, whichever date 
comes first. Each owner or operator shall either:
    (a) Reduce emissions of TOC (less methane and ethane) by 98 weight-
percent, or to a TOC (less methane and ethane) concentration of 20 ppmv, 
on a dry basis corrected to 3 percent oxygen, whichever is less 
stringent. If a boiler or process heater is used to comply with this 
paragraph, then the vent stream shall be introduced into the flame zone 
of the boiler or process heater; or
    (b) Combust the emissions in a flare that meets the requirements of 
Sec. 60.18; or
    (c) Maintain a TRE index value greater than 1.0 without use of a VOC 
emission control device.



Sec. 60.703  Monitoring of emissions and operations.

    (a) The owner or operator of an affected facility that uses an 
incinerator

[[Page 506]]

to seek to comply with the TOC emission limit specified under 
Sec. 60.702(a) shall install, calibrate, maintain, and operate according 
to manufacturer's specifications the following equipment:
    (1) A temperature monitoring device equipped with a continuous 
recorder and having an accuracy of 1 percent of the 
temperature being monitored expressed in degrees Celsius or 
0.5  deg.C, whichever is greater.
    (i) Where an incinerator other than a catalytic incinerator is used, 
a temperature monitoring device shall be installed in the firebox or in 
the ductwork immediately downstream of the firebox in a position before 
any substantial heat exchange is encountered.
    (ii) Where a catalytic incinerator is used, temperature monitoring 
devices shall be installed in the gas stream immediately before and 
after the catalyst bed.
    (2) A flow indicator that provides a record of vent stream flow 
diverted from being routed to the incinerator at least once every 15 
minutes for each affected facility, except as provided in paragraph 
(a)(2)(ii) of this section.
    (i) The flow indicator shall be installed at the entrance to any 
bypass line that could divert the vent stream from being routed to the 
incinerator, resulting in its emission to the atmosphere.
    (ii) Where the bypass line valve is secured in the closed position 
with a car-seal or a lock-and-key type configuration, a flow indicator 
is not required. A visual inspection of the seal or closure mechanism 
shall be performed at least once every month to ensure that the valve is 
maintained in the closed position and the vent stream is not diverted 
through the bypass line.
    (b) The owner or operator of an affected facility that uses a flare 
to seek to comply with Sec. 60.702(b) shall install, calibrate, 
maintain, and operate according to manufacturer's specifications the 
following equipment:
    (1) A heat sensing device, such as an ultraviolet beam sensor or 
thermocouple, at the pilot light to indicate the continuous presence of 
a flame.
    (2) A flow indicator that provides a record of vent stream flow 
diverted from being routed to the flare at least once every 15 minutes 
for each affected facility, except as provided in paragraph (b)(2)(ii) 
of this section.
    (i) The flow indicator shall be installed at the entrance to any 
bypass line that could divert the vent stream from being routed to the 
flare, resulting in its emission to the atmosphere.
    (ii) Where the bypass line valve is secured in the closed position 
with a car-seal or a lock-and-key type configuration, a flow indicator 
is not required. A visual inspection of the seal or closure mechanism 
shall be performed at least once every month to ensure that the valve is 
maintained in the closed position and the vent stream is not diverted 
through the bypass line.
    (c) The owner or operator of an affected facility that uses a boiler 
or process heater to seek to comply with Sec. 60.702(a) shall install, 
calibrate, maintain and operate according to the manufacturer's 
specifications the following equipment:
    (1) A flow indicator that provides a record of vent stream flow 
diverted from being routed to the boiler or process heater at least once 
every 15 minutes for each affected facility, except as provided in 
paragraph (c)(1)(ii) of this section.
    (i) The flow indicator shall be installed at the entrance to any 
bypass line that could divert the vent stream from being routed to the 
boiler or process heater, resulting in its emission to the atmosphere.
    (ii) Where the bypass line valve is secured in the closed position 
with a car-seal or a lock-and-key type configuration, a flow indicator 
is not required. A visual inspection of the seal or closure mechanism 
shall be performed at least once every month to ensure that the valve is 
maintained in the closed position and the vent stream is not diverted 
through the bypass line.
    (2) A temperature monitoring device in the firebox equipped with a 
continuous recorder and having an accuracy of 1 percent of 
the temperature being monitored expressed in degrees Celsius or 
0.5  deg.C, whichever is greater, for boilers or process 
heaters of less than 44 MW (150 million Btu/hr) design heat input 
capacity. Any vent stream introduced with primary fuel into a boiler or 
process heater is exempt from this requirement.

[[Page 507]]

    (d) The owner or operator of an affected facility that seeks to 
demonstrate compliance with the TRE index value limit specified under 
Sec. 60.702(c) shall install, calibrate, maintain, and operate according 
to manufacturer's specifications the following equipment, unless 
alternative monitoring procedures or requirements are approved for that 
facility by the Administrator:
    (1) Where an absorber is the final recovery device in the recovery 
system:
    (i) A scrubbing liquid temperature monitoring device having an 
accuracy of 1 percent of the temperature being monitored 
expressed in degrees Celsius or 0.5  deg.C, whichever is 
greater, and a specific gravity monitoring device having an accuracy of 
0.02 specific gravity units, each equipped with a continuous 
recorder; or
    (ii) An organic monitoring device used to indicate the concentration 
level of organic compounds exiting the recovery device based on a 
detection principle such as infra-red, photoionization, or thermal 
conductivity, each equipped with a continuous recorder.
    (2) Where a condenser is the final recovery device in the recovery 
system:
    (i) A condenser exit (product side) temperature monitoring device 
equipped with a continuous recorder and having an accuracy of 
1 percent of the temperature being monitored expressed in 
degrees Celsius or 0.5  deg.C, whichever is greater; or
    (ii) An organic monitoring device used to indicate the concentration 
level of organic compounds exiting the recovery device based on a 
detection principle such as infra-red, photoionization, or thermal 
conductivity, each equipped with a continuous recorder.
    (3) Where a carbon adsorber is the final recovery device unit in the 
recovery system:
    (i) An integrating steam flow monitoring device having an accuracy 
of 10 percent, and a carbon bed temperature monitoring 
device having an accuracy of 1 percent of the temperature 
being monitored expressed in degrees Celsius or 0.5  deg.C, 
whichever is greater, both equipped with a continuous recorder; or
    (ii) An organic monitoring device used to indicate the concentration 
level of organic compounds exiting the recovery device based on a 
detection principle such as infra-red, photoionization, or thermal 
conductivity, each equipped with a continuous recorder.
    (e) An owner or operator of an affected facility seeking to 
demonstrate compliance with the standards specified under Sec. 60.702 
with a control device other than an incinerator, boiler, process heater, 
or flare; or a recovery device other than an absorber, condenser, or 
carbon adsorber, shall provide to the Administrator information 
describing the operation of the control device or recovery device and 
the process parameter(s) which would indicate proper operation and 
maintenance of the device. The Administrator may request further 
information and will specify appropriate monitoring procedures or 
requirements.



Sec. 60.704  Test methods and procedures.

    (a) For the purpose of demonstrating compliance with Sec. 60.702, 
all affected facilities shall be run at full operating conditions and 
flow rates during any performance test.
    (b) The following methods in Appendix A to this part, except as 
provided under Sec. 60.8(b), shall be used as reference methods to 
determine compliance with the emission limit or percent reduction 
efficiency specified under Sec. 60.702(a).
    (1) Method 1 or 1A, as appropriate, for selection of the sampling 
sites. The control device inlet sampling site for determination of vent 
stream molar composition or TOC (less methane and ethane) reduction 
efficiency shall be prior to the inlet of the control device and after 
the recovery system.
    (2) Method 2, 2A, 2C, or 2D, as appropriate, for determination of 
the gas volumetric flow rates.
    (3) The emission rate correction factor, integrated sampling and 
analysis procedure of Method 3B shall be used to determine the oxygen 
concentration (%O2d) for the purposes of determining 
compliance with the 20 ppmv limit. The sampling site shall be the same 
as that of the TOC samples, and the samples shall be taken during the 
same

[[Page 508]]

time that the TOC samples are taken. The TOC concentration corrected to 
3 percent O2 (Cc) shall be computed using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TR31AU93.006

where:

Cc=Concentration of TOC corrected to 3 percent O2, 
          dry basis, ppm by volume.
CTOC=Concentration of TOC (minus methane and ethane), dry 
          basis, ppm by volume.
%O2d=Concentration of O2, dry basis, percent by 
          volume.

    (4) Method 18 to determine the concentration of TOC in the control 
device outlet and the concentration of TOC in the inlet when the 
reduction efficiency of the control device is to be determined.
    (i) The minimum sampling time for each run shall be 1 hour in which 
either an integrated sample or four grab samples shall be taken. If grab 
sampling is used, then the samples shall be taken at approximately 15-
minute intervals.
    (ii) The emission reduction (R) of TOC (minus methane and ethane) 
shall be determined using the following equation:
[GRAPHIC] [TIFF OMITTED] TR31AU93.007

where:

R=Emission reduction, percent by weight.
Ei=Mass rate of TOC entering the control device, kg TOC/hr.
Eo=Mass rate of TOC discharged to the atmosphere, kg TOC/hr.

    (iii) The mass rates of TOC (Ei, Eo) shall be 
computed using the following equations:
[GRAPHIC] [TIFF OMITTED] TR31AU93.008

where:

Cij, Coj=Concentration of sample component ``j'' 
          of the gas stream at the inlet and outlet of the control 
          device, respectively, dry basis, ppm by volume.
Mij, Moj=Molecular weight of sample component 
          ``j'' of the gas stream at the inlet and outlet of the control 
          device, respectively, g/g-mole (lb/lb-mole).
Qi, Qo=Flow rate of gas stream at the inlet and 
          outlet of the control device, respectively, dscm/min (dscf/
          hr).
K2=Constant, 2.494 x 10-6 (l/ppm) (g-mole/scm) 
          (kg/g) (min/hr), where standard temperature for (g-mole/scm) 
          is 20  deg.C.

    (iv) The TOC concentration (CTOC) is the sum of the 
individual components and shall be computed for each run using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TR31AU93.009

where:

CTOC=Concentration of TOC (minus methane and ethane), dry 
          basis, ppm by volume.
Cj=Concentration of sample components ``j'', dry basis, ppm 
          by volume.
n=Number of components in the sample.
    (5) The requirement for an initial performance test is waived, in 
accordance with Sec. 60.8(b), for the following:
    (i) When a boiler or process heater with a design heat input 
capacity of 44 MW (150 million Btu/hour) or greater is used to seek 
compliance with Sec. 60.702(a).
    (ii) When a vent stream is introduced into a boiler or process 
heater with the primary fuel.
    (iii) The Administrator reserves the option to require testing at 
such other times as may be required, as provided for in section 114 of 
the Act.
    (6) For purposes of complying with the 98 weight-percent reduction 
in Sec. 60.702(a), if the vent stream entering a boiler or process 
heater with a design capacity less than 44 MW (150 million Btu/hour) is 
introduced with the combustion air or as secondary fuel, the weight-
percent reduction of TOC (minus methane and ethane) across the 
combustion device shall be determined by comparing the TOC (minus 
methane and ethane) in all combusted vent streams, primary fuels, and 
secondary fuels with the TOC (minus methane and ethane) exiting the 
combustion device.
    (c) When a flare is used to seek to comply with Sec. 60.702(b), the 
flare shall comply with the requirements of Sec. 60.18.

[[Page 509]]

    (d) The following test methods in Appendix A to this part, except as 
provided under Sec. 60.8(b), shall be used for determining the net 
heating value of the gas combusted to determine compliance under 
Sec. 60.702(b) and for determining the process vent stream TRE index 
value to determine compliance under Sec. 60.700(c)(2) and 
Sec. 60.702(c).
    (1)(i) Method 1 or 1A, as appropriate, for selection of the sampling 
site. The sampling site for the vent stream flow rate and molar 
composition determination prescribed in Sec. 60.704 (d)(2) and (d)(3) 
shall be, except for the situations outlined in paragraph (d)(1)(ii) of 
this section, prior to the inlet of any control device, prior to any 
postreactor dilution of the stream with air, and prior to any 
postreactor introduction of halogenated compounds into the process vent 
stream. No traverse site selection method is needed for vents smaller 
than 4 inches in diameter.
    (ii) If any gas stream other than the reactor vent stream is 
normally conducted through the final recovery device:
    (A) The sampling site for vent stream flow rate and molar 
composition shall be prior to the final recovery device and prior to the 
point at which any nonreactor stream or stream from a nonaffected 
reactor process is introduced.
    (B) The efficiency of the final recovery device is determined by 
measuring the TOC concentration using Method 18 at the inlet to the 
final recovery device after the introduction of any vent stream and at 
the outlet of the final recovery device.
    (C) This efficiency of the final recovery device shall be applied to 
the TOC concentration measured prior to the final recovery device and 
prior to the introduction of any nonreactor stream or stream from a 
nonaffected reactor process to determine the concentration of TOC in the 
reactor process vent stream from the final recovery device. This 
concentration of TOC is then used to perform the calculations outlined 
in Sec. 60.704(d) (4) and (5).
    (2) The molar composition of the process vent stream shall be 
determined as follows:
    (i) Method 18 to measure the concentration of TOC including those 
containing halogens.
    (ii) ASTM D1946-77 (incorporation by reference as specified in 
Sec. 60.17 of this part) to measure the concentration of carbon monoxide 
and hydrogen.
    (iii) Method 4 to measure the content of water vapor.
    (3) The volumetric flow rate shall be determined using Method 2, 2A, 
2C, or 2D, as appropriate.
    (4) The net heating value of the vent stream shall be calculated 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR31AU93.010

where:

HT=Net heating value of the sample, MJ/scm, where the net 
          enthalpy per mole of vent stream is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to one mole is 20  deg.C, 
          as in the definition of Qs (vent stream flow rate).
K1=Constant, 1.740 x 10-7 (l/ppm) (g-mole/scm) 
          (MJ/kcal), where standard temperature for (g-mole/scm) is 20 
          deg.C.
Cj=Concentration on a dry basis of compound j in ppm, as 
          measured for organics by Method 18 and measured for hydrogen 
          and carbon monoxide by ASTM D1946-77 (incorporation by 
          reference as specified in Sec. 60.17 of this part) as 
          indicated in Sec. 60.704(d)(2).
Hj=Net heat of combustion of compound j, kcal/g-mole, based 
          on combustion at 25  deg.C and 760 mm Hg. The heats of 
          combustion of vent stream components would be required to be 
          determined using ASTM D2382-76 (incorporation by reference as 
          specified in Sec. 60.17 of this part) if published values are 
          not available or cannot be calculated.
Bws=Water vapor content of the vent stream, proportion by 
          volume.

    (5) The emission rate of TOC in the vent stream shall be calculated 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR31AU93.011

where:

ETOC=Emission rate of TOC in the sample, kg/hr.

[[Page 510]]

K2=Constant, 2.494 x 10-6 (l/ppm) (g-mole/scm) 
          (kg/g) (min/hr), where standard temperature for (g-mole/scm) 
          is 20  deg.C.
Cj=Concentration on a dry basis of compound j in ppm as 
          measured by Method 18 as indicated in Sec. 60.704(d)(2).
Mj=Molecular weight of sample j, g/g-mole.
Qs=Vent stream flow rate (dscm/min) at a temperature of 20 
          deg.C.

    (6) The total vent stream concentration (by volume) of compounds 
containing halogens (ppmv, by compound) shall be summed from the 
individual concentrations of compounds containing halogens which were 
measured by Method 18.
    (e) For purposes of complying with Sec. 60.700(c)(2) and 
Sec. 60.702(c), the owner or operator of a facility affected by this 
subpart shall calculate the TRE index value of the vent stream using the 
equation for incineration in paragraph (e)(1) of this section for 
halogenated vent streams. The owner or operator of an affected facility 
with a nonhalogenated vent stream shall determine the TRE index value by 
calculating values using both the incinerator equation in (e)(1) of this 
section and the flare equation in (e)(2) of this section and selecting 
the lower of the two values.
    (1) The equation for calculating the TRE index value of a vent 
stream controlled by an incinerator is as follows:
[GRAPHIC] [TIFF OMITTED] TR27NO95.000

    (i) Where for a vent stream flow rate (scm/min) at a standard 
temperature of 20  deg.C that is greater than or equal to 14.2 scm/min:

TRE=TRE index value.
Qs=Vent stream flow rate (scm/min) at a standard temperature 
          of 20  deg.C.
HT=Vent stream net heating value (MJ/scm), where the net 
          enthalpy per mole of vent stream is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to one mole is 20  deg.C 
          as in the definition of Qs.
Ys=Qs for all vent stream categories listed in 
          Table 1 except for Category E vent streams where 
          Ys=(Qs)(HT)/3.6.
ETOC=Hourly emissions of TOC reported in kg/hr.


a, b, c, d, e, and f are coefficients. The set of coefficients that 
apply to a vent stream can be obtained from Table 1.

Table 1.--Total Resource Effectiveness Coefficients for Vent Streams Controlled by an Incinerator Subject to the
                             New Source Performance Standards for Reactor Processes
----------------------------------------------------------------------------------------------------------------
                                               a           b           c           d           e           f
----------------------------------------------------------------------------------------------------------------
   DESIGN CATEGORY A1. FOR HALOGENATED PROCESS VENT STREAMS, IF 0NET HEATING VALUE (MJ/scm)3.5: Qs=Vent Stream Flow Rate (scm/min)
 
----------------------------------------------------------------------------------------------------------------
14.2Qs>18.8..................    19.18370     0.27580     0.75762    -0.13064           0     0.01025
18.8Qs>699..............................    20.00563     0.27580     0.30387    -0.13064           0     0.01025
699Qs>1,400.............................    39.87022     0.29973     0.30387    -0.13064           0     0.01449
1,400Qs>2,100...........................    59.73481     0.31467     0.30387    -0.13064           0     0.01775
2,100Qs>2,800...........................    79.59941     0.32572     0.30387    -0.13064           0     0.02049
2,800Qs>3,500...........................    99.46400     0.33456     0.30387    -0.13064           0     0.02291
 
----------------------------------------------------------------------------------------------------------------
DESIGN CATEGORY A2. FOR HALOGENATED PROCESS VENT STREAMS, IF NET HEATING VALUE (MJ/scm)>3.5: Qs=Vent Stream Flow
                                                 Rate (scm/min)
 
----------------------------------------------------------------------------------------------------------------
14.2Qs>18.8.............................    18.84466     0.26742    -0.20044           0           0     0.01025
18.8Qs>699..............................    19.66658     0.26742    -0.25332           0           0     0.01025
699Qs>1,400.............................    39.19213     0.29062    -0.25332           0           0     0.01449
1,400Qs>2,100...........................    58.71768     0.30511    -0.25332           0           0     0.01775
2,100Qs>2,800...........................    78.24323     0.31582    -0 25332           0           0     0.02049
2,800Qs>3,500...........................    97.76879     0.32439    -0.25332           0           0     0.02291
 
----------------------------------------------------------------------------------------------------------------

[[Page 511]]

 
  DESIGN CATEGORY B. FOR NONHALOGENATED PROCESS VENT STREAMS, IF 0NET HEATING VALUE (MJ/scm)0.48: Qs=Vent Stream Flow Rate (scm/min)
 
----------------------------------------------------------------------------------------------------------------
14.2Qs>1,340.................     8.54245     0.10555     0.09030    -0.17109           0     0.01025
1,340Qs>2,690...........................    16.94386     0.11470     0.09030    -0.17109           0     0.01449
2,690Qs>4,040...........................    25.34528     0.12042     0.09030    -0.17109           0     0.01775
 
----------------------------------------------------------------------------------------------------------------
  DESIGN CATEGORY C. FOR NONHALOGENATED PROCESS VENT STREAMS, IF 0.48NET HEATING VALUE (MJ/scm)1.9:
                                       Qs=Vent Stream Flow Rate (scm/min)
 
----------------------------------------------------------------------------------------------------------------
14.2Qs>1,340.................     9.25233     0.06105     0.31937    -0.16181           0     0.01025
1,340Qs>2,690...........................    18.36363     0.06635     0.31937    -0.16181           0     0.01449
2,690Qs>4,040...........................    27.47492     0.06965     0.31937    -0.16181           0     0.01775
 
----------------------------------------------------------------------------------------------------------------
   DESIGN CATEGORY D. FOR NONHALOGENATED PROCESS VENT STREAMS, IF 1.9NET HEATING VALUE (MJ/scm)3.6:
                                       Qs=Vent Stream Flow Rate (scm/min)
 
----------------------------------------------------------------------------------------------------------------
14.2Qs>1,180.................     6.67868     0.06943     0.02582           0           0     0.01025
1,180Qs>2,370...........................    13.21633     0.07546     0.02582           0           0     0.01449
2,370Qs>3,550...........................    19.75398     0.07922     0.02582           0           0     0.01755
 
----------------------------------------------------------------------------------------------------------------
 DESIGN CATEGORY E. FOR NONHALOGENATED PROCESS VENT STREAMS, IF NET HEATING VALUE (MJ/scm)>3.6: Ys=Dilution Flow
                                          Rate (scm/min)=(Qs) (HT)/3.6
 
----------------------------------------------------------------------------------------------------------------
14.2Ys>1,180.................     6.67868           0           0    -0.00707     0.02220     0.01025
1,180Ys>2,370...........................    13.21633           0           0    -0.00707     0.02412     0.01449
2,370Ys>3,550...........................    19.75398           0           0    -0.00707     0.02533     0.01755
----------------------------------------------------------------------------------------------------------------

    (ii) For a vent stream flow rate (scm/min) at a standard temperature 
of 20  deg.C that is less than 14.2 scm/min:

TRE=TRE index value.
Qs=14.2 scm/min.
HT=(FLOW)(HVAL)/14.2


where the following inputs are used:

FLOW=Vent stream flow rate (scm/min), at a standard temperature of 20 
          deg.C.
HVAL=Vent stream net heating value (MJ/scm), where the net enthalpy per 
          mole of vent stream is based on combustion at 25  deg.C and 
          760 mm Hg, but the standard temperature for determining the 
          volume corresponding to one mole is 20  deg.C as in definition 
          of Qs.
Ys=14.2 scm/min for all vent streams except for Category E 
          vent streams, where Ys=(14.2)(HT)/3.6.
ETOC=Hourly emissions of TOC reported in kg/hr.

a, b, c, d, e, and f are coefficients. The set of coefficients that 
apply to a vent stream can be obtained from Table 1.
    (2) The equation for calculating the TRE index value of a vent 
stream controlled by a flare is as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.013

where:

TRE=TRE index value.
ETOC=Hourly emission rate of TOC reported in kg/hr.
Qs=Vent stream flow rate (scm/min) at a standard temperature 
          of 20  deg.C.
HT=Vent stream net heating value (MJ/scm) where the net 
          enthalpy per mole of offgas is based on combustion at 25 
          deg.C and 760 mm Hg, but the standard temperature for 
          determining the volume corresponding to one mole is 20  deg.C 
          as in the definition of Qs.


[[Page 512]]



a, b, c, d, and e are coefficients. The set of coefficients that apply 
to a vent stream can be obtained from Table 2.

  Table 2.--Total Resource Effectiveness Coefficients for Vent Streams Controlled by a Flare Subject to the New
                               Source Performance Standards for Reactor Processes
----------------------------------------------------------------------------------------------------------------
                                                             a           b           c          d          e
----------------------------------------------------------------------------------------------------------------
HT11.2 MJ/scm.........................................      2.25        0.288      -0.193     -0.0051       2.08
HT11.2 MJ/scm..............................      0.309       0.0619     -0.0043    -0.0034       2.08
----------------------------------------------------------------------------------------------------------------

    (f) Each owner or operator of an affected facility seeking to comply 
with Sec. 60.700(c)(2) or Sec. 60.702(c) shall recalculate the TRE index 
value for that affected facility whenever process changes are made. 
Examples of process changes include changes in production capacity, 
feedstock type, or catalyst type, or whenever there is replacement, 
removal, or addition of recovery equipment. The TRE index value shall be 
recalculated based on test data, or on best engineering estimates of the 
effects of the change on the recovery system.
    (1) Where the recalculated TRE index value is less than or equal to 
1.0, the owner or operator shall notify the Administrator within 1 week 
of the recalculation and shall conduct a performance test according to 
the methods and procedures required by Sec. 60.704 in order to determine 
compliance with Sec. 60.702 (a) or (b). Performance tests must be 
conducted as soon as possible after the process change but no later than 
180 days from the time of the process change.
    (2) Where the recalculated TRE index value is less than or equal to 
8.0 but greater than 1.0, the owner or operator shall conduct a 
performance test in accordance with Sec. 60.8 and Sec. 60.704 and shall 
comply with Sec. 60.703, Sec. 60.704 and Sec. 60.705. Performance tests 
must be conducted as soon as possible after the process change but no 
later than 180 days from the time of the process change.
    (g) Any owner or operator subject to the provisions of this subpart 
seeking to demonstrate compliance with Sec. 60.700(c)(4) shall use 
Method 2, 2A, 2C, or 2D of appendix A to 40 CFR part 60, as appropriate, 
for determination of volumetric flow rate.
    (h) Each owner or operator seeking to demonstrate that a reactor 
process vent stream has a TOC concentration for compliance with the low 
concentration exemption in Sec. 60.700(c)(8) shall conduct an initial 
test to measure TOC concentration.
    (1) The sampling site shall be selected as specified in paragraph 
(d)(1)(i) of this section.
    (2) Method 18 or Method 25A of part 60, appendix A shall be used to 
measure concentration.
    (3) Where Method 18 is used to qualify for the low concentration 
exclusion in Sec. 60.700(c)(8), the procedures in Sec. 60.704(b)(4) (i) 
and (iv) shall be used to measure TOC concentration, and the procedures 
of Sec. 60.704(b)(3) shall be used to correct the TOC concentration to 3 
percent oxygen. To qualify for the exclusion, the results must 
demonstrate that the concentration of TOC, corrected to 3 percent 
oxygen, is below 300 ppm by volume.
    (4) Where Method 25A is used, the following procedures shall be used 
to calculate ppm by volume TOC concentration, corrected to 3 percent 
oxygen:
    (i) Method 25A shall be used only if a single organic compound is 
greater than 50 percent of total TOC, by volume, in the reactor process 
vent stream. This compound shall be the principal organic compound.
    (ii) The principal organic compound may be determined by either 
process knowledge or test data collected using an appropriate EPA 
Reference Method. Examples of information that could constitute process 
knowledge include calculations based on material balances, process 
stoichiometry, or previous test results provided the results are still 
relevant to the current reactor process vent stream conditions.

[[Page 513]]

    (iii) The principal organic compound shall be used as the 
calibration gas for Method 25A.
    (iv) The span value for Method 25A shall be 300 ppmv.
    (v) Use of Method 25A is acceptable if the response from the high-
level calibration gas is at least 20 times the standard deviation of the 
response from the zero calibration gas when the instrument is zeroed on 
the most sensitive scale.
    (vi) The owner or operator shall demonstrate that the concentration 
of TOC including methane and ethane measured by Method 25A, corrected to 
3 percent oxygen, is below 150 ppm by volume to qualify for the low 
concentration exclusion in Sec. 60.700(c)(8).
    (vii) The concentration of TOC shall be corrected to 3 percent 
oxygen using the procedures and equation in paragraph (b)(3) of this 
section.

[58 FR 45962, Aug. 31, 1993, as amended at 60 FR 58238, Nov. 27, 1995]



Sec. 60.705  Reporting and recordkeeping requirements.

    (a) Each owner or operator subject to Sec. 60.702 shall notify the 
Administrator of the specific provisions of Sec. 60.702 (Sec. 60.702 
(a), (b), or (c)) with which the owner or operator has elected to 
comply. Notification shall be submitted with the notification of initial 
start-up required by Sec. 60.7(a)(3). If an owner or operator elects at 
a later date to use an alternative provision of Sec. 60.702 with which 
he or she will comply, then the Administrator shall be notified by the 
owner or operator 90 days before implementing a change and, upon 
implementing the change, a performance test shall be performed as 
specified by Sec. 60.704 no later than 180 days from initial start-up.
    (b) Each owner or operator subject to the provisions of this subpart 
shall keep an up-to-date, readily accessible record of the following 
data measured during each performance test, and also include the 
following data in the report of the initial performance test required 
under Sec. 60.8. Where a boiler or process heater with a design heat 
input capacity of 44 MW (150 million Btu/hour) or greater is used or 
where the reactor process vent stream is introduced as the primary fuel 
to any size boiler or process heater to comply with Sec. 60.702(a), a 
report containing performance test data need not be submitted, but a 
report containing the information in Sec. 60.705(b)(2)(i) is required. 
The same data specified in this section shall be submitted in the 
reports of all subsequently required performance tests where either the 
emission control efficiency of a combustion device, outlet concentration 
of TOC, or the TRE index value of a vent stream from a recovery system 
is determined.
    (1) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.702(a) through use 
of either a thermal or catalytic incinerator:
    (i) The average firebox temperature of the incinerator (or the 
average temperature upstream and downstream of the catalyst bed for a 
catalytic incinerator), measured at least every 15 minutes and averaged 
over the same time period of the performance testing, and
    (ii) The percent reduction of TOC determined as specified in 
Sec. 60.704(b) achieved by the incinerator, or the concentration of TOC 
(ppmv, by compound) determined as specified in Sec. 60.704(b) at the 
outlet of the control device on a dry basis corrected to 3 percent 
oxygen.
    (2) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.702(a) through use 
of a boiler or process heater:
    (i) A description of the location at which the vent stream is 
introduced into the boiler or process heater, and
    (ii) The average combustion temperature of the boiler or process 
heater with a design heat input capacity of less than 44 MW (150 million 
Btu/hr) measured at least every 15 minutes and averaged over the same 
time period of the performance testing.
    (3) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.702(b) through use 
of a smokeless flare, flare design (i.e., steam-assisted, air-assisted 
or nonassisted), all visible emission readings, heat content 
determinations, flow rate measurements, and exit velocity determinations 
made during the performance test, continuous records of the flare pilot 
flame

[[Page 514]]

monitoring, and records of all periods of operations during which the 
pilot flame is absent.
    (4) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.702(c):
    (i) Where an absorber is the final recovery device in the recovery 
system, the exit specific gravity (or alternative parameter which is a 
measure of the degree of absorbing liquid saturation, if approved by the 
Administrator), and average exit temperature, of the absorbing liquid 
measured at least every 15 minutes and averaged over the same time 
period of the performance testing (both measured while the vent stream 
is normally routed and constituted); or
    (ii) Where a condenser is the final recovery device in the recovery 
system, the average exit (product side) temperature measured at least 
every 15 minutes and averaged over the same time period of the 
performance testing while the vent stream is routed and constituted 
normally; or
    (iii) Where a carbon adsorber is the final recovery device in the 
recovery system, the total steam mass flow measured at least every 15 
minutes and averaged over the same time period of the performance test 
(full carbon bed cycle), temperature of the carbon bed after 
regeneration [and within 15 minutes of completion of any cooling 
cycle(s)], and duration of the carbon bed steaming cycle (all measured 
while the vent stream is routed and constituted normally); or
    (iv) As an alternative to Sec. 60.705(b)(4) (i), (ii) or (iii), the 
concentration level or reading indicated by the organics monitoring 
device at the outlet of the absorber, condenser, or carbon adsorber, 
measured at least every 15 minutes and averaged over the same time 
period of the performance testing while the vent stream is normally 
routed and constituted.
    (v) All measurements and calculations performed to determine the TRE 
index value of the vent stream.
    (c) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
equipment operating parameters specified to be monitored under 
Sec. 60.703 (a) and (c) as well as up-to-date, readily accessible 
records of periods of operation during which the parameter boundaries 
established during the most recent performance test are exceeded. The 
Administrator may at any time require a report of these data. Where a 
combustion device is used to comply with Sec. 60.702(a), periods of 
operation during which the parameter boundaries established during the 
most recent performance tests are exceeded are defined as follows:
    (1) For thermal incinerators, all 3-hour periods of operation during 
which the average combustion temperature was more than 28  deg.C (50 
deg.F) below the average combustion temperature during the most recent 
performance test at which compliance with Sec. 60.702(a) was determined.
    (2) For catalytic incinerators, all 3-hour periods of operation 
during which the average temperature of the vent stream immediately 
before the catalyst bed is more than 28  deg.C (50  deg.F) below the 
average temperature of the vent stream during the most recent 
performance test at which compliance with Sec. 60.702(a) was determined. 
The owner or operator also shall record all 3-hour periods of operation 
during which the average temperature difference across the catalyst bed 
is less than 80 percent of the average temperature difference of the bed 
during the most recent performance test at which compliance with 
Sec. 60.702(a) was determined.
    (3) All 3-hour periods of operation during which the average 
combustion temperature was more than 28  deg.C (50  deg.F) below the 
average combustion temperature during the most recent performance test 
at which compliance with Sec. 60.702(a) was determined for boilers or 
process heaters with a design heat input capacity of less than 44 MW 
(150 million Btu/hr) where the vent stream is introduced with the 
combustion air or as a secondary fuel.
    (4) For boilers or process heaters, whenever there is a change in 
the location at which the vent stream is introduced into the flame zone 
as required under Sec. 60.702(a).
    (d) Each owner or operator subject to the provisions of this subpart 
shall keep records of the following:

[[Page 515]]

    (1) Up-to-date, readily accessible continuous records of the flow 
indication specified under Sec. 60.703(a)(2)(i), Sec. 60.703(b)(2)(i) 
and Sec. 60.703(c)(1)(i), as well as up-to-date, readily accessible 
records of all periods and the duration when the vent stream is diverted 
from the control device.
    (2) Where a seal mechanism is used to comply with 
Sec. 60.703(a)(2)(ii), Sec. 60.703(b)(2)(ii), and Sec. 60.703(c)(1)(ii), 
a record of continuous flow is not required. In such cases, the owner or 
operator shall keep up-to-date, readily accessible records of all 
monthly visual inspections of the seals as well as readily accessible 
records of all periods and the duration when the seal mechanism is 
broken, the bypass line valve position has changed, the serial number of 
the broken car-seal has changed, or when the key for a lock-and-key type 
configuration has been checked out.
    (e) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
flare pilot flame monitoring specified under Sec. 60.703(b), as well as 
up-to-date, readily accessible records of all periods of operations in 
which the pilot flame is absent.
    (f) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
equipment operating parameters specified to be monitored under 
Sec. 60.703(d), as well as up-to-date, readily accessible records of 
periods of operation during which the parameter boundaries established 
during the most recent performance test are exceeded. The Administrator 
may at any time require a report of these data. Where an owner or 
operator seeks to comply with Sec. 60.702(c), periods of operation 
during which the parameter boundaries established during the most recent 
performance tests are exceeded are defined as follows:
    (1) Where an absorber is the final recovery device in a recovery 
system, and where an organic compound monitoring device is not used:
    (i) All 3-hour periods of operation during which the average 
absorbing liquid temperature was more than 11  deg.C (20  deg.F) above 
the average absorbing liquid temperature during the most recent 
performance test, or
    (ii) All 3-hour periods of operation during which the average 
absorbing liquid specific gravity was more than 0.1 unit above, or more 
than 0.1 unit below, the average absorbing liquid specific gravity 
during the most recent performance test (unless monitoring of an 
alternative parameter, which is a measure of the degree of absorbing 
liquid saturation, is approved by the Administrator, in which case he 
will define appropriate parameter boundaries and periods of operation 
during which they are exceeded).
    (2) Where a condenser is the final recovery device in a system, and 
where an organic compound monitoring device is not used, all 3-hour 
periods of operation during which the average exit (product side) 
condenser operating temperature was more than 6  deg.C (11  deg.F) above 
the average exit (product side) operating temperature during the most 
recent performance test.
    (3) Where a carbon adsorber is the final recovery device in a 
system, and where an organic compound monitoring device is not used:
    (i) All carbon bed regeneration cycles during which the total mass 
steam flow was more than 10 percent below the total mass steam flow 
during the most recent performance test, or
    (ii) All carbon bed regeneration cycles during which the temperature 
of the carbon bed after regeneration (and after completion of any 
cooling cycle(s)) was more than 10 percent or 5  deg.C greater, 
whichever is less stringent, than the carbon bed temperature (in degrees 
Celsius) during the most recent performance test.
    (4) Where an absorber, condenser, or carbon adsorber is the final 
recovery device in the recovery system and where an organic compound 
monitoring device is used, all 3-hour periods of operation during which 
the average organic compound concentration level or reading of organic 
compounds in the exhaust gases is more than 20 percent greater than the 
exhaust gas organic compound concentration level or reading measured by 
the monitoring device during the most recent performance test.
    (g) Each owner or operator of an affected facility subject to the 
provisions

[[Page 516]]

of this subpart and seeking to demonstrate compliance with 
Sec. 60.702(c) shall keep up-to-date, readily accessible records of:
    (1) Any changes in production capacity, feedstock type, or catalyst 
type, or of any replacement, removal or addition of recovery equipment 
or reactors;
    (2) Any recalculation of the TRE index value performed pursuant to 
Sec. 60.704(f); and
    (3) The results of any performance test performed pursuant to the 
methods and procedures required by Sec. 60.704(d).
    (h) Each owner or operator of an affected facility that seeks to 
comply with the requirements of this subpart by complying with the flow 
rate cutoff in Sec. 60.700(c)(4) shall keep up-to-date, readily 
accessible records to indicate that the vent stream flow rate is less 
than 0.011 scm/min and of any change in equipment or process operation 
that increases the operating vent stream flow rate, including a 
measurement of the new vent stream flow rate.
    (i) Each owner or operator of an affected facility that seeks to 
comply with the requirements of this subpart by complying with the 
design production capacity provision in Sec. 60.700(c)(3) shall keep up-
to-date, readily accessible records of any change in equipment or 
process operation that increases the design production capacity of the 
process unit in which the affected facility is located.
    (j) Each owner or operator of an affected facility that seeks to 
comply with the requirements of this subpart by complying with the low 
concentration exemption in Sec. 60.700(c)(8) shall keep up-to-date, 
readily accessible records of any change in equipment or process 
operation that increases the concentration of the vent stream of the 
affected facility.
    (k) Each owner or operator subject to the provisions of this subpart 
is exempt from the quarterly reporting requirements contained in 
Sec. 60.7(c) of the General Provisions.
    (l) Each owner or operator that seeks to comply with the 
requirements of this subpart by complying with the requirements of 
Sec. 60.700 (c)(2), (c)(3), or (c)(4) or Sec. 60.702 shall submit to the 
Administrator semiannual reports of the following recorded information. 
The initial report shall be submitted within 6 months after the initial 
start-up date.
    (1) Exceedances of monitored parameters recorded under Sec. 60.705 
(c), (f), and (g).
    (2) All periods and duration recorded under Sec. 60.705(d) when the 
vent stream is diverted from the control device to the atmosphere.
    (3) All periods recorded under Sec. 60.705(f) in which the pilot 
flame of the flare was absent.
    (4) Any change in equipment or process operation that increases the 
operating vent stream flow rate above the low flow exemption level in 
Sec. 60.700(c)(4), including a measurement of the new vent stream flow 
rate, as recorded under Sec. 60.705(i). These must be reported as soon 
as possible after the change and no later than 180 days after the 
change. These reports may be submitted either in conjunction with 
semiannual reports or as a single separate report. A performance test 
must be completed within the same time period to verify the recalculated 
flow value and to obtain the vent stream characteristics of heating 
value and ETOC. The performance test is subject to the 
requirements of Sec. 60.8 of the General Provisions. Unless the facility 
qualifies for an exemption under any of the exemption provisions listed 
in Sec. 60.700(c), except for the total resource effectiveness index 
greater than 8.0 exemption in Sec. 60.700(c)(2), the facility must begin 
compliance with the requirements set forth in Sec. 60.702.
    (5) Any change in equipment or process operation, as recorded under 
Sec. 60.705(i), that increases the design production capacity above the 
low capacity exemption level in Sec. 60.700(c)(3) and the new capacity 
resulting from the change for the reactor process unit containing the 
affected facility. These must be reported as soon as possible after the 
change and no later than 180 days after the change. These reports may be 
submitted either in conjunction with semiannual reports or as a single 
separate report. A performance test must be completed within the same 
time period to obtain the vent stream flow rate, heating value, and 
ETOC. The performance test is subject

[[Page 517]]

to the requirements of Sec. 60.8 of the General Provisions. Unless the 
facility qualifies for an exemption under any of the exemption 
provisions listed in Sec. 60.700(c), the facility must begin compliance 
with the requirements set forth in Sec. 60.702.
    (6) Any recalculation of the TRE index value, as recorded under 
Sec. 60.705(g).
    (7) All periods recorded under Sec. 60.705(d) in which the seal 
mechanism is broken or the by-pass line valve position has changed. A 
record of the serial number of the car-seal or a record to show that the 
key to unlock the bypass line valve was checked out must be maintained 
to demonstrate the period, the duration, and frequency in which the 
bypass line was operated.
    (8) Any change in equipment or process operation that increases the 
vent stream concentration above the low concentration exemption level in 
Sec. 60.700(c)(8), including a measurement of the new vent stream 
concentration, as recorded under Sec. 60.705(j). These must be reported 
as soon as possible after the change and no later than 180 days after 
the change. These reports may be submitted either in conjunction with 
semiannual reports or as a single separate report. If the vent stream 
concentration is above 300 ppmv as measured using Method 18 or above 150 
ppmv as measured using Method 25A, a performance test must be completed 
within the same time period to obtain the vent stream flow rate, heating 
value, and ETOC. The performance test is subject to the 
requirements of Sec. 60.8 of the General Provisions. Unless the facility 
qualifies for an exemption under any of the exemption provisions listed 
in Sec. 60.700(c), except for the TRE index greater than 8.0 exemption 
in Sec. 60.700(c)(2), the facility must begin compliance with the 
requirements set forth in Sec. 60.702.
    (m) The requirements of Sec. 60.705(l) remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternative 
means of compliance surveillance adopted by such State. In that event, 
affected sources within the State will be relieved of the obligation to 
comply with Sec. 60.705(l), provided that they comply with the 
requirements established by the State.
    (n) Each owner or operator that seeks to demonstrate compliance with 
Sec. 60.700(c)(3) must submit to the Administrator an initial report 
detailing the design production capacity of the process unit.
    (o) Each owner or operator that seeks to demonstrate compliance with 
Sec. 60.700(c)(4) must submit to the Administrator an initial report 
including a flow rate measurement using the test methods specified in 
Sec. 60.704.
    (p) Each owner or operator that seeks to demonstrate compliance with 
Sec. 60.700(c)(8) must submit to the Administrator an initial report 
including a concentration measurement using the test method specified in 
Sec. 60.704.
    (q) The Administrator will specify appropriate reporting and 
recordkeeping requirements where the owner or operator of an affected 
facility complies with the standards specified under Sec. 60.702 other 
than as provided under Sec. 60.703 (a), (b), (c), and (d).
    (r) Each owner or operator whose reactor process vent stream is 
routed to a distillation unit subject to subpart NNN and who seeks to 
demonstrate compliance with Sec. 60.700(c)(5) shall submit to the 
Administrator a process design description as part of the initial 
report. This process design description must be retained for the life of 
the process. No other records or reports would be required unless 
process changes are made.
    (s) Each owner or operator who seeks to demonstrate compliance with 
Sec. 60.702 (a) or (b) using a control device must maintain on file a 
schematic diagram of the affected vent streams, collection system(s), 
fuel systems, control devices, and bypass systems as part of the initial 
report. This schematic diagram must be retained for the life of the 
system.
    (t) Each owner or operator that seeks to demonstrate compliance with 
Sec. 60.700(c)(2) must maintain a record of the initial test for 
determining the total resource effectiveness index and the results of 
the initial total resource effectiveness index calculation.

[58 FR 45962, Aug. 31, 1993, as amended at 60 FR 58238, Nov. 27, 1995]

[[Page 518]]



Sec. 60.706  Reconstruction.

    (a) For purposes of this subpart ``fixed capital cost of the new 
components,'' as used in Sec. 60.15, includes the fixed capital cost of 
all depreciable components which are or will be replaced pursuant to all 
continuous programs of component replacement which are commenced within 
any 2-year period following June 29, 1990. For purposes of this 
paragraph, ``commenced'' means that an owner or operator has undertaken 
a continuous program of component replacement or that an owner or 
operator has entered into a contractual obligation to undertake and 
complete, within a reasonable time, a continuous program of component 
replacement.
    (b)  [Reserved]



Sec. 60.707  Chemicals affected by subpart RRR.

------------------------------------------------------------------------
                        Chemical                            CAS No.\1\
------------------------------------------------------------------------
Acetaldehyde............................................         75-07-0
Acetic acid.............................................         64-19-7
Acetic anhydride........................................        108-24-7
Acetone.................................................         67-64-1
Acetone cyanohydrin.....................................         75-86-5
Acetylene...............................................         74-86-2
Acrylic acid............................................         79-10-7
Acrylonitrile...........................................        107-13-1
Adipic acid.............................................        124-04-9
Adiponitrile............................................        111-69-3
Alcohols, C-11 or lower, mixtures.......................
Alcohols, C-12 or higher, mixtures......................
Alcohols, C-12 or higher, unmixed.......................
Allyl chloride..........................................        107-05-1
Amylene.................................................        513-35-9
Amylenes, mixed.........................................
Aniline.................................................         62-53-3
Benzene.................................................         71-43-2
Benzenesulfonic acid....................................         98-11-3
Benzenesulfonic acid C10-16-alkyl derivatives, sodium         68081-81-2
 salts..................................................
Benzyl chloride.........................................        100-44-7
Bisphenol A.............................................         80-05-7
Brometone...............................................         76-08-4
1,3-Butadiene...........................................        106-99-0
Butadiene and butene fractions..........................
n-Butane................................................        106-97-8
1,4-Butanediol..........................................        110-63-4
Butanes, mixed..........................................
1-Butene................................................        106-98-9
2-Butene................................................      25167-67-3
Butenes, mixed..........................................
n-Butyl acetate.........................................        123-86-4
Butyl acrylate..........................................        141-32-2
n-Butyl alcohol.........................................         71-36-3
sec-Butyl alcohol.......................................         78-92-2
tert-Butyl alcohol......................................         75-65-0
Butylbenzyl phthalate...................................         85-68-7
tert-Butyl hydroperoxide................................         75-91-2
2-Butyne-1,4-diol.......................................        110-65-6
Butyraldehyde...........................................        123-72-8
Butyric anhydride.......................................        106-31-0
Caprolactam.............................................        105-60-2
Carbon disulfide........................................         75-15-0
Carbon tetrachloride....................................         56-23-5
Chloroacetic acid.......................................         79-11-8
Chlorobenzene...........................................        108-90-7
Chlorodifluoromethane...................................         75-45-6
Chloroform..............................................         67-66-3
p-Chloronitrobenzene....................................        100-00-5
Citric acid.............................................         77-92-9
Cumene..................................................         98-82-8
Cumene hydroperoxide....................................         80-15-9
Cyanuric chloride.......................................        108-77-0
Cyclohexane.............................................        110-82-7
Cyclohexane, oxidized...................................      68512-15-2
Cyclohexanol............................................        108-93-0
Cyclohexanone...........................................        108-94-1
Cyclohexanone oxime.....................................        100-64-1
Cyclohexene.............................................        110-83-8
Cyclopropane............................................         75-19-4
Diacetone alcohol.......................................        123-42-2
1,4-Dichlorobutene......................................        110-57-6
3,4-Dichloro-1-butene...................................      64037-54-3
Dichlorodifluoromethane.................................         75-71-8
Dichlorodimethylsilane..................................         75-78-5
Dichlorofluoromethane...................................         75-43-4
Diethanolamine..........................................        111-42-2
Diethylbenzene..........................................      25340-17-4
Diethylene glycol.......................................        111-46-6
Di-isodecyl phthalate...................................      26761-40-0
Dimethyl terephthalate..................................        120-61-6
2,4-(and 2,6)-dinitrotoluene............................        121-14-2
                                                                606-20-2
Dioctyl phthalate.......................................        117-81-7
Dodecene................................................      25378-22-7
Dodecylbenzene, nonlinear...............................
Dodecylbenzenesulfonic acid.............................      27176-87-0
Dodecylbenzenesulfonic acid, sodium salt................      25155-30-0
Epichlorohydrin.........................................        106-89-8
Ethanol.................................................         64-17-5
Ethanolamine............................................        141-43-5
Ethyl acetate...........................................        141-78-6
Ethyl acrylate..........................................        140-88-5
Ethylbenzene............................................        100-41-4
Ethyl chloride..........................................         75-00-3
Ethylene................................................         74-85-1
Ethylene dibromide......................................        106-93-4
Ethylene dichloride.....................................        107-06-2
Ethylene glycol.........................................        107-21-1
Ethylene glycol monobutyl ether.........................        111-76-2
Ethylene glycol monoethyl ether acetate.................        111-15-9
Ethylene glycol monomethyl ether........................        109-86-4
Ethylene oxide..........................................         75-21-8
2-Ethylhexyl alcohol....................................        104-76-7
(2-Ethylhexyl) amine....................................        104-75-6
6-Ethyl-1,2,3,4-tetrahydro 9,10-anthracenedione.........      15547-17-8
Formaldehyde............................................         50-00-0
Glycerol................................................         56-81-5
n-Heptane...............................................        142-82-5
Heptenes (mixed)........................................
Hexamethylene diamine...................................        124-09-4
Hexamethylene diamine adipate...........................       3323-53-3
Hexamethylenetetramine..................................        100-97-0
Hexane..................................................        110-54-3
Isobutane...............................................         75-28-5
Isobutanol..............................................         78-83-1
Isobutylene.............................................        115-11-7
Isobutyraldehyde........................................         78-84-2
Isopentane..............................................         78-78-4
Isoprene................................................         78-79-5
Isopropanol.............................................         67-63-0
Ketene..................................................        463-51-4
Linear alcohols, ethoxylated, mixed.....................
Linear alcohols, ethoxylated, and sulfated, sodium salt,
 mixed..................................................
Linear alcohols, sulfated, sodium salt, mixed...........

[[Page 519]]

 
Linear alkylbenzene.....................................        123-01-3
Maleic anhydride........................................        108-31-6
Mesityl oxide...........................................        141-79-7
Methanol................................................         67-56-1
Methylamine.............................................         74-39-5
ar-Methylbenzenediamine.................................      25376-45-8
Methyl chloride.........................................         74-87-3
Methylene chloride......................................         75-09-2
Methyl ethyl ketone.....................................         78-93-3
Methyl isobutyl ketone..................................        108-10-1
Methyl methacrylate.....................................         80-62-6
1-Methyl-2-pyrrolidone..................................        872-50-4
Methyl tert-butyl ether.................................
Naphthalene.............................................         91-20-3
Nitrobenzene............................................         98-95-3
1-Nonene................................................      27215-95-8
Nonyl alcohol...........................................        143-08-8
Nonylphenol.............................................      25154-52-3
Nonylphenol, ethoxylated................................       9016-45-9
Octene..................................................      25377-83-7
Oil-soluble petroleum sulfonate, calcium salt...........
Pentaerythritol.........................................        115-77-5
3-Pentenenitrile........................................       4635-87-4
Pentenes, mixed.........................................        109-67-1
Perchloroethylene.......................................        127-18-4
Phenol..................................................        108-95-2
1-Phenylethyl hydroperoxide.............................       3071-32-7
Phenylpropane...........................................        103-65-1
Phosgene................................................         75-44-5
Phthalic anhydride......................................         85-44-9
Propane.................................................         74-98-6
Propionaldehyde.........................................        123-38-6
Propyl alcohol..........................................         71-23-8
Propylene...............................................        115-07-1
Propylene glycol........................................         57-55-6
Propylene oxide.........................................         75-56-9
Sorbitol................................................         50-70-4
Styrene.................................................        100-42-5
Terephthalic acid.......................................        100-21-0
Tetraethyl lead.........................................         78-00-2
Tetrahydrofuran.........................................        109-99-9
Tetra (methyl-ethyl) lead...............................
Tetramethyl lead........................................         75-74-1
Toluene.................................................        108-88-3
Toluene-2,4-diamine.....................................         95-80-7
Toluene-2,4-(and, 2,6)-diisocyanate (80/20 mixture).....      26471-62-5
1,1,1-Trichloroethane...................................         71-55-6
1,1,2-Trichloroethane...................................         79-00-5
Trichloroethylene.......................................         79-01-6
Trichlorofluoromethane..................................         75-69-4
1,1,2-Trichloro-1,2,2-trifluoroethane...................         76-13-1
Triethanolamine.........................................        102-71-6
Triethylene glycol......................................        112-27-6
Vinyl acetate...........................................        108-05-4
Vinyl chloride..........................................         75-01-4
Vinylidene chloride.....................................         75-35-4
m-Xylene................................................        108-38-3
o-Xylene................................................         95-47-6
p-Xylene................................................        106-42-3
Xylenes (mixed).........................................      1330-20-7
------------------------------------------------------------------------
\1\ CAS numbers refer to the Chemical Abstracts Registry numbers
  assigned to specific chemicals, isomers, or mixtures of chemicals.
  Some isomers or mixtures that are covered by the standards do not have
  CAS numbers assigned to them. The standards apply to all of the
  chemicals listed, whether CAS numbers have been assigned or not.


[58 FR 45962, Aug. 31, 1993, as amended at 60 FR 58238, Nov. 27, 1995]



Sec. 60.708  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to States: 
Sec. 60.703(e).



    Subpart SSS--Standards of Performance for Magnetic Tape Coating 
                               Facilities

    Source: 53 FR 38914, Oct. 3, 1988, unless otherwise noted.



Sec. 60.710  Applicability and designation of affected facility.

    (a) The affected facilities to which the provisions of this subpart 
apply are:
    (1) Each coating operation; and
    (2) Each piece of coating mix preparation equipment.
    (b) Any new coating operation that utilizes less than 38 m\3\ of 
solvent or any modified or reconstructed coating operation that utilizes 
less than 370 m\3\ of solvent for the manufacture of magnetic tape per 
calendar year is subject only to the requirements of Secs. 60.714(a), 
60.717(b), and 60.717(c). If the amount of solvent utilized for the 
manufacture of magnetic tape equals or exceeds these amounts in any 
calendar year, the facility is subject to Sec. 60.712 and all other 
sections of this subpart. Once a facility has become subject to 
Sec. 60.712 and all other sections of this subpart, it will remain 
subject to those requirements regardless of changes in annual solvent 
utilization.
    (c) This subpart applies to any affected facility for which 
construction, modification, or reconstruction begins after January 22, 
1986.



Sec. 60.711  Definitions, symbols, and cross reference tables.

    (a) All terms used in this subpart that are not defined below have 
the meaning given to them in the Act and in subpart A of this part.
    (1) Base film means the substrate that is coated to produce magnetic 
tape.

[[Page 520]]

    (2) Capture system means any device or combination of devices that 
contains or collects an airborne pollutant and directs it into a duct.
    (3) Coating applicator means any apparatus used to apply a coating 
to a continuous base film.
    (4) Coating mix preparation equipment means all mills, mixers, 
holding tanks, polishing tanks, and other equipment used in the 
preparation of the magnetic coating formulation but does not include 
those mills that do not emit VOC because they are closed, sealed, and 
operated under pressure.
    (5) Coating operation means any coating applicator, flashoff area, 
and drying oven located between a base film unwind station and a base 
film rewind station that coat a continuous base film to produce magnetic 
tape.
    (6) Common emission control device means a control device 
controlling emissions from the coating operation as well as from another 
emission source within the plant.
    (7) Concurrent means construction of a control device is commenced 
or completed within the period beginning 6 months prior to the date 
construction of affected coating mix preparation equipment commences and 
ending 2 years after the date construction of affected coating mix 
preparation equipment is completed.
    (8) Control device means any apparatus that reduces the quantity of 
a pollutant emitted to the air.
    (9) Cover means, with respect to coating mix preparation equipment, 
a device that lies over the equipment opening to prevent VOC from 
escaping and that meets the requirements found in Sec. 60.712(c)(1)-(5).
    (10) Drying oven means a chamber in which heat is used to bake, 
cure, polymerize, or dry a surface coating.
    (11) Equivalent diameter means four times the area of an opening 
divided by its perimeter.
    (12) Flashoff area means the portion of a coating operation between 
the coating applicator and the drying oven where solvent begins to 
evaporate from the coated base film.
    (13) Magnetic tape means any flexible substrate that is covered on 
one or both sides with a coating containing magnetic particles and that 
is used for audio or video recording or information storage.
    (14) Natural draft opening means any opening in a room, building, or 
total enclosure that remains open during operation of the facility and 
that is not connected to a duct in which a fan is installed. The rate 
and direction of the natural draft across such an opening is a 
consequence of the difference in pressures on either side of the wall 
containing the opening.
    (15) Nominal 1-month period means a calendar month or, if 
established prior to the performance test in a statement submitted with 
notification of anticipated startup pursuant to 40 CFR 60.7(a)(2), a 
similar monthly time period (e.g., 30-day month or accounting month).
    (16) Temporary enclosure means a total enclosure that is constructed 
for the sole purpose of measuring the fugitive emissions from an 
affected facility. A temporary enclosure must be constructed and 
ventilated (through stacks suitable for testing) so that it has minimal 
impact on the performance of the permanent capture system. A temporary 
enclosure will be assumed to achieve total capture of fugitive VOC 
emissions if it conforms to the requirements found in 
Sec. 60.713(b)(5)(i) and if all natural draft openings are at least four 
duct or hood equivalent diameters away from each exhaust duct or hood. 
Alternatively, the owner or operator may apply to the Administrator for 
approval of a temporary enclosure on a case-by-case basis.
    (17) Total enclosure means a structure that is constructed around a 
source of emissions so that all VOC emissions are collected and 
exhausted through a stack or duct. With a total enclosure, there will be 
no fugitive emissions, only stack emissions. The only openings in a 
total enclosure are forced makeup air and exhaust ducts and any natural 
draft openings such as those that allow raw materials to enter and exit 
the enclosure for processing. All access doors or windows are closed 
during routine operation of the enclosed source. Brief, occasional 
openings of such doors or windows to accommodate process equipment 
adjustments are acceptable, but, if such openings are routine or if an 
access door remains open

[[Page 521]]

during the entire operation, the access door must be considered a 
natural draft opening. The average inward face velocity across the 
natural draft openings of the enclosure must be calculated including the 
area of such access doors. The drying oven itself may be part of the 
total enclosure. A permanent enclosure that meets the requirements found 
in Sec. 60.713(b)(5)(i) is assumed to be a total enclosure. The owner or 
operator of a permanent enclosure that does not meet the requirements 
may apply to the Administrator for approval of the enclosure as a total 
enclosure on a case-by-case basis. Such approval shall be granted upon a 
demonstration to the satisfaction of the Administrator that all VOC 
emissions are contained and vented to the control device.
    (18) Utilize refers to the use of solvent that is delivered to 
coating mix preparation equipment for the purpose of formulating 
coatings to be applied on an affected coating operation and any other 
solvent (e.g., dilution solvent) that is added at any point in the 
manufacturing process.
    (19) VOC content of the coating applied means the product of Method 
24 VOC analyses or formulation data (if the data are demonstrated to be 
equivalent to Method 24 results) and the total volume of coating fed to 
the coating applicator. This quantity is intended to include all VOC 
that actually are emitted from the coating operation in the gaseous 
phase. Thus, for purposes of the liquid-liquid VOC material balance in 
Sec. 60.713(b)(1), any VOC (including dilution solvent) added to the 
coatings must be accounted for, and any VOC contained in waste coatings 
or retained in the final product may be measured and subtracted from the 
total. (These adjustments are not necessary for the gaseous emission 
test compliance provisions of Sec. 60.713(b).)
    (20) Volatile Organic Compounds or VOC means any organic compounds 
that participate in atmospheric photochemical reactions or that are 
measured by Method 18, 24, 25, or 25A or an equivalent or alternative 
method as defined in 40 CFR 60.2.
    (b) The nomenclature used in this subpart has the following meaning:
(1) Ak=the area of each natural draft opening (k) in a total 
          enclosure, in square meters.
(2) Caj=the concentration of VOC in each gas stream (j) 
          exiting the emission control device, in parts per million by 
          volume.
(3) Cbi=the concentration of VOC in each gas stream (i) 
          entering the emission control device, in parts per million by 
          volume.
(4) Cdi=the concentration of VOC in each gas stream (i) 
          entering the emission control device from the affected coating 
          operation, in parts per million by volume.
(5) Cfk=the concentration of VOC in each uncontrolled gas 
          stream (k) emitted directly to the atmosphere from the 
          affected coating operation, in parts per million by volume.
(6) Cgv=the concentration of VOC in the gas stream entering 
          each individual carbon adsorber vessel (v), in parts per 
          million by volume. For the purposes of calculating the 
          efficiency of the individual adsorber vessel, Cgv 
          may be measured in the carbon adsorption system's common inlet 
          duct prior to the branching of individual inlet ducts.
(7) Chv=the concentration of VOC in the gas stream exiting 
          each individual carbon adsorber vessel (v), in parts per 
          million by volume.
(8) E=the control device efficiency achieved for the duration of the 
          emission test (expressed as a fraction).
(9) F=the VOC emission capture efficiency of the VOC capture system 
          achieved for the duration of the emission test (expressed as a 
          fraction).
(10) FV=the average inward face velocity across all natural draft 
          openings in a total enclosure, in meters per hour.
(11) G=the calculated weighted average mass of VOC per volume of coating 
          solids (in kilograms per liter) applied each nominal 1-month 
          period.
(12) Hv=the individual carbon adsorber vessel (v) efficiency 
          achieved for the duration of the emission test (expressed as a 
          fraction).
(13) Hsys=the carbon adsorption system efficiency calculated 
          when each adsorber vessel has an individual exhaust stack.
(14) Lsi=the volume fraction of solids in each coating (i) 
          applied during a nominal 1-month period as determined from the 
          facility's formulation records.
(15) Mci=the total mass in kilograms of each coating (i) 
          applied at an affected coating operation during a nominal 1-
          month period as determined from facility records. This 
          quantity shall be determined at a time and location in the 
          process after all ingredients (including any dilution solvent) 
          have been added to the coating, or appropriate adjustments 
          shall be made to account for any ingredients added after the 
          mass of the coating has been determined.

[[Page 522]]

(16) Mr=the total mass in kilograms of VOC recovered for a 
          nominal 1-month period.
(17) Qaj=the volumetric flow rate of each gas stream (j) 
          exiting the emission control device, in dry standard cubic 
          meters per hour when Method 18 or 25 is used to measure VOC 
          concentration or in standard cubic meters per hour (wet basis) 
          when Method 25A is used to measure VOC concentration.
(18) Qbi=the volumetric flow rate of each gas stream (i) 
          entering the emission control device, in dry standard cubic 
          meters per hour when Method 18 or 25 is used to measure VOC 
          concentration or in standard cubic meters per hour (wet basis) 
          when Method 25A is used to measure VOC concentration.
(19) Qdi=the volumetric flow rate of each gas stream (i) 
          entering the emission control device from the affected coating 
          operation, in dry standard cubic meters per hour when Method 
          18 or 25 is used to measure VOC concentration or in standard 
          cubic meters per hour (wet basis) when Method 25A is used to 
          measure VOC concentration.
(20) Qfk=the volumetric flow rate of each uncontrolled gas 
          stream (k) emitted directly to the atmosphere from the 
          affected coating operation, in dry standard cubic meters per 
          hour when Method 18 or 25 is used to measure VOC concentration 
          or in standard cubic meters per hour (wet basis) when Method 
          25A is used to measure VOC concentration.
(21) Qgv=the volumetric flow rate of the gas stream entering 
          each individual carbon adsorber vessel (v), in dry standard 
          cubic meters per hour when Method 18 or 25 is used to measure 
          VOC concentration or in standard cubic meters per hour (wet 
          basis) when Method 25A is used to measure VOC concentration. 
          For purposes of calculating the efficiency of the individual 
          adsorber vessel, the value of Qgv can be assumed to 
          equal the value of Qhv measured for that adsorber 
          vessel.
(22) Qhv=the volumetric flow rate of the gas stream exiting 
          each individual carbon adsorber vessel (v), in dry standard 
          cubic meters per hour when Method 18 or 25 is used to measure 
          VOC concentration or in standard cubic meters per hour (wet 
          basis) when Method 25A is used to measure VOC concentration.
(23) Qini=the volumetric flow rate of each gas stream (i) 
          entering the total enclosure through a forced makeup air duct, 
          in standard cubic meters per hour (wet basis).
(24) Qoutj=the volumetric flow rate of each gas stream (j) 
          exiting the total enclosure through an exhaust duct or hood, 
          in standard cubic meters per hour (wet basis).
(25) R=the overall VOC emission reduction achieved for the duration of 
          the emission test (expressed as a percentage).
(26) RSi=the total mass (kg) of VOC retained in the coated 
          base film after oven drying for a given magnetic tape product.
(27) Vci=the total volume in liters of each coating (i) 
          applied during a nominal 1-month period as determined from 
          facility records.
(28) Woi=the weight fraction of VOC in each coating (i) 
          applied at an affected coating operation during a nominal 1-
          month period as determined by Method 24. This value shall be 
          determined at a time and location in the process after all 
          ingredients (including any dilution solvent) have been added 
          to the coating, or appropriate adjustments shall be made to 
          account for any ingredients added after the weight fraction of 
          VOC in the coating has been determined.
    (c) Tables 1a and 1b present a cross reference of the affected 
facility status and the relevant section(s) of the regulation.

[[Page 523]]



                                                              Table 1a--Cross Reference a b
--------------------------------------------------------------------------------------------------------------------------------------------------------
                       Status                                                 Standard c                           Compliance provisions d--Sec.  60.713
--------------------------------------------------------------------------------------------------------------------------------------------------------
A. Coating operation alone:
    New............................................  Sec.  60.712(a): Recover or destroy at least 93 percent of   (b)(1), (b)(2), (b)(3), (b)(4),
                                                      the VOC applied.                                             (b)(5), (c), (d)
    Modified or reconstructed:
        1. If at least 90 percent of the VOC         Sec.  60.712(b)(1): (i) Maintain demonstrated level of VOC   (a)(1), (a)(3), (b)(1), (b)(2),
         applied is recovered or destroyed prior to   control or 93 percent, whichever is lower.                   (b)(3), (b)(4), (c), (d)
         modification/reconstruction.                (ii) If the VOC control device is subsequently replaced,
                                                      the new control device must be at least 95 percent
                                                      efficient, a demonstration must be made that the overall
                                                      level of VOC control is at least as high as required with
                                                      the old control device (90 to 93 percent) and, if the
                                                      demonstrated level is higher than the old level, maintain
                                                      the higher level of control (up to 93 percent).
        2. If existing coating operation has a       Sec.  60.712(b)(2): (i) Continue to vent all VOC emissions   (a)(2), (b)(5), (c), (d)
         total enclosure vented to a control device   to the control device and maintain control efficiency at
         that is at least 92 percent efficient.       or above the demonstrated level or 95 percent, whichever
                                                      is lower.
                                                     (ii) If the VOC control device is subsequently replaced,
                                                      the new control device must be at least 95 percent
                                                      efficient and all VOC emissions must be vented from the
                                                      total enclosure to the new control device.
        3. If existing coating operation is not in   Sec.  60.712(b)(3): Recover or destroy at least 93 percent   (b)(1), (b)(2), (b)(3), (b)(4),
         the previous two categories.                 of the VOC applied.                                          (b)(5), (c), (d)
B. Coating mix preparation equipment alone:
    New:
        1. With concurrent construction of new VOC   Sec.  60.712(c): Install and use covers and vent to a        (b)(6)
         control device (other than a condenser) on   control device that is at least 95 percent efficient e.
         the coating operation.
        2. Without concurrent construction of new    Sec.  60.712 (d)(1) or (d)(2): Install and use covers and    (b)(7), (b)(8)
         VOC control device on the coating            vent to a control device or install and use covers e.
         operation or with concurrent construction
         of a condenser.
    Modified or reconstructed......................  Sec.  60.712 (d)(1) or (d)(2): Install and use covers and    (b)(7), (b)(8)
                                                      vent to a control device or install and use covers e.
C. Both coating operation and coating mix            Sec.  60.712(e): In lieu of standards in Sec.  60.712(a)-    (b)(9)
 preparation equipment: New and modified or           (d), use coatings containing a maximum of 0.20 kg VOC per
 reconstructed.                                       liter of coating solids.
--------------------------------------------------------------------------------------------------------------------------------------------------------
a This table is presented for the convenience of the user and is not intended to supercede the language of the regulation. For the details of the
  requirements, refer to the text of the regulation.
b Refer to Part B to determine which subsections of Secs.  60.714, 60.715, and 60.717 correspond to each compliance provision (Sec.  60.713).
c As per Sec.  60.710(b), any new coating operation with solvent utilization < 38 m3/yr or any modified or reconstructed coating operation with solvent
  utilization < 370 m3/yr is exempt from the VOC standards (Sec.  60.712). Such coating operations are subject only to Secs.  60.714(a), 60.717(b), and
  60.717(c). However, should a coating operation once exceed the applicable annual solvent utilization cutoff, that coating operation shall be subject
  to the VOC standards (Sec.  60.712) and all other sections of the subpart. Once this has occurred, the coating operation shall remain subject to those
  requirements regardless of changes in annual solvent utilization.
d As applicable.
e Section 60.716 permits the use of an alternative means of VOC emission limitation that achieves an equivalent or greater VOC emission reduction.


[[Page 524]]


                                                                Table 1b--Cross Reference
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                               Installation of monitoring
     Compliance provisions a--Sec. 60.713        Test methods--Sec.     Category/equipment b   devices and recordkeeping--    Reporting and monitoring
                                                       60.715                                         Sec.  60.714          requirements c--Sec.  60.717
--------------------------------------------------------------------------------------------------------------------------------------------------------
A. Coating operation alone:
    (b)(1)--When emissions from only the       (a)                     .....................  (b), (i), (k)                 (a), (d)(1), (e), (h), (i)
     affected coating operation are
     controlled by a solvent recovery device,
     perform a liquid-liquid VOC material
     balance.
    (b)(2)--When emissions from only the       (b)-(g)                 General                (i), (k)                      (a), (e), (h), (i)
     affected coating operation are                                    CA                     (c)                           (d)(3), (d)(4)
     controlled by an incinerator or when a                            CO                     (d)                           (d)(5)
     common emission control device (other                             TI                     (e)                           (d)(6)
     than a carbon adsorption system with                              CI                     (f)                           (d)(7)
     individual exhaust stacks for each                                PE, TE                 (g)                           (d)(8)
     adsorber vessel) is used to control
     emissions from an affected coating
     operation as well as from other sources
     of VOC, perform a gaseous emission test.
    (b)(3)--When emissions from both the       (b)-(g)                 General                (i), (k)                      (a), (e), (h), (i)
     affected coating operation and from                               CA                     (c)                           (d)(3), (d)(4)
     other sources of VOC are controlled by a                          PE, TE                 (g)                           (d)(8)
     carbon adsorption system with individual
     exhaust stacks for each adsorber vessel,
     perform a gaseous emission test.
    (b)(4)--When emissions from more than one  (b)-(g)                 General                (i), (k)                      (a), (e), (h), (i)
     affected coating operation are vented                             CA                     (c)                           (d)(3), (d)(4)
     through the same duct to a control                                CO                     (d)                           (d)(5)
     device also controlling emissions from                            TI                     (e)                           (d)(6)
     nonaffected sources that are vented                               CI                     (f)                           (d)(7)
     separately from the affected coating                              PE, TE                 (g)                           (d)(8)
     operations, consider the combined
     affected coating operations as a single
     emission source and conduct a compliance
     test described in Sec.  60.713(b)(2) or
     (3).
    (b)(5)--Alternative to Sec.  60.713(b)(1)- (b)-(g)                 General                (i), (k)                      (a), (e) (h), (i)
     (4): Demonstrate that a total enclosure                           CA                     (c)                           (d)(3), (d)(4)
     is installed around the coating                                   CO                     (d)                           (d)(5)
     operation and that all VOC emissions are                          TI                     (e)                           (d)(6)
     vented to a control device with the                               CI                     (f)                           (d)(7)
     specified efficiency.                                             TE                     (h)                           (d)(8)
B. Coating mix preparation equipment alone:
    (b)(6)--Demonstrate that covers meeting    (b)-(g)                 General                (k)                           (a), (e), (h), (i)
     the requirements of Sec.  60.712(c)(1)-                           CA                     (c)                           (d)(3), (d)(4)
     (5) are installed and used properly;                              TI                     (e)                           (d)(6)
     procedures detailing the proper use of                            CI                     (f)                           (d)(7)
     covers are posted; the mix equipment is
     vented to a control device; and the
     control device efficiency is greater
     than or equal to 95 percent.
    (b)(7)--Demonstrate that covers meeting
     the requirements of Sec.  60.712(c)(1)-
     (5) are installed and used properly;
     procedures detailing the proper use of
     covers are posted; and the mix equipment
     is vented to a control device.
    (b)(8)--Demonstrate that covers meeting
     the requirement of Sec.  60.712(c)(1)-
     (5) are installed and used properly and
     that procedures detailing the proper use
     of the covers are posted.
C. Both coating operation and coating mix      (a)                     .....................  (i), (j) (k)                  (d)(2), (e), (g), (h), (i)
 preparation equipment: (b)(9)--Determine
 that weighted average mass of VOC in the
 coating per volume of coating solids applied
 for each month.
--------------------------------------------------------------------------------------------------------------------------------------------------------
a Section 60.713(a) specifies the procedures to be used prior to modification/reconstruction to establish the applicability of the VOC standards in Sec.
   60.712(b)(1) and (2) for modified/reconstructed coating operations. Section 60.713(a)(1) requires the use of the procedures of Sec.  60.713(b)(1),
  (2), (3), or (4) to demonstrate prior to modification/reconstruction that 90 percent of the applied VOC is recovered or destroyed. Section
  60.713(a)(2) requires the use of procedures of Sec. 60.713(b)(5) to demonstrate prior to modification/reconstruction that the coating operation has a
  total enclosure vented to a control device that is at least 92 percent efficient. Sections 60.713(c) and (d) do not have corresponding test methods,
  monitoring, reporting, or recordkeeping requirements.

[[Page 525]]

 
b TI = thermal incinerator; CI = catalytic incinerator; CA = carbon adsorber; CO = condenser; PE = partial enclosure; TE = total enclosure.
c See Sec.  60.717(f) for additional reporting requirements when coating mix preparation equipment is constructed at a time when no coating operation is
  being constructed. See Sec.  60.717(g) for addition reporting requirements when coating mix preparation equipment is constructed at the same time as
  an affected coating operation.

[53 FR 38914, Oct. 3, 1988; 53 FR 43799, Oct. 28, 1988, as amended at 53 
FR 47955, Nov. 29, 1988; 53 FR 49822, Dec. 9, 1988]

[[Page 526]]



Sec. 60.712  Standards for volatile organic compounds.

    Each owner or operator of any affected facility that is subject to 
the requirements of this subpart shall comply with the emission 
limitations set forth in this section on and after the date on which the 
initial performance test required by Sec. 60.8 is completed, but not 
later than 60 days after achieving the maximum production rate at which 
the affected facility will be operated or 180 days after initial 
startup, whichever date comes first.
    (a) Each owner or operator shall control emissions from a new 
coating operation by recovering or destroying at least 93 percent of the 
VOC content of the coating applied at the coating applicator.
    (b) Each owner or operator of a modified or reconstructed coating 
operation shall meet the appropriate standard set out in (b)(1), (2), or 
(3) of this section.
    (1) For coating operations demonstrated prior to modification or 
reconstruction pursuant to Sec. 60.713(a)(1) to have emissions 
controlled by the recovery or destruction of at least 90 percent of the 
VOC content of the coating applied at the coating applicator.
    (i) Subject to the provisions of (b)(1)(ii) of this section, each 
owner or operator shall continue to control emissions from the coating 
operation to at least the demonstrated level or 93 percent, whichever is 
lower.
    (ii) If the VOC control device in use during the emission reduction 
demonstration made pursuant to Sec. 60.713(a)(1) is subsequently 
replaced, each owner or operator shall:
    (A) Install a control device that is at least 95 percent efficient; 
and
    (B) Control emissions from the coating operation to at least the 
level determined pursuant to Sec. 60.713(a)(3)(ii).
    (2) For coating operations demonstrated prior to modification or 
reconstruction pursuant to Sec. 60.713(a)(2) to have a total enclosure 
installed around the coating operation and all VOC emissions ventilated 
to a control device that is at least 92 percent efficient.
    (i) Subject to the provisions of (b)(2)(ii) of this section, each 
owner or operator shall continue to ventilate all VOC emissions from the 
total enclosure to the control device and maintain control device 
efficiency at or above the demonstrated level or 95 percent, whichever 
is lower.
    (ii) If the VOC control device in use during the control device 
efficiency demonstration made pursuant to Sec. 60.713(a)(2) is 
subsequently replaced, each owner or operator shall install a VOC 
control device that is at least 95 percent efficient and ventilate all 
VOC emissions from the total enclosure to the control device.
    (3) For coating operations not subject to paragraph (b)(1) or (2) of 
this section, each owner or operator shall control emissions from the 
coating operation by recovering or destroying at least 93 percent of the 
VOC content of the coating applied at the coating applicator.
    (c) Each owner or operator constructing new coating mix preparation 
equipment with concurrent construction of a new VOC control device 
(other than a condenser) on a magnetic tape coating operation shall 
control emissions from the coating mix preparation equipment by 
installing and using a cover on each piece of equipment and venting the 
equipment to a 95 percent efficient control device. Each cover shall 
meet the following specifications:
    (1) Cover shall be closed at all times except when adding 
ingredients, withdrawing samples, transferring the contents, or making 
visual inspection when such activities cannot be carried out with cover 
in place. Such activities shall be carried out through ports of the 
minimum practical size.
    (2) Cover shall extend at least 2 cm beyond the outer rim of the 
opening or shall be attached to the rim;
    (3) Cover shall be of such design and construction that contact is 
maintained between cover and rim along the entire perimeter;
    (4) Any breach in the cover (such as an opening for insertion of a 
mixer shaft or port for addition of ingredients) shall be covered 
consistent with (c)(2) and (3) of this section when not actively in use. 
An opening sufficient to allow safe clearance for a mixer shaft is 
acceptable during those periods when the shaft is in place; and
    (5) A polyethylene or nonpermanent cover may be used provided it 
meets

[[Page 527]]

the requirements of (c)(2), (3), and (4) of this section. Such a cover 
shall not be reused after once being removed.
    (d) Each owner or operator of affected coating mix preparation 
equipment not subject to Sec. 60.712(c) shall control emissions from the 
coating mix preparation equipment by either:
    (1) Installing and using a cover that meets the specifications in 
paragraphs (c)(1)-(5) of this section and venting VOC emissions from the 
equipment to a VOC control device; or
    (2) Installing and using a cover that meets the specifications in 
paragraphs (c)(1)-(5) of this section.
    (e) In lieu of complying with Sec. 60.712(a) through (d), each owner 
or operator may use coatings that contain a maximum of 0.20 kg of VOC 
per liter of coating solids as calculated on a weighted average basis 
for each nominal 1-month period.



Sec. 60.713  Compliance provisions.

    (a) Applicability of Sec. 60.712(b)(1) and (2) (standards for 
modified or reconstructed coating operations) and determination of 
control level required in Sec. 60.712(b)(1)(ii)(B).
    (1) To establish applicability of Sec. 60.712(b)(1), each owner or 
operator must demonstrate, prior to modification or reconstruction, that 
at least 90 percent of the VOC content of the coating applied at the 
coating applicator is recovered or destroyed. Such demonstration shall 
be made using the procedures of paragraph (b)(1), (b)(2), (b)(3), or 
(b)(4) of this section, as appropriate.
    (2) To establish applicability of Sec. 60.712(b)(2), each owner or 
operator must demonstrate, prior to modification or reconstruction, that 
a total enclosure is installed around the existing coating operation and 
that all VOC emissions are ventilated to a control device that is at 
least 92 percent efficient. Such demonstration shall be made using the 
procedures of Sec. 60.713(b)(5).
    (3) To determine the level of control required in 
Sec. 60.712(b)(1)(ii)(B), the owner or operator must demonstrate:
    (i) That the VOC control device subsequently installed is at least 
95 percent efficient. Such demonstration shall be made using Equation 
(2) specified in paragraph (b)(2)(iv) of this section or Equations (4) 
and (5) specified in paragraphs (b)(3)(iv) and (v) of this section, as 
applicable, and the test methods and procedures specified in 
Sec. 60.715(b)-(g); and
    (ii) That the overall level of control after the VOC control device 
is installed is at least as high as the level demonstrated prior to 
modification or reconstruction pursuant to paragraph (a)(1) of this 
section. Such demonstrations shall be made using the procedures of 
paragraph (b)(1), (b)(2), (b)(3), or (b)(4) of this section, as 
appropriate. The required overall level of control subsequent to this 
demonstration shall be the level so demonstrated or 93 percent, 
whichever is lower.
    (b) Compliance demonstrations for Sec. 60.712(a), (b)(1), (b)(2), 
(b)(3), (c), (d), and (e).
    (1) To demonstrate compliance with Sec. 60.712(a), (b)(1), or (b)(3) 
(standards for coating operations) when emissions from only the affected 
coating operations are controlled by a dedicated solvent recovery 
device, each owner or operator of the affected coating operation shall 
perform a liquid-liquid VOC material balance over each and every nominal 
1-month period. When demonstrating compliance by this procedure, 
Sec. 60.8(f) of the General Provisions does not apply. The amount of 
liquid VOC applied and recovered shall be determined as discussed in 
paragraph (b)(1)(iii) of this section. The overall VOC emission 
reduction (R) is calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.057

    (i) The value of RSi is zero unless the owner or operator 
submits the following information to the Administrator for approval of a 
measured value of RSi that is greater than zero:
    (A) Measurement techniques; and
    (B) Documentation that the measured value of RSi exceeds 
zero.
    (ii) The measurement techniques of paragraph (b)(1)(i)(A) of this 
section

[[Page 528]]

shall be submitted to the Administrator for approval with the 
notification of anticipated startup required under Sec. 60.7(a)(2) of 
the General Provisions.
    (iii) Each owner or operator demonstrating compliance by the test 
method described in paragraph (b)(1) of this section shall:
    (A) Measure the amount of coating applied at the coating applicator;
    (B) Determine the VOC content of all coatings applied using the test 
method specified in Sec. 60.715(a);
    (C) Install, calibrate, maintain, and operate, according to the 
manufacturer's specifications, a device that indicates the cumulative 
amount of VOC recovered by the solvent recovery device over each nominal 
1-month period. The device shall be certified by the manufacturer to be 
accurate to within 2.0 percent;
    (D) Measure the amount of VOC recovered; and
    (E) Calculate the overall VOC emission reduction (R) for each and 
every nominal 1-month period using Equation 1.
    (iv) For facilities subject to Sec. 60.712 (a) or (b)(3), compliance 
is demonstrated if the value of R is equal to or greater than 93 
percent.
    (v) Subject to the provisions of (b)(1)(vi) of this section, for 
facilities subject to Sec. 60.712(b)(1), compliance is demonstrated if 
the value of R is equal to or greater than the percent reduction 
demonstrated pursuant to Sec. 60.713(a)(1) prior to modification or 
reconstruction or 93 percent whichever is lower.
    (vi) For facilities subject to Sec. 60.712(b)(1)(ii), compliance is 
demonstrated if the value of E (control device efficiency) is greater 
than or equal to 0.95 and if the value of R is equal to or greater than 
the percent reduction demonstrated pursuant to Sec. 60.713(a)(3) or 93 
percent, whichever is lower.
    (2) To demonstrate compliance with Sec. 60.712(a), (b)(1), or (b)(3) 
(standards for coating operations) when the emissions from only an 
affected coating operation are controlled by a dedicated incinerator or 
when a common emission control device (other than a fixed-bed carbon 
adsorption system with individual exhaust stacks for each adsorber 
vessel) is used to control emissions from an affected coating operation 
as well as from other sources of VOC, each owner or operator of an 
affected coating operation shall perform a gaseous emission test using 
the following procedures:
    (i) Construct the overall VOC emission reduction system so that all 
volumetric flow rates and total VOC emissions can be accurately 
determined by the applicable test methods and procedures specified in 
Sec. 60.715(b) through (g);
    (ii) Determine capture efficiency from the coating operation by 
capturing, venting, and measuring all VOC emissions from the operation. 
During a performance test, the owner or operator of an affected coating 
operation located in an area with other sources of VOC shall isolate the 
coating operation emissions from all other sources of VOC by one of the 
following methods:
    (A) Build a temporary enclosure (see Sec. 60.711(a)(16)) around the 
affected coating operation; or
    (B) Shut down all other sources of VOC and continue to exhaust 
fugitive emissions from the affected coating operation through any 
building ventilation system and other room exhausts such as drying 
ovens. All ventilation air must be vented through stacks suitable for 
testing;
    (iii) Operate the emission control device with all emission sources 
connected and operating;
    (iv) Determine the efficiency (E) of the control device using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.058

    (v) Determine the efficiency (F) of the VOC capture system using the 
following equation:

[[Page 529]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.059

    (vi) For each affected coating operation subject to Sec. 60.712(a) 
or (b)(3), compliance is demonstrated if the product of (E) x (F) is 
equal to or greater than 0.93.
    (vii) For each affected coating operation subject to 
Sec. 60.712(b)(1)(i), compliance is demonstrated if the product of 
(E) x (F) is equal to or greater than the fractional reduction 
demonstrated pursuant to Sec. 60.713(a)(1) prior to modification or 
reconstruction or 0.93, whichever is lower.
    (viii) For each affected coating operation subject to 
Sec. 60.712(b)(1)(ii), compliance is demonstrated if the value of E is 
greater than or equal to 0.95 and if the product of (E) x (F) is equal 
to or greater than the fractional reduction demonstrated pursuant to 
Sec. 60.713(a)(3) or 0.93, whichever is lower.
    (3) To demonstrate compliance with Sec. 60.712(a), (b)(1), or (b)(3) 
(standards for coating operations) when a fixed-bed carbon adsorption 
system with individual exhaust stacks for each adsorber vessel is used 
to control emissions from an affected coating operation as well as from 
other sources of VOC, each owner or operator of an affected coating 
operation shall perform a gaseous emission test using the following 
procedures:
    (i) Construct the overall VOC emission reduction system so that each 
volumetric flow rate and the total VOC emissions can be accurately 
determined by the applicable test methods and procedures specified in 
Sec. 60.715(b) through (g);
    (ii) Assure that all VOC emissions from the coating operation are 
segregated from other VOC sources and that the emissions can be captured 
for measurement, as described in Sec. 60.713(b)(2)(ii)(A) and (B);
    (iii) Operate the emission control device with all emission sources 
connected and operating;
    (iv) Determine the efficiency (Hv) of each individual 
adsorber vessel (v) using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.060

    (v) Determine the efficiency of the carbon adsorption system 
(Hsys) by computing the average efficiency of the adsorber 
vessels as weighted by the volumetric flow rate (Qhv) of each 
individual adsorber vessel (v) using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.061

    (vi) Determine the efficiency (F) of the VOC capture system using 
Equation (3).
    (vii) For the affected coating operation subject to Sec. 60.712(a) 
or (b)(3), compliance is demonstrated if the product of 
(Hsys) x (F) is equal to or greater than 0.93.
    (viii) For the affected coating operation subject to 
Sec. 60.712(b)(1)(i), compliance is demonstrated if the product of 
(Hsys) x (F) is equal to or greater than the fractional 
reduction demonstrated pursuant to Sec. 60.713(a)(1) prior to 
modification or reconstruction or 0.93, whichever is lower.
    (ix) For each affected coating operation subject to 
Sec. 60.712(b)(1)(ii), compliance is demonstrated if the value of 
Hsys is greater than or equal to 0.95 and if the product of 
(Hsys) x (F) is equal to or greater than the fractional 
reduction demonstrated pursuant to Sec. 60.713(a)(3) or 0.93, whichever 
is lower.
    (4) To demonstrate compliance with Sec. 60.712(a), (b)(1), or (b)(3) 
(standards for coating operations) when the VOC emissions from more than 
one affected coating operation are collected by a common capture system 
and are vented through a common duct to a control

[[Page 530]]

device that is also controlling emissions from nonaffected sources and 
the emissions from the nonaffected sources are vented separately from 
the affected coating operations, the owner or operator may:
    (i) Consider the combined affected coating operations as a single 
emission source; and
    (ii) Conduct a compliance test on this single source by the methods 
described in Sec. 60.713(b)(2) or (3), as applicable.
    (5) An alternative method of demonstrating compliance with 
Sec. 60.712(a) or (b)(3) (standards for coating operations) and the sole 
method of demonstrating compliance with Sec. 60.712(b)(2) (standards for 
modified or reconstructed coating operations) is the installation of a 
total enclosure around the coating operation and the ventilation of all 
VOC emissions from the total enclosure to a control device with the 
efficiency specified in paragraph (b)(5)(iii)(A) or (B) of this section, 
as applicable. If this method is selected, the compliance test methods 
described in paragraphs (b)(1), (b)(2), (b)(3), and (b)(4) of this 
section are not required. Instead, each owner or operator of an affected 
coating operation shall:
    (i) Demonstrate that a total enclosure is installed. An enclosure 
that meets the requirements in paragraphs (b)(5)(i)(A) through (D) of 
this section shall be assumed to be a total enclosure. The owner or 
operator of an enclosed coating operation that does not meet the 
requirements may apply to the Administrator for approval of the 
enclosure as a total enclosure on a case-by-case basis. The enclosure 
shall be considered a total enclosure if it is demonstrated to the 
satisfaction of the Administrator that all VOC emissions from the 
affected coating operation are contained and vented to the control 
device. The requirements for automatic approval are as follows:
    (A) Total area of all natural draft openings shall not exceed 5 
percent of the total surface area of the total enclosure's walls, floor, 
and ceiling;
    (B) All sources of emissions within the enclosure shall be a minimum 
of four equivalent diameters away from each natural draft opening;
    (C) Average inward face velocity across all natural draft openings 
(FV) shall be a minimum of 3,600 meters per hour as determined by the 
following procedures:
    (1) Construct all forced makeup air ducts and all exhaust ducts so 
that the volumetric flow rate in each can be accurately determined by 
the test methods and procedures specified in Sec. 60.715(c) and (d). 
Volumetric flow rates shall be calculated without the adjustment 
normally made for moisture content; and
    (2) Determine FV by the following equation:
    [GRAPHIC] [TIFF OMITTED] TC01JN92.062
    
    (D) The air passing through all natural draft openings shall flow 
into the enclosure continuously. If FV is less than or equal to 9,000 
meters per hour, the continuous inward flow of air shall be verified by 
continuous observation using smoke tubes, streamers, tracer gases, or 
other means approved by the Administrator over the period that the 
volumetric flow rate tests required to determine FV are carried out. If 
FV is greater than 9,000 meters per hour, the direction of airflow 
through the natural draft openings shall be presumed to be inward at all 
times without verification.
    (ii) Determine the control device efficiency using Equation (2) or 
Equations (4) and (5), as applicable, and the test methods and 
procedures specified in Sec. 60.715(b) through (g).
    (iii) Compliance is demonstrated if the installation of a total 
enclosure is demonstrated and the value of E determined from Equation 
(2) (or the value of Hsys determined from Equations (4) and 
(5), as applicable) is equal to or greater than the required efficiency 
as specified below:
    (A) For coating operations subject to the standards of 
Sec. 60.712(a), (b)(2)(ii), and (b)(3), 0.95 (95 percent); or

[[Page 531]]

    (B) For coating operations subject to the standards of 
Sec. 60.712(b)(2)(i), the value of E determined from Equation (2) (or 
the value of Hsys determined from Equations (4) and (5), as 
applicable) pursuant to Sec. 60.713(a)(2) prior to modification or 
reconstruction or 0.95 (95 percent), whichever is lower.
    (6) To demonstrate compliance with Sec. 60.712(c) (standard for new 
mix equipment with concurrent construction of a control device), each 
owner or operator of affected coating mix preparation equipment shall 
demonstrate upon inspection that:
    (i) Covers satisfying the requirements of Sec. 60.712(c)(1)-(5) have 
been installed and are being used properly;
    (ii) Procedures detailing the proper use of covers, as specified in 
Sec. 60.712(c)(1), have been posted in all areas where affected coating 
mix preparation equipment is used;
    (iii) The coating mix preparation equipment is vented to a control 
device; and
    (iv) The control device efficiency (E or Hsys, as 
applicable) determined using Equation (2) or Equations (4) and (5), 
respectively, and the test methods and procedures specified in 
Sec. 60.715(b)-(g) is equal to or greater than 0.95.
    (7) To demonstrate compliance with Sec. 60.712(d)(1) (standard for 
mix equipment), each owner or operator of affected coating mix 
preparation equipment shall demonstrate upon inspection that:
    (i) Covers satisfying the requirements of Sec. 60.712(c)(1)-(5) have 
been installed and are being used properly;
    (ii) Procedures detailing the proper use of covers, as specified in 
Sec. 60.712(c)(1), have been posted in all areas where affected coating 
mix preparation equipment is used; and
    (iii) The coating mix preparation equipment is vented to a control 
device.
    (8) To demonstrate compliance with Sec. 60.712(d)(2) (standard for 
mix equipment), each owner or operator of affected coating mix 
preparation equipment shall demonstrate upon inspection that both:
    (i) Covers satisfying the requirements of Sec. 60.712(c)(1)-(5) have 
been installed and are being used properly; and
    (ii) Procedures detailing the proper use of covers, as specified in 
Sec. 60.712(c)(1), have been posted in all areas where affected coating 
mix preparation equipment is used.
    (9) To determine compliance with Sec. 60.712(e) (high-solids 
coatings alternative standard), each owner or operator of an affected 
facility shall determine the weighted average mass of VOC contained in 
the coating per volume of coating solids applied for each and every 
nominal 1-month period according to the following procedures:
    (i) Determine the weight fraction of VOC in each coating applied 
using Method 24 as specified in Sec. 60.715(a);
    (ii) Determine the volume of coating solids in each coating applied 
from the facility records; and
    (iii) Compute the weighted average by the following equation:
    [GRAPHIC] [TIFF OMITTED] TC01JN92.063
    
    (iv) For each affected facility where the value of G is less than or 
equal to 0.20 kilogram of VOC per liter of coating solids applied, the 
facility is in compliance.
    (c) Startups and shutdowns are normal operation for this source 
category. Emissions from these operations are to be included when 
determining if the standards for coating operations specified in 
Sec. 60.712(a) and (b) are being attained.
    (d) If a control device other than a carbon adsorber, condenser, or 
incinerator is used to control emissions from an affected facility, the 
necessary operating specifications for that device must be obtained from 
the Administrator. An example of such a device is a flare.

[53 FR 38914, Oct. 3, 1988; 53 FR 43799, Oct. 28, 1988, as amended at 53 
FR 47955, Nov. 29, 1988]

[[Page 532]]



Sec. 60.714  Installation of monitoring devices and recordkeeping.

    All monitoring devices required under the provisions of this section 
shall be installed and calibrated, according to the manufacturer's 
specifications, prior to the initial performance tests in locations such 
that representative values of the monitored parameters will be obtained. 
The parameters to be monitored shall be continuously measured and 
recorded during all performance tests.
    (a) Each owner or operator of an affected coating operation that 
utilizes less solvent annually than the applicable cutoff provided in 
Sec. 60.710(b) and that is not subject to Sec. 60.712 (standards for 
coating operations) shall maintain records of actual solvent use.
    (b) Each owner or operator of an affected coating operation 
demonstrating compliance by the test method described in 
Sec. 60.713(b)(1) (liquid material balance) shall maintain records of 
all the following for each and every nominal 1-month period:
    (1) Amount of coating applied at the applicator;
    (2) Results of the reference test method specified in Sec. 60.715(a) 
for determining the VOC content of all coatings applied;
    (3) Amount VOC recovered; and
    (4) Calculation of the percent VOC recovered.
    (c) Each owner or operator of an affected coating operation or 
affected coating mix preparation equipment controlled by a carbon 
adsorption system and demonstrating compliance by the procedures 
described in Sec. 60.713(b)(2), (3), (4), (5), or (6) (which include 
control device efficiency determinations) shall carry out the monitoring 
and recordkeeping provisions of paragraph (c)(1) or (2) of this section, 
as appropriate.
    (1) For carbon adsorption systems with a common exhaust stack for 
all the individual adsorber vessels, install, calibrate, maintain, and 
operate, according to the manufacturer's specifications, a monitoring 
device that continuously indicates and records the concentration level 
of organic compounds in either the control device outlet gas stream or 
in both the control device inlet and outlet gas streams. The outlet gas 
stream would be monitored if the percent increase in the concentration 
level of organic compounds is used as the basis for reporting, as 
described in Sec. 60.717(d)(3). The inlet and outlet gas streams would 
be monitored if the percent control device efficiency is used as the 
basis for reporting, as described in Sec. 60.717(d)(4).
    (2) For carbon adsorption systems with individual exhaust stacks for 
each adsorber vessel, install, calibrate, maintain, and operate, 
according to the manufacturer's specifications, a monitoring device that 
continuously indicates and records the concentration level of organic 
compounds in the outlet gas stream for a minimum of one complete 
adsorption cycle per day for each adsorber vessel. The owner or operator 
may also monitor and record the concentration level of organic compounds 
in the common carbon adsorption system inlet gas stream or in each 
individual carbon adsorber vessel inlet stream. The outlet gas streams 
alone would be monitored if the percent increase in the concentration 
level of organic compounds is used as the basis for reporting, as 
described in Sec. 60.717(d)(3). In this case, the owner or operator 
shall compute daily a 3-day rolling average concentration level of 
organics in the outlet gas stream from each individual adsorber vessel. 
The inlet and outlet gas streams would be monitored if the percent 
control device efficiency is used as the basis for reporting, as 
described in Sec. 60.717(d)(4). In this case, the owner or operator 
shall compute daily a 3-day rolling average efficiency for each 
individual adsorber vessel.
    (d) Each owner or operator of an affected coating operation 
controlled by a condensation system and demonstrating compliance by the 
procedures described in Sec. 60.713(b)(2), (4), or (5) (which include 
control device efficiency determinations) shall install, calibrate, 
maintain, and operate, according to the manufacturer's specifications, a 
monitoring device that continuously indicates and records the 
temperature of the condenser exhaust stream.
    (e) Each owner or operator of an affected coating operation or 
affected coating mix preparation equipment

[[Page 533]]

controlled by a thermal incinerator and demonstrating compliance by the 
procedures described in Sec. 60.713(b)(2), (4), (5), or (6) (which 
include control device efficiency determinations) shall install, 
calibrate, maintain, and operate, according to the manufacturer's 
specifications, a monitoring device that continuously indicates and 
records the combustion temperature of the incinerator. The monitoring 
device shall have an accuracy within 1 percent of the 
temperature being measured in Celsius degrees.
    (f) Each owner or operator of an affected coating operation or 
affected coating mix preparation equipment controlled by a catalytic 
incinerator and demonstrating compliance by the procedures described in 
Sec. 60.713(b)(2), (4), (5), or (6) (which include control device 
efficiency determinations) shall install, calibrate, maintain, and 
operate, according to the manufacturer's specifications, a monitoring 
device that continuously indicates and records the gas temperature both 
upstream and downstream of the catalyst bed. The monitoring device shall 
have an accuracy within 1 percent of the temperature being 
measured in Celsius degrees.
    (g) Each owner or operator of an affected coating operation 
demonstrating compliance pursuant to Sec. 60.713(b)(2), (3), or (4) 
(which include VOC capture system efficiency determinations) shall 
submit a monitoring plan for the VOC capture system to the Administrator 
for approval along with the notification of anticipated startup required 
under Sec. 60.7(a)(2) of the General Provisions. This plan shall 
identify the parameter to be monitored as an indicator of VOC capture 
system performance (e.g., the amperage to the exhaust fans or duct flow 
rates) and the method for monitoring the chosen parameter. The owner or 
operator shall install, calibrate, maintain, and operate, according to 
the manufacturer's specifications, a monitoring device that continuously 
indicates and records the value of the chosen parameter.
    (h) Each owner or operator of an affected coating operation who uses 
the equipment alternative described in Sec. 60.713(b)(5) to demonstrate 
compliance shall follow the procedures described in paragraph (g) of 
this section to establish a monitoring plan for the total enclosure.
    (i) Each owner or operator of an affected coating operation shall 
record time periods of coating operations when an emission control 
device is not in use.
    (j) Each owner or operator of an affected coating operation or 
affected coating mix preparation equipment complying with Sec. 60.712(e) 
shall maintain records of the monthly weighted average mass of VOC 
contained in the coating per volume of coating solids applied for each 
coating, as described in Sec. 60.713(b)(9)(i) through (iv).
    (k) Records of the measurements and calculations required in 
Secs. 60.713 and 60.714 must be retained for at least 2 years following 
the date of the measurements and calculations.

(Sec. 114 of the Clean Air Act as amended (42 U.S.C. 7414))

[53 FR 38914, Oct. 3, 1988, as amended at 64 FR 7467, Feb. 12, 1999]



Sec. 60.715  Test methods and procedures.

    Methods in appendix A of this part, except as provided under 
Sec. 60.8(b), shall be used to determine compliance as follows:
    (a) Method 24 is used to determine the VOC content in coatings. If 
it is demonstrated to the satisfaction of the Administrator that plant 
coating formulation data are equivalent to Method 24 results, 
formulation data may be used. In the event of any inconsistency between 
a Method 24 test and a facility's formulation data, the Method 24 test 
will govern. For Method 24, the coating sample must be a 1-liter sample 
taken into a 1-liter container at a location and time such that the 
sample will be representative of the coating applied to the base film 
(i.e., the sample shall include any dilution solvent or other VOC added 
during the manufacturing process). The container must be tightly sealed 
immediately after the sample is taken. Any solvent or other VOC added 
after the sample is taken must be measured and accounted for in the 
calculations that use Method 24 results.
    (b) Method 18, 25, or 25A, as appropriate to the conditions at the 
site, is

[[Page 534]]

used to determine VOC concentration. The owner or operator shall submit 
notice of the intended test method to the Administrator for approval 
along with the notification of the performance test required under 
Sec. 60.8(d) of the General Provisions. Method selection shall be based 
on consideration of the diversity of organic species present and their 
total concentration and on consideration of the potential presence of 
interfering gases. Except as indicated in paragraphs (b)(1) and (2) of 
this section, the test shall consist of three separate runs, each 
lasting a minimum of 30 minutes.
    (1) When the method is to be used in the determination of the 
efficiency of a fixed-bed carbon adsorption system with a common exhaust 
stack for all the individual adsorber vessels pursuant to 
Sec. 60.713(b)(2), (4), (5), or (6), the test shall consist of three 
separate runs, each coinciding with one or more complete sequences 
through the adsorption cycles of all the individual adsorber vessels.
    (2) When the method is to be used in the determination of the 
efficiency of a fixed-bed carbon adsorption system with individual 
exhaust stacks for each adsorber vessel pursuant to Sec. 60.713(b)(3), 
(4), (5), or (6), each adsorber vessel shall be tested individually. The 
test for each adsorber vessel shall consist of three separate runs. Each 
run shall coincide with one or more complete adsorption cycles.
    (c) Method 1 or 1A is used for sample and velocity traverses.
    (d) Method 2, 2A, 2C, or 2D is used for velocity and volumetric flow 
rates.
    (e) Method 3 is used for gas analysis.
    (f) Method 4 is used for stack gas moisture.
    (g) Methods 2, 2A, 2C, 2D, 3, and 4 shall be performed, as 
applicable, at least twice during each test period.

[53 FR 38914, Oct. 3, 1988; 53 FR 43799, Oct. 28, 1988]



Sec. 60.716  Permission to use alternative means of emission limitation.

    (a) If, in the Administrator's judgment, an alternative means of 
emission limitation will achieve a reduction in emissions of VOC from 
any emission point subject to Sec. 60.712(c) or (d) (standards for mix 
equipment) at least equivalent to that required by Sec. 60.712 (c) or 
(d), respectively, the Administrator will publish in the Federal 
Register a notice permitting the use of the alternative means. The 
notice may condition permission on requirements related to the operation 
and maintenance of the alternative means.
    (b) Any notice under paragraph (a) of this section shall be 
published only after public notice and an opportunity for a public 
hearing.
    (c) Any person seeking permission under this section shall submit 
either results from an emission test that documents the collection and 
measurement of all VOC emissions from a given control device or an 
engineering evaluation that documents the determination of such 
emissions.



Sec. 60.717  Reporting and monitoring requirements.

    (a) For all affected coating operations subject to Sec. 60.712(a), 
(b)(1), (b)(2), or (b)(3) and all affected coating mix preparation 
equipment subject to Sec. 60.712(c), the performance test data and 
results shall be submitted to the Administrator as specified in 
Sec. 60.8(a) of the General Provisions (40 CFR part 60, subpart A). In 
addition, the average values of the monitored parameters measured at 
least every 15 minutes and averaged over the period of the performance 
test shall be submitted with the results of all performance tests.
    (b) Each owner or operator of an affected coating operation claiming 
to utilize less than the applicable volume of solvent specified in 
Sec. 60.710(b) in the first calendar year of operation shall submit to 
the Administrator, with the notification of projected startup, a 
material flow chart indicating projected solvent use. The owner or 
operator shall also submit actual solvent use records at the end of the 
initial calendar year.
    (c) Each owner or operator of an affected coating operation 
initially utilizing less than the applicable volume of solvent specified 
in Sec. 60.710(b) per calendar year shall report the first calendar year 
in which actual annual solvent use exceeds the applicable volume.
    (d) Each owner or operator of an affected coating operation, or 
affected

[[Page 535]]

coating mix preparation equipment subject to Sec. 60.712(c), shall 
submit semiannual reports to the Administrator documenting the 
following:
    (1) The 1-month amount of VOC contained in the coating, the VOC 
recovered, and the percent emission reduction for months of 
noncompliance for any affected coating operation demonstrating 
compliance by the performance test method described in Sec. 60.713(b)(1) 
(liquid material balance);
    (2) The VOC contained in the coatings for the manufacture of 
magnetic tape for any 1-month period during which the weighted average 
solvent content (G) of the coatings exceeded 0.20 kilogram per liter of 
coating solids for those affected facilities complying with 
Sec. 60.712(e) (high-solids coatings alternative standard);
    (3) For those affected facilities monitoring only the carbon 
adsorption system outlet concentration levels of organic compounds, the 
periods (during actual coating operations) specified in paragraph 
(d)(3)(i) or (ii) of this section, as applicable.
    (i) For carbon adsorption systems with a common exhaust stack for 
all the individual adsorber vessels, all periods of three consecutive 
adsorption cycles of all the individual adsorber vessels during which 
the average value of the concentration level of organic compounds in the 
common outlet gas stream is more than 20 percent greater than the 
average value measured during the most recent performance test that 
demonstrated compliance.
    (ii) For carbon adsorption systems with individual exhaust stacks 
for each adsorber vessel, all 3-day rolling averages for each adsorber 
vessel when the concentration level of organic compounds in the 
individual outlet gas stream is more than 20 percent greater than the 
average value for that adsorber vessel measured during the most recent 
performance test that demonstrated compliance.
    (4) For those affected facilities monitoring both the carbon 
adsorption system inlet and outlet concentration levels of organic 
compounds, the periods (during actual coating operations), specified in 
(d)(4)(i) or (ii) of this section, as applicable.
    (i) For carbon adsorption systems with a common exhaust stack for 
all the individual adsorber vessels, all periods of three consecutive 
adsorption cycles of all the individual adsorber vessels during which 
the average carbon adsorption system efficiency falls below the 
applicable level as follows:
    (A) For those affected facilities demonstrating compliance by the 
performance test method described in Sec. 60.713(b)(2) or (4), the value 
of E determined using Equation (2) during the most recent performance 
test that demonstrated compliance.
    (B) For those affected facilities demonstrating compliance pursuant 
to Sec. 60.713(b)(5)(iii)(A) or Sec. 60.713(b)(6), 0.95 (95 percent).
    (C) For those affected facilities demonstrating compliance pursuant 
to Sec. 60.713(b)(5)(iii)(B), the required value of E determined using 
Equation (2) pursuant to Sec. 60.713(a)(2) prior to modification or 
reconstruction or 0.95 (95 percent), whichever is lower.
    (ii) For carbon adsorption systems with individual exhaust stacks 
for each adsorber vessel, all 3-day rolling averages for each adsorber 
vessel when the efficiency falls below the applicable level as follows:
    (A) For those affected facilities demonstrating compliance by the 
performance test method described in Sec. 60.713(b)(3) or (4), the value 
of Hv determined using Equation (4) during the most recent 
performance test that demonstrated compliance.
    (B) For those affected facilities demonstrating compliance pursuant 
to Sec. 60.713(b)(5)(iii)(A) or Sec. 60.713(b)(6), 0.95 (95 percent).
    (C) For those affected facilities demonstrating compliance pursuant 
to Sec. 60.713(b)(5)(iii)(B), the value of Hv determined 
using Equation 4 pursuant to Sec. 60.713(a)(2) prior to modification or 
reconstruction.
    (5) All 3-hour periods (during actual coating operations) during 
which the average exhaust temperature is 5 or more Celsius degrees above 
the average temperature measured during the most recent performance test 
that demonstrated compliance for those affected facilities monitoring 
condenser exhaust gas temperature;

[[Page 536]]

    (6) All 3-hour periods (during actual coating operations) during 
which the average combustion temperature is more than 28 Celsius degrees 
below the average combustion temperature during the most recent 
performance test that demonstrated compliance for those affected 
facilities monitoring thermal incinerator combustion gas temperature;
    (7) All 3-hour periods (during actual coating operations) during 
which the average gas temperature immediately before the catalyst bed is 
more than 28 Celsius degrees below the average gas temperature during 
the most recent performance test that demonstrated compliance and all 3-
hour periods (during actual coating operations) during which the average 
gas temperature difference across the catalyst bed is less than 80 
percent of the average gas temperature difference during the most recent 
performance test that demonstrated compliance for those affected 
facilities monitoring catalytic incinerator catalyst bed temperature; 
and
    (8) All 3-hour periods (during actual coating operations) during 
which the average total enclosure or VOC capture system monitoring 
device readings vary by 5 percent or more from the average value 
measured during the most recent performance test that demonstrated 
compliance for those affected facilities monitoring a total enclosure 
pursuant to Sec. 60.714(h) or VOC capture system pursuant to 
Sec. 60.714(g).
    (e) Each owner or operator of an affected coating operation, or 
affected coating mix preparation equipment subject to Sec. 60.712(c), 
not required to submit reports under Sec. 60.717(d) because no 
reportable periods have occurred shall submit semiannual reports so 
affirming.
    (f) Each owner or operator of affected coating mix preparation 
equipment that is constructed at a time when no affected coating 
operation is being constructed shall:
    (1) Be exempt from the reporting requirements specified in 
Sec. 60.7(a)(1), (2), and (4); and
    (2) Submit the notification of actual startup specified in 
Sec. 60.7(a)(3).
    (g) The owner or operator of affected coating mix preparation 
equipment that is constructed at the same time as an affected coating 
operation shall include the affected coating mix preparation equipment 
in all the reporting requirements for the affected coating operation 
specified in Sec. 60.7(a)(1) through (4).
    (h) The reports required under paragraphs (b) through (e) of this 
section shall be postmarked within 30 days of the end of the reporting 
period.
    (i) The requirements of this subsection remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternative 
means of compliance surveillance adopted by such States. In this event, 
affected sources within the State will be relieved of the obligation to 
comply with this subsection, provided that they comply with the 
requirements established by the State.

(Sec. 114 of the Clean Air Act as amended (42 U.S.C. 7414))

[53 FR 38914, Oct. 3, 1988; 53 FR 43799, Oct. 28, 1988, as amended at 53 
FR 47955, Nov. 29, 1988; 64 FR 7467, Feb. 12, 1999]



Sec. 60.718  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to States:

Sec. 60.711(a)(16)
Sec. 60.713(b)(1)(i)
Sec. 60.713(b)(1)(ii)
Sec. 60.713(b)(5)(i)
Sec. 60.713(d)
Sec. 60.715(a)
Sec. 60.716

[53 FR 38914, Oct. 3, 1988; 53 FR 47955, Nov. 29, 1988]



 Subpart TTT--Standards of Performance for Industrial Surface Coating: 
         Surface Coating of Plastic Parts for Business Machines

    Source: 53 FR 2676, Jan. 29, 1988, unless otherwise noted.

[[Page 537]]



Sec. 60.720  Applicability and designation of affected facility.

    (a) The provisions of this subpart apply to each spray booth in 
which plastic parts for use in the manufacture of business machines 
receive prime coats, color coats, texture coats, or touch-up coats.
    (b) This subpart applies to any affected facility for which 
construction, modification, or reconstruction begins after January 8, 
1986.



Sec. 60.721  Definitions.

    (a) As used in this subpart, all terms not defined herein shall have 
the meaning given them in the Act or in subpart A of this part.
    Business machine means a device that uses electronic or mechanical 
methods to process information, perform calculations, print or copy 
information, or convert sound into electrical impulses for transmission, 
such as:
    (1) Products classified as typewriters under SIC Code 3572;
    (2) Products classified as electronic computing devices under SIC 
Code 3573;
    (3) Products classified as calculating and accounting machines under 
SIC Code 3574;
    (4) Products classified as telephone and telegraph equipment under 
SIC Code 3661;
    (5) Products classified as office machines, not elsewhere 
classified, under SIC Code 3579; and
    (6) Photocopy machines, a subcategory of products classified as 
photographic equipment under SIC code 3861.
    Coating operation means the use of a spray booth for the application 
of a single type of coating (e.g., prime coat); the use of the same 
spray booth for the application of another type of coating (e.g., 
texture coat) constitutes a separate coating operation for which 
compliance determinations are performed separately.
    Coating solids applied means the coating solids that adhere to the 
surface of the plastic business machine part being coated.
    Color coat means the coat applied to a part that affects the color 
and gloss of the part, not including the prime coat or texture coat. 
This definition includes fog coating, but does not include conductive 
sensitizers or electromagnetic interference/radio frequency interference 
shielding coatings.
    Conductive sensitizer means a coating applied to a plastic substrate 
to render it conductive for purposes of electrostatic application of 
subsequent prime, color, texture, or touch-up coats.
    Electromagnetic interference/radio frequency interference (EMI/RFI) 
shielding coating means a conductive coating that is applied to a 
plastic substrate to attenuate EMI/RFI signals.
    Fog coating (also known as mist coating and uniforming) means a thin 
coating applied to plastic parts that have molded-in color or texture or 
both to improve color uniformity.
    Nominal 1-month period means either a calendar month, 30-day month, 
accounting month, or similar monthly time period that is established 
prior to the performance test (i.e., in a statement submitted with 
notification of anticipated actual startup pursuant to 40 CFR 60.7(2)).
    Plastic parts means panels, housings, bases, covers, and other 
business machine components formed of synthetic polymers.
    Prime coat means the initial coat applied to a part when more than 
one coating is applied, not including conductive sensitizers or 
electromagnetic interference/radio frequency interference shielding 
coatings.
    Spray booth means the structure housing automatic or manual spray 
application equipment where a coating is applied to plastic parts for 
business machines.
    Texture coat means the rough coat that is characterized by discrete, 
raised spots on the exterior surface of the part. This definition does 
not include conductive sensitizers or EMI/RFI shielding coatings.
    Touch-up coat means the coat applied to correct any imperfections in 
the finish after color or texture coats have been applied. This 
definition does not include conductive sensitizers or EMI/RFI shielding 
coatings.
    Transfer efficiency means the ratio of the amount of coating solids 
deposited onto the surface of a plastic business machine part to the 
total amount of coating solids used.

[[Page 538]]

    VOC emissions means the mass of VOC's emitted from the surface 
coating of plastic parts for business machines expressed as kilograms of 
VOC's per liter of coating solids applied (i.e., deposited on the 
surface).
    (b) All symbols used in this subpart not defined below are given 
meaning in the Act or subpart A of this part.

Dc=density of each coating as received (kilograms per liter)
Dd=density of each diluent VOC (kilograms per liter)
Lc=the volume of each coating consumed, as received (liters)
Ld=the volume of each diluent VOC added to coatings (liters)
Ls=the volume of coating solids consumed (liters)
Md=the mass of diluent VOC's consumed (kilograms)
Mo=the mass of VOC's in coatings consumed, as received 
(kilograms)
N=the volume-weighted average mass of VOC emissions to the atmosphere 
per unit volume of coating solids applied (kilograms per liter)
T=the transfer efficiency for each type of application equipment used at 
a coating operation (fraction)
Tavg=the volume-weighted average transfer efficiency for a 
coating operation (fraction)
Vs=the proportion of solids in each coating, as received 
(fraction by volume)
Wo=the proportion of VOC's in each coating, as received 
(fraction by weight)

[53 FR 2676, Jan. 29, 1988, as amended at 54 FR 25459, June 15, 1989]



Sec. 60.722  Standards for volatile organic compounds.

    (a) Each owner or operator of any affected facility which is subject 
to the requirements of this subpart shall comply with the emission 
limitations set forth in this section on and after the date on which the 
initial performance test, required by Secs. 60.8 and 60.723 is 
completed, but not later than 60 days after achieving the maximum 
production rate at which the affected facility will be operated, or 180 
days after the initial startup, whichever date comes first. No affected 
facility shall cause the discharge into the atmosphere in excess of:
    (1) 1.5 kilograms of VOC's per liter of coating solids applied from 
prime coating of plastic parts for business machines.
    (2) 1.5 kilograms of VOC's per liter of coating solids applied from 
color coating of plastic parts for business machines.
    (3) 2.3 kilograms of VOC's per liter of coating solids applied from 
texture coating of plastic parts for business machines.
    (4) 2.3 kilograms of VOC's per liter of coatings solids applied from 
touch-up coating of plastic parts for business machines.
    (b) All VOC emissions that are caused by coatings applied in each 
affected facility, regardless of the actual point of discharge of 
emissions into the atmosphere, shall be included in determining 
compliance with the emission limits in paragraph (a) of this section.



Sec. 60.723  Performance tests and compliance provisions.

    (a) Section 60.8 (d) and (f) do not apply to the performance test 
procedures required by this section.
    (b) The owner or operator of an affected facility shall conduct an 
initial performance test as required under Sec. 60.8(a) and thereafter a 
performance test each nominal 1-month period for each affected facility 
according to the procedures in this section.
    (1) The owner or operator shall determine the composition of 
coatings by analysis of each coating, as received, using Reference 
Method 24, from data that have been determined by the coating 
manufacturer using Reference Method 24, or by other methods approved by 
the Administrator.
    (2) The owner or operator shall determine the volume of coating and 
the mass of VOC used for dilution of coatings from company records 
during each nominal 1-month period. If a common coating distribution 
system serves more than one affected facility or serves both affected 
and nonaffected spray booths, the owner or operator shall estimate the 
volume of coatings used at each facility by using procedures approved by 
the Administrator.
    (i) The owner or operator shall calculate the volume-weighted 
average mass of VOC's in coatings emitted per unit volume of coating 
solids applied (N) at each coating operation [i.e., for each type of 
coating (prime, color, texture, and touch-up) used] during each

[[Page 539]]

nominal 1-month period for each affected facility. Each 1-month 
calculation is considered a performance test. Except as provided in 
paragraph (b)(2)(iii) of this section, N will be determined by the 
following procedures:
    (A) Calculate the mass of VOC's used (Mo+Md) 
for each coating operation during each nominal 1-month period for each 
affected facility by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.064


where n is the number of coatings of each type used during each nominal 
1-month period and m is the number of different diluent VOC's used 
during each nominal 1-month period. ( Ldj 
Ddj will be 0 if no VOC's are added to the coatings, as 
received.)
    (B) Calculate the total volume of coating solids consumed 
(Ls) in each nominal 1-month period for each coating 
operation for each affected facility by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.065


where n is the number of coatings of each type used during each nominal 
1-month period.
    (C) Select the appropriate transfer efficiency (T) from Table 1 for 
each type of coating applications equipment used at each coating 
operation. If the owner or operator can demonstrate to the satisfaction 
of the Administrator that transfer efficiencies other than those shown 
are appropriate, the Administrator will approve their use on a case-by-
case basis. Transfer efficiency values for application methods not 
listed below shall be approved by the Administrator on a case-by-case 
basis. An owner or operator must submit sufficient data for the 
Administrator to judge the validity of the transfer efficiency claims.
    (D) Where more than one application method is used within a single 
coating operation, the owner or operator shall determine the volume of 
each coating applied by each method through a means acceptable to the 
Administrator and compute the volume-weighted average transfer 
efficiency by the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.066


[[Page 540]]



                     Table 1--Transfer Efficiencies
------------------------------------------------------------------------
                                   Transfer
       Application methods        efficiency        Type of coating
------------------------------------------------------------------------
Air atomized spray..............        0.25  Prime, color, texture,
                                               touch-up, and fog coats.
Air-assistd airless spray.......         .40  Prime and color coats.
Electrostatic air spray.........         .40      Do.
------------------------------------------------------------------------


where n is the number of coatings of each type used and p is the number 
of application methods used.
    (E) Calculate the volume-weighted average mass of VOC's emitted per 
unit volume of coating solids applied (N) during each nominal 1-month 
period for each coating operation for each affected facility by the 
folowing equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.106

(Tavg=T when only one type of coating operation occurs).

    (ii) Where the volume-weighted average mass of VOC's emitted to the 
atmosphere per unit volume of coating solids applied (N) is less than or 
equal to 1.5 kilograms per liter for prime coats, is less than or equal 
to 1.5 kilograms per liter for color coats, is less than or equal to 2.3 
kilograms per liter for texture coats, and is less than or equal to 2.3 
kilograms per liter for touch-up coats, the affected facility is in 
compliance.
    (iii) If each individual coating used by an affected facility has a 
VOC content (kg VOC/l of solids), as received, which when divided by the 
lowest transfer efficiency at which the coating is applied for each 
coating operation results in a value equal to or less than 1.5 kilograms 
per liter for prime and color coats and equal to or less than 2.3 
kilograms per liter for texture and touch-up coats, the affected 
facility is in compliance provided that no VOC's are added to the 
coatings during distribution or application.
    (iv) If an affected facility uses add-on controls to control VOC 
emissions and if the owner or operator can demonstrate to the 
Administrator that the volume-weighted average mass of VOC's emitted to 
the atmosphere during each nominal 1-month period per unit volume of 
coating solids applied (N) is within each of the applicable limits 
expressed in paragraph (b)(2)(ii) of this section because of this 
equipment, the affected facility is in compliance. In such cases, 
compliance will be determined by the Administrator or a case-by-case 
basis.



Sec. 60.724  Reporting and recordkeeping requirements.

    (a) The reporting requirements of Sec. 60.8(a) apply only to the 
initial performance test. Each owner or operator subject to the 
provisions of this subpart shall include the following data in the 
report of the initial performance test required under Sec. 60.8(a):

    (1) Except as provided for in paragraph (a)(2) of this section, the 
volume-weighted average mass of VOC's emitted to the atmosphere per 
volume of applied coating solids (N) for the initial nominal 1-month 
period for each coating operation from each affected facility.
    (2) For each affected facility where compliance is determined under 
the provisions of Sec. 60.723(b)(2)(iii), a list of the coatings used 
during the initial nominal 1-month period, the VOC content of each 
coating calculated from data determined using Reference Method 24, and 
the lowest transfer efficiency at which each coating is applied during 
the initial nominal 1-month period.
    (b) Following the initial report, each owner or operator shall:
    (1) Report the volume-weighted average mass of VOC's per unit volume 
of coating solids applied for each coating operation for each affected 
facility during each nominal 1-month period in which the facility is not 
in compliance with the applicable emission limits specified in 
Sec. 60.722. Reports of noncompliance shall be submitted on a quarterly 
basis, occurring every 3 months following the initial report; and
    (2) Submit statements that each affected facility has been in 
compliance with the applicable emission limits specified in Sec. 60.722 
during each nominal 1-month period. Statements of compliance shall be 
submitted on a semiannual basis.
    (c) These reports shall be postmarked not later than 10 days after 
the end of

[[Page 541]]

the periods specified in Sec. 60.724(b)(1) and Sec. 60.724(b)(2).
    (d) Each owner or operator subject to the provisions of this subpart 
shall maintain at the source, for a period of at least 2 years, records 
of all data and calculations used to determine monthly VOC emissions 
from each coating operation for each affected facility as specified in 
40 CFR 60.7(d).
    (e) Reporting and recordkeeping requirements for facilities using 
add-on controls will be determined by the Administrator on a case-by-
case basis.



Sec. 60.725  Test methods and procedures.

    (a) The reference methods in appendix A to this part except as 
provided under Sec. 60.8(b) shall be used to determine compliance with 
Sec. 60.722 as follows:

    (1) Method 24 for determination of VOC content of each coating as 
received.
    (2) For Method 24, the sample must be at least a 1-liter sample in a 
1-liter container.
    (b) Other methods may be used to determine the VOC content of each 
coating if approved by the Administrator before testing.



Sec. 60.726  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to the States:

Section 60.723(b)(1)
Section 60.723(b)(2)(i)(C)
Section 60.723(b)(2)(iv)
Section 60.724(e)
Section 60.725(b)

[53 FR 2676, Jan. 29, 1988, as amended at 53 FR 19300, May 27, 1988]



   Subpart UUU--Standards of Performance for Calciners and Dryers in 
                           Mineral Industries

    Source: 57 FR 44503, Sept. 28, 1992, unless otherwise noted.



Sec. 60.730  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each calciner and dryer at a mineral processing plant. Feed and 
product conveyors are not considered part of the affected facility. For 
the brick and related clay products industry, only the calcining and 
drying of raw materials prior to firing of the brick are covered.
    (b) An affected facility that is subject to the provisions of 
subpart LL, Metallic Mineral Processing Plants, is not subject to the 
provisions of this subpart. Also, the following processes and process 
units used at mineral processing plants are not subject to the 
provisions of this subpart: vertical shaft kilns in the magnesium 
compounds industry; the chlorination-oxidation process in the titanium 
dioxide industry; coating kilns, mixers, and aerators in the roofing 
granules industry; and tunnel kilns, tunnel dryers, apron dryers, and 
grinding equipment that also dries the process material used in any of 
the 17 mineral industries (as defined in Sec. 60.731, ``Mineral 
processing plant'').
    (c) The owner or operator of any facility under paragraph (a) of 
this section that commences construction, modification, or 
reconstruction after April 23, 1986, is subject to the requirements of 
this subpart.



Sec. 60.731  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Clean Air Act and in subpart A of this part.
    Calciner means the equipment used to remove combined (chemically 
bound) water and/or gases from mineral material through direct or 
indirect heating. This definition includes expansion furnaces and 
multiple hearth furnaces.
    Control device means the air pollution control equipment used to 
reduce particulate matter emissions released to the atmosphere from one 
or more affected facilities.
    Dryer means the equipment used to remove uncombined (free) water 
from mineral material through direct or indirect heating.

[[Page 542]]

    Installed in series means a calciner and dryer installed such that 
the exhaust gases from one flow through the other and then the combined 
exhaust gases are discharged to the atmosphere.
    Mineral processing plant means any facility that processes or 
produces any of the following minerals, their concentrates or any 
mixture of which the majority (>50 percent) is any of the following 
minerals or a combination of these minerals: alumina, ball clay, 
bentonite, diatomite, feldspar, fire clay, fuller's earth, gypsum, 
industrial sand, kaolin, lightweight aggregate, magnesium compounds, 
perlite, roofing granules, talc, titanium dioxide, and vermiculite.



Sec. 60.732  Standards for particulate matter.

    Each owner or operator of any affected facility that is subject to 
the requirements of this subpart shall comply with the emission 
limitations set forth in this section on and after the date on which the 
initial performance test required by Sec. 60.8 is completed, but not 
later than 180 days after the initial startup, whichever date comes 
first. No emissions shall be discharged into the atmosphere from any 
affected facility that:
    (a) Contains particulate matter in excess of 0.092 gram per dry 
standard cubic meter (g/dscm) [0.040 grain per dry standard cubic foot 
(gr/dscf)] for calciners and for calciners and dryers installed in 
series and in excess of 0.057 g/dscm for dryers; and
    (b) Exhibits greater than 10 percent opacity, unless the emissions 
are discharged from an affected facility using a wet scrubbing control 
device.



Sec. 60.733  Reconstruction.

    The cost of replacement of equipment subject to high temperatures 
and abrasion on processing equipment shall not be considered in 
calculating either the ``fixed capital cost of the new components'' or 
the ``fixed capital cost that would be required to construct a 
comparable new facility'' under Sec. 60.15. Calciner and dryer equipment 
subject to high temperatures and abrasion are: end seals, flights, and 
refractory lining.



Sec. 60.734  Monitoring of emissions and operations.

    (a) With the exception of the process units described in paragraphs 
(b), (c), and (d) of this section, the owner or operator of an affected 
facility subject to the provisions of this subpart who uses a dry 
control device to comply with the mass emission standard shall install, 
calibrate, maintain, and operate a continuous monitoring system to 
measure and record the opacity of emissions discharged into the 
atmosphere from the control device.
    (b) In lieu of a continuous opacity monitoring system, the owner or 
operator of a ball clay vibrating grate dryer, a bentonite rotary dryer, 
a diatomite flash dryer, a diatomite rotary calciner, a feldspar rotary 
dryer, a fire clay rotary dryer, an industrial sand fluid bed dryer, a 
kaolin rotary calciner, a perlite rotary dryer, a roofing granules fluid 
bed dryer, a roofing granules rotary dryer, a talc rotary calciner, a 
titanium dioxide spray dryer, a titanium dioxide fluid bed dryer, a 
vermiculite fluid bed dryer, or a vermiculite rotary dryer who uses a 
dry control device may have a certified visible emissions observer 
measure and record three 6-minute averages of the opacity of visible 
emissions to the atmosphere each day of operation in accordance with 
Method 9 of appendix A of part 60.
    (c) The owner or operator of a ball clay rotary dryer, a diatomite 
rotary dryer, a feldspar fluid bed dryer, a fuller's earth rotary dryer, 
a gypsum rotary dryer, a gypsum flash calciner, gypsum kettle calciner, 
an industrial sand rotary dryer, a kaolin rotary dryer, a kaolin 
multiple hearth furnace, a perlite expansion furnace, a talc flash 
dryer, a talc rotary dryer, a titanium dioxide direct or indirect rotary 
dryer or a vermiculite expansion furnace who uses a dry control device 
is exempt from the monitoring requirements of this section.
    (d) The owner or operator of an affected facility subject to the 
provisions of this subpart who uses a wet scrubber to comply with the 
mass emission standard for any affected facility shall install, 
calibrate, maintain, and operate monitoring devices that continuously 
measure and record the pressure

[[Page 543]]

loss of the gas stream through the scrubber and the scrubbing liquid 
flow rate to the scrubber. The pressure loss monitoring device must be 
certified by the manufacturer to be accurate within 5 percent of water 
column gauge pressure at the level of operation. The liquid flow rate 
monitoring device must be certified by the manufacturer to be accurate 
within 5 percent of design scrubbing liquid flow rate.



Sec. 60.735  Recordkeeping and reporting requirements.

    (a) Records of the measurements required in Sec. 60.734 of this 
subpart shall be retained for at least 2 years.
    (b) Each owner or operator who uses a wet scrubber to comply with 
Sec. 60.732 shall determine and record once each day, from the 
recordings of the monitoring devices in Sec. 60.734(d), an arithmetic 
average over a 2-hour period of both the change in pressure of the gas 
stream across the scrubber and the flowrate of the scrubbing liquid.
    (c) Each owner or operator shall submit written reports semiannually 
of exceedances of control device operating parameters required to be 
monitored by Sec. 60.734 of this subpart. For the purpose of these 
reports, exceedances are defined as follows:
    (1) All 6-minute periods during which the average opacity from dry 
control devices is greater than 10 percent; or
    (2) Any daily 2-hour average of the wet scrubber pressure drop 
determined as described in Sec. 60.735(b) that is less than 90 percent 
of the average value recorded according to Sec. 60.736(c) during the 
most recent performance test that demonstrated compliance with the 
particulate matter standard; or
    (3) Each daily wet scrubber liquid flow rate recorded as described 
in Sec. 60.735(b) that is less than 80 percent or greater than 120 
percent of the average value recorded according to Sec. 60.736(c) during 
the most recent performance test that demonstrated compliance with the 
particulate matter standard.
    (d) The requirements of this section remain in force until and 
unless the Agency, in delegating enforcement authority to a State under 
section 111(c) of the Clean Air Act, approves reporting requirements or 
an alternative means of compliance surveillance adopted by such State. 
In that event, affected facilities within the State will be relieved of 
the obligation to comply with this section provided that they comply 
with the requirements established by the State.

[57 FR 44503, Sept. 28, 1992, as amended at 58 FR 40591, July 29, 1993]



Sec. 60.736  Test methods and procedures.

    (a) In conducting the performance tests required in Sec. 60.8, the 
owner or operator shall use the test methods in appendix A of this part 
or other methods and procedures as specified in this section, except as 
provided in Sec. 60.8(b).
    (b) The owner or operator shall determine compliance with the 
particulate matter standards in Sec. 60.732 as follows:
    (1) Method 5 shall be used to determine the particulate matter 
concentration. The sampling time and volume for each test run shall be 
at least 2 hours and 1.70 dscm.
    (2) Method 9 and the procedures in Sec. 60.11 shall be used to 
determine opacity from stack emissions.
    (c) During the initial performance test of a wet scrubber, the owner 
or operator shall use the monitoring devices of Sec. 60.734(d) to 
determine the average change in pressure of the gas stream across the 
scrubber and the average flowrate of the scrubber liquid during each of 
the particulate matter runs. The arithmetic averages of the three runs 
shall be used as the baseline average values for the purposes of 
Sec. 60.735(c).



Sec. 60.737  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities which will not be delegated to States: No 
restrictions.



     Subpart VVV--Standards of Performance for Polymeric Coating of 
                    Supporting Substrates Facilities

    Source: 54 FR 37551, Sept. 11, 1989, unless otherwise noted.

[[Page 544]]



Sec. 60.740  Applicability and designation of affected facility.

    (a) The affected facility to which the provisions of this subpart 
apply is each coating operation and any onsite coating mix preparation 
equipment used to prepare coatings for the polymeric coating of 
supporting substrates.
    (b) Any affected facility for which the amount of VOC used is less 
than 95 Mg per 12-month period is subject only to the requirements of 
Secs. 60.744(b), 60.747(b), and 60.747(c). If the amount of VOC used is 
95 Mg or greater per 12-month period, the facility is subject to all the 
requirements of this subpart. Once a facility has become subject to the 
requirements of this subpart, it will remain subject to those 
requirements regardless of changes in annual VOC use.
    (c) This subpart applies to any affected facility for which 
construction, modification, or reconstruction begins after April 30, 
1987, except for the facilities specified in paragraph (d) of this 
section.
    (d) This subpart does not apply to the following:
    (1) Coating mix preparation equipment used to manufacture coatings 
at one plant for shipment to another plant for use in an affected 
facility (coating operation) or for sale to another company for use in 
an affected facility (coating operation);
    (2) Coating mix preparation equipment or coating operations during 
those times they are used to prepare or apply waterborne coatings so 
long as the VOC content of the coating does not exceed 9 percent by 
weight of the volatile fraction;
    (3) Web coating operations that print an image on the surface of the 
substrate or any coating applied on the same printing line that applies 
the image.



Sec. 60.741  Definitions, symbols, and cross-reference tables.

    (a) All terms used in this subpart not defined below have the 
meaning given to them in the Act and in subpart A of this part.
    Coating applicator means any apparatus used to apply a coating to a 
continuous substrate.
    Coating mix preparation equipment means all mixing vessels in which 
solvent and other materials are blended to prepare polymeric coatings.
    Coating operation means any coating applicator(s), flashoff area(s), 
and drying oven(s) located between a substrate unwind station and a 
rewind station that coats a continuous web to produce a substrate with a 
polymeric coating. Should the coating process not employ a rewind 
station, the end of the coating operation is after the last drying oven 
in the process.
    Common emission control device means a device controlling emissions 
from an affected coating operation as well as from any other emission 
source.
    Concurrent means the period of time in which construction of an 
emission control device serving an affected facility is commenced or 
completed, beginning 6 months prior to the date that construction of the 
affected facility commences and ending 2 years after the date that 
construction of the affected facility is completed.
    Control device means any apparatus that reduces the quantity of a 
pollutant emitted to the air.
    Cover means, with respect to coating mix preparation equipment, a 
device that fits over the equipment opening to prevent emissions of 
volatile organic compounds (VOC) from escaping.
    Drying oven means a chamber within which heat is used to dry a 
surface coating; drying may be the only process or one of multiple 
processes performed in the chamber.
    Equivalent diameter means four times the area of an opening divided 
by its perimeter.
    Flashoff area means the portion of a coating operation between the 
coating applicator and the drying oven where VOC begins to evaporate 
from the coated substrate.
    Natural draft opening means any opening in a room, building, or 
total enclosure that remains open during operation of the facility and 
that is not connected to a duct in which a fan is installed. The rate 
and direction of the natural draft across such an opening is a 
consequence of the difference in pressures on either side of the wall or 
barrier containing the opening.

[[Page 545]]

    Nominal 1-month period means a calendar month or, if established 
prior to the performance test in a statement submitted with notification 
of anticipated startup pursuant to 40 CFR 60.7(a)(2), a similar monthly 
time period (e.g., 30-day month or accounting month).
    Onsite coating mix preparation equipment means those pieces of 
coating mix preparation equipment located at the same plant as the 
coating operation they serve.
    Polymeric coating of supporting substrates means a web coating 
process that applies elastomers, polymers, or prepolymers to a 
supporting web other than paper, plastic film, metallic foil, or metal 
coil.
    Substrate means the surface to which a coating is applied.
    Temporary enclosure means a total enclosure that is constructed for 
the sole purpose of measuring the fugitive VOC emissions from an 
affected facility.
    Total enclosure means a structure that is constructed around a 
source of emissions and operated so that all VOC emissions are collected 
and exhausted through a stack or duct. With a total enclosure, there 
will be no fugitive emissions, only stack emissions. The drying oven 
itself may be part of the total enclosure.
    Vapor capture system means any device or combination of devices 
designed to contain, collect, and route solvent vapors released from the 
coating mix preparation equipment or coating operation.
    VOC in the applied coating means the product of Method 24 VOC 
analyses or formulation data (if those data are demonstrated to be 
equivalent to Method 24 results) and the total volume of coating fed to 
the coating applicator.
    VOC used means the amount of VOC delivered to the coating mix 
preparation equipment of the affected facility (including any contained 
in premixed coatings or other coating ingredients prepared off the plant 
site) for the formulation of polymeric coatings to be applied to 
supporting substrates at the coating operation, plus any solvent added 
after initial formulation is complete (e.g., dilution solvent added at 
the coating operation). If premixed coatings that require no mixing at 
the plant site are used, ``VOC used'' means the amount of VOC delivered 
to the coating applicator(s) of the affected facility.
    Volatile organic compounds or VOC means any organic compounds that 
participate in atmospheric photochemical reactions; or that are measured 
by a reference method, an equivalent method, an alternative method, or 
that are determined by procedures specified under any subpart.
    Waterborne coating means a coating which contains more than 5 weight 
percent water in its volatile fraction.
    Web coating means the coating of products, such as fabric, paper, 
plastic film, metallic foil, metal coil, cord, and yarn, that are 
flexible enough to be unrolled from a large roll; and coated as a 
continuous substrate by methods including, but not limited to, knife 
coating, roll coating, dip coating, impregnation, rotogravure, and 
extrusion.
    (b) The nomenclature used in this subpart has the following meaning:

Ak=the area of each natural draft opening (k) in a total 
enclosure, in square meters.
Caj=the concentration of VOC in each gas stream (j) exiting 
the emission control device, in parts per million by volume.
Cbi=the concentration of VOC in each gas stream (i) entering 
the emission control device, in parts per million by volume.
Cdi=the concentration of VOC in each gas stream (i) entering 
the emission control device from the affected coating operation, in 
parts per million by volume.
Cfk=the concentration of VOC in each uncontrolled gas stream 
(k) emitted directly to the atmosphere from the affected coating 
operation, in parts per million by volume.
Cgv=the concentration of VOC in the gas stream entering each 
individual carbon adsorber vessel (v), in parts per million by volume. 
For purposes of calculating the efficiency of the individual adsorber 
vessel, Cgv may be measured in the carbon adsorption system's 
common inlet duct prior to the branching of individual inlet ducts.
Chv=the concentration of VOC in the gas stream exiting each 
individual carbon adsorber vessel (v), in parts per million by volume.
E=the control device efficiency achieved for the duration of the 
emission test (expressed as a fraction).
F=the VOC emission capture efficiency of the vapor capture system 
achieved for the duration of the emission test (expressed as a 
fraction).

[[Page 546]]

FV=the average inward face velocity across all natural draft openings in 
a total enclosure, in meters per hour.
Hv=the individual carbon adsorber vessel (v) efficiency 
achieved for the duration of the emission test (expressed as a 
fraction).
Hsys=the carbon adsorption system efficiency calculated when 
each adsorber vessel has an individual exhaust stack.
Mci=the total mass (kg) of each coating (i) applied to the 
substrate at an affected coating operation during a nominal 1-month 
period as determined from facility records.
Mr=the total mass (kg) of VOC recovered for a nominal 1-month 
period.
Qaj=the volumetric flow rate of each gas stream (j) exiting 
the emission control device, in dry standard cubic meters per hour when 
Method 18 or 25 is used to measure VOC concentration or in standard 
cubic meters per hour (wet basis) when Method 25A is used to measure VOC 
concentration.
Qbi=the volumetric flow rate of each gas stream (i) entering 
the emission control device, in dry standard cubic meters per hour when 
Method 18 or 25 is used to measure VOC concentration or in standard 
cubic meters per hour (wet basis) when Method 25A is used to measure VOC 
concentration.
Qdi=the volumetric flow rate of each gas stream (i) entering 
the emission control device from the affected coating operation, in dry 
standard cubic meters per hour when Method 18 or 25 is used to measure 
VOC concentration or in standard cubic meters per hour (wet basis) when 
Method 25A is used to measure VOC concentration.
Qfk=the volumetric flow rate of each uncontrolled gas stream 
(k) emitted directly to the atmosphere from the affected coating 
operation, in dry standard cubic meters per hour when Method 18 or 25 is 
used to measure VOC concentration or in standard cubic meters per hour 
(wet basis) when Method 25A is used to measure VOC concentration.
Qgv=the volumetric flow rate of the gas stream entering each 
individual carbon adsorber vessel (v), in dry standard cubic meters per 
hour when Method 18 or 25 is used to measure VOC concentration or in 
standard cubic meters per hour (wet basis) when Method 25A is used to 
measure VOC concentration. For purposes of calculating the efficiency of 
the individual adsorber vessel, the value of Qgv can be 
assumed to equal the value of Qhv measured for that adsorber 
vessel.
Qhv=the volumetric flow rate of the gas stream exiting each 
individual carbon adsorber vessel (v), in dry standard cubic meters per 
hour when Method 18 or 25 is used to measure VOC concentration or in 
standard cubic meters per hour (wet basis) when Method 25A is used to 
measure VOC concentration.
Qini=the volumetric flow rate of each gas stream 
(i) entering the total enclosure through a forced makeup air duct, in 
standard cubic meters per hour (wet basis).
Qoutj=the volumetric flow rate of each gas stream 
(j) exiting the total enclosure through an exhaust duct or hood, in 
standard cubic meters per hour (wet basis).
R=the overall VOC emission reduction achieved for the duration of the 
emission test (expressed as a fraction).
RSi=the total mass (kg) of VOC retained on the coated 
substrate after oven drying or contained in waste coating for a given 
combination of coating and substrate.
Woi=the weight fraction of VOC in each coating (i) applied at 
an affected coating operation during a nominal 1-month period as 
determined by Method 24.

    (c) Tables 1a and 1b present a cross reference of the affected 
facility status and the relevant section(s) of the regulation.

                      Table 1a--Cross Referencea b
------------------------------------------------------------------------
                                                         Compliance
              Status                   Standard        provisions Sec.
                                                           60.743
------------------------------------------------------------------------
A. Coating operation:
    1. If projected VOC use is     Sec.  60.740(b)  Not applicable.
     <95 Mg/yr.                     : Monitor VOC
                                    use.
    2. If projected VOC use is 95  Sec.  60.742(b)  (a)(1), (a)(2),
     Mg/yr.                         (1): Reduce      (a)(3), or (a)(4);
                                    VOC emissions
                                    to the
                                    atmosphere
                                    from the
                                    coating
                                    operation by
                                    at least 90
                                    percent; or.
                                   Sec.  60.742(b)  (b), (e).
                                    (2): Install,
                                    operate, and
                                    maintain a
                                    total
                                    enclosure
                                    around the
                                    coating
                                    operation and
                                    vent the
                                    captured VOC
                                    emissions from
                                    the total
                                    enclosure to a
                                    control device
                                    that is at
                                    least 95
                                    percent
                                    efficient.
B. Coating mix preparation
 equipment:
    1. If projected VOC use is 95  Sec.  60.742(c)  (d), (e).
     Mg/yr but <130 Mg/yr.          (3): (i)
                                    Install,
                                    operate, and
                                    maintain a
                                    cover on each
                                    piece of
                                    affected
                                    equipment; or
                                    (ii) install,
                                    operate, and
                                    maintain a
                                    cover on each
                                    piece of
                                    affected
                                    equipment and
                                    vent VOC
                                    emissions to a
                                    VOC control
                                    device.

[[Page 547]]

 
    2. If projected VOC use is     Sec.  60.742(c)  (d).
     130 Mg/yr but there is no      (2): (i)
     concurrent construction of a   Install,
     control device.                operate, and
                                    maintain a
                                    cover on each
                                    piece of
                                    affected
                                    equipment; or
                                    (ii) install,
                                    operate, and
                                    maintain a
                                    cover on each
                                    piece of
                                    affected
                                    equipment and
                                    vent VOC
                                    emissions to a
                                    VOC control
                                    device.
    3. If projected VOC use is     Sec.  60.742(c)  (c), (e).
     130 Mg/yr and there is         (1): Install,
     concurrent construction of a   operate, and
     control device.                maintain a
                                    cover on each
                                    piece of
                                    affected
                                    equipment and
                                    vent VOC
                                    emissions from
                                    the covered
                                    equipment to a
                                    95 percent
                                    efficient
                                    control device
                                    while
                                    preparation of
                                    the coating is
                                    taking place
                                    within the
                                    vessel.
------------------------------------------------------------------------
a This table is presented for the convenience of the user and is not
  intended to supersede the language of the regulation. For the details
  of the requirements, refer to the text of the regulation.
b Refer to Table 1b to determine which subsections of Secs.  60.744,
  60.745, and 60.747 correspond to each compliance provision (Sec.
  60.743).


                                                                Table 1b--Cross Reference
--------------------------------------------------------------------------------------------------------------------------------------------------------
    Compliance provisions--Sec.                                                          Monitoring requirements--Sec.     Reporting and recordkeeping
              60.743                 Test methods--Sec.  60.745   Category/equipment a               60.744                 requirements--Sec.  60.747
--------------------------------------------------------------------------------------------------------------------------------------------------------
A. Coating operation:
    (a)(1)--Gaseous emission test   (b)-(g)....................  General, CA, CO, TI,   (a), (i), (j), (k), (c)(1),      (a), (d)(7), (f), (g), (h),
     for coating operations not                                   CI, PE, TE.            (d), (e), (f), (g).              (d)(1)(i), (d)(2)(i), (d)(3),
     using carbon adsorption beds                                                                                         (d)(4), (d)(5), (d)(6).
     with individual exhausts.
    (a)(2)--Gaseous emission test   (b)-(g)....................  General, CA, PE, TE..  (a), (i), (j), (k), (c)(2), (g)  (a), (d)(7), (f), (g), (h),
     for coating operations using                                                                                         (d)(1)(ii), (d)(2)(ii),
     carbon adsorption beds with                                                                                          (d)(6).
     individual exhausts.
    (a)(3)--Monthly liquid          (a)........................  VOC recovery.........  (i), (k).......................  (e), (f), (g), (h).
     material balance--can be used
     only when a VOC recovery
     device controls only those
     emissions from one affected
     coating operation.
    (a)(4)--Short-term (3 to 7      (a)........................  General, CA, CO, PE,   (a), (i), (j), (k), (c)(1),      (a), (d)(7), (f), (g), (h),
     day) liquid material balance--                               TE.                    (c)(2), (d), (g).                (d)(1), (d)(2), (d)(3),
     may be used as an alternative                                                                                        (d)(6).
     to (a)(3).
    (b)--Alternative standard for   (b)-(g)....................  General, CA, CO, TI,   (a), (i), (j), (k), (c)(1),      (a), (d)(7), (f), (g), (h),
     coating operation--                                          CI, PE, TE.            (c)(2), (d), (e), (f), (h).      (d)(1), (d)(2), (d)(3),
     demonstrate use of approved                                                                                          (d)(4), (d)(5), (d)(6).
     total enclosure and emissions
     vented to a 95 percent
     efficient control device.
B. Coating mix preparation
 equipment:
    (c)--Standard for equipment     (b)-(g)....................  General, CA, TI, CI..  (a), (i), (j), (k), (c)(1),      (a), (d)(7), (f), (g), (h),
     servicing a coating operation                                                       (c)(2), (e), (f).                (d)(1), (d)(2), (d)(4),
     with concurrent construction                                                                                         (d)(5).
     of a control device that uses
     at least 130 Mg/yr of VOC--
     demonstrate that covers
     meeting specifications are
     installed and used properly;
     procedures detailing proper
     use are posted; the mix
     equipment is vented to a 95
     percent efficient control
     device.
    (d)--Standard for equipment     No other requirements apply  .....................  ...............................  ...............................
     servicing a coating operation
     that does not have concurrent
     construction of a control
     device but uses at least 130
     Mg/yr of VOC or for equipment
     servicing a coating operation
     that uses <130 Mg/yr but 95
     Mg/yr of VOC--demonstrate
     that covers meeting
     specifications are installed
     and used properly; procedures
     detailing proper use are
     posted; the mix equipment is
     vented to a control device
     (optional).
--------------------------------------------------------------------------------------------------------------------------------------------------------
a CA=carbon adsorber; CO=condenser; TI=thermal incinerator; CI=catalytic incinerator; PE=partial enclosure; TE=total enclosure.


[[Page 548]]



Sec. 60.742  Standards for volatile organic compounds.

    (a) Each owner or operator of an affected facility that is subject 
to the requirements of this subpart shall comply with the emissions 
limitations set forth in this section on and after the date on which the 
initial performance test required by Sec. 60.8 is completed, but not 
later than 60 days after achieving the maximum production rate at which 
the affected facility will be operated or 180 days after initial 
startup, whichever date comes first.
    (b) For the coating operation, each owner or operator of an affected 
facility shall either:
    (1) Reduce VOC emissions to the atmosphere from the coating 
operation by at least 90 percent (``emission reduction'' standard); or
    (2) Install, operate, and maintain a total enclosure around the 
coating operation and vent the captured VOC emissions from the total 
enclosure to a control device that is at least 95 percent effecient 
(alternative standard).
    (c) For the onsite coating mix preparation equipment of an affected 
facility, the owner or operator shall comply with the following 
requirements, as applicable:
    (1) For an affected facility that has concurrent construction of a 
control device and uses at least 130 Mg of VOC per 12-month period, the 
owner or operator shall install, operate, and maintain a cover on each 
piece of affected coating mix preparation equipment and vent VOC 
emissions from the covered mix equipment to a 95 percent efficient 
control device while preparation of the coating is taking place within 
the vessel.
    (2) For an affected facility that does not have concurrent 
construction of a control device but uses at least 130 Mg of VOC per 12-
month period, the owner or operator shall either:
    (i) Install, operate, and maintain a cover on each piece of affected 
coating mix preparation equipment; or
    (ii) Install, operate, and maintain a cover on each piece of 
affected coating mix preparation equipment and vent VOC emissions to a 
VOC control device.
    (3) For an affected facility that uses at least 95 Mg but less than 
130 Mg of VOC per 12-month period, the owner or operator shall either.
    (i) Install, operate, and maintain a cover on each piece of affected 
coating mix preparation equipment; or
    (ii) Install, operate, and maintain a cover on each piece of 
affected coating mix preparation equipment and vent VOC emissions to a 
VOC control device.



Sec. 60.743  Compliance provisions.

    (a) To demonstrate compliance with the emission reduction standard 
for coating operations specified in Sec. 60.742(b)(1), the owner or 
operator of the affected facility shall use one of the following 
methods.
    (1) Gaseous emission test for coating operations not using carbon 
adsorption beds with individual exhausts. This method is applicable when 
the emissions from any affected coating operation are controlled by a 
control device other than a fixed-bed carbon adsorption system with 
individual exhaust stacks for each adsorber vessel. The owner or 
operator using this method shall comply with the following procedures:
    (i) Construct the vapor capture system and control device so that 
all gaseous volumetric flow rates and total VOC emissions can be 
accurately determined by the applicable test methods and procedures 
specified in Sec. 60.745(b) through (g);
    (ii) Determine capture efficiency from the coating operation by 
capturing, venting, and measuring all VOC emissions from the coating 
operation. During a performance test, the owner or operator of an 
affected coating operation located in an area with other sources of VOC 
shall isolate the coating operation emissions from all other sources of 
VOC by one of the following methods:
    (A) Build a temporary enclosure, as defined in Sec. 60.741(a) and 
conforming to the requirements of Sec. 60.743(b)(1), around the affected 
coating operation. The temporary enclosure must be constructed and 
ventilated (through stacks suitable for testing) so that it has minimal 
impact on performance of the capture system; or
    (B) Shut down all other sources of VOC and continue to exhaust 
fugitive

[[Page 549]]

emissions from the affected coating operation through any building 
ventilation system and other room exhausts such as those on drying 
ovens. All such ventilation air must be vented through stacks suitable 
for testing because the VOC content in each must be determined.
    (iii) Operate the emission control device with all emission sources 
connected and operating.
    (iv) Determine the efficiency (E) of the control device by Equation 
1:
[GRAPHIC] [TIFF OMITTED] TC01JN92.067

    (v) Determine the efficiency (F) of the vapor capture system by 
Equation 2:
[GRAPHIC] [TIFF OMITTED] TC01JN92.068

    (vi) For each affected coating operation subject to 
Sec. 60.742(b)(1) (emission reduction standard for coating operations), 
compliance is demonstrated if the product of (E)x(F) is equal to or 
greater than 0.90.
    (2) Gaseous emission test for coating operations using carbon 
adsorption beds with individual exhausts. This method is applicable when 
emissions from any affected coating operation are controlled by a fixed-
bed carbon adsorption system with individual exhaust stacks for each 
adsorber vessel. The owner or operator using this method shall comply 
with the following procedures:
    (i) Construct the vapor capture system and control device so that 
each volumetric flow rate and the total VOC emissions can be accurately 
determined by the applicable test methods and procedures specified in 
Sec. 60.745 (b) through (g);
    (ii) Assure that all VOC emissions from the coating operation are 
segregated from other VOC sources and that the emissions can be captured 
for measurement, as described in Sec. 60.743(a)(1)(ii) (A) and (B);
    (iii) Operate the emission control device with all emission sources 
connected and operating;
    (iv) Determine the efficiency (Hv) of each individual 
adsorber vessel (v) using Equation 3:

[[Page 550]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.069

    (v) Determine the efficiency of the carbon adsorption system 
(Hsys) by computing the average efficiency of the adsorber 
vessels as weighted by the volumetric flow rate (Qhv) of each 
individual adsorber vessel (v) using Equation 4:
[GRAPHIC] [TIFF OMITTED] TC01JN92.070

    (vi) Determine the efficiency (F) of the vapor capture system using 
Equation (2).
    (vii) For each affected coating operation subject to 
Sec. 60.742(b)(1) (emission reduction standard for coating operations), 
compliance is demonstrated if the product of (Hsys)x(F) is 
equal to or greater than 0.90.
    (3) Monthly liquid material balance. This method can be used only 
when a VOC recovery device controls only those emissions from one 
affected coating operation. It may not be used if the VOC recovery 
device controls emissions from any other VOC emission sources. When 
demonstrating compliance by this method, Sec. 60.8(f) (Performance 
Tests) of this part does not apply. The owner or operator using this 
method shall comply with the following procedures to determine the VOC 
emission reduction for each nominal 1-month period:
    (i) Measure the amount of coating applied at the coating applicator. 
This quantity shall be determined at a time and location in the process 
after all ingredients (including any dilution solvent) have been added 
to the coating, or appropriate adjustments shall be made to account for 
any ingredients added after the amount of coating has been determined;
    (ii) Determine the VOC content of all coatings applied using the 
test method specified in Sec. 60.745(a). This value shall be determined 
at a time and location in the process after all ingredients (including 
any dilution solvent) have been added to the coating, or appropriate 
adjustments shall be made to account for any ingredients added after the 
VOC content in the coating has been determined;
    (iii) Install, calibrate, maintain, and operate, according to the 
manufacturer's specifications, a device that indicates the cumulative 
amount of VOC recovered by the control device over each nominal 1-month 
period. The device shall be certified by the manufacturer to be accurate 
to within 2.0 percent;
    (iv) Measure the amount of VOC recovered; and
    (v) Calculate the overall VOC emission reduction (R) for each and 
every nominal 1-month period using Equation 5. Emissions during startups 
and shutdowns are to be included when determining R because startups and 
shutdowns are part of normal operation for this source category.

[[Page 551]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.071


If the value of R is equal to or greater than 0.90, compliance with 
Sec. 60.742(b)(1) is demonstrated.
    (A) The value of RSi is zero unless the owner or operator 
submits the following information to the Administrator for approval of a 
measured value of RSi that is greater than zero but less than 
or equal to 6 percent by weight of the liquid VOC applied:
    (1) Measurement techniques; and
    (2) Documentation that the measured value of RSi exceeds 
zero but is less than or equal to 6 percent by weight of the liquid VOC 
applied.
    (B) For those facilities not subject to paragraph (a)(3)(v)(A) of 
this section, the value of RSi is zero unless the owner or 
operator submits the following information to the Administrator for 
approval of a measured value of RSi that is greater than 6 
percent by weight of the liquid VOC applied.
    (1) Measurement techniques;
    (2) Documentation that the measured value of RSi exceeds 
6 percent by weight of the liquid VOC applied; and
    (3) Either documentation of customer specifications requiring higher 
values or documentation that the desired properties of the product make 
it necessary for RSi to exceed 6 percent by weight of the 
liquid VOC applied and that such properties cannot be achieved by other 
means.
    (C) The measurement techniques of paragraphs (a)(3)(v)(A)(1) and 
(a)(3)(v)(B)(1) of this section shall be submitted to the Administrator 
for approval with the notification of anticipated startup required under 
Sec. 60.7(a)(2).
    (vi) The point at which Mr is to be measured shall be 
established when the compliance procedures are approved. The presumptive 
point of measurement shall be prior to separation/ purification; a point 
after separation/purification may be adopted for enhanced convenience or 
accuracy.
    (4) Short-term liquid material balance. This method may be used as 
an alternative to the monthly liquid material balance described in 
paragraph (a)(3) of this section. The owner or operator using this 
method shall comply with the following procedures to determine VOC 
emission reduction for a 3- to 7-day period and shall continuously 
monitor VOC emissions as specified in Sec. 60.744.
    (i) Use the procedures described in paragraphs (a)(3) (i) through 
(vi) of this section to determine the overall emission reduction, R. 
Compliance is demonstrated if the value of R is equal to or greater than 
0.90.
    (ii) The number of days for the performance test (3 to 7) is to be 
based on the affected facility's representative performance consistent 
with the requirements of Sec. 60.8(c). Data demonstrating that the 
chosen test period is representative shall be submitted to the 
Administrator for approval with the notification of anticipated startup 
required under Sec. 60.7(a)(2).
    (b) Each owner or operator of an affected coating operation subject 
to the standard specified in Sec. 60.742(b)(2) (alternative standard for 
coating operations) shall:
    (1) Demonstrate that a total enclosure is installed. The total 
enclosure shall either be approved by the Administrator in accordance 
with the provisions of Sec. 60.746, or meet the requirements in 
paragraphs (b)(1) (i) through (vi) of this section, as follows:
    (i) The only openings in the enclosure are forced makeup air and 
exhaust ducts and natural draft openings such as those through which raw 
materials enter and exist the coating operation;
    (ii) Total area of all natural draft openings does not exceed 5 
percent of the total surface area of the total enclosure's walls, floor, 
and ceiling;
    (iii) All access doors and windows are closed during normal 
operation of the

[[Page 552]]

enclosed coating operation, except for brief, occasional openings to 
accommodate process equipment adjustments. If such openings are 
frequent, or if the access door or window remains open for a significant 
amount of time during the process operation, it must be considered a 
natural draft opening. Access doors used routinely by workers to enter 
and exit the enclosed area shall be equipped with automatic closure 
devices;
    (iv) Average inward face velocity (FV) across all natural draft 
openings is a minimum of 3,600 meters per hour as determined by the 
following procedures:
    (A) Construct all forced makeup air ducts and all exhaust ducts so 
that the volumetric flow rate in each can be accurately determined by 
the test methods and procedures specified in Sec. 60.745 (c) and (d). 
Volumetric flow rates shall be calculated without the adjustment 
normally made for moisture content; and
    (B) Determine FV by Equation 6:
    [GRAPHIC] [TIFF OMITTED] TC01JN92.072
    
    (v) The air passing through all natural draft openings flows into 
the enclosure continuously. If FV is less than or equal to 9,000 meters 
per hour, the continuous inward airflow shall be verified by continuous 
observation using smoke tubes, streamers, tracer gases, or other means 
approved by the Administrator over the period that the volumetric flow 
rate tests required to determine FV are carried out. If FV is greater 
than 9,000 meters per hour, the direction of airflow thourgh the natural 
draft openings shall be presumed to be inward at all times without 
verification.
    (vi) All sources of emissions within the enclosure shall be a 
minimum of four equivalent diameters away from each natural draft 
opening.
    (2) Determine the control device efficiency using Equation (1) or 
Equations (3) and (4), as applicable, and the test methods and 
procedures specified in Sec. 60.745 (b) through (g).
    (3) Compliance is demonstrated if the installation of a total 
enclosure is demonstrated and the value of E determined from Equation 
(1) or the value of Hsys determined from Equations (3) and 
(4), as applicable, is equal to or greater than 0.95.
    (c) To demonstrate compliance with Sec. 60.742(c)(1) (standard for 
coating mix preparation equipment servicing a coating operation with 
concurrent construction of a control device that uses at least 130 Mg 
per year of VOC), each owner or operator of affected coating mix 
preparation equipment shall demonstrate that:
    (1) Covers meeting the following specifications have been installed 
and are being used properly:
    (i) Cover shall be closed at all times except when adding 
ingredients, withdrawing samples, transferring the contents, or making 
visual inspection when such activities cannot be carried out with cover 
in place. Such activities shall be carried out through ports of the 
minimum practical size;
    (ii) Cover shall extend at least 2 centimeters beyond the outer rim 
of the opening or shall be attached to the rim;
    (iii) Cover shall be of such design and construction that contact is 
maintained between cover and rim along the entire perimeter;
    (iv) Any breach in the cover (such as a slit for insertion of a 
mixer shaft or port for addition of ingredients) shall be covered 
consistent with paragraphs

[[Page 553]]

(c)(1) (i), (ii), and (iii) of this section when not actively in use. An 
opening sufficient to allow safe clearance for a mixer shaft is 
acceptable during those periods when the shaft is in place; and
    (v) A polyehtylene or nonpermanent cover may be used provided it 
meets the requirements of paragraphs (c)(1) (ii), (iii), and (iv) of 
this section. Such a cover shall not be reused after once being removed.
    (2) Procedures detailing the proper use of covers, as specified in 
paragraph (c)(1)(i) of this section, have been posted in all areas where 
affected coatings mix preparation equipment is used;
    (3) The coating mix preparation equipment is vented to a control 
device while preparation of the coating is taking place within the 
vessel; and
    (4) The control device efficiency (E or Hsys, as 
applicable) determined using Equation (1) or Equations (3) and (4), 
respectively, and the test methods and procedures specified in 
Sec. 60.745 (b) through (g) is equal to or greater than 0.95.
    (d) To demonstrate compliance with Sec. 60.742(c)(2) (standard for 
coating mix preparation equipment servicing a coating operation that 
does not have concurrent construction of a control device but uses at 
least 130 Mg of VOC per year) or Sec. 60.742(c)(3) (standard for coating 
mix preparation equipment servicing a coating operation that uses at 
least 95 Mg but less than 130 Mg of VOC per year), each owner or 
operator of affected coating mix preparation equipment shall demonstrate 
upon inspection that:
    (1) Covers satisfying the specifications in paragraphs (c)(1) (i) 
through (v) of this section have been installed and are being properly 
operated and maintained; and
    (2) Procedures detailing the proper use of covers, as specified in 
paragraph (c)(1)(i) of this section, have been posted in all areas where 
affected coating mix preparation equipment is used.
    (3) Owners or operators meeting the standard specified in 
Sec. 60.742 (c)(2)(ii) or (c)(3)(ii) shall also demonstrate that the 
coating mix preparation equipment is vented to a control device.
    (e) If a control device other than a carbon adsorber, condenser, or 
incinerator is used to control emissions from an affected facility, the 
necessary operating specifications for that device must be approved by 
the Administrator. An example of such a device is a flare.



Sec. 60.744  Monitoring requirements.

    (a) Each owner or operator of an affected facility shall install and 
calibrate all monitoring devices required under the provisions of this 
section according to the manufacturer's specifications, prior to the 
initial performance test in locations such that representative values of 
the monitored parameters will be obtained. The parameters to be 
monitored shall be continuously measured and recorded during each 
performance test.
    (b) Each owner or operator of an affected facility that uses less 
than 95 Mg of VOC per year and each owner or operator of an affected 
facility subject to the provisions specified in Sec. 60.742(c)(3) shall:
    (1) Make semiannual estimates of the projected annual amount of VOC 
to be used for the manufacture of polymeric coated substrate at the 
affected coating operation in that year; and
    (2) Maintain records of actual VOC use.
    (c) Each owner or operator of an affected facility controlled by a 
carbon adsorption system and demonstrating compliance by the procedures 
described in Sec. 60.743 (a)(1), (2), (b), or (c) (which include control 
device efficiency determinations) or Sec. 60.743(a)(4) (short-term 
liquid material balance) shall carry out the monitoring provisions of 
paragraph (c)(1) or (2) of this section, as appropriate.
    (1) For carbon adsorption systems with a common exhaust stack for 
all the individual adsorber vessels, install, calibrate, maintain, and 
operate, according to the manufacturer's specifications, a monitoring 
device that continuously indicates and records the concentration level 
of organic compounds in either the control device outlet gas stream or 
in both the control device inlet and outlet gas streams. The outlet gas 
stream shall be monitored if the percent increase in the concentration 
level of organic compounds is used as the basis for reporting, as 
described in Sec. 60.747(d)(1)(i). The

[[Page 554]]

inlet and outlet gas streams shall be monitored if the percent control 
device efficiency is used as the basis for reporting, as described in 
Sec. 60.747(d)(2)(i).
    (2) For carbon adsorption systems with individual exhaust stacks for 
each adsorber vessel, install, calibrate, maintain, and operate, 
according to the manufacturer's specifications, a monitoring device that 
continuously indicates and records the concentration level of organic 
compounds in the outlet gas stream for a minimum of one complete 
adsorption cycle per day for each adsorber vessel. The owner or operator 
may also monitor and record the concentration level of organic compounds 
in the common carbon adsorption system inlet gas stream or in each 
individual carbon adsorber vessel inlet stream. The outlet gas streams 
shall be monitored if the percent increase in the concentration level of 
organic compounds is used as the basis for reporting, as described in 
Sec. 60.747(d)(1)(ii). In this case, the owner or operator shall compute 
daily a 3-day rolling average concentration level of organics in the 
outlet gas stream from each individual adsorber vessel. The inlet and 
outlet gas streams shall be monitored if the percent control device 
efficiency is used as the basis for reporting, as described in 
Sec. 60.747(d)(2)(ii). In this case, the owner or operator shall compute 
daily a 3-day rolling average efficiency for each individual adsorber 
vessel.
    (d) Each owner or operator of an affected facility controlled by a 
condensation system and demonstrating compliance by the test methods 
described in Sec. 60.743 (a)(1), (2), (b), or (c) (which include control 
device efficiency determinations) or Sec. 60.743(a)(4) (short-term 
liquid material balance) shall install, calibrate, maintain, and 
operate, according to the manufacturer's specifications, a monitoring 
device that continuously indicates and records the temperature of the 
condenser exhaust stream.
    (e) Each owner or operator of an affected facility controlled by a 
thermal incinerator and demonstrating compliance by the test methods 
described in Sec. 60.743 (a)(1), (2), (b), or (c) (which include control 
device efficiency determinations) shall install, calibrate, maintain, 
and operate, according to the manufacturer's specifications, a 
monitoring device that continuously indicates and records the combustion 
temperature of the incinerator. The monitoring device shall have an 
accuracy within 1 percent of the temperature being measured 
in Celsius degrees.
    (f) Each owner or operator of an affected facility controlled by a 
catalytic incinerator and demonstrating compliance by the test methods 
described in Sec. 60.743 (a)(1), (2), (b), or (c) (which include control 
device efficiency determinations) shall install, calibrate, maintain, 
and operate, according to the manufacturer's specifications, a 
monitoring device that continuously indicates and records the gas 
temperature both upstream and downstream of the catalyst bed. The 
monitoring device shall have an accuracy within 1 percent of 
the temperature being measured in Celsius degrees.
    (g) Each owner or operator of an affected facility who demonstrates 
compliance by the test methods described in Sec. 60.743(a)(1) or (2) 
(which include vapor capture system efficiency determinations) or 
Sec. 60.743(a)(4) (short-term liquid material balance) shall submit a 
monitoring plan for the vapor capture system to the Administrator for 
approval with the notification of anticipated startup required under 
Sec. 60.7(a)(2) of the General Provisions. This plan shall identify the 
parameter to be monitored as an indicator of vapor capture system 
performance (e.g., the amperage to the exhaust fans or duct flow rates) 
and the method for monitoring the chosen parameter. The owner or 
operator shall install, calibrate, maintain, and operate, according to 
the manufacturer's specifications, a monitoring device that continuously 
indicates and records the value of the chosen parameter.
    (h) Each owner or operator of an affected facility who demonstrates 
compliance as described in Sec. 60.743(b) shall follow the procedures 
described in paragraph (g) of this section to establish a monitoring 
system for the total enclosure.
    (i) Each owner or operator of an affected facility shall record time 
periods of mixing or coating operations when the emission control device 
is malfunctioning or not in use.

[[Page 555]]

    (j) Each owner or operator of an affected facility shall record time 
periods of mixing or coating operations when each monitoring device is 
malfunctioning or not in use.
    (k) Records of the measurements and calculations required in 
Sec. 60.743 and Sec. 60.744 must be retained for at least 2 years 
following the date of the measurements and calculations.



Sec. 60.745  Test methods and procedures.

    Methods in appendix A of this part, except as provided under 
Sec. 60.8(b), shall be used to determine compliance as follows:
    (a) Method 24 is used to determine the VOC content in coatings. If 
it is demonstrated to the satisfaction of the Administrator that coating 
formulation data are equivalent to Method 24 results, formulation data 
may be used. In the event of any inconsistency between a Method 24 test 
and a facility's formulation data, the Method 24 test will govern. For 
Method 24, the coating sample must be a 1-liter sample collected in a 1-
liter container at a point in the process where the sample will be 
representative of the coating applied to the substrate (i.e., the sample 
shall include any dilution solvent or other VOC added during the 
manufacturing process). The container must be tightly sealed immediately 
after the sample is collected. Any solvent or other VOC added after the 
sample is taken must be measured and accounted for in the calculations 
that use Method 24 results.
    (b) Method 25 shall be used to determine VOC concentrations from 
incinerator gas streams. Alternative Methods (18 or 25A), may be used as 
explained in the applicability section of Method 25 in cases where use 
of Method 25 is demonstrated to be technically infeasible. The owner or 
operator shall submit notice of the intended test method to the 
Administrator for approval along with the notification of the 
performance test required under Sec. 60.8(d) of the General Provisions. 
Except as indicated in paragraphs (b)(1) and (b)(2) of this section, the 
test shall consist of three separate runs, each lasting a minimum of 30 
minutes.
    (1) When the method is to be used in the determination of the 
efficiency of a fixed-bed carbon adsorption system with a common exhaust 
stack for all the individual adsorber vessels pursuant to Sec. 60.743 
(a)(1), (b), or (c), the test shall consist of three separate runs, each 
coinciding with one or more complete system rotations through the 
adsorption cycles of all the individual adsorber vessels.
    (2) When the method is to be used in the determination of the 
efficiency of a fixed-bed carbon adsorption system with individual 
exhaust stacks for each adsorber vessel pursuant to Sec. 60.743 (a)(2), 
(b), or (c), each adsorber vessel shall be tested individually. Each 
test shall consist of three separate runs, each coinciding with one or 
more complete adsorption cycles.
    (c) Method 1 or 1A is used for sample and velocity traverses;
    (d) Method 2, 2A, 2C, or 2D is used for velocity and volumetric flow 
rates;
    (e) Method 3 is used for gas analysis;
    (f) Method 4 is used for stack gas moisture;
    (g) Methods 2, 2A, 2C, or 2D; 3; and 4 shall be performed, as 
applicable, at least twice during each test run.



Sec. 60.746  Permission to use alternative means of emission limitation.

    (a) If, in the Administrator's judgment, an alternative means of 
emission limitation will achieve a reduction in emissions of VOC from 
any emission point subject to Sec. 60.742(c) at least equivalent to that 
required by Sec. 60.742(b)(2) or Sec. 60.742(c), respectively, the 
Administrator will publish in the Federal Register a notice permitting 
the use of the alternative means. The Administrator may condition 
permission on requirements that may be necessary to ensure operation and 
maintenance to achieve the same emission reduction as specified in 
Sec. 60.742(b)(2) or Sec. 60.742(c), respectively.
    (b) Any notice under paragraph (a) of this section shall be 
published only after public notice and an opportunity for a public 
hearing.
    (c) Any person seeking permission under this section shall submit to 
the Administrator either results from an emission test that accurately 
collects and measures all VOC emissions from a given control device or 
an engineering

[[Page 556]]

evaluation that accurately determines such emissions.



Sec. 60.747  Reporting and recordkeeping requirements.

    (a) For each affected facility subject to the requirements of 
Sec. 60.742(b) and (c), the owner or operator shall submit the 
performance test data and results to the Administrator as specified in 
Sec. 60.8(a) of this part. In addition, the average values of the 
monitored parameters measured at least every 15 minutes and averaged 
over the period of the performance test shall be submitted with the 
results of all performance tests.
    (b) Each owner or operator of an affected facility subject to the 
provisions specified in Sec. 60.742(c)(3) and claiming to use less than 
130 Mg of VOC in the first year of operation and each owner or operator 
of an affected facility claiming to use less than 95 Mg of VOC in the 
first year of operation shall submit to the Administrator, with the 
notification of anticipated startup required under Sec. 60.7(a)(2) of 
the General Provisions, a material flow chart indicating projected VOC 
use. The owner or operator shall also submit actual VOC use records at 
the end of the initial year.
    (c) Each owner or operator of an affected facility subject to the 
provisions of Sec. 60.742(c)(3) and initially using less than 130 Mg of 
VOC per year and each owner or operator of an affected facility 
initially using less than 95 Mg of VOC per year shall:
    (1) Record semiannual estimates of projected VOC use and actual 12-
month VOC use;
    (2) Report the first semiannual estimate in which projected annual 
VOC use exceeds the applicable cutoff; and
    (3) Report the first 12-month period in which the actual VOC use 
exceeds the applicable cutoff.
    (d) Each owner or operator of an affected facility demonstrating 
compliance by the methods described in Sec. 60.743(a)(1), (2), (4), (b), 
or (c) shall maintain records and submit quarterly reports to the 
Administrator documenting the following:
    (1) For those affected facilities monitoring only the carbon 
adsorption system outlet concentration levels of organic compounds, the 
periods (during actual coating operations) specified in paragraph 
(d)(1)(i) or (ii) of this section, as applicable.
    (i) For carbon adsorption systems with a common exhaust stack for 
all the individual adsorber vessels, all periods of three consecutive 
system rotations through the adsorption cycles of all the individual 
adsorber vessels during which the average value of the concentration 
level of organic compounds in the common outlet gas stream is more than 
20 percent greater than the average value measured during the most 
recent performance test that demonstrated compliance.
    (ii) For carbon adsorption systems with individual exhaust stacks 
for each adsorber vessel, all 3-day rolling averages for each adsorber 
vessel when the concentration level of organic compounds in the 
individual outlet gas stream is more than 20 percent greater than the 
average value for that adsorber vessel measured during the most recent 
performance test that demonstrated compliance.
    (2) For those affected facilities monitoring both the carbon 
adsorption system inlet and outlet concentration levels of organic 
compounds, the periods (during actual coating operations), specified in 
paragraph (d)(2)(i) or (ii) of this section, as applicable.
    (i) For carbon adsorption systems with a common exhaust stack for 
all the individual adsorber vessels, all periods of three consecutive 
adsorption cycles of all the individual adsorber vessels during which 
the average carbon adsorption system efficiency falls below the 
applicable level as follows:
    (A) For those affected facilities demonstrating compliance by the 
performance test method described in Sec. 60.743(a)(1), the value of E 
determined using Equation (1) during the most recent performance test 
that demonstrated compliance.
    (B) For those affected facilities demonstrating compliance by the 
performance test described in Sec. 60.743(a)(4), the average value of 
the system efficiency measured with the monitor during the most recent 
performance test that demonstrated compliance.

[[Page 557]]

    (C) For those affected facilities demonstrating compliance pursuant 
to Sec. 60.743(b) or (c), 0.95.
    (ii) For carbon adsorption systems with individual exhaust stacks 
for each adsorber vessel, all 3-day rolling averages for each adsorber 
vessel during which the average carbon adsorber vessel efficiency falls 
below the applicable level as follows:
    (A) For those affected facilities demonstrating compliance by the 
performance test method described in Sec. 60.743(a)(2), (b), or (c), the 
value of Hv determined using Equation (3) during the most 
recent performance test that demonstrated compliance.
    (B) For those affected facilities demonstrating compliance by the 
performance test described in Sec. 60.743(a)(4), the average efficiency 
for that adsorber vessel measured with the monitor during the most 
recent performance test that demonstrated compliance.
    (3) For those affected facilities monitoring condenser exhaust gas 
temperature, all 3-hour periods (during actual coating operations) 
during which the average exhaust temperature is 5 or more Celsius 
degrees above the average temperature measured during the most recent 
performance test that demonstrated compliance;
    (4) For those affected facilities monitoring thermal incinerator 
combustion gas temperature, all 3-hour periods (during actual coating 
operations) during which the average combustion temperature of the 
device is more than 28 Celsius degrees below the average combustion 
temperature of the device during the most recent performance test that 
demonstrated compliance;
    (5) For those affected facilities monitoring catalytic incinerator 
catalyst bed temperature, all 3-hour periods (during actual coating 
operations) during which the average gas temperature immediately before 
the catalyst bed is more than 28 Celsius degrees below the average gas 
temperature during the most recent performance test that demonstrated 
compliance and all 3-hour periods (during actual coating operations) 
during which the average gas temperature difference across the catalyst 
bed is less than 80 percent of the average gas temperature difference 
during the most recent performance test that demonstrated compliance;
    (6) For each affected facility monitoring a total enclosure pursuant 
to Sec. 60.744(h) or vapor capture system pursuant to Sec. 60.744(g), 
all 3-hour periods (during actual coating operations) during which the 
average total enclosure or vapor capture system monitor readings vary by 
5 percent or more from the average value measured during the most recent 
performance test that demonstrated compliance.
    (7) Each owner or operator of an affected coating operation not 
required to submit reports under paragraphs (d)(1) through (6) of this 
section because no reportable periods have occurred shall submit 
semiannual statements clarifying this fact.
    (e) Each owner or operator of an affected coating operation, 
demonstrating compliance by the test methods described in 
Sec. 60.743(a)(3) (liquid-liquid material balance) shall submit the 
following:
    (1) For months of compliance, semiannual reports to the 
Administrator stating that the affected coating operation was in 
compliance for each 1-month period; and
    (2) For months of noncompliance, quarterly reports to the 
Administrator documenting the 1-month amount of VOC contained in the 
coatings, the 1-month amount of VOC recovered, and the percent emission 
reduction for each month.
    (f) Each owner or operator of an affected coating operation, either 
by itself or with associated coating mix preparation equipment, shall 
submit the following with the reports required under paragraphs (d) and 
(e) of this section:
    (1) All periods during actual mixing or coating operations when a 
required monitoring device (if any) was malfunctioning or not operating; 
and
    (2) All periods during actual mixing or coating operations when the 
control device was malfunctioning or not operating.
    (g) The reports required under paragraphs (b), (c), (d), and (e) of 
this section shall be postmarked within 30 days of the end of the 
reporting period.
    (h) Records required in Sec. 60.747 must be retained for at least 2 
years.

[[Page 558]]

    (i) The requirements of this section remain in force until and 
unless EPA, in delegating enforcement authority to a State under section 
111(c) of the Act, approves reporting requirements or an alternative 
means of compliance surveillance adopted by such States. In this event, 
affected sources within the State will be relieved of the obligation to 
comply with this subsection, provided that they comply with the 
requirements established by the State.



Sec. 60.748  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under section 111(c) of the Act, the authorities contained in 
paragraph (b) of this section shall be retained by the Administrator and 
not transferred to a State.
    (b) Authorities that will not be delegated to States: 
Secs. 60.743(a)(3)(v) (A) and (B); 60.743(e); 60.745(a); 60.746.



    Subpart WWW--Standards of Performance for Municipal Solid Waste 
                                Landfills

    Source: 61 FR 9919, Mar. 12, 1996, unless otherwise noted.



Sec. 60.750  Applicability, designation of affected facility, and delegation of authority.

    (a) The provisions of this subpart apply to each municipal solid 
waste landfill that commenced construction, reconstruction or 
modification on or after May 30, 1991. Physical or operational changes 
made to an existing MSW landfill solely to comply with Subpart Cc of 
this part are not considered construction, reconstruction, or 
modification for the purposes of this section.
    (b) The following authorities shall be retained by the Administrator 
and not transferred to the State: Sec. 60.754(a)(5).
    (c) Activities required by or conducted pursuant to a CERCLA, RCRA, 
or State remedial action are not considered construction, 
reconstruction, or modification for purposes of this subpart.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32750, June 16, 1998]



Sec. 60.751  Definitions.

    As used in this subpart, all terms not defined herein shall have the 
meaning given them in the Act or in subpart A of this part.
    Active collection system means a gas collection system that uses gas 
mover equipment.
    Active landfill means a landfill in which solid waste is being 
placed or a landfill that is planned to accept waste in the future.
    Closed landfill means a landfill in which solid waste is no longer 
being placed, and in which no additional solid wastes will be placed 
without first filing a notification of modification as prescribed under 
Sec. 60.7(a)(4). Once a notification of modification has been filed, and 
additional solid waste is placed in the landfill, the landfill is no 
longer closed.
    Closure means that point in time when a landfill becomes a closed 
landfill.
    Commercial solid waste means all types of solid waste generated by 
stores, offices, restaurants, warehouses, and other nonmanufacturing 
activities, excluding residential and industrial wastes.
    Controlled landfill means any landfill at which collection and 
control systems are required under this subpart as a result of the 
nonmethane organic compounds emission rate. The landfill is considered 
controlled at the time a collection and control system design plan is 
submitted in compliance with Sec. 60.752(b)(2)(i).
    Design capacity means the maximum amount of solid waste a landfill 
can accept, as indicated in terms of volume or mass in the most recent 
permit issued by the State, local, or Tribal agency responsible for 
regulating the landfill, plus any in-place waste not accounted for in 
the most recent permit. If the owner or operator chooses to convert the 
design capacity from volume to mass or from mass to volume to 
demonstrate its design capacity is less than 2.5 million megagrams or 
2.5 million cubic meters, the calculation must include a site specific 
density, which must be recalculated annually.
    Disposal facility means all contiguous land and structures, other 
appurtenances, and improvements on the

[[Page 559]]

land used for the disposal of solid waste.
    Emission rate cutoff means the threshold annual emission rate to 
which a landfill compares its estimated emission rate to determine if 
control under the regulation is required.
    Enclosed combustor means an enclosed firebox which maintains a 
relatively constant limited peak temperature generally using a limited 
supply of combustion air. An enclosed flare is considered an enclosed 
combustor.
    Flare means an open combustor without enclosure or shroud.
    Gas mover equipment means the equipment (i.e., fan, blower, 
compressor) used to transport landfill gas through the header system.
    Household waste means any solid waste (including garbage, trash, and 
sanitary waste in septic tanks) derived from households (including, but 
not limited to, single and multiple residences, hotels and motels, 
bunkhouses, ranger stations, crew quarters, campgrounds, picnic grounds, 
and day-use recreation areas).
    Industrial solid waste means solid waste generated by manufacturing 
or industrial processes that is not a hazardous waste regulated under 
Subtitle C of the Resource Conservation and Recovery Act, parts 264 and 
265 of this title. Such waste may include, but is not limited to, waste 
resulting from the following manufacturing processes: electric power 
generation; fertilizer/agricultural chemicals; food and related 
products/by-products; inorganic chemicals; iron and steel manufacturing; 
leather and leather products; nonferrous metals manufacturing/foundries; 
organic chemicals; plastics and resins manufacturing; pulp and paper 
industry; rubber and miscellaneous plastic products; stone, glass, clay, 
and concrete products; textile manufacturing; transportation equipment; 
and water treatment. This term does not include mining waste or oil and 
gas waste.
    Interior well means any well or similar collection component located 
inside the perimeter of the landfill waste. A perimeter well located 
outside the landfilled waste is not an interior well.
    Landfill means an area of land or an excavation in which wastes are 
placed for permanent disposal, and that is not a land application unit, 
surface impoundment, injection well, or waste pile as those terms are 
defined under Sec. 257.2 of this title.
    Lateral expansion means a horizontal expansion of the waste 
boundaries of an existing MSW landfill. A lateral expansion is not a 
modification unless it results in an increase in the design capacity of 
the landfill.
    Modification means an increase in the permitted volume design 
capacity of the landfill by either horizontal or vertical expansion 
based on its permitted design capacity as of May 30, 1991. Modification 
does not occur until the owner or operator commences construction on the 
horizontal or vertical expansion.
    Municipal solid waste landfill or MSW landfill means an entire 
disposal facility in a contiguous geographical space where household 
waste is placed in or on land. An MSW landfill may also receive other 
types of RCRA Subtitle D wastes (Sec. 257.2 of this title) such as 
commercial solid waste, nonhazardous sludge, conditionally exempt small 
quantity generator waste, and industrial solid waste. Portions of an MSW 
landfill may be separated by access roads. An MSW landfill may be 
publicly or privately owned. An MSW landfill may be a new MSW landfill, 
an existing MSW landfill, or a lateral expansion.
    Municipal solid waste landfill emissions or MSW landfill emissions 
means gas generated by the decomposition of organic waste deposited in 
an MSW landfill or derived from the evolution of organic compounds in 
the waste.
    NMOC means nonmethane organic compounds, as measured according to 
the provisions of Sec. 60.754.
    Nondegradable waste means any waste that does not decompose through 
chemical breakdown or microbiological activity. Examples are, but are 
not limited to, concrete, municipal waste combustor ash, and metals.
    Passive collection system means a gas collection system that solely 
uses positive pressure within the landfill to move the gas rather than 
using gas mover equipment.

[[Page 560]]

    Sludge means any solid, semisolid, or liquid waste generated from a 
municipal, commercial, or industrial wastewater treatment plant, water 
supply treatment plant, or air pollution control facility, exclusive of 
the treated effluent from a wastewater treatment plant.
    Solid waste means any garbage, sludge from a wastewater treatment 
plant, water supply treatment plant, or air pollution control facility 
and other discarded material, including solid, liquid, semisolid, or 
contained gaseous material resulting from industrial, commercial, 
mining, and agricultural operations, and from community activities, but 
does not include solid or dissolved material in domestic sewage, or 
solid or dissolved materials in irrigation return flows or industrial 
discharges that are point sources subject to permits under 33 U.S.C. 
1342, or source, special nuclear, or by-product material as defined by 
the Atomic Energy Act of 1954, as amended (42 U.S.C 2011 et seq.).
    Sufficient density means any number, spacing, and combination of 
collection system components, including vertical wells, horizontal 
collectors, and surface collectors, necessary to maintain emission and 
migration control as determined by measures of performance set forth in 
this part.
    Sufficient extraction rate means a rate sufficient to maintain a 
negative pressure at all wellheads in the collection system without 
causing air infiltration, including any wellheads connected to the 
system as a result of expansion or excess surface emissions, for the 
life of the blower.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32750, June 16, 1998; 64 
FR 9262, Feb. 24, 1999]



Sec. 60.752  Standards for air emissions from municipal solid waste landfills.

    (a) Each owner or operator of an MSW landfill having a design 
capacity less than 2.5 million megagrams by mass or 2.5 million cubic 
meters by volume shall submit an initial design capacity report to the 
Administrator as provided in Sec. 60.757(a). The landfill may calculate 
design capacity in either megagrams or cubic meters for comparison with 
the exemption values. Any density conversions shall be documented and 
submitted with the report. Submittal of the initial design capacity 
report shall fulfill the requirements of this subpart except as provided 
for in paragraphs (a)(1) and (a)(2) of this section.
    (1) The owner or operator shall submit to the Administrator an 
amended design capacity report, as provided for in Sec. 60.757(a)(3).
    (2) When an increase in the maximum design capacity of a landfill 
exempted from the provisions of Sec. 60.752(b) through Sec. 60.759 of 
this subpart on the basis of the design capacity exemption in paragraph 
(a) of this section results in a revised maximum design capacity equal 
to or greater than 2.5 million megagrams and 2.5 million cubic meters, 
the owner or operator shall comply with the provision of paragraph (b) 
of this section.
    (b) Each owner or operator of an MSW landfill having a design 
capacity equal to or greater than 2.5 million megagrams and 2.5 million 
cubic meters, shall either comply with paragraph (b)(2) of this section 
or calculate an NMOC emission rate for the landfill using the procedures 
specified in Sec. 60.754. The NMOC emission rate shall be recalculated 
annually, except as provided in Sec. 60.757(b)(1)(ii) of this subpart. 
The owner or operator of an MSW landfill subject to this subpart with a 
design capacity greater than or equal to 2.5 million megagrams and 2.5 
million cubic meters is subject to part 70 or 71 permitting 
requirements.
    (1) If the calculated NMOC emission rate is less than 50 megagrams 
per year, the owner or operator shall:
    (i) Submit an annual emission report to the Administrator, except as 
provided for in Sec. 60.757(b)(1)(ii); and
    (ii) Recalculate the NMOC emission rate annually using the 
procedures specified in Sec. 60.754(a)(1) until such time as the 
calculated NMOC emission rate is equal to or greater than 50 megagrams 
per year, or the landfill is closed.
    (A) If the NMOC emission rate, upon recalculation required in 
paragraph (b)(1)(ii) of this section, is equal to or greater than 50 
megagrams per year, the owner or operator shall install a

[[Page 561]]

collection and control system in compliance with paragraph (b)(2) of 
this section.
    (B) If the landfill is permanently closed, a closure notification 
shall be submitted to the Administrator as provided for in 
Sec. 60.757(d).
    (2) If the calculated NMOC emission rate is equal to or greater than 
50 megagrams per year, the owner or operator shall:
    (i) Submit a collection and control system design plan prepared by a 
professional engineer to the Administrator within 1 year:
    (A) The collection and control system as described in the plan shall 
meet the design requirements of paragraph (b)(2)(ii) of this section.
    (B) The collection and control system design plan shall include any 
alternatives to the operational standards, test methods, procedures, 
compliance measures, monitoring, recordkeeping or reporting provisions 
of Secs. 60.753 through 60.758 proposed by the owner or operator.
    (C) The collection and control system design plan shall either 
conform with specifications for active collection systems in Sec. 60.759 
or include a demonstration to the Administrator's satisfaction of the 
sufficiency of the alternative provisions to Sec. 60.759.
    (D) The Administrator shall review the information submitted under 
paragraphs (b)(2)(i) (A),(B) and (C) of this section and either approve 
it, disapprove it, or request that additional information be submitted. 
Because of the many site-specific factors involved with landfill gas 
system design, alternative systems may be necessary. A wide variety of 
system designs are possible, such as vertical wells, combination 
horizontal and vertical collection systems, or horizontal trenches only, 
leachate collection components, and passive systems.
    (ii) Install a collection and control system that captures the gas 
generated within the landfill as required by paragraphs (b)(2)(ii)(A) or 
(B) and (b)(2)(iii) of this section within 30 months after the first 
annual report in which the emission rate equals or exceeds 50 megagrams 
per year, unless Tier 2 or Tier 3 sampling demonstrates that the 
emission rate is less than 50 megagrams per year, as specified in 
Sec. 60.757(c)(1) or (2).
    (iii) Route all the collected gas to a control system that complies 
with the requirements in either paragraph (b)(2)(iii) (A), (B) or (C) of 
this section.
    (A) An open flare designed and operated in accordance with 
Sec. 60.18;
    (B) A control system designed and operated to reduce NMOC by 98 
weight-percent, or, when an enclosed combustion device is used for 
control, to either reduce NMOC by 98 weight percent or reduce the outlet 
NMOC concentration to less than 20 parts per million by volume, dry 
basis as hexane at 3 percent oxygen. The reduction efficiency or parts 
per million by volume shall be established by an initial performance 
test to be completed no later than 180 days after the initial startup of 
the approved control system using the test methods specified in 
Sec. 60.754(d).
    (C) Route the collected gas to a treatment system that processes the 
collected gas for subsequent sale or use. All emissions from any 
atmospheric vent from the gas treatment system shall be subject to the 
requirements of paragraph (b)(2)(iii) (A) or (B) of this section.
    (iv) Operate the collection and control device installed to comply 
with this subpart in accordance with the provisions of Sec. Sec. 60.753, 
60.755 and 60.756.
    (v) The collection and control system may be capped or removed 
provided that all the conditions of paragraphs (b)(2)(v) (A), (B), and 
(C) of this section are met:
    (A) The landfill shall be a closed landfill as defined in 
Sec. 60.751 of this subpart. A closure report shall be submitted to the 
Administrator as provided in Sec. 60.757(d);
    (B) The collection and control system shall have been in operation a 
minimum of 15 years; and
    (C) Following the procedures specified in Sec. 60.754(b) of this 
subpart, the calculated NMOC gas produced by the landfill shall be less 
than 50 megagrams per year on three successive test dates. The test 
dates shall be no less than 90 days apart, and no more than 180 days 
apart.
    (c) For purposes of obtaining an operating permit under title V of 
the Act,

[[Page 562]]

the owner or operator of a MSW landfill subject to this subpart with a 
design capacity less than 2.5 million megagrams or 2.5 million cubic 
meters is not subject to the requirement to obtain an operating permit 
for the landfill under part 70 or 71 of this chapter, unless the 
landfill is otherwise subject to either part 70 or 71. For purposes of 
submitting a timely application for an operating permit under part 70 or 
71, the owner or operator of a MSW landfill subject to this subpart with 
a design capacity greater than or equal to 2.5 million megagrams and 2.5 
million cubic meters, and not otherwise subject to either part 70 or 71, 
becomes subject to the requirements of Secs. 70.5(a)(1)(i) or 
71.5(a)(1)(i) of this chapter, regardless of when the design capacity 
report is actually submitted, no later than:
    (1) June 10, 1996 for MSW landfills that commenced construction, 
modification, or reconstruction on or after May 30, 1991 but before 
March 12, 1996;
    (2) Ninety days after the date of commenced construction, 
modification, or reconstruction for MSW landfills that commence 
construction, modification, or reconstruction on or after March 12, 
1996.
    (d) When a MSW landfill subject to this subpart is closed, the owner 
or operator is no longer subject to the requirement to maintain an 
operating permit under part 70 or 71 of this chapter for the landfill if 
the landfill is not otherwise subject to the requirements of either part 
70 or 71 and if either of the following conditions are met:
    (1) The landfill was never subject to the requirement for a control 
system under paragraph (b)(2) of this section; or
    (2) The owner or operator meets the conditions for control system 
removal specified in paragraph (b)(2)(v) of this section.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32751, June 16, 1998]



Sec. 60.753  Operational standards for collection and control systems.

    Each owner or operator of an MSW landfill with a gas collection and 
control system used to comply with the provisions of 
Sec. 60.752(b)(2)(ii) of this subpart shall:
    (a) Operate the collection system such that gas is collected from 
each area, cell, or group of cells in the MSW landfill in which solid 
waste has been in place for:
    (1) 5 years or more if active; or
    (2) 2 years or more if closed or at final grade;
    (b) Operate the collection system with negative pressure at each 
wellhead except under the following conditions:
    (1) A fire or increased well temperature. The owner or operator 
shall record instances when positive pressure occurs in efforts to avoid 
a fire. These records shall be submitted with the annual reports as 
provided in Sec. 60.757(f)(1);
    (2) Use of a geomembrane or synthetic cover. The owner or operator 
shall develop acceptable pressure limits in the design plan;
    (3) A decommissioned well. A well may experience a static positive 
pressure after shut down to accommodate for declining flows. All design 
changes shall be approved by the Administrator;
    (c) Operate each interior wellhead in the collection system with a 
landfill gas temperature less than 55 o C and with either a 
nitrogen level less than 20 percent or an oxygen level less than 5 
percent. The owner or operator may establish a higher operating 
temperature, nitrogen, or oxygen value at a particular well. A higher 
operating value demonstration shall show supporting data that the 
elevated parameter does not cause fires or significantly inhibit 
anaerobic decomposition by killing methanogens.
    (1) The nitrogen level shall be determined using Method 3C, unless 
an alternative test method is established as allowed by 
Sec. 60.752(b)(2)(i) of this subpart.
    (2) Unless an alternative test method is established as allowed by 
Sec. 60.752(b)(2)(i) of this subpart, the oxygen shall be determined by 
an oxygen meter using Method 3A except that:
    (i) The span shall be set so that the regulatory limit is between 20 
and 50 percent of the span;
    (ii) A data recorder is not required;
    (iii) Only two calibration gases are required, a zero and span, and 
ambient air may be used as the span;

[[Page 563]]

    (iv) A calibration error check is not required;
    (v) The allowable sample bias, zero drift, and calibration drift are 
10 percent.
    (d) Operate the collection system so that the methane concentration 
is less than 500 parts per million above background at the surface of 
the landfill. To determine if this level is exceeded, the owner or 
operator shall conduct surface testing around the perimeter of the 
collection area and along a pattern that traverses the landfill at 30 
meter intervals and where visual observations indicate elevated 
concentrations of landfill gas, such as distressed vegetation and cracks 
or seeps in the cover. The owner or operator may establish an 
alternative traversing pattern that ensures equivalent coverage. A 
surface monitoring design plan shall be developed that includes a 
topographical map with the monitoring route and the rationale for any 
site-specific deviations from the 30 meter intervals. Areas with steep 
slopes or other dangerous areas may be excluded from the surface 
testing.
    (e) Operate the system such that all collected gases are vented to a 
control system designed and operated in compliance with 
Sec. 60.752(b)(2)(iii). In the event the collection or control system is 
inoperable, the gas mover system shall be shut down and all valves in 
the collection and control system contributing to venting of the gas to 
the atmosphere shall be closed within 1 hour; and
    (f) Operate the control or treatment system at all times when the 
collected gas is routed to the system.
    (g) If monitoring demonstrates that the operational requirements in 
paragraphs (b), (c), or (d) of this section are not met, corrective 
action shall be taken as specified in Sec. 60.755(a)(3) through (5) or 
Sec. 60.755(c) of this subpart. If corrective actions are taken as 
specified in Sec. 60.755, the monitored exceedance is not a violation of 
the operational requirements in this section.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32751, June 16, 1998]



Sec. 60.754  Test methods and procedures.

    (a)(1) The landfill owner or operator shall calculate the NMOC 
emission rate using either the equation provided in paragraph (a)(1)(i) 
of this section or the equation provided in paragraph (a)(1)(ii) of this 
section. Both equations may be used if the actual year-to-year solid 
waste acceptance rate is known, as specified in paragraph (a)(1)(i), for 
part of the life of the landfill and the actual year-to-year solid waste 
acceptance rate is unknown, as specified in paragraph (a)(1)(ii), for 
part of the life of the landfill. The values to be used in both 
equations are 0.05 per year for k, 170 cubic meters per megagram for 
LO, and 4,000 parts per million by volume as hexane for the 
CNMOC. For landfills located in geographical areas with a 
thirty year annual average precipitation of less than 25 inches, as 
measured at the nearest representative official meteorologic site, the k 
value to be used is 0.02 per year.
    (i) The following equation shall be used if the actual year-to-year 
solid waste acceptance rate is known.
[GRAPHIC] [TIFF OMITTED] TR12MR96.025

where,

MNMOC=Total NMOC emission rate from the landfill, megagrams 
          per year
k=methane generation rate constant, year-1
Lo=methane generation potential, cubic meters per megagram 
          solid waste
Mi=mass of solid waste in the ith section, 
          megagrams
ti=age of the ith section, years
CNMOC=concentration of NMOC, parts per million by volume as 
          hexane
3.6  x  10-9=conversion factor

    The mass of nondegradable solid waste may be subtracted from the 
total mass of solid waste in a particular section of the landfill when 
calculating the value for Mi if documentation of the nature 
and amount of such wastes is maintained


[[Page 564]]


    (ii) The following equation shall be used if the actual year-to-year 
solid waste acceptance rate is unknown.

MNMOC=2Lo R (e-kc - e-k t) 
          (CNM OC) (3.6  x  10-9)

where,
MNMOC=mass emission rate of NMOC, megagrams per year
Lo=methane generation potential, cubic meters per megagram 
          solid waste
R=average annual acceptance rate, megagrams per year
k=methane generation rate constant, year-1
t=age of landfill, years
CNMOC=concentration of NMOC, parts per million by volume as 
          hexane
c=time since closure, years. For active landfill c = O and 
          e-kc=1
                               3.6  x  10-9=conversion factor

    The mass of nondegradable solid waste may be subtracted from the 
average annual acceptance rate when calculating a value for R, if 
documentation of the nature and amount of such wastes is maintained.

    (2) Tier 1. The owner or operator shall compare the calculated NMOC 
mass emission rate to the standard of 50 megagrams per year.
    (i) If the NMOC emission rate calculated in paragraph (a)(1) of this 
section is less than 50 megagrams per year, then the landfill owner 
shall submit an emission rate report as provided in Sec. 60.757(b)(1), 
and shall recalculate the NMOC mass emission rate annually as required 
under Sec. 60.752(b)(1).
    (ii) If the calculated NMOC emission rate is equal to or greater 
than 50 megagrams per year, then the landfill owner shall either comply 
with Sec. 60.752(b)(2), or determine a site-specific NMOC concentration 
and recalculate the NMOC emission rate using the procedures provided in 
paragraph (a)(3) of this section.
    (3) Tier 2. The landfill owner or operator shall determine the NMOC 
concentration using the following sampling procedure. The landfill owner 
or operator shall install at least two sample probes per hectare of 
landfill surface that has retained waste for at least 2 years. If the 
landfill is larger than 25 hectares in area, only 50 samples are 
required. The sample probes should be located to avoid known areas of 
nondegradable solid waste. The owner or operator shall collect and 
analyze one sample of landfill gas from each probe to determine the NMOC 
concentration using Method 25C of appendix A of this part or Method 18 
of appendix A of this part. If using Method 18 of appendix A of this 
part, the minimum list of compounds to be tested shall be those 
published in the most recent Compilation of Air Pollutant Emission 
Factors (AP-42). If composite sampling is used, equal volumes shall be 
taken from each sample probe. If more than the required number of 
samples are taken, all samples shall be used in the analysis. The 
landfill owner or operator shall divide the NMOC concentration from 
Method 25C of appendix A of this part by six to convert from 
CNMOC as carbon to CNM OC as hexane.
    (i) The landfill owner or operator shall recalculate the NMOC mass 
emission rate using the equations provided in paragraph (a)(1)(i) or 
(a)(1)(ii) of this section and using the average NMOC concentration from 
the collected samples instead of the default value in the equation 
provided in paragraph (a)(1) of this section.
    (ii) If the resulting mass emission rate calculated using the site-
specific NMOC concentration is equal to or greater than 50 megagrams per 
year, then the landfill owner or operator shall either comply with 
Sec. 60.752(b)(2), or determine the site-specific methane generation 
rate constant and recalculate the NMOC emission rate using the site-
specific methane generation rate using the procedure specified in 
paragraph (a)(4) of this section.
    (iii) If the resulting NMOC mass emission rate is less than 50 
megagrams per year, the owner or operator shall submit a periodic 
estimate of the emission rate report as provided in Sec. 60.757(b)(1) 
and retest the site-specific NMOC concentration every 5 years using the 
methods specified in this section.
    (4) Tier 3. The site-specific methane generation rate constant shall 
be determined using the procedures provided in Method 2E of appendix A 
of this part. The landfill owner or operator shall estimate the NMOC 
mass emission rate using equations in paragraph (a)(1)(i) or (a)(1)(ii) 
of this section and

[[Page 565]]

using a site-specific methane generation rate constant k, and the site-
specific NMOC concentration as determined in paragraph (a)(3) of this 
section instead of the default values provided in paragraph (a)(1) of 
this section. The landfill owner or operator shall compare the resulting 
NMOC mass emission rate to the standard of 50 megagrams per year.
    (i) If the NMOC mass emission rate as calculated using the site-
specific methane generation rate and concentration of NMOC is equal to 
or greater than 50 megagrams per year, the owner or operator shall 
comply with Sec. 60.752(b)(2).
    (ii) If the NMOC mass emission rate is less than 50 megagrams per 
year, then the owner or operator shall submit a periodic emission rate 
report as provided in Sec. 60.757(b)(1) and shall recalculate the NMOC 
mass emission rate annually, as provided in Sec. 60.757(b)(1) using the 
equations in paragraph (a)(1) of this section and using the site-
specific methane generation rate constant and NMOC concentration 
obtained in paragraph (a)(3) of this section. The calculation of the 
methane generation rate constant is performed only once, and the value 
obtained from this test shall be used in all subsequent annual NMOC 
emission rate calculations.
    (5) The owner or operator may use other methods to determine the 
NMOC concentration or a site-specific k as an alternative to the methods 
required in paragraphs (a)(3) and (a)(4) of this section if the method 
has been approved by the Administrator.
    (b) After the installation of a collection and control system in 
compliance with Sec. 60.755, the owner or operator shall calculate the 
NMOC emission rate for purposes of determining when the system can be 
removed as provided in Sec. 60.752(b)(2)(v), using the following 
equation:

MNMOC = 1.89  x  10-3 QLFG 
          CNMOC

where,

MNMOC = mass emission rate of NMOC, megagrams per year
QLFG = flow rate of landfill gas, cubic meters per minute
CNMOC = NMOC concentration, parts per million by volume as 
          hexane

    (1) The flow rate of landfill gas, QLFG, shall be 
determined by measuring the total landfill gas flow rate at the common 
header pipe that leads to the control device using a gas flow measuring 
device calibrated according to the provisions of section 4 of Method 2E 
of appendix A of this part.
    (2) The average NMOC concentration, CNMOC, shall be 
determined by collecting and analyzing landfill gas sampled from the 
common header pipe before the gas moving or condensate removal equipment 
using the procedures in Method 25C or Method 18 of appendix A of this 
part. If using Method 18 of appendix A of this part, the minimum list of 
compounds to be tested shall be those published in the most recent 
Compilation of Air Pollutant Emission Factors (AP-42). The sample 
location on the common header pipe shall be before any condensate 
removal or other gas refining units. The landfill owner or operator 
shall divide the NMOC concentration from Method 25C of appendix A of 
this part by six to convert from CNMOC as carbon to 
CNMOC as hexane.
    (3) The owner or operator may use another method to determine 
landfill gas flow rate and NMOC concentration if the method has been 
approved by the Administrator.
    (c) When calculating emissions for PSD purposes, the owner or 
operator of each MSW landfill subject to the provisions of this subpart 
shall estimate the NMOC emission rate for comparison to the PSD major 
source and significance levels in Secs. 51.166 or 52.21 of this chapter 
using AP-42 or other approved measurement procedures.
    (d) For the performance test required in Sec. 60.752(b)(2)(iii)(B), 
Method 25C or Method 18 of appendix A of this part shall be used to 
determine compliance with 98 weight-percent efficiency or the 20 ppmv 
outlet concentration level, unless another method to demonstrate 
compliance has been approved by the Administrator as provided by 
Sec. 60.752(b)(2)(i)(B). If using Method 18 of appendix A of this part, 
the minimum list of compounds to be tested shall be those published in 
the most recent Compilation of Air Pollutant Emission Factors (AP-42). 
The following equation shall be used to calculate efficiency:

Control Efficiency = (NMOCin - NMOCout)/
          (NMOCin)


[[Page 566]]


where,

NMOCin = mass of NMOC entering control device
NMOCout = mass of NMOC exiting control device

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32751, June 16, 1998]



Sec. 60.755  Compliance provisions.

    (a) Except as provided in Sec. 60.752(b)(2)(i)(B), the specified 
methods in paragraphs (a)(1) through (a)(6) of this section shall be 
used to determine whether the gas collection system is in compliance 
with Sec. 60.752(b)(2)(ii).
    (1) For the purposes of calculating the maximum expected gas 
generation flow rate from the landfill to determine compliance with 
Sec. 60.752(b)(2)(ii)(A)(1), one of the following equations shall be 
used. The k and Lo kinetic factors should be those published 
in the most recent Compilation of Air Pollutant Emission Factors (AP-42) 
or other site specific values demonstrated to be appropriate and 
approved by the Administrator. If k has been determined as specified in 
Sec. 60.754(a)(4), the value of k determined from the test shall be 
used. A value of no more than 15 years shall be used for the intended 
use period of the gas mover equipment. The active life of the landfill 
is the age of the landfill plus the estimated number of years until 
closure.
    (i) For sites with unknown year-to-year solid waste acceptance rate:

Qm = 2Lo R (e-kc - e-kt)

where,

Qm = maximum expected gas generation flow rate, cubic meters 
          per year
Lo = methane generation potential, cubic meters per megagram 
          solid waste
R = average annual acceptance rate, megagrams per year
k = methane generation rate constant, year-1
t = age of the landfill at equipment installation plus the time the 
          owner or operator intends to use the gas mover equipment or 
          active life of the landfill, whichever is less. If the 
          equipment is installed after closure, t is the age of the 
          landfill at installation, years
c = time since closure, years (for an active landfill c = O and 
          e-kc = 1)

    (ii) For sites with known year-to-year solid waste acceptance rate:
    [GRAPHIC] [TIFF OMITTED] TR12MR96.026
    
where,

QM=maximum expected gas generation flow rate, cubic meters 
          per year
k=methane generation rate constant, year-1
Lo=methane generation potential, cubic meters per megagram 
          solid waste
Mi=mass of solid waste in the ith section, 
          megagrams
ti=age of the ith section, years

    (iii) If a collection and control system has been installed, actual 
flow data may be used to project the maximum expected gas generation 
flow rate instead of, or in conjunction with, the equations in 
paragraphs (a)(1) (i) and (ii) of this section. If the landfill is still 
accepting waste, the actual measured flow data will not equal the 
maximum expected gas generation rate, so calculations using the 
equations in paragraphs (a)(1) (i) or (ii) or other methods shall be 
used to predict the maximum expected gas generation rate over the 
intended period of use of the gas control system equipment.
    (2) For the purposes of determining sufficient density of gas 
collectors for compliance with Sec. 60.752(b)(2)(ii)(A)(2), the owner or 
operator shall design a system of vertical wells, horizontal collectors, 
or other collection devices, satisfactory to the Administrator, capable 
of controlling and extracting gas from all portions of the landfill 
sufficient to meet all operational and performance standards.
    (3) For the purpose of demonstrating whether the gas collection 
system flow rate is sufficient to determine compliance with 
Sec. 60.752(b)(2)(ii)(A)(3), the owner or operator shall measure gauge 
pressure in the gas collection header at each individual well, monthly. 
If a positive pressure exists, action shall be initiated to correct the 
exceedance within 5 calendar days, except for the three conditions 
allowed under Sec. 60.753(b). If negative pressure cannot be achieved 
without excess air infiltration within 15 calendar days of the first 
measurement, the gas collection system shall be expanded to correct the 
exceedance within 120 days of the initial measurement of positive 
pressure. Any attempted corrective measure shall not cause exceedances 
of other

[[Page 567]]

operational or performance standards. An alternative timeline for 
correcting the exceedance may be submitted to the Administrator for 
approval.
    (4) Owners or operators are not required to expand the system as 
required in paragraph (a)(3) of this section during the first 180 days 
after gas collection system startup.
    (5) For the purpose of identifying whether excess air infiltration 
into the landfill is occurring, the owner or operator shall monitor each 
well monthly for temperature and nitrogen or oxygen as provided in 
Sec. 60.753(c). If a well exceeds one of these operating parameters, 
action shall be initiated to correct the exceedance within 5 calendar 
days. If correction of the exceedance cannot be achieved within 15 
calendar days of the first measurement, the gas collection system shall 
be expanded to correct the exceedance within 120 days of the initial 
exceedance. Any attempted corrective measure shall not cause exceedances 
of other operational or performance standards. An alternative timeline 
for correcting the exceedance may be submitted to the Administrator for 
approval.
    (6) An owner or operator seeking to demonstrate compliance with 
Sec. 60.752(b)(2)(ii)(A)(4) through the use of a collection system not 
conforming to the specifications provided in Sec. 60.759 shall provide 
information satisfactory to the Administrator as specified in 
Sec. 60.752(b)(2)(i)(C) demonstrating that off-site migration is being 
controlled.
    (b) For purposes of compliance with Sec. 60.753(a), each owner or 
operator of a controlled landfill shall place each well or design 
component as specified in the approved design plan as provided in 
Sec. 60.752(b)(2)(i). Each well shall be installed no later than 60 days 
after the date on which the initial solid waste has been in place for a 
period of:
    (1) 5 years or more if active; or
    (2) 2 years or more if closed or at final grade.
    (c) The following procedures shall be used for compliance with the 
surface methane operational standard as provided in Sec. 60.753(d).
    (1) After installation of the collection system, the owner or 
operator shall monitor surface concentrations of methane along the 
entire perimeter of the collection area and along a pattern that 
traverses the landfill at 30 meter intervals (or a site-specific 
established spacing) for each collection area on a quarterly basis using 
an organic vapor analyzer, flame ionization detector, or other portable 
monitor meeting the specifications provided in paragraph (d) of this 
section.
    (2) The background concentration shall be determined by moving the 
probe inlet upwind and downwind outside the boundary of the landfill at 
a distance of at least 30 meters from the perimeter wells.
    (3) Surface emission monitoring shall be performed in accordance 
with section 4.3.1 of Method 21 of appendix A of this part, except that 
the probe inlet shall be placed within 5 to 10 centimeters of the 
ground. Monitoring shall be performed during typical meteorological 
conditions.
    (4) Any reading of 500 parts per million or more above background at 
any location shall be recorded as a monitored exceedance and the actions 
specified in paragraphs (c)(4) (i) through (v) of this section shall be 
taken. As long as the specified actions are taken, the exceedance is not 
a violation of the operational requirements of Sec. 60.753(d).
    (i) The location of each monitored exceedance shall be marked and 
the location recorded.
    (ii) Cover maintenance or adjustments to the vacuum of the adjacent 
wells to increase the gas collection in the vicinity of each exceedance 
shall be made and the location shall be re-monitored within 10 calendar 
days of detecting the exceedance.
    (iii) If the re-monitoring of the location shows a second 
exceedance, additional corrective action shall be taken and the location 
shall be monitored again within 10 days of the second exceedance. If the 
re-monitoring shows a third exceedance for the same location, the action 
specified in paragraph (c)(4)(v) of this section shall be taken, and no 
further monitoring of that location is required until the action 
specified in paragraph (c)(4)(v) has been taken.
    (iv) Any location that initially showed an exceedance but has a 
methane concentration less than 500 ppm methane above background at the 
10-

[[Page 568]]

day re-monitoring specified in paragraph (c)(4) (ii) or (iii) of this 
section shall be re-monitored 1 month from the initial exceedance. If 
the 1-month remonitoring shows a concentration less than 500 parts per 
million above background, no further monitoring of that location is 
required until the next quarterly monitoring period. If the 1-month 
remonitoring shows an exceedance, the actions specified in paragraph 
(c)(4) (iii) or (v) shall be taken.
    (v) For any location where monitored methane concentration equals or 
exceeds 500 parts per million above background three times within a 
quarterly period, a new well or other collection device shall be 
installed within 120 calendar days of the initial exceedance. An 
alternative remedy to the exceedance, such as upgrading the blower, 
header pipes or control device, and a corresponding timeline for 
installation may be submitted to the Administrator for approval.
    (5) The owner or operator shall implement a program to monitor for 
cover integrity and implement cover repairs as necessary on a monthly 
basis.
    (d) Each owner or operator seeking to comply with the provisions in 
paragraph (c) of this section shall comply with the following 
instrumentation specifications and procedures for surface emission 
monitoring devices:
    (1) The portable analyzer shall meet the instrument specifications 
provided in section 3 of Method 21 of appendix A of this part, except 
that ``methane'' shall replace all references to VOC.
    (2) The calibration gas shall be methane, diluted to a nominal 
concentration of 500 parts per million in air.
    (3) To meet the performance evaluation requirements in section 3.1.3 
of Method 21 of appendix A of this part, the instrument evaluation 
procedures of section 4.4 of Method 21 of appendix A of this part shall 
be used.
    (4) The calibration procedures provided in section 4.2 of Method 21 
of appendix A of this part shall be followed immediately before 
commencing a surface monitoring survey.
    (e) The provisions of this subpart apply at all times, except during 
periods of start-up, shutdown, or malfunction, provided that the 
duration of start-up, shutdown, or malfunction shall not exceed 5 days 
for collection systems and shall not exceed 1 hour for treatment or 
control devices.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32752, June 16, 1998]



Sec. 60.756  Monitoring of operations.

    Except as provided in Sec. 60.752(b)(2)(i)(B),
    (a) Each owner or operator seeking to comply with 
Sec. 60.752(b)(2)(ii)(A) for an active gas collection system shall 
install a sampling port and a thermometer other temperature measuring 
device, or an access port for temperature measurements at each wellhead 
and:
    (1) Measure the gauge pressure in the gas collection header on a 
monthly basis as provided in Sec. 60.755(a)(3); and
    (2) Monitor nitrogen or oxygen concentration in the landfill gas on 
a monthly basis as provided in Sec. 60.755(a)(5); and
    (3) Monitor temperature of the landfill gas on a monthly basis as 
provided in Sec. 60.755(a)(5).
    (b) Each owner or operator seeking to comply with 
Sec. 60.752(b)(2)(iii) using an enclosed combustor shall calibrate, 
maintain, and operate according to the manufacturer's specifications, 
the following equipment.
    (1) A temperature monitoring device equipped with a continuous 
recorder and having a minimum accuracy of 1 percent of the 
temperature being measured expressed in degrees Celsius or 
0.5  deg.C, whichever is greater. A temperature monitoring 
device is not required for boilers or process heaters with design heat 
input capacity greater than 44 megawatts.
    (2) A device that records flow to or bypass of the control device. 
The owner or operator shall either:
    (i) Install, calibrate, and maintain a gas flow rate measuring 
device that shall record the flow to the control device at least every 
15 minutes; or
    (ii) Secure the bypass line valve in the closed position with a car-
seal or a lock-and-key type configuration. A visual inspection of the 
seal or closure mechanism shall be performed at least once every month 
to ensure that the valve is maintained in the closed position and that 
the gas flow is not diverted through the bypass line.

[[Page 569]]

    (c) Each owner or operator seeking to comply with 
Sec. 60.752(b)(2)(iii) using an open flare shall install, calibrate, 
maintain, and operate according to the manufacturer's specifications the 
following equipment:
    (1) A heat sensing device, such as an ultraviolet beam sensor or 
thermocouple, at the pilot light or the flame itself to indicate the 
continuous presence of a flame.
    (2) A device that records flow to or bypass of the flare. The owner 
or operator shall either:
    (i) Install, calibrate, and maintain a gas flow rate measuring 
device that shall record the flow to the control device at least every 
15 minutes; or
    (ii) Secure the bypass line valve in the closed position with a car-
seal or a lock-and-key type configuration. A visual inspection of the 
seal or closure mechanism shall be performed at least once every month 
to ensure that the valve is maintained in the closed position and that 
the gas flow is not diverted through the bypass line.
    (d) Each owner or operator seeking to demonstrate compliance with 
Sec. 60.752(b)(2)(iii) using a device other than an open flare or an 
enclosed combustor shall provide information satisfactory to the 
Administrator as provided in Sec. 60.752(b)(2)(i)(B) describing the 
operation of the control device, the operating parameters that would 
indicate proper performance, and appropriate monitoring procedures. The 
Administrator shall review the information and either approve it, or 
request that additional information be submitted. The Administrator may 
specify additional appropriate monitoring procedures.
    (e) Each owner or operator seeking to install a collection system 
that does not meet the specifications in Sec. 60.759 or seeking to 
monitor alternative parameters to those required by Sec. 60.753 through 
Sec. 60.756 shall provide information satisfactory to the Administrator 
as provided in Sec. 60.752(b)(2)(i) (B) and (C) describing the design 
and operation of the collection system, the operating parameters that 
would indicate proper performance, and appropriate monitoring 
procedures. The Administrator may specify additional appropriate 
monitoring procedures.
    (f) Each owner or operator seeking to demonstrate compliance with 
Sec. 60.755(c), shall monitor surface concentrations of methane 
according to the instrument specifications and procedures provided in 
Sec. 60.755(d). Any closed landfill that has no monitored exceedances of 
the operational standard in three consecutive quarterly monitoring 
periods may skip to annual monitoring. Any methane reading of 500 ppm or 
more above background detected during the annual monitoring returns the 
frequency for that landfill to quarterly monitoring.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32752, June 16, 1998]



Sec. 60.757  Reporting requirements.

    Except as provided in Sec. 60.752(b)(2)(i)(B),
    (a) Each owner or operator subject to the requirements of this 
subpart shall submit an initial design capacity report to the 
Administrator.
    (1) The initial design capacity report shall fulfill the 
requirements of the notification of the date construction is commenced 
as required by Sec. 60.7(a)(1) and shall be submitted no later than:
    (i) June 10, 1996, for landfills that commenced construction, 
modification, or reconstruction on or after May 30, 1991 but before 
March 12, 1996 or
    (ii) Ninety days after the date of commenced construction, 
modification, or reconstruction for landfills that commence 
construction, modification, or reconstruction on or after March 12, 
1996.
    (2) The initial design capacity report shall contain the following 
information:
    (i) A map or plot of the landfill, providing the size and location 
of the landfill, and identifying all areas where solid waste may be 
landfilled according to the permit issued by the State, local, or tribal 
agency responsible for regulating the landfill.
    (ii) The maximum design capacity of the landfill. Where the maximum 
design capacity is specified in the permit issued by the State, local, 
or tribal agency responsible for regulating the landfill, a copy of the 
permit specifying the maximum design capacity may be submitted as part 
of the report. If the

[[Page 570]]

maximum design capacity of the landfill is not specified in the permit, 
the maximum design capacity shall be calculated using good engineering 
practices. The calculations shall be provided, along with the relevant 
parameters as part of the report. The State, Tribal, local agency or 
Administrator may request other reasonable information as may be 
necessary to verify the maximum design capacity of the landfill.
    (3) An amended design capacity report shall be submitted to the 
Administrator providing notification of an increase in the design 
capacity of the landfill, within 90 days of an increase in the maximum 
design capacity of the landfill to or above 2.5 million megagrams and 
2.5 million cubic meters. This increase in design capacity may result 
from an increase in the permitted volume of the landfill or an increase 
in the density as documented in the annual recalculation required in 
Sec. 60.758(f).
    (b) Each owner or operator subject to the requirements of this 
subpart shall submit an NMOC emission rate report to the Administrator 
initially and annually thereafter, except as provided for in paragraphs 
(b)(1)(ii) or (b)(3) of this section. The Administrator may request such 
additional information as may be necessary to verify the reported NMOC 
emission rate.
    (1) The NMOC emission rate report shall contain an annual or 5-year 
estimate of the NMOC emission rate calculated using the formula and 
procedures provided in Sec. 60.754(a) or (b), as applicable.
    (i) The initial NMOC emission rate report may be combined with the 
initial design capacity report required in paragraph (a) of this section 
and shall be submitted no later than indicated in paragraphs 
(b)(1)(i)(A) and (B) of this section. Subsequent NMOC emission rate 
reports shall be submitted annually thereafter, except as provided for 
in paragraphs (b)(1)(ii) and (b)(3) of this section.
    (A) June 10, 1996, for landfills that commenced construction, 
modification, or reconstruction on or after May 30, 1991, but before 
March 12, 1996, or
    (B) Ninety days after the date of commenced construction, 
modification, or reconstruction for landfills that commence 
construction, modification, or reconstruction on or after March 12, 
1996.
    (ii) If the estimated NMOC emission rate as reported in the annual 
report to the Administrator is less than 50 megagrams per year in each 
of the next 5 consecutive years, the owner or operator may elect to 
submit an estimate of the NMOC emission rate for the next 5-year period 
in lieu of the annual report. This estimate shall include the current 
amount of solid waste-in-place and the estimated waste acceptance rate 
for each year of the 5 years for which an NMOC emission rate is 
estimated. All data and calculations upon which this estimate is based 
shall be provided to the Administrator. This estimate shall be revised 
at least once every 5 years. If the actual waste acceptance rate exceeds 
the estimated waste acceptance rate in any year reported in the 5-year 
estimate, a revised 5-year estimate shall be submitted to the 
Administrator. The revised estimate shall cover the 5-year period 
beginning with the year in which the actual waste acceptance rate 
exceeded the estimated waste acceptance rate.
    (2) The NMOC emission rate report shall include all the data, 
calculations, sample reports and measurements used to estimate the 
annual or 5-year emissions.
    (3) Each owner or operator subject to the requirements of this 
subpart is exempted from the requirements of paragraphs (b)(1) and (2) 
of this section, after the installation of a collection and control 
system in compliance with Sec. 60.752(b)(2), during such time as the 
collection and control system is in operation and in compliance with 
Sec. Sec. 60.753 and 60.755.
    (c) Each owner or operator subject to the provisions of 
Sec. 60.752(b)(2)(i) shall submit a collection and control system design 
plan to the Administrator within 1 year of the first report, required 
under paragraph (b) of this section, in which the emission rate exceeds 
50 megagrams per year, except as follows:
    (1) If the owner or operator elects to recalculate the NMOC emission 
rate after Tier 2 NMOC sampling and analysis as provided in 
Sec. 60.754(a)(3) and the resulting rate is less than 50

[[Page 571]]

megagrams per year, annual periodic reporting shall be resumed, using 
the Tier 2 determined site-specific NMOC concentration, until the 
calculated emission rate is equal to or greater than 50 megagrams per 
year or the landfill is closed. The revised NMOC emission rate report, 
with the recalculated emission rate based on NMOC sampling and analysis, 
shall be submitted within 180 days of the first calculated exceedance of 
50 megagrams per year.
    (2) If the owner or operator elects to recalculate the NMOC emission 
rate after determining a site-specific methane generation rate constant 
(k), as provided in Tier 3 in Sec. 60.754(a)(4), and the resulting NMOC 
emission rate is less than 50 Mg/yr, annual periodic reporting shall be 
resumed. The resulting site-specific methane generation rate constant 
(k) shall be used in the emission rate calculation until such time as 
the emissions rate calculation results in an exceedance. The revised 
NMOC emission rate report based on the provisions of Sec. 60.754(a)(4) 
and the resulting site-specific methane generation rate constant (k) 
shall be submitted to the Administrator within 1 year of the first 
calculated emission rate exceeding 50 megagrams per year.
    (d) Each owner or operator of a controlled landfill shall submit a 
closure report to the Administrator within 30 days of waste acceptance 
cessation. The Administrator may request additional information as may 
be necessary to verify that permanent closure has taken place in 
accordance with the requirements of 40 CFR 258.60. If a closure report 
has been submitted to the Administrator, no additional wastes may be 
placed into the landfill without filing a notification of modification 
as described under Sec. 60.7(a)(4).
    (e) Each owner or operator of a controlled landfill shall submit an 
equipment removal report to the Administrator 30 days prior to removal 
or cessation of operation of the control equipment.
    (1) The equipment removal report shall contain all of the following 
items:
    (i) A copy of the closure report submitted in accordance with 
paragraph (d) of this section;
    (ii) A copy of the initial performance test report demonstrating 
that the 15 year minimum control period has expired; and
    (iii) Dated copies of three successive NMOC emission rate reports 
demonstrating that the landfill is no longer producing 50 megagrams or 
greater of NMOC per year.
    (2) The Administrator may request such additional information as may 
be necessary to verify that all of the conditions for removal in 
Sec. 60.752(b)(2)(v) have been met.
    (f) Each owner or operator of a landfill seeking to comply with 
Sec. 60.752(b)(2) using an active collection system designed in 
accordance with Sec. 60.752(b)(2)(ii) shall submit to the Administrator 
annual reports of the recorded information in (f)(1) through (f)(6) of 
this paragraph. The initial annual report shall be submitted within 180 
days of installation and start-up of the collection and control system, 
and shall include the initial performance test report required under 
Sec. 60.8. For enclosed combustion devices and flares, reportable 
exceedances are defined under Sec. 60.758(c).
    (1) Value and length of time for exceedance of applicable parameters 
monitored under Sec. 60.756(a), (b), (c), and (d).
    (2) Description and duration of all periods when the gas stream is 
diverted from the control device through a bypass line or the indication 
of bypass flow as specified under Sec. 60.756.
    (3) Description and duration of all periods when the control device 
was not operating for a period exceeding 1 hour and length of time the 
control device was not operating.
    (4) All periods when the collection system was not operating in 
excess of 5 days.
    (5) The location of each exceedance of the 500 parts per million 
methane concentration as provided in Sec. 60.753(d) and the 
concentration recorded at each location for which an exceedance was 
recorded in the previous month.
    (6) The date of installation and the location of each well or 
collection system expansion added pursuant to paragraphs (a)(3), (b), 
and (c)(4) of Sec. 60.755.

[[Page 572]]

    (g) Each owner or operator seeking to comply with 
Sec. 60.752(b)(2)(iii) shall include the following information with the 
initial performance test report required under Sec. 60.8:
    (1) A diagram of the collection system showing collection system 
positioning including all wells, horizontal collectors, surface 
collectors, or other gas extraction devices, including the locations of 
any areas excluded from collection and the proposed sites for the future 
collection system expansion;
    (2) The data upon which the sufficient density of wells, horizontal 
collectors, surface collectors, or other gas extraction devices and the 
gas mover equipment sizing are based;
    (3) The documentation of the presence of asbestos or nondegradable 
material for each area from which collection wells have been excluded 
based on the presence of asbestos or nondegradable material;
    (4) The sum of the gas generation flow rates for all areas from 
which collection wells have been excluded based on nonproductivity and 
the calculations of gas generation flow rate for each excluded area; and
    (5) The provisions for increasing gas mover equipment capacity with 
increased gas generation flow rate, if the present gas mover equipment 
is inadequate to move the maximum flow rate expected over the life of 
the landfill; and
    (6) The provisions for the control of off-site migration.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32752, June 16, 1998]



Sec. 60.758  Recordkeeping requirements.

    (a) Except as provided in Sec. 60.752(b)(2)(i)(B), each owner or 
operator of an MSW landfill subject to the provisions of Sec. 60.752(b) 
shall keep for at least 5 years up-to-date, readily accessible, on-site 
records of the design capacity report which triggered Sec. 60.752(b), 
the current amount of solid waste in-place, and the year-by-year waste 
acceptance rate. Off-site records may be maintained if they are 
retrievable within 4 hours. Either paper copy or electronic formats are 
acceptable.
    (b) Except as provided in Sec. 60.752(b)(2)(i)(B), each owner or 
operator of a controlled landfill shall keep up-to-date, readily 
accessible records for the life of the control equipment of the data 
listed in paragraphs (b)(1) through (b)(4) of this section as measured 
during the initial performance test or compliance determination. Records 
of subsequent tests or monitoring shall be maintained for a minimum of 5 
years. Records of the control device vendor specifications shall be 
maintained until removal.
    (1) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.752(b)(2)(ii):
    (i) The maximum expected gas generation flow rate as calculated in 
Sec. 60.755(a)(1). The owner or operator may use another method to 
determine the maximum gas generation flow rate, if the method has been 
approved by the Administrator.
    (ii) The density of wells, horizontal collectors, surface 
collectors, or other gas extraction devices determined using the 
procedures specified in Sec. 60.759(a)(1).
    (2) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.752(b)(2)(iii) 
through use of an enclosed combustion device other than a boiler or 
process heater with a design heat input capacity greater than 44 
megawatts:
    (i) The average combustion temperature measured at least every 15 
minutes and averaged over the same time period of the performance test.
    (ii) The percent reduction of NMOC determined as specified in 
Sec. 60.752(b)(2)(iii)(B) achieved by the control device.
    (3) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with 
Sec. 60.752(b)(2)(iii)(B)(1) through use of a boiler or process heater 
of any size: a description of the location at which the collected gas 
vent stream is introduced into the boiler or process heater over the 
same time period of the performance testing.
    (4) Where an owner or operator subject to the provisions of this 
subpart seeks to demonstrate compliance with Sec. 60.752(b)(2)(iii)(A) 
through use of an open flare, the flare type (i.e., steam-assisted, air-
assisted, or nonassisted),

[[Page 573]]

all visible emission readings, heat content determination, flow rate or 
bypass flow rate measurements, and exit velocity determinations made 
during the performance test as specified in Sec. 60.18; continuous 
records of the flare pilot flame or flare flame monitoring and records 
of all periods of operations during which the pilot flame of the flare 
flame is absent.
    (c) Except as provided in Sec. 60.752(b)(2)(i)(B), each owner or 
operator of a controlled landfill subject to the provisions of this 
subpart shall keep for 5 years up-to-date, readily accessible continuous 
records of the equipment operating parameters specified to be monitored 
in Sec. 60.756 as well as up-to-date, readily accessible records for 
periods of operation during which the parameter boundaries established 
during the most recent performance test are exceeded.
    (1) The following constitute exceedances that shall be recorded and 
reported under Sec. 60.757(f):
    (i) For enclosed combustors except for boilers and process heaters 
with design heat input capacity of 44 megawatts (150 million British 
thermal unit per hour) or greater, all 3-hour periods of operation 
during which the average combustion temperature was more than 28 oC 
below the average combustion temperature during the most recent 
performance test at which compliance with Sec. 60.752(b)(2)(iii) was 
determined.
    (ii) For boilers or process heaters, whenever there is a change in 
the location at which the vent stream is introduced into the flame zone 
as required under paragraph (b)(3)(i) of this section.
    (2) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible continuous records of the 
indication of flow to the control device or the indication of bypass 
flow or records of monthly inspections of car-seals or lock-and-key 
configurations used to seal bypass lines, specified under Sec. 60.756.
    (3) Each owner or operator subject to the provisions of this subpart 
who uses a boiler or process heater with a design heat input capacity of 
44 megawatts or greater to comply with Sec. 60.752(b)(2)(iii) shall keep 
an up-to-date, readily accessible record of all periods of operation of 
the boiler or process heater. (Examples of such records could include 
records of steam use, fuel use, or monitoring data collected pursuant to 
other State, local, Tribal, or Federal regulatory requirements.)
    (4) Each owner or operator seeking to comply with the provisions of 
this subpart by use of an open flare shall keep up-to-date, readily 
accessible continuous records of the flame or flare pilot flame 
monitoring specified under Sec. 60.756(c), and up-to-date, readily 
accessible records of all periods of operation in which the flame or 
flare pilot flame is absent.
    (d) Except as provided in Sec. 60.752(b)(2)(i)(B), each owner or 
operator subject to the provisions of this subpart shall keep for the 
life of the collection system an up-to-date, readily accessible plot map 
showing each existing and planned collector in the system and providing 
a unique identification location label for each collector.
    (1) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible records of the installation 
date and location of all newly installed collectors as specified under 
Sec. 60.755(b).
    (2) Each owner or operator subject to the provisions of this subpart 
shall keep readily accessible documentation of the nature, date of 
deposition, amount, and location of asbestos-containing or nondegradable 
waste excluded from collection as provided in Sec. 60.759(a)(3)(i) as 
well as any nonproductive areas excluded from collection as provided in 
Sec. 60.759(a)(3)(ii).
    (e) Except as provided in Sec. 60.752(b)(2)(i)(B), each owner or 
operator subject to the provisions of this subpart shall keep for at 
least 5 years up-to-date, readily accessible records of all collection 
and control system exceedances of the operational standards in 
Sec. 60.753, the reading in the subsequent month whether or not the 
second reading is an exceedance, and the location of each exceedance.
    (f) Landfill owners or operators who convert design capacity from 
volume to mass or mass to volume to demonstrate that landfill design 
capacity

[[Page 574]]

is less than 2.5 million megagrams or 2.5 million cubic meters, as 
provided in the definition of ``design capacity'', shall keep readily 
accessible, on-site records of the annual recalculation of site-specific 
density, design capacity, and the supporting documentation. Off-site 
records may be maintained if they are retrievable within 4 hours. Either 
paper copy or electronic formats are acceptable.

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32752, June 16, 1998]



Sec. 60.759  Specifications for active collection systems.

    (a) Each owner or operator seeking to comply with 
Sec. 60.752(b)(2)(i) shall site active collection wells, horizontal 
collectors, surface collectors, or other extraction devices at a 
sufficient density throughout all gas producing areas using the 
following procedures unless alternative procedures have been approved by 
the Administrator as provided in Sec. 60.752(b)(2)(i)(C) and (D):
    (1) The collection devices within the interior and along the 
perimeter areas shall be certified to achieve comprehensive control of 
surface gas emissions by a professional engineer. The following issues 
shall be addressed in the design: depths of refuse, refuse gas 
generation rates and flow characteristics, cover properties, gas system 
expandibility, leachate and condensate management, accessibility, 
compatibility with filling operations, integration with closure end use, 
air intrusion control, corrosion resistance, fill settlement, and 
resistance to the refuse decomposition heat.
    (2) The sufficient density of gas collection devices determined in 
paragraph (a)(1) of this section shall address landfill gas migration 
issues and augmentation of the collection system through the use of 
active or passive systems at the landfill perimeter or exterior.
    (3) The placement of gas collection devices determined in paragraph 
(a)(1) of this section shall control all gas producing areas, except as 
provided by paragraphs (a)(3)(i) and (a)(3)(ii) of this section.
    (i) Any segregated area of asbestos or nondegradable material may be 
excluded from collection if documented as provided under Sec. 60.758(d). 
The documentation shall provide the nature, date of deposition, location 
and amount of asbestos or nondegradable material deposited in the area, 
and shall be provided to the Administrator upon request.
    (ii) Any nonproductive area of the landfill may be excluded from 
control, provided that the total of all excluded areas can be shown to 
contribute less than 1 percent of the total amount of NMOC emissions 
from the landfill. The amount, location, and age of the material shall 
be documented and provided to the Administrator upon request. A separate 
NMOC emissions estimate shall be made for each section proposed for 
exclusion, and the sum of all such sections shall be compared to the 
NMOC emissions estimate for the entire landfill. Emissions from each 
section shall be computed using the following equation:

Qi = 2 k Lo Mi (e-kt i) 
          (CNM OC) (3.6  x  10-9)

where,

Qi = NMOC emission rate from the ith section, 
          megagrams per year
k = methane generation rate constant, year-1
Lo = methane generation potential, cubic meters per megagram 
          solid waste
Mi = mass of the degradable solid waste in the ith 
          section, megagram
ti = age of the solid waste in the ith section, 
          years
CNMOC = concentration of nonmethane organic compounds, parts 
          per million by volume
3.6 x 10-9 = conversion factor

    (iii) The values for k and CNMOC determined in field 
testing shall be used if field testing has been performed in determining 
the NMOC emission rate or the radii of influence (this distance from the 
well center to a point in the landfill where the pressure gradient 
applied by the blower or compressor approaches zero). If field testing 
has not been performed, the default values for k, LO and 
CNMOC provided in Sec. 60.754(a)(1) or the alternative values 
from Sec. 60.754(a)(5) shall be used. The mass of nondegradable solid 
waste contained within the given section may be subtracted from the 
total mass of the section when estimating emissions provided the nature, 
location, age, and amount of the nondegradable material

[[Page 575]]

is documented as provided in paragraph (a)(3)(i) of this section.
    (b) Each owner or operator seeking to comply with 
Sec. 60.752(b)(2)(i)(A) shall construct the gas collection devices using 
the following equipment or procedures:
    (1) The landfill gas extraction components shall be constructed of 
polyvinyl chloride (PVC), high density polyethylene (HDPE) pipe, 
fiberglass, stainless steel, or other nonporous corrosion resistant 
material of suitable dimensions to: convey projected amounts of gases; 
withstand installation, static, and settlement forces; and withstand 
planned overburden or traffic loads. The collection system shall extend 
as necessary to comply with emission and migration standards. Collection 
devices such as wells and horizontal collectors shall be perforated to 
allow gas entry without head loss sufficient to impair performance 
across the intended extent of control. Perforations shall be situated 
with regard to the need to prevent excessive air infiltration.
    (2) Vertical wells shall be placed so as not to endanger underlying 
liners and shall address the occurrence of water within the landfill. 
Holes and trenches constructed for piped wells and horizontal collectors 
shall be of sufficient cross-section so as to allow for their proper 
construction and completion including, for example, centering of pipes 
and placement of gravel backfill. Collection devices shall be designed 
so as not to allow indirect short circuiting of air into the cover or 
refuse into the collection system or gas into the air. Any gravel used 
around pipe perforations should be of a dimension so as not to penetrate 
or block perforations.
    (3) Collection devices may be connected to the collection header 
pipes below or above the landfill surface. The connector assembly shall 
include a positive closing throttle valve, any necessary seals and 
couplings, access couplings and at least one sampling port. The 
collection devices shall be constructed of PVC, HDPE, fiberglass, 
stainless steel, or other nonporous material of suitable thickness.
    (c) Each owner or operator seeking to comply with 
Sec. 60.752(b)(2)(i)(A) shall convey the landfill gas to a control 
system in compliance with Sec. 60.752(b)(2)(iii) through the collection 
header pipe(s). The gas mover equipment shall be sized to handle the 
maximum gas generation flow rate expected over the intended use period 
of the gas moving equipment using the following procedures:
    (1) For existing collection systems, the flow data shall be used to 
project the maximum flow rate. If no flow data exists, the procedures in 
paragraph (c)(2) of this section shall be used.
    (2) For new collection systems, the maximum flow rate shall be in 
accordance with Sec. 60.755(a)(1).

[61 FR 9919, Mar. 12, 1996, as amended at 63 FR 32753, June 16, 1998; 64 
FR 9262, Feb. 24, 1999]

                   Appendix A to Part 60--Test Methods

Method 1--Sample and velocity traverses for stationary sources
Method 1A--Sample and velocity traverses for stationary sources with 
          small stacks or ducts
Method 2--Determination of stack gas velocity and volumetric flow rate 
          (Type S pitot tube)
Method 2A--Direct measurement of gas volume through pipes and small 
          ducts
Method 2B--Determination of exhaust gas volume flow rate from gasoline 
          vapor incinerators
Method 2C--Determination of stack gas velocity and volumetric flow rate 
          in small stacks or ducts (standard pitot tube)
Method 2D--Measurement of gas volumetric flow rates in small pipes and 
          ducts
Method 2E--Determination of landfill gas; gas production flow rate
Method 2F--Determination of Stack Gas Velocity and Volumetric Flow Rate 
          With Three-Dimensional Probes
Method 2G--Determination of Stack Gas Velocity and Volumetric Flow Rate 
          With Two-Dimensional Probes
Method 2H--Determination of Stack Gas Velocity Taking Into Account 
          Velocity Decay Near the Stack Wall
Method 3--Gas analysis for the determination of dry molecular weight
Method 3A--Determination of Oxygen and Carbon Dioxide Concentrations in 
          Emissions From Stationary Sources (Instrumental Analyzer 
          Procedure)
Method 3B--Gas analysis for the determination of emission rate 
          correction factor or excess air
Method 3C--Determination of carbon dioxide, methane, nitrogen, and 
          oxygen from stationary sources
Method 4--Determination of moisture content in stack gases

[[Page 576]]

Method 5--Determination of particulate emissions from stationary sources
Method 5A--Determination of particulate emissions from the asphalt 
          processing and asphalt roofing industry
Method 5B--Determination of nonsulfuric acid particulate matter from 
          stationary sources
Method 5C  [Reserved]
Method 5D--Determination of particulate matter emissions from positive 
          pressure fabric filters
Method 5E--Determination of particulate emissions from the wool 
          fiberglass insulation manufacturing industry
Method 5F--Determination of nonsulfate particulate matter from 
          stationary sources
Method 5G--Determination of particulate emissions from wood heaters from 
          a dilution tunnel sampling location
Method 5H--Determination of particulate emissions from wood heaters from 
          a stack location
Method 6--Determination of sulfur dioxide emissions from stationary 
          sources
Method 6A--Determination of sulfur dioxide, moisture, and carbon dioxide 
          emissions from fossil fuel combustion sources
Method 6B--Determination of sulfur dioxide and carbon dioxide daily 
          average emissions from fossil fuel combustion sources
Method 6C--Determination of Sulfur Dioxide Emissions From Stationary 
          Sources (Instrumental Analyzer Procedure)
Method 7--Determination of nitrogen oxide emissions from stationary 
          sources
Method 7A--Determination of nitrogen oxide emissions from stationary 
          sources--Ion chromatographic method
Method 7B--Determination of nitrogen oxide emissions from stationary 
          sources (Ultraviolet spectrophotometry)
Method 7C--Determination of nitrogen oxide emissions from stationary 
          sources--Alkaline-permanganate/colorimetric method
Method 7D--Determination of nitrogen oxide emissions from stationary 
          sources--Alkaline-permanganate/ion chromatographic method
Method 7E--Determination of Nitrogen Oxides Emissions From Stationary 
          Sources (Instrumental Analyzer Procedure)
Method 8--Determination of sulfuric acid mist and sulfur dioxide 
          emissions from stationary sources
Method 9--Visual determination of the opacity of emissions from 
          stationary sources
Alternate method 1--Determination of the opacity of emissions from 
          stationary sources remotely by lidar
Method 10--Determination of carbon monoxide emissions from stationary 
          sources
Method 10A--Determination of carbon monoxide emissions in certifying 
          continuous emission monitoring systems at petroleum refineries
Method 10B--Determination of carbon monoxide emissions from stationary 
          sources
Method 11--Determination of hydrogen sulfide content of fuel gas streams 
          in petroleum refineries
Method 12--Determination of inorganic lead emissions from stationary 
          sources
Method 13A--Determination of total fluoride emissions from stationary 
          sources--SPADNS zirconium lake method
Method 13B--Determination of total fluoride emissions from stationary 
          sources--Specific ion electrode method
Method 14--Determination of fluoride emissions from potroom roof 
          monitors for primary aluminum plants
Method 14A-- Determination of Total Fluoride Emissions from Selected 
          Sources at Primary Aluminum Production Facilities
Method 15--Determination of hydrogen sulfide, carbonyl sulfide, and 
          carbon disulfide emissions from stationary sources
Method 15A--Determination of total reduced sulfur emissions from sulfur 
          recovery plants in petroleum refineries
Method 16--Semicontinuous determination of sulfur emissions from 
          stationary sources
Method 16A--Determination of total reduced sulfur emissions from 
          stationary sources (impinger technique)
Method 16B--Determination of total reduced sulfur emissions from 
          stationary sources
Method 17--Determination of particulate emissions from stationary 
          sources (in-stack filtration method)
Method 18--Measurement of gaseous organic compound emissions by gas 
          chromatography
Method 19--Determination of sulfur dioxide removal efficiency and 
          particulate, sulfur dioxide and nitrogen oxides emission rates
Method 20--Determination of nitrogen oxides, sulfur dioxide, and diluent 
          emissions from stationary gas turbines
Method 21--Determination of volatile organic compound leaks
Method 22--Visual determination of fugitive emissions from material 
          sources and smoke emissions from flares
Method 23--Determination of Polychlorinated Dibenzo-p-Dioxins and 
          Polychlorinated Dibenzofurans From Stationary Sources
Method 24--Determination of volatile matter content, water content, 
          density, volume solids, and weight solids of surface coatings
Method 24A--Determination of volatile matter content and density of 
          printing inks and related coatings
Method 25--Determination of total gaseous nonmethane organic emissions 
          as carbon

[[Page 577]]

Method 25A--Determination of total gaseous organic concentration using a 
          flame ionization analyzer
Method 25B--Determination of total gaseous organic concentration using a 
          nondispersive infrared analyzer
Method 25C--Determination of nonmethane organic compounds (NMOC) in MSW 
          landfill gases
Method 25D--Determination of the Volatile Organic Concentration of Waste 
          Samples
Method 25E--Determination of Vapor Phase Organic Concentration in Waste 
          Samples
Method 26--Determination of Hydrogen Chloride Emissions From Stationary 
          Sources
Method 26A--Determination of hydrogen halide and halogen emissions from 
          stationary sources--isokinetic method
Method 27--Determination of vapor tightness of gasoline delivery tank 
          using pressure-vacuum test
Method 28--Certification and auditing of wood heaters
Method 28A--Measurement of air to fuel ratio and minimum achievable burn 
          rates for wood-fired appliances
Method 29--Determination of metals emissions from stationary sources
    The test methods in this appendix are referred to in Sec. 60.8 
(Performance Tests) and Sec. 60.11 (Compliance With Standards and 
Maintenance Requirements) of 40 CFR part 60, subpart A (General 
Provisions). Specific uses of these test methods are described in the 
standards of performance contained in the subparts, beginning with 
Subpart D.
    Within each standard of performance, a section title ``Test Methods 
and Procedures'' is provided to: (1) Identify the test methods to be 
used as reference methods to the facility subject to the respective 
standard and (2) identify any special instructions or conditions to be 
followed when applying a method to the respective facility. Such 
instructions (for example, establish sampling rates, volumes, or 
temperatures) are to be used either in addition to, or as a substitute 
for procedures in a test method. Similarly, for sources subject to 
emission monitoring requirements, specific instructions pertaining to 
any use of a test method as a reference method are provided in the 
subpart or in Appendix B.
    Inclusion of methods in this appendix is not intended as an 
endorsement or denial of their applicability to sources that are not 
subject to standards of performance. The methods are potentially 
applicable to other sources; however, applicability should be confirmed 
by careful and appropriate evaluation of the conditions prevalent at 
such sources.
    The approach followed in the formulation of the test methods 
involves specifications for equipment, procedures, and performance. In 
concept, a performance specification approach would be preferable in all 
methods because this allows the greatest flexibility to the user. In 
practice, however, this approach is impractical in most cases because 
performance specifications cannot be established. Most of the methods 
described herein, therefore, involve specific equipment specifications 
and procedures, and only a few methods in this appendix rely on 
performance criteria.
    Minor changes in the test methods should not necessarily affect the 
validity of the results and it is recognized that alternative and 
equivalent methods exist. Section 60.8 provides authority for the 
Administrator to specify or approve (1) equivalent methods, (2) 
alternative methods, and (3) minor changes in the methodology of the 
test methods. It should be clearly understood that unless otherwise 
identified all such methods and changes must have prior approval of the 
Administrator. An owner employing such methods or deviations from the 
test methods without obtaining prior approval does so at the risk of 
subsequent disapproval and retesting with approved methods.
    Within the test methods, certain specific equipment or procedures 
are recognized as being acceptable or potentially acceptable and are 
specifically identified in the methods. The items identified as 
acceptable options may be used without approval but must be identified 
in the test report. The potentially approvable options are cited as 
``subject to the approval of the Administrator'' or as ``or 
equivalent.'' Such potentially approvable techniques or alternatives may 
be used at the discretion of the owner without prior approval. However, 
detailed descriptions for applying these potentially approvable 
techniques or alternatives are not provided in the test methods. Also, 
the potentially approvable options are not necessarily acceptable in all 
applications. Therefore, an owner electing to use such potentially 
approvable techniques or alternatives is responsible for: (1) assuring 
that the techniques or alternatives are in fact applicable and are 
properly executed; (2) including a written description of the 
alternative method in the test report (the written method must be clear 
and must be capable of being performed without additional instruction, 
and the the degree of detail should be similar to the detail contained 
in the test methods); and (3) providing any rationale or supporting data 
necessary to show the validity of the alternative in the particular 
application. Failure to meet these requirements can result in the 
Administrator's disapproval of the alternative.

     Method 1--Sample and Velocity Traverses for Stationary Sources

1. Principle and Applicability

    1.1  Principle. To aid in the representative measurement of 
pollutant emissions and/or total volumetric flow rate from a stationary 
source, a measurement site where the effluent stream is flowing in a 
known direction is

[[Page 578]]

selected, and the cross-section of the stack is divided into a number of 
equal areas. A traverse point is then located within each of these equal 
areas.
    1.2  Applicability. This method is applicable to flowing gas streams 
in ducts, stacks, and flues. The method cannot be used when: (1) flow is 
cyclonic or swirling (see Section 2.4), (2) a stack is smaller than 
about 0.30 meter (12 in.) in diameter, or 0.071 m2(113 
in.2) cross-sectional area, or (3) the measurement site is 
less than two stack or duct diameters downstream or less than a half 
diameter upstream from a flow disturbance.
    The requirements of this method must be considered before 
construction of a new facility from which emissions will be measured; 
failure to do so may require subsequent alterations to the stack or 
deviation from the standard procedure. Cases involving variants are 
subject to approval by the Administrator, U.S. Environmental Protection 
Agency.

2. Procedure

    2.1  Selection of Measurement Site. Sampling or velocity measurement 
is performed at a site located at least eight stack or duct diameters 
downstream and two diameters upstream from any flow disturbance such as 
a bend, expansion, or contraction in the stack, or from a visible flame. 
If necessary, an alternative location may be selected, at a position at 
least two stack or duct diameters downstream and a half diameter 
upstream from any flow disturbance. For a rectangular cross section, an 
equivalent diameter (De) shall be calculated from the 
following equation, to determine the upstream and downstream distances:
[GRAPHIC] [TIFF OMITTED] TC16NO91.246

where L=length and W=width.

    An alternative procedure is available for determining the 
acceptability of a measurement location not meeting the criteria above. 
This procedure, determination of gas flow angles at the sampling points 
and comparing the results with acceptability criteria, is described in 
Section 2.5.
    2.2  Determining the Number of Traverse Points.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.073
    

[[Page 579]]


    2.2.1  Particulate Traverses. When the eight- and two-diameter 
criterion can be met, the minimum number of traverse points shall be: 
(1) twelve, for circular or rectangular stacks with diameters (or 
equivalent diameters) greater than 0.61 meter (24 in.); (2) eight, for 
circular stacks with diameters between 0.30 and 0.61 meter (12-24 in.); 
(3) nine, for rectangular stacks with equivalent diameters between 0.30 
and 0.61 meter (12-24 in.).
    When the eight- and two-diameter criterion cannot be met, the 
minimum number of traverse points is determined from Figure 1-1. Before 
referring to the figure, however, determine the distances from the 
chosen measurement site to the nearest upstream and downstream 
disturbances, and divide each distance by the stack diameter or 
equivalent diameter, to determine the distance in terms of the number of 
duct diameters. Then, determine from Figure 1-1 the minimum number of 
traverse points that corresponds: (1) to the number of duct diameters 
upstream; and (2) to the number of diameters downstream. Select the 
higher of the two minimum numbers of traverse points, or a greater 
value, so that for circular stacks the number is a multiple of 4, and 
for rectangular stacks, the number is one of those shown in Table 1-1.

         Table 1-1. Cross-Section Layout for Rectangular Stacks
------------------------------------------------------------------------
                Number of traverse points                  Matrix layout
------------------------------------------------------------------------
9.......................................................             3x3
12......................................................             4x3
16......................................................             4x4
20......................................................             5x4
25......................................................             5x5
30......................................................             6x5
36......................................................             6x6
42......................................................             7x6
49......................................................             7x7
------------------------------------------------------------------------

                                                          [GRAPHIC] [TIFF OMITTED] TC01JN92.074
                                                          
    2.2.2  Velocity (Non-Particulate) Traverses. When velocity or 
volumetric flow rate is to be determined (but not particulate matter), 
the same procedure as that for particulate traverses (Section 2.2.1) is 
followed, except that Figure 1-2 may be used instead of Figure 1-1.

[[Page 580]]

    2.3  Cross-sectional Layout and Location of Traverse Points.
    2.3.1  Circular Stacks. Locate the traverse points on two 
perpendicular diameters according to Table 1-2 and the example shown in 
Figure 1-3. Any equation (for examples, see Citations 2 and 3 in the 
Bibliography) that gives the same values as those in Table 1-2 may be 
used in lieu of Table 1-2.
    For particulate traverses, one of the diameters must be in a plane 
containing the greatest expected concentration variation, e.g., after 
bends, one diameter shall be in the plane of the bend. This requirement 
becomes less critical as the distance from the disturbance increases; 
therefore, other diameter locations may be used, subject to approval of 
the Administrator.
    In addition for stacks having diameters greater than 0.61 m (24 in.) 
no traverse points shall be located within 2.5 centimeters (1.00 in.) of 
the stack walls; and for stack diameters equal to or less than 0.61 m 
(24 in.), no traverse points shall be located within 1.3 cm (0.50 in.) 
of the stack walls. To meet these criteria, observe the procedures given 
below.
    2.3.1.1  Stacks With Diameters Greater Than 0.61 m (24 in.). When 
any of the traverse points as located in Section 2.3.1 fall within 2.5 
cm (1.00 in.) of the stack walls, relocate them away from the stack 
walls to: (1) a distance of 2.5 cm (1.00 in.); or (2) a distance equal 
to the nozzle inside diameter, whichever is larger. These relocated 
traverse points (on each end of a diameter) shall be the ``adjusted'' 
traverse points.
    Whenever two successive traverse points are combined to form a 
single adjusted traverse point, treat the adjusted point as two separate 
traverse points, both in the sampling (or velocity measurement) 
procedure, and in recording the data.
[GRAPHIC] [TIFF OMITTED] TC01JN92.075


                            Table 1-2. Location of Traverse Points in Circular Stacks
                         [Percent of stack diameter from inside wall to traverse point]
----------------------------------------------------------------------------------------------------------------
                                                   Number of traverse points on a diameter--
 Traverse point number on a  -----------------------------------------------------------------------------------
          diameter              2      4      6      8      10     12     14     16     18     20     22     24
----------------------------------------------------------------------------------------------------------------
1...........................   14.6    6.7    4.4    3.2    2.6    2.1    1.8    1.6    1.4    1.3    1.1    1.1
2...........................   85.4   25.0   14.6   10.5    8.2    6.7    5.7    4.9    4.4    3.9    3.5    3.2
3...........................  .....   75.0   29.6   19.4   14.6   11.8    9.9    8.5    7.5    6.7    6.0    5.5
4...........................  .....   93.3   70.4   32.3   22.6   17.7   14.6   12.5   10.9    9.7    8.7    7.9
5...........................  .....  .....   85.4   67.7   34.2   25.0   20.1   16.9   14.6   12.9   11.6   10.5
6...........................  .....  .....   95.6   80.6   65.8   35.6   26.9   22.0   18.8   16.5   14.6   13.2
7...........................  .....  .....  .....   89.5   77.4   64.4   36.6   28.3   23.6   20.4   18.0   16.1
8...........................  .....  .....  .....   96.8   85.4   75.0   63.4   37.5   29.6   25.0   21.8   19.4
9...........................  .....  .....  .....  .....   91.8   82.3   73.1   62.5   38.2   30.6   26.2   23.0
10..........................  .....  .....  .....  .....   97.4   88.2   79.9   71.7   61.8   38.8   31.5   27.2
11..........................  .....  .....  .....  .....  .....   93.3   85.4   78.0   70.4   61.2   39.3   32.3
12..........................  .....  .....  .....  .....  .....   97.9   90.1   83.1   76.4   69.4   60.7   39.8
13..........................  .....  .....  .....  .....  .....  .....   94.3   87.5   81.2   75.0   68.5   60.2
14..........................  .....  .....  .....  .....  .....  .....   98.2   91.5   85.4   79.6   73.8   67.7
15..........................  .....  .....  .....  .....  .....  .....  .....   95.1   89.1   83.5   78.2   72.8
16..........................  .....  .....  .....  .....  .....  .....  .....   98.4   92.5   87.1   82.0   77.0
17..........................  .....  .....  .....  .....  .....  .....  .....  .....   95.6   90.3   85.4   80.6
18..........................  .....  .....  .....  .....  .....  .....  .....  .....   98.6   93.3   88.4   83.9

[[Page 581]]

 
19..........................  .....  .....  .....  .....  .....  .....  .....  .....  .....   96.1   91.3   86.8
20..........................  .....  .....  .....  .....  .....  .....  .....  .....  .....   98.7   94.0   89.5
21..........................  .....  .....  .....  .....  .....  .....  .....  .....  .....  .....   96.5   92.1
22..........................  .....  .....  .....  .....  .....  .....  .....  .....  .....  .....   98.9   94.5
23..........................  .....  .....  .....  .....  .....  .....  .....  .....  .....  .....  .....   96.8
24..........................  .....  .....  .....  .....  .....  .....  .....  .....  .....  .....  .....   98.9
----------------------------------------------------------------------------------------------------------------

    2.3.1.2  Stacks With Diameters Equal to or Less Than 0.61 m (24 
in.). Follow the procedure in Section 2.3.1.1, noting only that any 
``adjusted'' points should be relocated away from the stack walls to: 
(1) a distance of 1.3 cm (0.50 in.); or (2) a distance equal to the 
nozzle inside diameter, whichever is larger.
    2.3.2  Rectangular Stacks. Determine the number of traverse points 
as explained in Sections 2.1 and 2.2 of this method. From Table 1-1, 
determine the grid configuration. Divide the stack cross-section into as 
many equal rectangular elemental areas as traverse points, and then 
locate a traverse point at the centroid of each equal area according to 
the example in Figure 1-4.
    If the tester desires to use more than the minimum number of 
traverse points, expand the ``minimum number of traverse points'' matrix 
(see Table 1-1) by adding the extra traverse points along one or the 
other or both legs of the matrix; the final matrix need not be balanced. 
For example, if a 4x3 ``minimum number of points'' matrix were expanded 
to 36 points, the final matrix could be 9x4 or 12x3, and would not 
necessarily have to be 6x6. After constructing the final matrix, divide 
the stack cross-section into as many equal rectangular, elemental areas 
as traverse points, and locate a traverse point at the centroid of each 
equal area.
    The situation of traverse points being too close to the stack walls 
is not expected to arise with rectangular stacks. If this problem should 
ever arise, the Administrator must be contacted for resolution of the 
matter.
    2.4  Verification of Absence of Cyclonic Flow. In most stationary 
sources, the direction of stack gas flow is essentially parallel to the 
stack walls. However, cyclonic flow may exist (1) after such devices as 
cyclones and inertial demisters following venturi scrubbers, or (2) in 
stacks having tangential inlets or other duct configurations which tend 
to induce swirling; in these instances, the presence or absence of 
cyclonic flow at the sampling location must be determined. The following 
techniques are acceptable for this determination.
[GRAPHIC] [TIFF OMITTED] TC01JN92.076

    Level and zero the manometer. Connect a Type S pitot tube to the 
manometer. Position the Type S pitot tube at each traverse point, in 
succession, so that the planes of the face openings of the pitot tube 
are perpendicular to the stack cross-sectional plane; when the Type S 
pitot tube is in this position, it is at ``0 deg. reference.'' Note the 
differential pressure (p) reading at each traverse point. If a 
null (zero) pitot reading is obtained at 0 deg. reference at a given 
traverse point, an acceptable flow condition exists at that point. If 
the pitot reading is not zero at 0 deg. reference, rotate the pitot tube 
(up to plus-minus90 deg. yaw angle), until a null reading is 
obtained. Carefully determine and record the value of the rotation angle 
() to the nearest degree. After the null technique has been 
applied at each traverse point, calculate the average of the absolute 
values of ; assign values of 0 deg. to those points 
for which no rotation was required, and include these in the overall 
average. If the average value of is greater than 20 deg., the 
overall flow condition in the stack is unacceptable and alternative 
methodology, subject to the approval of the Administrator, must be used 
to perform accurate sample and velocity traverses.
    The alternative procedure described in Section 2.5 may be used to 
determine the rotation angles in lieu of the procedure described above.
    2.5  Alternative Measurement Site Selection Procedure. This 
alternative applies to sources where measurement locations are

[[Page 582]]

less than 2 equivalent stack or duct diameters downstream or less than 
\1/2\ duct diameter upstream from a flow disturbance. The alternative 
should be limited to ducts larger than 24 in. in diameter where blockage 
and wall effects are minimal. A directional flow-sensing probe is used 
to measure pitch and yaw angles of the gas flow at 40 or more traverse 
points; the resultant angle is calculated and compared with acceptable 
criteria for mean and standard deviation.
    Note: Both the pitch and yaw angles are measured from a line passing 
through the traverse point and parallel to the stack axis. The pitch 
angle is the angle of the gas flow component in the plane that INCLUDES 
the traverse line and is parallel to the stack axis. The yaw angle is 
the angle of the gas flow component in the plane PERPENDICULAR to the 
traverse line at the traverse point and is measured from the line 
passing through the traverse point and parallel to the stack axis.
    2.5.1  Apparatus.
    2.5.1.1  Directional Probe. Any directional probe, such as United 
Sensor Type DA Three-Dimensional Directional Probe, capable of measuring 
both the pitch and yaw angles of gas flows is acceptable. (Note: Mention 
of trade name or specific products does not constitute endorsement by 
the U.S. Environmental Protection Agency.) Assign an identification 
number to the directional probe, and permanently mark or engrave the 
number on the body of the probe. The pressure holes of directional 
probes are susceptible to plugging when used in particulate-laden gas 
streams. Therefore, a system for cleaning the pressure holes by ``back-
purging'' with pressurized air is required.
    2.5.1.2  Differential Pressure Gauges. Inclined manometers, U-tube 
manometers, or other differential pressure gauges (e.g., magnehelic 
gauges) that meet the specifications described in Method 2, section 2.2.
    Note: If the differential pressure gauge produces both negative and 
positive readings, then both negative and positive pressure readings 
shall be calibrated at a minimum of three points as specified in Method 
2, section 2.2.
    2.5.2  Traverse Points. Use a minimum of 40 traverse points for 
circular ducts and 42 points for rectangular ducts for the gas flow 
angle determinations. Follow section 2.3 and Table 1-1 or 1-2 for the 
location and layout of the traverse points. If the measurement location 
is determined to be acceptable according to the criteria in this 
alternative procedure, use the same traverse point number and locations 
for sampling and velocity measurements.
    2.5.3  Measurement Procedure.
    2.5.3.1  Prepare the directional probe and differential pressure 
gauges as recommended by the manufacturer. Capillary tubing or surge 
tanks may be used to dampen pressure fluctuations. It is recommended, 
but not required, that a pretest leak check be conducted. To perform a 
leak check, pressurize or use suction on the impact opening until a 
reading of at least 7.6 cm (3 in.) H2O registers on the 
differential pressure gauge, then plug the impact opening. The pressure 
of a leak-free system will remain stable for at least 15 seconds.
    2.5.3.2  Level and zero the manometers. Since the manometer level 
and zero may drift because of vibrations and temperature changes, 
periodically check the level and zero during the traverse.
    2.5.3.3  Position the probe at the appropriate locations in the gas 
stream, and rotate until zero deflection is indicated for the yaw angle 
pressure gauge. Determine and record the yaw angle. Record the pressure 
gauge readings for the pitch angle, and determine the pitch angle from 
the calibration curve. Repeat this procedure for each traverse point. 
Complete a ``back-purge'' of the pressure lines and the impact openings 
prior to measurements of each traverse point.
    A post-test check as described in section 2.5.3.1 is required. If 
the criteria for a leak-free system are not met, repair the equipment, 
and repeat the flow angle measurements.
    2.5.4  Calculate the resultant angle at each traverse point, the 
average resultant angle, and the standard deviation using the following 
equations. Complete the calculations retaining at least one extra 
significant figure beyond that of the acquired data. Round the values 
after the final calculations.
    2.5.4.1  Calculate the resultant angle at each traverse point:

Ri=arc cosine [(cosine Yi)(cosine Pi)]  
  

                                                                 Eq. 1-2

Where:
Ri=Resultant angle at traverse point i, degree.
Yi=Yaw angle at traverse point i, degree.
Pi=Pitch angle at traverse point i, degree.

    2.5.4.2  Calculate the average resultant for the measurements:
    [GRAPHIC] [TIFF OMITTED] TC16NO91.107
    
Where:
R=Average resultant angle, degree.
n=Total number of traverse points.

    2.5.4.3  Calculate the standard deviations:
    [GRAPHIC] [TIFF OMITTED] TN30AU93.031
    

[[Page 583]]


                                                                 Eq. 1-4
Where:

Sd=Standard deviation, degree.

    2.5.5  The measurement location is acceptable if R20 deg. 
and Sd10 deg..
    2.5.6  Calibration. Use a flow system as described in Sections 
4.1.2.1 and 4.1.2.2 of Method 2. In addition, the flow system shall have 
the capacity to generate two test-section velocities: one between 365 
and 730 m/min (1200 and 2400 ft/min) and one between 730 and 1100 m/min 
(2400 and 3600 ft/min).
    2.5.6.1  Cut two entry ports in the test section. The axis through 
the entry ports shall be perpendicular to each other and intersect in 
the centroid of the test section. The ports should be elongated slots 
parallel to the axis of the test section and of sufficient length to 
allow measurement of pitch angles while maintaining the pitot head 
position at the test-section centroid. To facilitate alignment of the 
directional probe during calibration, the test section should be 
constructed of plexiglass or some other transparent material. All 
calibration measurements should be made at the same point in the test 
section, preferably at the centroid of the test section.
    2.5.6.2  To ensure that the gas flow is parallel to the central axis 
of the test section, follow the procedure in Section 2.4 for cyclonic 
flow determination to measure the gas flow angles at the centroid of the 
test section from two test ports located 90 deg.apart. The gas flow 
angle measured in each port must be 2 deg. of 0 deg.. 
Straightening vanes should be installed, if necessary, to meet this 
criterion.
    2.5.6.3  Pitch Angle Calibration. Perform a calibration traverse 
according to the manufacturer's recommended protocol in 5 deg. 
increments for angles from -60 deg. to =60 deg. at one velocity in each 
of the two ranges specified above. Average the pressure ratio values 
obtained for each angle in the two flow ranges, and plot a calibration 
curve with the average values of the pressure ratio (or other suitable 
measurement factor as recommended by the manufacturer) versus the pitch 
angle. Draw a smooth line through the data points. Plot also the data 
values for each traverse point. Determine the differences between the 
measured data values and the angle from the calibration curve at the 
same pressure ratio. The difference at each comparison must be within 
2 deg. for angles between 0 deg. and 40 deg. and within 3 deg.for angles 
between 40  deg. and 60 deg..
    2.5.6.4  Yaw Angle Calibration. Mark the three-dimensional probe to 
allow the determination of the yaw position of the probe. This is 
usually a line extending the length of the probe and aligned with the 
impact opening. To determine the accuracy of measurements of the yaw 
angle, only the zero or null position need be calilbrated as follows. 
Place the directional probe in the test section, and rotate the probe 
until the zero position is found. With a protractor or other angle 
measuring device, measure the angle indicated by the yaw angle indicator 
on the three-dimensional probe. This should be within 2 deg.of 0 deg.. 
Repeat this measurement for any other points along the length of the 
pitot where yaw angle measurements could be read in order to account for 
variations in the pitot markings used to indicate pitot head positions.

3. Bibliography

    1. Determining Dust Concentration in a Gas Stream, ASME. Performance 
Test Code No. 27. New York, 1957.
    2. Devorkin, Howard, et al. Air Pollution Source Testing Manual. Air 
Pollution Control District. Los Angeles, CA November 1963.
    3. Methods for Determination of Velocity, Volume, Dust and Mist 
Content of Gases. Western Precipitation Division of Joy Manufacturing 
Co. Los Angeles, CA. Bulletin WP-50. 1968.
    4. Standard Method for Sampling Stacks for Particulate Matter. In: 
1971 Book of ASTM Standards, Part 23. ASTM Designation D-2928-71. 
Philadelphia, PA 1971.
    5. Hanson, H.A., et al. Particulate Sampling Strategies for Large 
Power Plants Including Nonuniform Flow. USEPA, ORD, ESRL, Research 
Triangle Park, NC. EPA-600/2-76-170, June 1976.
    6. Entropy Environmentalists, Inc. Determination of the Optimum 
Number of Sampling Points: An Analysis of Method 1 Criteria. 
Environmental Protection Agency, Research Triangle Park, NC. EPA 
Contract No. 68-01-3172, Task 7.
    7. Hanson, H.A., R.J. Davini, J.K. Morgan, and A.A. Iversen. 
Particulate Sampling Strategies for Large Power Plants Including 
Nonuniform Flow. U.S. Environmental Protection Agency. Research Triangle 
Park, NC. Publication No. EPA-600/2-76-170. June 1976. 350 p.
    8. Brooks, E.F., and R.L. Williams. Flow and Gas Sampling Manual. 
U.S. Environmental Protection Agency. Research Triangle Park, NC. 
Publication No. EPA-600/2-76-203. July 1976. 93 p.
    9. Entropy Environmentalists, Inc. Traverse Point Study. EPA 
Contract No. 68-02-3172. June 1977. 19 p.
    10. Brown, J. and K. Yu. Test Report: Particulate Sampling Strategy 
in Circular Ducts. Emission Measurement Branch, Emission Standards and 
Engineering Division. U.S. Environmental Protection Agency, Research 
Triangle Park, NC. 27711. July 31, 1980. 12 p.
    11. Hawksley, P.G.W., S. Badzioch, and J.H. Blackett. Measurement of 
Solids in Flue Gases. Leatherhead, England, The British Coal Utilisation 
Research Association, 1961. p. 129-133.

[[Page 584]]

    12. Knapp, K.T. The Number of Sampling Points Needed for 
Representative Source Sampling. In: Proceedings of the Fourth National 
Conference on Energy and the Environment, Theodore, L., et al. (ed.). 
Dayton, Dayton Section of the American Institute of Chemical Engineers. 
October 3-7, 1976. p. 563-568.
    13. Smith, W.S. and D.J. Grove. A Proposed Extension of EPA Method 1 
Criteria. ``Pollution Engineering.'' XV (8):36-37. August 1983.
    14. Gerhart, P.M. and M.J. Dorsey. Investigation of Field Test 
Procedures for Large Fans. University of Akron. Akron, OH. (EPRI 
Contract CS-1651). Final Report (RP-1649-5) December 1980.
    15. Smith, W.S. and D.J. Grove. A New Look at Isokinetic Sampling--
Theory and Applications. ``Source Evaluation Society Newsletter.'' VIII 
(3):19-24. August 1983.

  Method 1A--Sample and Velocity Traverses for Stationary Sources with 
                          Small Stacks or Ducts

                     1. Applicability and Principle

    1.1  The applicability and principle of this method are identical to 
Method 1, except this method's applicability is limited to stacks or 
ducts less than about 0.30 meter (12 in.) in diameter or 0.071 m\2\ (113 
in.\2\) in cross-sectional area, but equal to or greater than about 0.10 
meter (4 in.) in diameter or 0.0081 m\2\ (12.57 in.\2\) in cross-
sectional area.
    1.2  In these small diameter stacks or ducts, the conventional 
Method 5 stack assembly (consisting of a Type S pitot tube attached to a 
sampling probe, equipped with a nozzle and thermocouple) blocks a 
significant portion of the cross section of the duct and causes 
inaccurate measurements. Therefore, for particulate matter (PM) sampling 
in small stacks or ducts, the gas velocity is measured using a standard 
pitot tube downstream of the actual emission sampling site. The straight 
run of duct between the PM sampling and velocity measurement sites 
allows the flow profile, temporarily disturbed by the presence of the 
sampling probe, to redevelop and stabilize.
    1.3  The cross-sectional layout and location of traverse points and 
the verification of the absence of cyclonic flow are the same as in 
Method 1, Sections 2.3 and 2.4, respectively. Differences from Method 1, 
except as noted, are given below.

                              2. Procedure

    2.1  Selection of Sampling and Measurement Sites.
    2.1.1  PM Measurements. Select a PM sampling site located preferably 
at least 8 equivalent stack or duct diameters downstream and 10 
equivalent diameters upstream from any flow disturbances such as bends, 
expansions, or contractions in the stack, or from a visible flame. Next, 
locate the velocity measurement site 8 equivalent diameters downstream 
of the PM sampling site. See Figure 1A-1. If such locations are not 
available, select an alternative PM sampling site that is at least 2 
equivalent stack or duct diameters downstream and 2\1/2\ diameters 
upstream from any flow disturbance. Then, locate the velocity 
measurement site 2 equivalent diameters downstream from the PM sampling 
site. Follow Section 2.1 of Method 1 for calculating equivalent 
diameters for a rectangular cross section.

[[Page 585]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.077

    2.1.2  PM Sampling (Steady Flow) or only Velocity Measurements. For 
PM sampling when the volumetric flow rate in a duct is constant with 
respect to time, Section 2.1 of Method 1 may be followed, with the PM 
sampling and velocity measurement performed at one location. To 
demonstrate that the flow rate is constant (within 10 percent)

[[Page 586]]

when PM measurements are made, perform complete velocity traverses 
before and after the PM sampling run, and calculate the deviation of the 
flow rate derived after the PM sampling run from the one derived before 
the PM sampling run. The PM sampling run is acceptable if the deviation 
does not exceed 10 percent.
    2.2  Determining the Number of Traverse Points.
    2.2.1  PM Sampling. Use Figure 1-1 of Method 1 to determine the 
number of traverse points to use at both the velocity measurement and PM 
sampling locations. Before referring to the figure, however, determine 
the distances between both the velocity measurement and PM sampling 
sites to the nearest upstream and downstream disturbances. Then divide 
each distance by the stack diameter or equivalent diameter to express 
the distances in terms of the number of duct diameters. Next, determine 
the number of traverse points from Figure 1-1 of Method 1 corresponding 
to each of these four distances. Choose the highest of the four numbers 
of traverse points (or a greater number) so that, for circular ducts, 
the number is a multiple of four, and for rectangular ducts, the number 
is one of those shown in Table 1-1 of Method 1. When the optimum duct 
diameter location criteria can be satisfied, the minimum number of 
traverse points required is eight for circular ducts and nine for 
rectangular ducts.
    2.2.2  PM Sampling (Steady Flow) or Velocity Measurements. Use 
Figure 1-2 of Method 1 to determine the number of traverse points, 
following the same procedure used for PM sampling traverses as described 
in Section 2.2.1 of Method 1. When the optimum duct diameter location 
criteria can be satisfied, the minimum number of traverse points 
required is eight for circular ducts and nine for rectangular ducts.

                             3. Bibliography

    1. Same as in Method 1, Section 3, Citations 1 through 6.
    2. Vollaro, Robert F. Recommended Procedure for Sample Traverses in 
Ducts Smaller Than 12 Inches in Diameter. U.S. Environmental Protection 
Agency, Emission Measurement Branch, Research Triangle Park, NC. January 
1977.

 Method 2--Determination of Stack Gas Velocity and Volumetric Flow Rate 
                           (Type S Pitot Tube)

1. Principle and Applicability

    1.1  Principle. The average gas velocity in a stack is determined 
from the gas density and from measurement of the average velocity head 
with a Type S (Stausscheibe or reverse type) pitot tube.
    1.2  Applicability. This method is applicable for measurement of the 
average velocity of a gas stream and for quantifying gas flow.
    This procedure is not applicable at measurement sites which fail to 
meet the criteria of Method 1, Section 2.1. Also, the method cannot be 
used for direct measurement in cyclonic or swirling gas streams; Section 
2.4 of Method 1 shows how to determine cyclonic or swirling flow 
conditions. When unacceptable conditions exist, alternative procedures, 
subject to the approval of the Administrator, U.S. Environmental 
Protection Agency, must be employed to make accurate flow rate 
determinations; examples of such alternative procedures are: (1) to 
install straightening vanes; (2) to calculate the total volumetric flow 
rate stoichiometrically, or (3) to move to another measurement site at 
which the flow is acceptable.

2. Apparatus

    Specifications for the apparatus are given below. Any other 
apparatus that has been demonstrated (subject to approval of the 
Administrator) to be capable of meeting the specifications will be 
considered acceptable.

[[Page 587]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.078

    2.1 Type S Pitot Tube. The Type S pitot tube (Figure 2-1) shall be 
made of metal tubing (e.g., stainless steel). It is recommended that the 
external tubing diameter (dimension Dt Figure 2-2b) be 
between 0.48 and 0.95 centimeter (\3/16\ and \3/8\ inch). There shall be 
an equal distance from the base of each leg of the pitot tube to its 
face-opening plane (dimensions PA and PB Figure 2-
2b); it is recommended that this distance be between 1.05 and 1.50 times 
the external tubing diameter. The face openings of the pitot tube shall, 
preferably, be aligned as shown in Figure 2-2; however, slight 
misalignments of the openings are permissible (see Figure 2-3).
    The Type S pitot tube shall have a known coefficient, determined as 
outlined in Section 4. An identification number shall be assigned to the 
pitot tube; this number shall be permanently marked or engraved on the 
body of the tube.

[[Page 588]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.079

 Figure 2-2. Properly constructed Type S pitot tube, shown in: (a) end 
  view; face opening planes perpendicular to transverse axis; (b) top 
view; face opening planes parallel to longitudinal axis; (c) side view; 
 both legs of equal length and centerlines coincident, when viewed from 
both sides. Baseline coefficient values of 0.84 may be assigned to pitot 
                       tubes constructed this way.
      

[[Page 589]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.080

  Figure 2-3. Types of face-opening misalignment that can result from 
field use or improper construction of Type S pitot tubes. These will not 
affect the baseline value of Cp(s) so long as 1 and 2 
> 10 deg., 1 and 2 > 5 deg., z > 0.32 cm (1/8 in.) and 
          w > 0.08 cm (1/32 in.) (citation 11 in Bibliography).
    A standard pitot tube may be used instead of a Type S, provided that 
it meets the specifications of Sections 2.7 and 4.2; note, however, that 
the static and impact pressure holes of standard pitot tubes are 
susceptible to plugging in particulate-laden gas streams. Therefore, 
whenever a standard pitot tube is used to perform a traverse, adequate 
proof must be furnished that the openings of the pitot tube have not 
plugged up during the traverse period; this can be done by taking a 
velocity head (p) reading at the final traverse point, cleaning 
out the impact and static holes of the standard pitot tube by ``back-
purging'' with pressurized air, and then taking another p 
reading. If the p readings made before and after the air purge 
are the same (plus-minus5 percent), the traverse is 
acceptable. Otherwise, reject the run. Note that if p at the 
final traverse point is unsuitably low, another point may be selected. 
If ``back-purging'' at regular intervals is part of the procedure, then 
comparative p readings shall be taken, as above, for the last 
two back purges at which suitably high p readings are observed.

[[Page 590]]

    2.2  Differential Pressure Gauge. An inclined manometer or 
equivalent device is used. Most sampling trains are equipped with a 10-
in. (water column) inclined-vertical manometer, having 0.01-in. 
H2O divisions on the 0-to 1-in. inclined scale, and 0.1-in. 
H2O divisions on the 1- to 10-in. vertical scale. This type 
of manometer (or other gauge of equivalent sensitivity) is satisfactory 
for the measurement of p values as low as 1.3 mm (0.05 in.) 
H2O. However, a differential pressure gauge of greater 
sensitivity shall be used (subject to the approval of the 
Administrator), if any of the following is found to be true: (1) the 
arithmetic average of all p readings at the traverse points in 
the stack is less than 1.3 mm (0.05 in.) H2O; (2) for 
traverses of 12 or more points, more than 10 percent of the individual 
p readings are below 1.3 mm (0.05 in.) H2O; (3) for 
traverses of fewer than 12 points, more than one p reading is 
below 1.3 mm (0.05 in.) H2O. Citation 18 in Bibliography 
describes commercially available instrumentation for the measurement of 
low-range gas velocities.
    As an alternative to criteria (1) through (3) above, the following 
calculation may be performed to determine the necessity of using a more 
sensitive differential pressure gauge:
[GRAPHIC] [TIFF OMITTED] TC01JN92.081

Where:

pi=Individual velocity head reading at a traverse 
          point, mm H2O (in. H2O).
n=Total number of traverse points.
K=0.13 mm H2O when metric units are used and 0.005 in. 
          H2O when English units are used.

If T is greater than 1.05, the velocity head data are unacceptable and a 
more sensitive differential pressure gauge must be used.
    Note: If differential pressure gauges other than inclined manometers 
are used (e.g., magnehelic gauges), their calibration must be checked 
after each test series. To check the calibration of a differential 
pressure gauge, compare p readings of the gauge with those of a 
gauge-oil manometer at a minimum of three points, approximately 
representing the range of p values in the stack. If, at each 
point, the values of p as read by the differential pressure 
gauge and gauge-oil manometer agree to within 5 percent, the 
differential pressure gauge shall be considered to be in proper 
calibration. Otherwise, the test series shall either be voided, or 
procedures to adjust the measured p values and final results 
shall be used subject to the approval of the Administrator.
    2.3  Temperature Gauge. A thermocouple, liquid-filled bulb 
thermometer, bimetallic thermometer, mercury-in-glass thermometer, or 
other gauge, capable of measuring temperature to within 1.5 percent of 
the minimum absolute stack temperature shall be used. The temperature 
gauge shall be attached to the pitot tube such that the sensor tip does 
not touch any metal; the gauge shall be in an interference-free 
arrangement with respect to the pitot tube face openings (see Figure 2-1 
and also Figure 2-7 in Section 4). Alternative positions may be used if 
the pitot tube-temperature gauge system is calibrated according to the 
procedure of Section 4. Provided that a difference of not more than 1 
percent in the average velocity measurement is introduced, the 
temperature gauge need not be attached to the pitot tube; this 
alternative is subject to the approval of the Administrator.
    2.4  Pressure Probe and Gauge. A piezometer tube and mercury- or 
water-filled U-tube manometer capable of measuring stack pressure to 
within 2.5 mm (0.1 in.) Hg is used. The static tap of a standard type 
pitot tube or one leg of a Type S pitot tube with the face opening 
planes positioned parallel to the gas flow may also be used as the 
pressure probe.
    2.5  Barometer. A mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg) may be 
used. In many cases, the barometric reading may be obtained from a 
nearby National Weather Service station, in which case the station value 
(which is the absolute barometric pressure) shall be requested and an 
adjustment for elevation differences between the weather station and the 
sampling point shall be applied at a rate of minus 2.5 mm (0.1 in.) Hg 
per 30-meter (100 foot) elevation increase or vice-versa for elevation 
decrease.
    2.6  Gas Density Determination Equipment. Method 3 equipment, if 
needed (see Section 3.6), to determine the stack gas dry molecular 
weight, and Reference Method 4 or Method 5 equipment for moisture 
content determination; other methods may be used subject to approval of 
the Administrator.
    2.7  Calibration Pitot Tube. When calibration of the Type S pitot 
tube is necessary (see Section 4), a standard pitot tube is used as a 
reference. The standard pitot tube shall, preferably, have a known 
coefficient, obtained either (1) directly from the National Bureau of 
Standards, Route 270, Quince Orchard Road, Gaithersburg, Maryland, or 
(2) by calibration against another standard pitot tube with an NBS-
traceable coefficient. Alternatively, a standard pitot tube designed 
according to the criteria given in 2.7.1 through 2.7.5 below and 
illustrated in Figure 2-4 (see also Citations 7, 8, and 17 in 
Bibliography) may be used. Pitot tubes designed according to these 
specifications will have baseline coefficients of about 
0.99plus-minus0.01.

[[Page 591]]

    2.7.1  Hemispherical (shown in Figure 2-4), ellipsoidal, or conical 
tip.
    2.7.2  A minimum of six diameters straight run (based upon D, the 
external diameter of the tube) between the tip and the static pressure 
holes.
    2.7.3  A minimum of eight diameters straight run between the static 
pressure holes and the centerline of the external tube, following the 90 
degree bend.
    2.7.4  Static pressure holes of equal size (approximately 0.1 D), 
equally spaced in a piezometer ring configuration.
    2.7.5  Ninety degree bend, with curved or mitered junction.
    2.8  Differential Pressure Gauge for Type S Pitot Tube Calibration. 
An inclined manometer or equivalent is used. If the single-velocity 
calibration technique is employed (see Section 4.1.2.3), the calibration 
differential pressure gauge shall be readable to the nearest 0.13 mm 
H2O (0.005 in. H2O). For multivelocity 
calibrations, the gauge shall be readable to the nearest 0.13 mm 
H2O (0.005 in. H2O) for p values between 
1.3 and 25 mm H2O (0.05 and 1.0 in. H2O), and to 
the nearest 1.3 mm H2O (0.05 in. H2O) for 
p values above 25 mm H2O (1.0 in. H2O). A 
special, more sensitive gauge will be required to read p values 
below 1.3 mm H2O [0.05 in. H2O] (see Citation 18 
in Bibliography).

[[Page 592]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.082

3. Procedure

    3.1  Set up the apparatus as shown in Figure 2-1. Capillary tubing 
or surge tanks installed between the manometer and pitot tube may be 
used to dampen p fluctuations. It is recommended, but not 
required, that a pretest leak-check be conducted, as follows: (1) blow 
through the pitot impact opening

[[Page 593]]

until at least 7.6 cm (3 in.) H2O velocity pressure registers 
on the manometer; then, close off the impact opening. The pressure shall 
remain stable for at least 15 seconds; (2) do the same for the static 
pressure side, except using suction to obtain the minimum of 7.6 cm (3 
in.) H2O. Other leak-check procedures, subject to the 
approval of the Administrator, may be used.
    3.2  Level and zero the manometer. Because the manometer level and 
zero may drift due to vibrations and temperature changes, make periodic 
checks during the traverse. Record all necessary data as shown in the 
example data sheet (Figure 2-5).
    3.3  Measure the velocity head and temperature at the traverse 
points specified by Method 1. Ensure that the proper differential 
pressure gauge is being used for the range of p values 
encountered (see Section 2.2). If it is necessary to change to a more 
sensitive gauge, do so, and remeasure the p and temperature 
readings at each traverse point. Conduct a post-test leak-check 
(mandatory), as described in Section 3.1 above, to validate the traverse 
run.
    3.4  Measure the static pressure in the stack. One reading is 
usually adequate.
    3.5  Determine the atmospheric pressure.

[[Page 594]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.083

    3.6 Determine the stack gas dry molecular weight. For combustion 
processes or processes that emit essentially CO2, 
O2, CO, and N2, use Method 3. For processes 
emitting essentially air, an analysis need not be conducted; use a dry 
molecular weight of 29.0. For other processes, other methods, subject

[[Page 595]]

to the approval of the Administrator, must be used.
    3.7 Obtain the moisture content from Reference Method 4 (or 
equivalent) or from Method 5.
    3.8 Determine the cross-sectional area of the stack or duct at the 
sampling location. Whenever possible, physically measure the stack 
dimensions rather than using blueprints.

4. Calibration

    4.1 Type S Pitot Tube. Before its initial use, carefully examine the 
Type S pitot tube in top, side, and end views to verify that the face 
openings of the tube are aligned within the specifications illustrated 
in Figure 2-2 or 2-3. The pitot tube shall not be used if it fails to 
meet these alignment specifications.
    After verifying the face opening alignment, measure and record the 
following dimensions of the pitot tube: (a) the external tubing diameter 
(dimension Dt, Figure 2-2b); and (b) the base-to-opening 
plane distances (dimensions PA and PB, Figure 2-
2b). If Dt is between 0.48 and 0.95 cm (\3/16\ and \3/8\ in.) 
and if PA and PB are equal and between 1.05 and 
1.50 Dt, there are two possible options: (1) the pitot tube 
may be calibrated according to the procedure outlined in Sections 4.1.2 
through 4.1.5 below, or (2) a baseline (isolated tube) coefficient value 
of 0.84 may be assigned to the pitot tube. Note, however, that if the 
pitot tube is part of an assembly, calibration may still be required, 
despite knowledge of the baseline coefficient value (see Section 4.1.1).
    If Dt, PA, and PB are outside the 
specified limits, the pitot tube must be calibrated as outlined in 4.1.2 
through 4.1.5 below.
    4.1.1 Type S Pitot Tube Assemblies. During sample and velocity 
traverses, the isolated Type S pitot tube is not always used; in many 
instances, the pitot tube is used in combination with other source-
sampling components (thermocouple, sampling probe, nozzle) as part of an 
``assembly.'' The presence of other sampling components can sometimes 
affect the baseline value of the Type S pitot tube coefficient (Citation 
9 in Bibliography); therefore an assigned (or otherwise known) baseline 
coefficient value may or may not be valid for a given assembly. The 
baseline and assembly coefficient values will be identical only when the 
relative placement of the components in the assembly is such that 
aerodynamic interference effects are eliminated. Figures 2-6 through 2-8 
illustrate interference-free component arrangements for Type S pitot 
tubes having external tubing diameters between 0.48 and 0.95 cm (\3/16\ 
and \3/8\ in.). Type S pitot tube assemblies that fail to meet any or 
all of the specifications of Figures 2-6 through 2-8 shall be calibrated 
according to the procedure outlined in Sections 4.1.2 through 4.1.5 
below, and prior to calibration, the values of the intercomponent 
spacings (pitot-nozzle, pitot-thermocouple, pitot-probe sheath) shall be 
measured and recorded.
    Note: Do not use any Type S pitot tube assembly which is constructed 
such that the impact pressure opening plane of the pitot tube is below 
the entry plane of the nozzle (see Figure 2-6b).
    4.1.2  Calibration Setup. If the Type S pitot tube is to be 
calibrated, one leg of the tube shall be permanently marked A, and the 
other, B. Calibration shall be done in a flow system having the 
following essential design features:

[[Page 596]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.084


[[Page 597]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.085

    4.1.2.1  The flowing gas stream must be confined to a duct of 
definite cross-sectional area, either circular or rectangular. For 
circular cross-sections, the minimum duct diameter shall be 30.5 cm (12 
in.); for rectangular cross-sections, the width (shorter side) shall be 
at least 25.4 cm (10 in.).
    4.1.2.2  The cross-sectional area of the calibration duct must be 
constant over a distance of 10 or more duct diameters. For a rectangular 
cross-section, use an equivalent diameter, calculated from the following 
equation, to determine the number of duct diameters:

[[Page 598]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.108

Where:
De=Equivalent diameter
L=Length
W=Width

    To ensure the presence of stable, fully developed flow patterns at 
the calibration site, or ``test section,'' the site must be located at 
least eight diameters downstream and two diameters upstream from the 
nearest disturbances.
    Note: The eight- and two-diameter criteria are not absolute; other 
test section locations may be used (subject to approval of the 
Administrator), provided that the flow at the test site is stable and 
demonstrably parallel to the duct axis.
    4.1.2.3  The flow system shall have the capacity to generate a test-
section velocity around 915 m/min (3,000 ft/min). This velocity must be 
constant with time to guarantee steady flow during calibration. Note 
that Type S pitot tube coefficients obtained by single-velocity 
calibration at 915 m/min (3,000 ft/min) will generally be valid to 
within plus-minus3 percent for the measurement of velocities 
above 305 m/min (1,000 ft/min) and to within plus-minus5 to 6 
percent for the measurement of velocities between 180 and 305 m/min (600 
and 1,000 ft/min). If a more precise correlation between Cp 
and velocity is desired, the flow system shall have the capacity to 
generate at least four distinct, time-invariant test-section velocities 
covering the velocity range from 180 to 1,525 m/min (600 to 5,000 ft/
min), and calibration data shall be taken at regular velocity intervals 
over this range (see Citations 9 and 14 in Bibliography for details).
    4.1.2.4  Two entry ports, one each for the standard and Type S pitot 
tubes, shall be cut in the test section; the standard pitot entry port 
shall be located slightly downstream of the Type S port, so that the 
standard and Type S impact openings will lie in the same cross-sectional 
plane during calibration. To facilitate alignment of the pitot tubes 
during calibration, it is advisable that the test section be constructed 
of plexiglas or some other transparent material.
    4.1.3  Calibration Procedure. Note that this procedure is a general 
one and must not be used without first referring to the special 
considerations presented in Section 4.1.5. Note also that this procedure 
applies only to single-velocity calibration. To obtain calibration data 
for the A and B sides of the Type S pitot tube, proceed as follows:
    4.1.3.1  Make sure that the manometer is properly filled and that 
the oil is free from contamination and is of the proper density. Inspect 
and leak-check all pitot lines; repair or replace if necessary.
    4.1.3.2  Level and zero the manometer. Turn on the fan and allow the 
flow to stabilize. Seal the Type S entry port.
    4.1.3.3  Ensure that the manometer is level and zeroed. Position the 
standard pitot tube at the calibration point (determined as outlined in 
Section 4.1.5.1), and align the tube so that its tip is pointed directly 
into the flow. Particular care should be taken in aligning the tube to 
avoid yaw and pitch angles. Make sure that the entry port surrounding 
the tube is properly sealed.
    4.1.3.4  Read  pstd and record its value in a 
data table similar to the one shown in Figure 2-9. Remove the standard 
pitot tube from the duct and disconnect it from the manometer. Seal the 
standard entry port.
    4.1.3.5  Connect the Type S pitot tube to the manometer. Open the 
Type S entry port. Check the manometer level and zero. Insert and align 
the Type S pitot tube so that its A side impact opening is at the same 
point as was the standard pitot tube and is pointed directly into the 
flow. Make sure that the entry port surrounding the tube is properly 
sealed.
    4.1.3.6  Read p8 and enter its value in the data 
table. Remove the Type S pitot tube from the duct and disconnect it from 
the manometer.
    4.1.3.7  Repeat steps 4.1.3.3 through 4.1.3.6 above until three 
pairs of p readings have been obtained.
    4.1.3.8  Repeat steps 4.1.3.3 through 4.1.3.7 above for the B side 
of the Type S pitot tube.
    4.1.3.9  Perform calculations, as described in Section 4.1.4 below.
    4.1.4  Calculations.
    4.1.4.1  For each of the six pairs of p readings (i.e., 
three from side A and three from side B) obtained in Section 4.1.3 
above, calculate the value of the Type S pitot tube coefficient as 
follows:

[[Page 599]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.086

[GRAPHIC] [TIFF OMITTED] TC01JN92.087

Where:

Cp(s)=Type S pitot tube coefficient
Cp(std)=Standard pitot tube coefficient; use 0.99 if the 
          coefficient is unknown and the tube is designed according to 
          the criteria of Sections 2.7.1 to 2.7.5 of this method.
pstd=Velocity head measured by the standard pitot 
          tube, cm H2O (in. H2O)

[[Page 600]]

ps=Velocity head measured by the Type S pitot tube, 
          cm H2O (in. H2O)

    4.1.4.2  Calculate Cp (side A), the mean A-side 
coefficient, and Cp (side B), the mean B-side coefficient: 
calculate the difference between these two average values.
    4.1.4.3  Calculate the deviation of each of the three A-side values 
of Cp(s) from Cp (side A), and the deviation of 
each B-side value of Cp(s) from Cp (side B). Use 
the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.088

    4.1.4.4  Calculate , the average deviation from the mean, 
for both the A and B sides of the pitot tube. Use the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.089

    4.1.4.5  Use the Type S pitot tube only if the values of  
(side A) and  (side B) are less than or equal to 0.01 and if 
the absolute value of the difference between Cp (A) and 
Cp (B) is 0.01 or less.
    4.1.5  Special considerations.
    4.1.5.1  Selection of calibration point.
    4.1.5.1.1  When an isolated Type S pitot tube is calibrated, select 
a calibration point at or near the center of the duct, and follow the 
procedures outlined in Sections 4.1.3 and 4.1.4 above. The Type S pitot 
coefficients so obtained, i.e., Cp (side A) and Cp 
(side B), will be valid, so long as either: (1) the isolated pitot tube 
is used; or (2) the pitot tube is used with other components (nozzle, 
thermocouple, sample probe) in an arrangement that is free from 
aerodynamic interference effects (see Figures 2-6 through 2-8).
    4.1.5.1.2  For Type S pitot tube-thermocouple combinations (without 
sample probe), select a calibration point at or near the center of the 
duct, and follow the procedures outlined in Sections 4.1.3 and 4.1.4 
above. The coefficients so obtained will be valid so long as the pitot 
tube-thermocouple combination is used by itself or with other components 
in an interference-free arrangement (Figures 2-6 and 2-8).
    4.1.5.1.3  For assemblies with sample probes, the calibration point 
should be located at or near the center of the duct; however, insertion 
of a probe sheath into a small duct may cause significant cross-
sectional area blockage and yield incorrect coefficient values (Citation 
9 in Bibliography). Therefore, to minimize the blockage effect, the 
calibration point may be a few inches off-center if necessary. The 
actual blockage effect will be negligible when the theoretical blockage, 
as determined by a projected-area model of the probe sheath, is 2 
percent or less of the duct cross-sectional area for assemblies without 
external sheaths (Figure 2-10a), and 3 percent or less for assemblies 
with external sheaths (Figure 2-10b).
    4.1.5.2  For those probe assemblies in which pitot tube-nozzle 
interference is a factor (i.e., those in which the pitot-nozzle 
separation distance fails to meet the specification illustrated in 
Figure 2-6a), the value of Cp(s) depends upon the amount of 
free-space between the tube and nozzle, and therefore is a function of 
nozzle size. In these instances, separate calibrations shall be 
performed with each of the commonly used nozzle sizes in place. Note 
that the single-velocity calibration technique is acceptable for this 
purpose, even though the larger nozzle sizes (>0.635 cm or \1/4\ in.) 
are not ordinarily used for isokinetic sampling at velocities around 915 
m/min (3,000 ft/min), which is the calibration velocity; note also that 
it is not necessary to draw an isokinetic sample during calibration (see 
Citation 19 in Section 6).
    4.1.5.3  For a probe assembly constructed such that its pitot tube 
is always used in the same orientation, only one side of the pitot tube 
need be calibrated (the side which will face the flow). The pitot tube 
must still meet the alignment specifications of Figure 2-2 or 2-3, 
however, and must have an average deviation () value of 0.01 or 
less (see Section 4.1.4.4).

[[Page 601]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.090

    4.1.6  Field Use and Recalibration.
    4.1.6.1  Field Use.
    4.1.6.1.1  When a Type S pitot tube (isolated tube or assembly) is 
used in the field, the appropriate coefficient value (whether assigned 
or obtained by calibration) shall be used to perform velocity 
calculations. For

[[Page 602]]

calibrated Type S pitot tubes, the A side coefficient shall be used when 
the A side of the tube faces the flow, and the B side coefficient shall 
be used when the B side faces the flow; alternatively, the arithmetic 
average of the A and B side coefficient values may be used, irrespective 
of which side faces the flow.
    4.1.6.1.2  When a probe assembly is used to sample a small duct (12 
to 36 in. in diameter), the probe sheath sometimes blocks a significant 
part of the duct cross-section, causing a reduction in the effective 
value of Cp(s). Consult Citation 9 in Bibliography for 
details. Conventional pitot-sampling probe assemblies are not 
recommended for use in ducts having inside diameters smaller than 12 
inches (Citation 16 in Bibliography).
    4.1.6.2  Recalibration.
    4.1.6.2.1  Isolated Pitot Tubes. After each field use, the pitot 
tube shall be carefully reexamined in top, side, and end views. If the 
pitot face openings are still aligned within the specifications 
illustrated in Figure 2-2 or 2-3, it can be assumed that the baseline 
coefficient of the pitot tube has not changed. If, however, the tube has 
been damaged to the extent that it no longer meets the specifications of 
Figure 2-2 or 2-3, the damage shall either be repaired to restore proper 
alignment of the face openings or the tube shall be discarded.
    4.1.6.2.2  Pitot Tube Assemblies. After each field use, check the 
face opening alignment of the pitot tube, as in Section 4.1.6.2.1; also, 
remeasure the intercomponent spacings of the assembly. If the 
intercomponent spacings have not changed and the face opening alignment 
is acceptable, it can be assumed that the coefficient of the assembly 
has not changed. If the face opening alignment is no longer within the 
specifications of Figures 2-2 or 2-3, either repair the damage or 
replace the pitot tube (calibrating the new assembly, if necessary). If 
the intercomponent spacings have changed, restore the original spacings 
or recalibrate the assembly.
    4.2  Standard pitot tube (if applicable). If a standard pitot tube 
is used for the velocity traverse, the tube shall be constructed 
according to the criteria of Section 2.7 and shall be assigned a 
baseline coefficient value of 0.99. If the standard pitot tube is used 
as part of an assembly, the tube shall be in an interference-free 
arrangement (subject to the approval of the Administrator).
    4.3  Temperature Gauges. After each field use, calibrate dial 
thermometers, liquid-filled bulb thermometers, thermocouple-
potentiometer systems, and other gauges at a temperature within 10 
percent of the average absolute stack temperature. For temperatures up 
to 405  deg.C (761  deg.F), use an ASTM mercury-in-glass reference 
thermometer, or equivalent, as a reference; alternatively, either a 
reference thermocouple and potentiometer (calibrated by NBS) or 
thermometric fixed points, e.g., ice bath and boiling water (corrected 
for barometric pressure) may be used. For temperatures above 405  deg.C 
(761  deg.F), use an NBS-calibrated reference thermocouple-potentiometer 
system or an alternate reference, subject to the approval of the 
Administrator.
    If, during calibration, the absolute temperatures measured with the 
gauge being calibrated and the reference gauge agree within 1.5 percent, 
the temperature data taken in the field shall be considered valid. 
Otherwise, the pollutant emission test shall either be considered 
invalid or adjustments (if appropriate) of the test results shall be 
made, subject to the approval of the Administrator.
    4.4  Barometer. Calibrate the barometer used against a mercury 
barometer.

5.  Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after final 
calculation.
    5.1  Nomenclature.

A=Cross-sectional area of stack, m2(ft2).
Bws=Water vapor in the gas stream (from Method 5 or Reference 
          Method 4), proportion by volume.
Cp=Pitot tube coefficient, dimensionless.
Kp=Pitot tube constant,
[GRAPHIC] [TIFF OMITTED] TC01JN92.091

for the metric system and
[GRAPHIC] [TIFF OMITTED] TC01JN92.092

for the English system.

Md=Molecular weight of stack gas, dry basis (see Section 3.6) 
          g/g-mole (lb/lb-mole).
Ms=Molecular weight of stack gas, wet basis, g/g-mole (lb/lb-
          mole).

=Md (1-Bws) +18.0 Bws
                                                           Eq. 2-5

Pbar=Barometric pressure at measurement site, mm Hg (in. Hg).
Pg=Stack static pressure, mm Hg (in. Hg).
Ps=Absolute stack gas pressure, mm Hg (in. Hg).
=Pbar+Pg
                                                           Eq. 2-6
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
Qsd=Dry volumetric stack gas flow rate corrected to standard 
          conditions, dscm/hr (dscf/hr).
ts=Stack temperature,  deg.C (  deg.F).
Ts=Absolute stack temperature,  deg.K, ( deg.R).
=273+ts for metric.
                                                                 Eq. 2-7
=460+ts for English.

[[Page 603]]

                                                                 Eq. 2-8
Tstd=Standard absolute temperature, 293  deg.K (528 deg. R).
vs=Average stack gas velocity, m/sec (ft/sec).
p=Velocity head of stack gas, mm H2O (in. 
          H2O).
3,600=Conversion factor, sec/hr.
18.0=Molecular weight of water, g/g-mole (lb/lb-mole).
5.2  Average Stack Gas Velocity.
[GRAPHIC] [TIFF OMITTED] TC01JN92.093

5.3  Average Stack Gas Dry Volumetric Flow Rate.
[GRAPHIC] [TIFF OMITTED] TC16NO91.109


To convert Qsd from dscm/hr (dscf/hr) to dscm/min (dscf/min), 
          divide Qsd by 60.

6.  Bibliography

    1. Mark, L. S. Mechanical Engineers' Handbook. New York, McGraw-Hill 
Book Co., Inc. 1951.
    2. Perry, J. H. Chemical Engineers' Handbook. New York. McGraw-Hill 
Book Co., Inc. 1960.
    3. Shigehara, R. T., W. F. Todd, and W. S. Smith. Significance of 
Errors in Stack Sampling Measurements. U.S. Environmental Protection 
Agency, Research Triangle Park, NC (Presented at the Annual Meeting of 
the Air Pollution Control Association, St. Louis, MO, June 14-19, 1970.)
    4. Standard Method for Sampling Stacks for Particulate Matter. In: 
1971 Book of ASTM Standards, Part 23. Philadelphia, PA 1971. ASTM 
Designation D-2928-71.
    5. Vennard, J. K. Elementary Fluid Mechanics. New York. John Wiley 
and Sons, Inc. 1947.
    6. Fluid Meters--Their Theory and Application. American Society of 
Mechanical Engineers, New York, NY 1959.
    7. ASHRAE Handbook of Fundamentals. 1972. p. 208.
    8. Annual Book of ASTM Standards, Part 26. 1974. p. 648.
    9. Vollaro, R. F. Guidelines for Type S Pitot Tube Calibration. U.S. 
Environmental Protection Agency. Research Triangle Park, NC (Presented 
at 1st Annual Meeting, Source Evaluation Society, Dayton, OH, September 
18, 1975.)
    10. Vollaro, R. F. A Type S Pitot Tube Calibration Study. U.S. 
Environmental Protection Agency, Emission Measurement Branch, Research 
Triangle Park, NC July 1974.
    11. Vollaro, R. F. The Effects of Impact Opening Misalignment on the 
Value of the Type S Pitot Tube Coefficient. U.S. Environmental 
Protection Agency, Emission Measurement Branch, Research Triangle Park, 
NC. October 1976.
    12. Vollaro, R. F. Establishment of a Basline Coefficient Value for 
Properly Constructed Type S Pitot Tubes. U.S. Environmental Protection 
Agency, Emission Measurement Branch, Research Triangle Park, NC. 
November 1976.
    13. Vollaro, R. F. An Evaluation of Single-Velocity Calibration 
Technique as a Means of Determining Type S Pitot Tubes Coefficient. U.S. 
Environmental Protection Agency, Emission Measurement Branch, Research 
Triangle Park, NC. August 1975.
    14. Vollaro, R. F. The Use of Type S Pitot Tubes for the Measurement 
of Low Velocities. U.S. Environmental Protection Agency, Emission 
Measurement Branch, Research Triangle Park, NC. November 1976.
    15. Smith, Marvin L. Velocity Calibration of EPA Type Source 
Sampling Probe. United Technologies Corporation, Pratt and Whitney 
Aircraft Division, East Hartford, CN. 1975.
    16. Vollaro, R. F. Recommended Procedure for Sample Traverses in 
Ducts Smaller than 12 Inches in Diameter. U.S. Environmental Protection 
Agency, Emission Measurement Branch, Research Triangle Park, NC. 
November 1976.
    17. Ower, E. and R. C. Pankhurst. The Measurement of Air Flow, 4th 
Ed., London, Pergamon Press. 1966.
    18. Vollaro, R. F. A Survey of Commercially Available 
Instrumentation for the Measurement of Low-Range Gas Velocities. U.S. 
Environmental Protection Agency, Emission Measurement Branch, Research 
Triangle Park, NC. November 1976. (Unpublished Paper)
    19. Gnyp, A. W., C. C. St. Pierre, D. S. Smith, D. Mozzon, and J. 
Steiner. An Experimental Investigation of the Effect of Pitot Tube-
Sampling Probe Configurations on the Magnitude of the S Type Pitot Tube 
Coefficient for Commercially Available Source Sampling Probes. Prepared 
by the University of Windsor for the Ministry of the Environment, 
Toronto, Canada. February 1975.

[[Page 604]]

  Method 2A--Direct Measurement of Gas Volume Through Pipes and Small 
                                  Ducts

1. Applicability and Principle
    1.1  Applicability. This method applies to the measurement of gas 
flow rates in pipes and small ducts, either in-line or at exhaust 
positions, within the temperature range of 0 to 50  deg.C.
    1.2  Principle. A gas volume meter is used to measure gas volume 
directly. Temperature and pressure measurements are made to correct the 
volume to standard conditions.

2. Apparatus

    Specifications for the apparatus are given below. Any other 
apparatus that has been demonstrated (subject to approval of the 
Administrator) to be capable of meeting the specifications will be 
considered acceptable.
    2.1  Gas Volume Meter. A positive displacement meter, turbine meter, 
or other direct volume measuring device capable of measuring volume to 
within 2 percent. The meter shall be equipped with a temperature gauge 
(2 percent of the minimum absolute temperature) and a 
pressure gauge (2.5 mm Hg). The manufacturer's recommended 
capacity of the meter shall be sufficient for the expected maximum and 
minimum flow rates at the sampling conditions. Temperature, pressure, 
corrosive characteristics, and pipe size are factors necessary to 
consider in choosing a suitable gas meter.
    2.2  Barometer. A mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg. In many cases, the 
barometric reading may be obtained from a nearby National Weather 
Service station, in which case the station value (which is the absolute 
barometric pressure) shall be requested, and an adjustment for elevation 
differences between the weather station and the sampling point shall be 
applied at a rate of minus 2.5 mm Hg per 30-meter elevation increase, or 
vice-versa for elevation decrease.
    2.3  Stopwatch. Capable of measurement to within 1 second.
3. Procedure
    3.1  Installation. As there are numerous types of pipes and small 
ducts that may be subject to volume measurement, it would be difficult 
to describe all possible installation schemes. In general, flange 
fittings should be used for all connections wherever possible. Gaskets 
or other seal materials should be used to assure leak-tight connections. 
The volume meter should be located so as to avoid severe vibrations and 
other factors that may affect the meter calibration.
    3.2  Leak Test. A volume meter installed at a location under 
positive pressure may be leak-checked at the meter connections by using 
a liquid leak detector solution containing a surfactant. Apply a small 
amount of the solution to the connections. If a leak exists, bubbles 
will form, and the leak must be corrected.
    A volume meter installed at a location under negative pressure is 
very difficult to test for leaks without blocking flow at the inlet of 
the line and watching for meter movement. If this procedure is not 
possible, visually check all connections and assure tight seals.

    3.3  Volume Measurement.
    3.3.1  For sources with continuous, steady emission flow rates, 
record the initial meter volume reading, meter temperature(s), meter 
pressure, and start the stopwatch. Throughout the test period, record 
the meter temperature(s) and pressure so that average values can be 
determined. At the end of the test, stop the timer and record the 
elapsed time, the final volume reading, meter temperature(s), and 
pressure. Record the barometric pressure at the beginning and end of the 
test run. Record the data on a table similar to Figure 2A-1.

[[Page 605]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.094

    3.3.2  For sources with noncontinuous, non-steady emission flow 
rates, use the procedure in 3.3.1 with the addition of the following: 
Record all the meter parameters and the start and stop times 
corresponding to each process cyclical or noncontinuous event.

4. Calibration


[[Page 606]]


    4.1  Volume Meter. The volume meter is calibrated against a standard 
reference meter prior to its initial use in the field. The reference 
meter is a spirometer or liquid displacement meter with a capacity 
consistent with that of the test meter.
    Alternatively, a calibrated, standard pitot may be used as the 
reference meter in conjunction with a wind tunnel assembly. Attach the 
test meter to the wind tunnel so that the total flow passes through the 
test meter. For each calibration run, conduct a 4-point traverse along 
one stack diameter at a position at least eight diameters of straight 
tunnel downstream and two diameters upstream of any bend, inlet, or air 
mover. Determine the traverse point locations as specified in Method 1. 
Calculate the reference volume using the velocity values following the 
procedure in Method 2, the wind tunnel cross-sectional area, and the run 
time.
    Set up the test meter in a configuration similar to that used in the 
field installation (i.e., in relation to the flow moving device). 
Connect the temperature and pressure gauges as they are to be used in 
the field. Connect the reference meter at the inlet of the flow line, if 
appropriate for the meter, and begin gas flow through the system to 
condition the meters. During this conditioning operation, check the 
system for leaks.
    The calibration shall be run over at least three different flow 
rates. The calibration flow rates shall be about 0.3, 0.6, and 0.9 times 
the test meter's rated maximum flow rate.
    For each calibration run, the data to be collected include: 
reference meter initial and final volume readings, the test meter 
initial and final volume reading, meter average temperature and 
pressure, barometric pressure, and run time. Repeat the runs at each 
flow rate at least three times.
    Calculate the test meter calibration coefficient, Ym, for 
each run as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.110

Where:

Ym=Test volume meter calibration coefficient, dimensionless.
Vr=Reference meter volume reading, m3.
Vm=Test meter volume reading, m3.
tr=Reference meter average temperature,  deg. C.
tm=Test meter average temperature,  deg. C.
Pb=Barometric pressure, mm Hg.
Pg=Test meter average static pressure, mm Hg.
f=Final reading for run.
i=Initial reading for run.
    Compare the three Ym values at each of the flow rates 
tested and determine the maximum and minimum values. The difference 
between the maximum and minimum values at each flow rate should be no 
greater than 0.030. Extra runs may be required to complete this 
requirement. If this specification cannot be met in six successive runs, 
the test meter is not suitable for use. In addition, the meter 
coefficients should be between 0.95 and 1.05. If these specifications 
are met at all the flow rates, average all the Ym values from 
runs meeting the specifications to obtain an average meter calibration 
coefficient, Ym.
    The procedure above shall be performed at least once for each volume 
meter. Thereafter, an abbreviated calibration check shall be completed 
following each field test. The calibration of the volume meter shall be 
checked by performing three calibration runs at a single, intermediate 
flow rate (based on the previous field test) with the meter pressure set 
at the average value encountered in the field test. Calculate the 
average value of the calibration factor. If the calibration has changed 
by more than 5 percent, recalibrate the meter over the full range of 
flow as described above.
    Note. If the volume meter calibration coefficient values obtained 
before and after a test series differ by more than 5 percent, the test 
series shall either be voided, or calculations for the test series shall 
be performed using whichever meter coefficient value (i.e., before or 
after) gives the greater value of pollutant emission rate.
    4.2  Temperature Gauge. After each test series, check the 
temperature gauge at ambient temperature. Use an American Society for 
Testing and Materials (ASTM) mercury-in-glass reference thermometer, or 
equivalent, as a reference. If the gauge being checked agrees within 2 
percent (absolute temperature) of the reference, the temperature data 
collected in the field shall be considered valid. Otherwise, the test 
data shall be considered invalid or adjustments of the test results 
shall be made, subject to the approval of the Administrator.
    4.3  Barometer. Calibrate the barometer used against a mercury 
barometer prior to the field test.

5. Calculations

    Carry out the calculations, retaining at least one extra decimal 
figure beyond that of

[[Page 607]]

the acquired data. Round off figures after the final calculation.
    5.1 Nomenclature.
Pb=Barometric pressure, mm Hg.
Pg=Average static pressure in volume meter, mm Hg.
Qs=Gas flow rate, m3/min, standard conditions.
Tm=Average absolute meter temperature,  deg.K.
Vm=Meter volume reading, m3.
Ym=Average meter calibration coefficient, dimensionless.
f=Final reading for test period.
i=Initial reading for test period.
s=Standard conditions, 20  deg.C and 760 mm Hg.
=Elapsed test period time, min.
    5.2  Volume.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.111
    
    5.3  Gas Flow Rate.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.112
    
6. Bibliography

    1.  Rom, Jerome J. Maintenance, Calibration, and Operation of 
Isokinetic Source Sampling Equipment. U.S. Environmental Protection 
Agency. Research Triangle Park, NC, Publication No. APTD-0576. March 
1972.
    2.  Wortman, Martin, R. Vollaro, and P.R. Westlin. Dry Gas Volume 
Meter Calibrations. Source Evaluation Society Newsletter. Vol. 2, No. 2. 
May 1977.
    3.  Westlin, P.R. and R.T. Shigehara. Procedure for Calibrating and 
Using Dry Gas Volume Meters as Calibration Standards. Source Evaluation 
Society Newsletter. Vol. 3, No. 1. February 1978.

 Method 2B--Determination of Exhaust Gas Volume Flow Rate From Gasoline 
                           Vapor Incinerators

1. Applicability and Principle

    1.1  Applicability. This method applies to the measurement of 
exhaust volume flow rate from incinerators that process gasoline vapors 
consisting primarily of alkanes, alkenes, and/or arenes (aromatic 
hydrocarbons). It is assumed that the amount of auxiliary fuel is 
negligible.
    1.2  Principle. The incinerator exhaust flow rate is determined by 
carbon balance. Organic carbon concentration and volume flow rate are 
measured at the incinerator inlet. Organic carbon, carbon dioxide 
(CO2), and carbon monoxide (CO) concentrations are measured 
at the outlet. Then the ratio of total carbon at the incinerator inlet 
and outlet is multiplied by the inlet volume to determine the exhaust 
volume and volume flow rate.

2. Apparatus

    2.1  Volume Meter. Equipment described in Method 2A.
    2.2  Organic Analyzers (2). Equipment described in Method 25A or 
25B.
    2.3  CO Analyzer. Equipment described in Method 10.
    2.4  CO2 Analyzer. A nondispersive infrared (NDIR) 
CO2 analyzer and supporting equipment with comparable 
specifications as CO analyzer described in Method 10.

3. Procedure

    3.1  Inlet Installation. Install a volume meter in the vapor line to 
incinerator inlet according to the procedure in Method 2A. At the volume 
meter inlet, install a sample probe as described in Method 25A. Connect 
to the probe a leak-tight, heated (if necessary to prevent condensation) 
sample line (stainless steel or equivalent) and an organic analyzer 
system as described in Method 25A or 25B.
    3.2  Exhaust Installation. Three sample analyzers are required for 
the incinerator exhaust: CO2, CO, and organic analyzers. A 
sample manifold with a single sample probe may be used. Install a sample 
probe as described in Method 25A. Connect a leak-tight heated sample 
line to the sample probe. Heat the sample line sufficiently to prevent 
any condensation.
    3.3  Recording Requirements. The output of each analyzer must be 
permanently recorded on an analog strip chart, digital recorder, or 
other recording device. The chart speed or number of readings per time 
unit must be similar for all analyzers so that data can be correlated. 
The minimum data recording requirement for each analyzer is one 
measurement value per minute.
    3.4  Preparation. Prepare and calibrate all equipment and analyzers 
according to the procedures in the respective methods. For the 
CO2 analyzer, follow the procedures described in Method 10 
for CO analysis substituting CO2 calibration gas where the 
method calls for CO calibration gas. The span value for the 
CO2 analyzer shall be 15 percent by volume. All calibration 
gases must be introduced at the connection between the probe and the 
sample line. If a

[[Page 608]]

manifold system is used for the exhaust analyzers, all the analyzers and 
sample pumps must be operating when the calibrations are done. Note: For 
the purposes of this test, methane should not be used as an organic 
calibration gas.
    3.5  Sampling. At the beginning of the test period, record the 
initial parameters for the inlet volume meter according to the 
procedures in Method 2A and mark all of the recorder strip charts to 
indicate the start of the test. Continue recording inlet organic and 
exhaust CO2, CO, and organic concentrations throughout the 
test. During periods of process interruption and halting of gas flow, 
stop the timer and mark the recorder strip charts so that data from this 
interruption are not included in the calculations. At the end of the 
test period, record the final parameters for the inlet volume meter and 
mark the end on all of the recorder strip charts.
    3.6  Post Test Calibrations. At the conclusion of the sampling 
period, introduce the calibration gases as specified in the respective 
reference methods. If an analyzer output does not meet the 
specifications of the method, invalidate the test data for the period. 
Alternatively, calculate the volume results using initial calibration 
data and using final calibration data and report both resulting volumes. 
Then, for emissions calculations, use the volume measurement resulting 
in the greatest emission rate or concentration.

4. Calculations

    Carry out the calculations, retaining at least one extra decimal 
figure beyond that of the acquired data. Round off figures after the 
final calculation.
    4.1 Nomenclature.
COe=Mean carbon monoxide concentration in system exhaust, 
          ppm.
CO2e=Mean carbon dioxide concentration in system exhaust, 
          ppm.
HCe=Mean organic concentration in system exhaust as defined 
          by the calibration gas, ppm.
HCi=Mean organic concentration in system inlet as defined by 
          the calibration gas, ppm.
K=Calibration gas factor
    =2 for ethane calibration gas.
    =3 for propane calibration gas.
    =4 for butane calibration gas.
    =Appropriate response factor for other calibration gas.
Ves=Exhaust gas volume, m3.
Vis=Inlet gas volume, m3.
Qes=Exhaust gas volume flow rate, m3/min.
Qis=Inlet gas volume flow rate, m3/min.
=Sample run time, min.
s=Standard conditions: 20  deg.C, 760 mm Hg.
300=Estimated concentration of ambient CO2, ppm. 
          (CO2 concentration in the ambient air may be 
          measured during the test period using an NDIR).
    4.2  Concentrations. Determine mean concentrations of inlet 
organics, outlet CO2, outlet CO, and outlet organics 
according to the procedures in the respective methods and the analyzers' 
calibration curves, and for the time intervals specified in the 
applicable regulations. Concentrations should be determined on a parts 
per million by volume (ppm) basis.
    4.3  Exhaust Gas Volume. Calculate the exhaust gas volume as 
follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.113

    4.4  Exhaust Gas Volume Flow Rate. Calculate the exhaust gas volume 
flow rate as follows:
Qes=Ves/

                                                                Eq. 2B-2

5. Bibliography

    1.  Measurement of Volatile Organic Compounds. U.S. Environmental 
Protection Agency. Office of Air Quality Planning and Standards, 
Research Triangle Park, NC 27711. Publication No. EPA-450/2-78-041. 
October 1978. 55 p.

Method 2C--Determination of Stack Gas Velocity and Volumetric Flow Rate 
             in Small Stacks or Ducts (Standard Pitot Tube)

1. Applicability and Principle
    1.1  Applicability.
    1.1.1  The applicability of this method is identical to Method 2, 
except this method is limited to stationery source stacks or ducts less 
than about 0.30 meter (12 in.) in diameter or 0.071 m2 (113 
in.2) in cross-sectional area, but equal to or greater than 
about 0.10 meter (4 in.) in diameter or 0.0081 m2 (12.57 
in.2) in cross-sectional area.
    1.1.2  The apparatus, procedure, calibration, calculations, and 
biliography are the

[[Page 609]]

same as in Method 2, Sections 2, 3, 4, 5, and 6, except as noted in the 
following sections.
    1.2  Principle. The average gas velocity in a stack or duct is 
determined from the gas density and from measurement of velocity heads 
with a standard pitot tube.

                              2. Apparatus

    2.1  Standard Pitot Tube (instead of Type S). Use a standard pitot 
tube that meets the specifications of Section 2.7 of Method 2. Use a 
coefficient value of 0.99 unless it is calibrated against another 
standard pitot tube with an NBS-traceable coefficient.
    2.2  Alternative Pitot Tube. A modified hemispherical-nosed pitot 
tube (see Figure 2C-1), which features a shortened stem and enlarged 
impact and static pressure holes, may be used. This pitot tube is useful 
in liquid drop-laden gas streams when a pitot ``back purge'' is 
ineffective. Use a coefficient value of 0.99 unless the pitot is 
calibrated as mentioned in Section 2.1 above.

[[Page 610]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.095

                              3. Procedure

    Follow the general procedures in Section 3 of Method 2, except 
conduct the measurements at the traverse points specified in Method 1A. 
The static and impact pressure holes of standard pitot tubes are 
susceptible to plugging in PM-laden gas streams. Therefore, the tester 
must furnish adequate proof

[[Page 611]]

that the openings of the pitot tube have not plugged during the traverse 
period; this proof can be obained by first recording the velocity head 
(p) reading at the final traverse point, then cleaning out the 
impact and static holes of the standard pitot tube by ``back-purging'' 
with pressurized air, and finally by recording another p 
reading at the final traverse point. If the p reading made 
after the air purge is within 5 percent of the reading during the 
traverse, then the traverse is acceptable. Otherwise, reject the run. 
Note that if the p at the final traverse point is so low as to 
make this determination too difficult, then another traverse point may 
be selected. If ``back purging'' at regular intervals is part of the 
procedure, then take comparative p readings, as above, for the 
last two back purges at which suitable high p readings are 
observed.

 Method 2D--Measurement of Gas Volumetric Flow Rates in Small Pipes and 
                                  Ducts

                     1. Applicability and Principle

    1.1  Applicability. This method applies to the measurement of gas 
flow rates in small pipes and ducts, either before or after emission 
control devices.
    1.2  Principle. To measure flow rate or pressure drop, all the stack 
gas is directed through a rotameter, orifice plate or similar flow rate 
measuring device. The measuring device has been previously calibrated in 
a manner that insures its proper calibration for the gas or gas mixture 
being measured. Absolute temperature and pressure measurements are also 
made to calculate volumetric flow rates at standard conditions.

                              2. Apparatus

    Specifications for the apparatus are given below. Any other 
apparatus that has been demonstrated (subject to approval of the 
Administrator) to be capable of meeting the specifications will be 
considered acceptable.
    2.1  Flow Rate Measuring Device. A rotameter, orifice plate, or 
other flow rate measuring device capable of measuring all the stack flow 
rate to within 5 percent of its true value. The measuring device shall 
be equipped with a temperature gauge accurate to within 2 percent of the 
minimum absolute stack temperature and a pressure gauge accurate to 
within 5 mm Hg. The capacity of the measuring device shall be sufficient 
for the expected maximum and minimum flow rates at the stack gas 
conditions. The magnitude and variability of stack gas flow rate, 
molecular weight, temperature, pressure, compressibility, dew point, 
corrosiveness, and pipe or duct size are all factors to consider in 
choosing a suitable measuring device.
    2.2  Barometer. Same as in Method 2, Section 2.5.
    2.3  Stopwatch. Capable of incremental time measurement to within 1 
second.

                              3. Procedure

    3.1  Installation. Use the procedure in Method 2A, Section 3.1.
    3.2  Leak Check. Use the procedure in Method 2A, Section 3.2.
    3.3  Flow Rate Measurement.
    3.3.1  Continuous, Steady Flow. At least once an hour, record the 
measuring device flow rate reading, and the measuring device temperature 
and pressure. Make a minimum of twelve equally spaced readings of each 
parameter during the test period. Record the barometric pressure at the 
beginning and end of the test period. Record the data on a table similar 
to Figure 2D-1.
_______________________________________________________________________
_______________________________________________________________________
Plant______________________________
Date______________ Run number________
Sample location______________________
Barometric pressure, mm (in.) Hg    Start______ Finish______
Operators ____________________
Measuring device number______  Calibration coefficient______
Calibration gas__________  
Last date calibrated________

----------------------------------------------------------------------------------------------------------------
                                                                                        Temperature
              Time                 Flow rate reading  Static pressure mm ---------------------------------------
                                                           (in.) Hg          deg.C (  deg.F)     deg.K ( deg.R)
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
                                  Average...........
                                                     --------------------                    -------------------
 
----------------------------------------------------------------------------------------------------------------

    Figure 2D-1. Flow rate measurement data.

    3.3.2  Noncontinuous and Nonsteady Flows. Use flow rate measuring 
devices with particular caution. Calibration will be affected by 
variation in stack gas temperature, pressure, compressibility, and 
molecular weight. Use the procedure in Section 3.3.1. Record all the 
measuring device parameters on a time interval frequency sufficient to 
adequately profile each process cyclical or noncontinuous event. A 
multichannel continuous recorder may be used.

[[Page 612]]

                             4. Calibration

    4.1  Flow Rate Measuring Device. Use the procedure in Method 2A, 
Section 4, and apply the same performance standards. Calibrate the 
measuring device with the principal stack gas to be measured (e.g., air, 
nitrogen) against a standard reference meter. A calibrated dry gas meter 
is an acceptable reference meter. Ideally, calibrate the measuring 
device in the field with the actual gas to be measured. For measuring 
devices that have a volume rate readout, calculate the measuring device 
calibration coefficient, Ym, for each run as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.114

where:
    Qr=reference meter flow rate reading, m3/min 
(ft3/min).
    Qm=measuring device flow rate reading, m3/min 
(ft3/min).
    Tr=reference meter average absolute temperature,  deg. K 
( deg. R).
    Tm=measuring device average absolute temperature,  deg. K 
( deg. R).
    Pbar=barometric pressure, mm Hg (in. Hg).
    Pg=measuring device average static pressure, mm Hg (in. 
Hg).

    For measuring devices that do not have a readout as flow rate, refer 
to the manufacturer's instructions to calculate the Qm 
corresponding to each Qr.
    4.2  Temperature Gauge. Use the procedure and specifications in 
Method 2A, Section 4.2. Perform the calibration at a temperature that 
approximates field test conditions.
    4.3  Barometer. Calibrate the barometer to be used in the field test 
with a mercury barometer prior to the field test.

                      5. Gas Flow Rate Calculation

    Calculate the stack gas flow rate, Qs, as follows:
    [GRAPHIC] [TIFF OMITTED] TC16NO91.115
    
where:
    Kl = 0.3858 for international system of units (SI); 17.64 
for English units.

                             6. Bibliography

    1. Spink, L.K. Principles and Practice of Flowmeter Engineering. The 
Foxboro Company. Foxboro, MA. 1967.
    2. Benedict, Robert P. Fundamentals of Temperature, Pressure, and 
Flow Measurements. John Wiley and Sons, Inc. New York, NY. 1969.
    3. Orifice Metering of Natural Gas. American Gas Association. 
Arlington, VA. Report No. 3. March 1978. 88 p.

   Method 2E--Determination of Landfill Gas; Gas Production Flow Rate

                     1. Applicability and Principle

    1.1  Applicability. This method applies to the measurement of 
landfill gas (LFG) production flow rate from municipal solid waste (MSW) 
landfills and is used to calculate the flow rate of nonmethane organic 
compounds (NMOC) from landfills. This method also applies to calculating 
a site-specific k value as provided in Sec. 60.754(a)(4). It is unlikely 
that a site-specific k value obtained through Method 2E testing will 
lower the annual emission estimate below 50 Mg/yr NMOC unless the Tier 2 
emission estimate is only slightly higher than 50 Mg/yr NMOC. Dry, arid 
regions may show a more significant difference between the default and 
calculated k values than wet regions.
    1.2  Principle. Extraction wells are installed either in a cluster 
of three or at five locations dispersed throughout the landfill. A 
blower is used to extract LFG from the landfill. LFG composition, 
landfill pressures near the extraction well, and volumetric flow rate of 
LFG extracted from the wells are measured and the landfill gas 
production flow rate is calculated.

                              2. Apparatus

    2.1  Well Drilling Rig. Capable of boring a 0.6 meters diameter hole 
into the landfill to a minimum of 75 percent of the landfill depth. The 
depth of the well shall not exceed the bottom of the landfill or the 
liquid level.
    2.2  Gravel. No fines. Gravel diameter should be appreciably larger 
than perforations stated in sections 2.10 and 3.2 of this method.
    2.3  Bentonite.
    2.4  Backfill Material. Clay, soil, and sandy loam have been found 
to be acceptable.
    2.5  Extraction Well Pipe. Polyvinyl chloride (PVC), high density 
polyethylene (HDPE), fiberglass, stainless steel, or other suitable 
nonporous material capable of transporting landfill gas with a minimum 
diameter of 0.075 meters and suitable wall-thickness.
    2.6  Wellhead Assembly. Valve capable of adjusting gas flow at the 
wellhead and outlet, and a flow measuring device, such as an in-line 
orifice meter or pitot tube. A schematic of the wellhead assembly is 
shown in figure 1.

[[Page 613]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.306

    2.7  Cap. PVC, HDPE, fiberglass, stainless steel, or other suitable 
nonporous material capable of transporting landfill gas with a suitable 
wall-thickness.
    2.8  Header Piping. PVC, HDPE, fiberglass, stainless steel, or other 
suitable nonporous material capable of transporting landfill gas with a 
suitable wall-thickness.
    2.9  Auger. Capable of boring a 0.15 to 0.23 meters diameter hole to 
a depth equal to the top of the perforated section of the extraction 
well, for pressure probe installation.
    2.10  Pressure Probe. PVC or stainless steel (316), 0.025 meters. 
Schedule 40 pipe. Perforate the bottom two thirds. A minimum requirement 
for perforations is slots or holes with an open area equivalent to four 
6.0 millimeter diameter holes spaced 90 deg. apart every 0.15 meters.
    2.11  Blower and Flare Assembly. A water knockout, flare or 
incinerator, and an explosion-proof blower, capable of extracting LFG at 
a flow rate of at least 8.5 cubic meters per minute.
    2.12  Standard Pitot Tube and Differential Pressure Gauge for Flow 
Rate Calibration with Standard Pitot. Same as Method 2, sections 2.1 and 
2.8.
    2.13  Gas flow measuring device. Permanently mounted Type S pitot 
tube or an orifice meter.
    2.14  Barometer. Same as Method 4, section 2.1.5.
    2.15  Differential Pressure Gauge. Water-filled U-tube manometer or 
equivalent, capable of measuring within 0.02 mm Hg, for measuring the 
pressure of the pressure probes.

                              3. Procedure

    3.1  Placement of Extraction Wells. The landfill owner or operator 
shall either install a single cluster of three extraction wells in a 
test area or space five wells over the landfill. The cluster wells are 
recommended but may be used only if the composition, age of the solid 
waste, and the landfill depth of the test area can be determined. 
CAUTION: Since this method is complex, only experienced personnel should 
conduct the test. Landfill gas contains methane, therefore explosive 
mixtures may exist at or near the landfill. It is advisable to take 
appropriate safety precautions when testing landfills, such as 
installing explosion-proof equipment and refraining from smoking.
    3.1.1  Cluster Wells. Consult landfill site records for the age of 
the solid waste, depth, and composition of various sections of the 
landfill. Select an area near the perimeter of the landfill with a depth 
equal to or greater than the average depth of the landfill and with the 
average age of the solid waste between 2 and 10 years old. Avoid areas 
known to contain nondecomposable materials, such as concrete and 
asbestos. Locate wells as shown in figure 2.

[[Page 614]]

    Because the age of the solid waste in a test area will not be 
uniform, calculate a weighted average to determine the average age of 
the solid waste as follows.
[GRAPHIC] [TIFF OMITTED] TR12MR96.027

where,

Aavg=average age of the solid waste tested, year
fi=fraction of the solid waste in the ith section
Ai=age of the ith fraction, year
[GRAPHIC] [TIFF OMITTED] TR12MR96.019

    3.1.2  Equal Volume Wells. This procedure is used when the 
composition, age of solid waste, and landfill depth are not well known. 
Divide the portion of the landfill that has had waste for at least 2 
years into five areas representing equal volumes. Locate an extraction 
well near the center of each area. Avoid areas known to contain 
nondecomposable materials, such as concrete and asbestos.
    3.2  Installation of Extraction Wells. Use a well drilling rig to 
dig a 0.6 meters diameter hole in the landfill to a minimum of 75 
percent of the landfill depth, not to exceed the bottom of the landfill 
or the water table. Perforate the bottom two thirds of the extraction 
well pipe. Perforations shall not be closer than 6 meters from the 
cover. Perforations shall be holes or slots with an open area equivalent 
to 1.0 centimeter diameter holes spaced 90 degrees apart every 0.1 to 
0.2 meters. Place the extraction well in the center of the hole and 
backfill with 2.0 to 7.5 centimeters gravel to a level 0.3 meters above 
the perforated section. Add a layer of backfill material 1.2 meters 
thick. Add a layer of bentonite 1.0 meter thick, and backfill the 
remainder of the hole with cover material or material equal in 
permeability to the existing cover material. The specifications for 
extraction well installation are shown in figure 3.

[[Page 615]]

[GRAPHIC] [TIFF OMITTED] TR12MR96.020

    3.3  Pressure Probes. Shallow pressure probes are used in the check 
for infiltration of air into the landfill, and deep pressure probes are 
used to determine the radius of influence. Locate the deep pressure 
probes along three radial arms approximately 120 degrees apart at 
distances of 3, 15, 30, and 45 meters from the extraction well. The 
tester

[[Page 616]]

has the option of locating additional pressure probes at distances every 
15 meters beyond 45 meters. Example placements of probes are shown in 
figure 4.
    The probes located 15, 30, and 45 meters from each well, and any 
additional probes located along the three radial arms (deep probes), 
shall extend to a depth equal to the top of the perforated section of 
the extraction wells. Locate three shallow probes at a distance of 3 m 
from the extraction well. Shallow probes shall extend to a depth equal 
to half the depth of the deep probes.

[[Page 617]]

[GRAPHIC] [TIFF OMITTED] TR12MR96.021

    Use an auger to dig a hole, approximately 0.15 to 0.23 meters in 
diameter, for each pressure probe. Perforate the bottom two thirds of 
the pressure probe. Perforations shall be holes or slots with an open 
area equivalent to four 6.0 millimeter diameter holes spaced 90 degrees 
apart every 0.15 meters. Place the pressure probe in the center of the 
hole and

[[Page 618]]

backfill with gravel to a level 0.30 meters above the perforated 
section. Add a layer of backfill material at least 1.2 meters thick. Add 
a layer of bentonite at least 0.3 meters thick, and backfill the 
remainder of the hole with cover material or material equal in 
permeability to the existing cover material. The specifications for 
pressure probe installation are shown in figure 5.

[[Page 619]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.307

    3.4  LFG Flow Rate Measurement. Determine the flow rate of LFG from 
the test wells continuously during testing with an orifice meter. 
Alternative methods to measure the LFG flow rate may be used with 
approval of the Administrator. Locate the orifice meter as shown in 
figure 1. Attach the wells to the blower and flare assembly. The

[[Page 620]]

individual wells may be ducted to a common header so that a single 
blower and flare assembly and flow meter may be used. Use the procedures 
in section 4.1 to calibrate the flow meter.
    3.5  Leak Check. A leak check of the above ground system is required 
for accurate flow rate measurements and for safety. Sample LFG at the 
wellhead sample port and at a point downstream of the flow measuring 
device. Use Method 3C to determine nitrogen (N2) 
concentrations. Determine the difference by using the formula below.

Difference=Co-Cw

where,

Co=concentration of N2 at the outlet, ppmv
Cw=concentration of N2 at the wellhead, ppmv
    The system passes the leak check if the difference is less than 
10,000 ppmv. If the system fails the leak check, make the appropriate 
adjustments to the above ground system and repeat the leak check.
    3.6  Static Testing. The purpose of the static testing is to 
determine the initial conditions of the landfill. Close the control 
valves on the wells so that there is no flow of landfill gas from the 
well. Measure the gauge pressure (Pg) at each deep pressure 
probe and the barometric pressure (Pbar) every 8 hours for 3 
days. Convert the gauge pressure of each deep pressure probe to absolute 
pressure by using the following equation. Record as Pi.

Pi=Pbar+Pg

where,

Pbar=Atmospheric pressure, mm Hg
Pg=Gauge pressure of the deep probes, mm Hg
Pi=Initial absolute pressure of the deep probes during static 
          testing, mm Hg
    3.6.1  For each probe, average all of the 8 hr deep pressure probe 
readings and record as Pia. The Pia is used in 
section 3.7.6 to determine the maximum radius of influence.
    3.6.2  Measure the LFG temperature and the static flow rate of each 
well once during static testing using a flow measurement device, such as 
a Type S pitot tube and measure the temperature of the landfill gas. The 
flow measurements should be made either just before or just after the 
measurements of the probe pressures and are used in determining the 
initial flow from the extraction well during the short term testing. The 
temperature measurement is used in the check for infiltration.
    3.7  Short Term Testing. The purpose of short term testing is to 
determine the maximum vacuum that can be applied to the wells without 
infiltration of air into the landfill. The short term testing is done on 
one well at a time. During the short term testing, burn LFG with a flare 
or incinerator.
    3.7.1  Use the blower to extract LFG from a single well at a rate at 
least twice the static flow rate of the respective well measured in 
section 3.6.2. If using a single blower and flare assembly and a common 
header system, close the control valve on the wells not being measured. 
Allow 24 hours for the system to stabilize at this flow rate.
    3.7.2  Check for infiltration of air into the landfill by measuring 
the temperature of the LFG at the wellhead, the gauge pressures of the 
shallow pressure probes, and the LFG N2 concentration by 
using Method 3C. CAUTION: Increased vacuum at the wellhead may cause 
infiltration of air into the landfill, which increases the possibility 
of a landfill fire. Infiltration of air into the landfill may occur if 
any of the following conditions are met: the LFG N2 
concentration is more than 20 percent, any of the shallow probes have a 
negative gauge pressure, or the temperature has increased above 55 
deg.C or the maximum established temperature during static testing. If 
infiltration has not occurred, increase the blower vacuum by 4 mm Hg, 
wait 24 hours, and repeat the infiltration check. If at any time, the 
temperature change exceeds the limit, stop the test until it is safe to 
proceed. Continue the above steps of increasing blower vacuum by 4 mm 
Hg, waiting 24 hours, and checking for infiltration until the 
concentration of N2 exceeds 20 percent or any of the shallow 
probes have a negative gauge pressure, at which time reduce the vacuum 
at the wellhead so that the N2 concentration is less than 20 
percent and the gauge pressures of the shallow probes are positive. This 
is the maximum vacuum at which infiltration does not occur.
    3.7.3  At this maximum vacuum, measure Pbar every 8 hours 
for 24 hours and record the LFG flow rate as Qs and the probe 
gauge pressures for all of the probes as Pf. Convert the 
gauge pressures of the deep probes to absolute pressures for each 8-hour 
reading at Qs as follows:
P=Pbar+Pf

where,

Pbar=Atmospheric pressure, mm Hg
Pf=Final absolute pressure of the deep probes during short 
          term testing, mm Hg
P=Pressure of the deep probes, mm Hg
    3.7.4  For each probe, average the 8-hr deep pressure probe readings 
and record as Pfa.
    3.7.5  For each probe, compare the initial average pressure 
(Pia) from section 3.6.1 to the final average pressure 
(Pfa). Determine the furthermost point from the wellhead 
along each radial arm where Pfa  Pia. 
This distance is the maximum radius of influence (ROI), which is the 
distance from the well affected by the vacuum. Average these values to 
determine the average maximum radius of influence (Rma).
    The average Rma may also be determined by plotting on 
semi-log paper the pressure

[[Page 621]]

differentials (Pfa-Pia) on the y-axis (abscissa) 
versus the distances (3, 15, 30 and 45 meters) from the wellhead on the 
x-axis (ordinate). Use a linear regression analysis to determine the 
distance when the pressure differential is zero. Additional pressure 
probes may be used to obtain more points on the semi-long plot of 
pressure differentials versus distances.
    3.7.6  Calculate the depth (Dst) affected by the 
extraction well during the short term test as follows. If the computed 
value of Dst exceeds the depth of the landfill, set 
Dst equal to the landfill depth.

Dst=WD + Rma2

where,

Dst=depth, m
WD=well depth, m
Rma=maximum radius of influence, m
    3.7.7  Calculate the void volume for the extraction well (V) as 
follows.

V=0.40 Rma2 Dst

where,

V=void volume of test well, m3
Rma=maximum radius of influence, m
Dst=depth, m
    3.7.8  Repeat the procedures in section 3.7 for each well.
    3.8  Calculate the total void volume of the test wells 
(Vv) by summing the void volumes (V) of each well.
    3.9  Long Term Testing. The purpose of long term testing is to 
determine the methane generation rate constant, k. Use the blower to 
extract LFG from the wells. If a single blower and flare assembly and 
common header system are used, open all control valves and set the 
blower vacuum equal to the highest stabilized blower vacuum demonstrated 
by any individual well in section 3.7. Every 8 hours, sample the LFG 
from the wellhead sample port, measure the gauge pressures of the 
shallow pressure probes, the blower vacuum, the LFG flow rate, and use 
the criteria for infiltration in section 3.7.2 and Method 3C to check 
for infiltration. If infiltration is detected, do not reduce the blower 
vacuum, but reduce the LFG flow rate from the well by adjusting the 
control valve on the wellhead. Adjust each affected well individually. 
Continue until the equivalent of two total void volumes (Vv) 
have been extracted, or until Vt=2 Vv.
    3.9.1  Calculate Vt, the total volume of LFG extracted 
from the wells, as follows.
[GRAPHIC] [TIFF OMITTED] TR12MR96.028

where,

Vt=total volume of LFG extracted from wells, m3
Qi=LFG flow rate measured at orifice meter at the 
          ith interval, cubic meters per minute
tvi=time of the ith interval, hour (usually 8)
    3.9.2  Record the final stabilized flow rate as Qf. If, 
during the long term testing, the flow rate does not stabilize, 
calculate Qf by averaging the last 10 recorded flow rates.
    3.9.3  For each deep probe, convert each gauge pressure to absolute 
pressure as in section 3.7.4. Average these values and record as 
Psa. For each probe, compare Pia to 
Psa. Determine the furthermost point from the wellhead along 
each radial arm where Psa  Pia. This 
distance is the stabilized radius of influence. Average these values to 
determine the average stabilized radius of influence (Rsa).
    3.10  Determine the NMOC mass emission rate using the procedures in 
section 5.
    3.11  Deactivation of pressure probe holes. Upon completion of 
measurements, if pressure probes are removed, restore the integrity of 
the landfill cover by backfilling and sealing to prevent venting of LFG 
to the atmosphere or air infiltration.

                             4. Calibrations

    Gas Flow Measuring Device Calibration Procedure. Locate a standard 
pitot tube in line with a gas flow measuring device. Use the procedures 
in Method 2D, section 4, to calibrate the orifice meter. Method 3C may 
be used to determine the dry molecular weight. It may be necessary to 
calibrate more than one gas flow measuring device to bracket the 
landfill gas flow rates. Construct a calibration curve by plotting the 
pressure drops across the gas flow measuring device for each flow rate 
versus the average dry gas volumetric flow rate in cubic meters per 
minute of the gas. Use this calibration curve to determine the 
volumetric flow from the wells during testing.

                             5. Calculations

    5.1  Nomenclature.

Aavg=average age of the solid waste tested, year
Ai=age of solid waste in the ith fraction, year
A=age of landfill, year
Ar=acceptance rate, megagrams per year
CNMOC=NMOC concentration, ppmv as hexane 
          (CNMOC=Ct/6)
Ct=NMOC concentration, ppmv (carbon equivalent) from Method 
          25C
D = depth affected by the test wells, m
Dst=depth affected by the test wells in the short term test, 
          m
DLF=landfill depth, m
f = fraction of decomposable solid waste in the landfill
fi=fraction of the solid waste in the ith section
k=methane generation rate constant, year-1
Lo=methane generation potential, cubic meters per megagram
Lo=revised methane generation potential to account for the 
          amount of

[[Page 622]]

          nondecomposable material in the landfill, cubic meters per 
          megagram
Mi=mass of solid waste of the ith section, 
          megagrams
Mr=mass of decomposable solid waste affected by the test 
          well, megagrams
Mw=number of wells
Pbar=atmospheric pressure, mm Hg
Pg=gauge pressure of the deep pressure probes, mm Hg
Pi=initial absolute pressure of the deep pressure probes 
          during static testing, mm Hg
Pia=average initial absolute pressure of the deep pressure 
          probes during static testing, mm Hg
Pf=final absolute pressure of the deep pressure probes during 
          short term testing, mm Hg
Pfa=average final absolute pressure of the deep pressure 
          probes during short term testing, mm Hg
Ps=final absolute pressure of the deep pressure probes during 
          long term testing, mm Hg
Psa=average final absolute pressure of the deep pressure 
          probes during long term testing, mm Hg
QB=required blow flow rate, cubic meters per minute
Qf=final stabilized flow rate, cubic meters per minute
Qi=LFG flow rate measured at orifice meter during the 
          ith interval, cubic meters per minute
Qs=maximum LFG flow rate at each well determined by short 
          term test, cubic meters per minute
Qt=NMOC mass emission rate, cubic meters per minute
Rm=maximum radius of influence, m
Rma=average maximum radius of influence, m
Rs=stabilized radius of influence for an individual well, m
Rsa=average stabilized radius of influence, m
ti=age of section i, year
tt=total time of long term testing, year
V=void volume of test well, m3
Vr=volume of solid waste affected by the test well, 
          m3
Vt=total volume of solid waste affected by the long term 
          testing, m3
Vv=total void volume affected by test wells, m3
WD=well depth, m
=solid waste density, m3 (Assume 0.64 megagrams per 
          cubic meter if data are unavailable)
    5.2  Use the following equation to calculate the depth affected by 
the test well. If using cluster wells, use the average depth of the 
wells for WD. If the value of D is greater than the depth of the 
landfill, set D equal to the landfill depth.

D=WD+Rsa
    5.3  Use the following equation to calculate the volume of solid 
waste affected by the test well.

Vr=Rsa2  D
    5.4  Use the following equation to calculate the mass affected by 
the test well.

Mr=Vr
    5.5  Modify Lo to account for the nondecomposable solid 
waste in the landfill.

Lo'=f Lo
    5.6  In the following equation, solve for k by iteration. A 
suggested procedure is to select a value for k, calculate the left side 
of the equation, and if not equal to zero, select another value for k. 
Continue this process until the left hand side of the equation equals 
zero, 0.001.
[GRAPHIC] [TIFF OMITTED] TR12MR96.029

    5.7  Use the following equation to determine landfill NMOC mass 
emission rate if the yearly acceptance rate of solid waste has been 
consistent (10 percent) over the life of the landfill.

Qt = 2 Lo' Ar (1 - e-k A) 
          CNMOC / (5.256  x  1011)
    5.8  Use the following equation to determine landfill NMOC mass 
emission rate if the acceptance rate has not been consistent over the 
life of the landfill.
[GRAPHIC] [TIFF OMITTED] TR12MR96.030

                             6. Bibliography

    1. Same as Method 2, appendix A, 40 CFR part 60.
    2. Emcon Associates, Methane Generation and Recovery from Landfills. 
Ann Arbor Science, 1982.
    3. The Johns Hopkins University, Brown Station Road Testing and Gas 
Recovery Projections. Laurel, Maryland: October 1982.
    4. Mandeville and Associates, Procedure Manual for Landfill Gases 
Emission Testing.
    5. Letter and attachments from Briggum, S., Waste Management of 
North America, to Thorneloe, S., EPA. Response to July 28, 1988 request 
for additional information. August 18,1988.
    6. Letter and attachments from Briggum, S., Waste Management of 
North America, to Wyatt, S., EPA. Response to December 7, 1988 request 
for additional information. January 16, 1989.

[[Page 623]]

Method 2F--Determination of Stack Gas Velocity And Volumetric Flow Rate 
                      With Three-Dimensional Probes

    Note: This method does not include all of the specifications (e.g., 
equipment and supplies) and procedures (e.g., sampling) essential to its 
performance. Some material has been incorporated from other methods in 
this part. Therefore, to obtain reliable results, those using this 
method should have a thorough knowledge of at least the following 
additional test methods: Methods 1, 2, 3 or 3A, and 4.

                       1.0  Scope and Application

1.1  This method is applicable for the determination of yaw angle, pitch 
angle, axial velocity and the volumetric flow rate of a gas stream in a 
stack or duct using a three-dimensional (3-D) probe. This method may be 
used only when the average stack or duct gas velocity is greater than or 
equal to 20 ft/sec. When the above condition cannot be met, alternative 
procedures, approved by the Administrator, U.S. Environmental Protection 
Agency, shall be used to make accurate flow rate determinations.

                         2.0  Summary of Method

    2.1  A 3-D probe is used to determine the velocity pressure and the 
yaw and pitch angles of the flow velocity vector in a stack or duct. The 
method determines the yaw angle directly by rotating the probe to null 
the pressure across a pair of symmetrically placed ports on the probe 
head. The pitch angle is calculated using probe-specific calibration 
curves. From these values and a determination of the stack gas density, 
the average axial velocity of the stack gas is calculated. The average 
gas volumetric flow rate in the stack or duct is then determined from 
the average axial velocity.

                            3.0  Definitions

    3.1.  Angle-measuring Device Rotational Offset (RADO). 
The rotational position of an angle-measuring device relative to the 
reference scribe line, as determined during the pre-test rotational 
position check described in section 8.3.
    3.2  Axial Velocity. The velocity vector parallel to the axis of the 
stack or duct that accounts for the yaw and pitch angle components of 
gas flow. The term ``axial'' is used herein to indicate that the 
velocity and volumetric flow rate results account for the measured yaw 
and pitch components of flow at each measurement point.
    3.3  Calibration Pitot Tube. The standard (Prandtl type) pitot tube 
used as a reference when calibrating a 3-D probe under this method.
    3.4  Field Test. A set of measurements conducted at a specific unit 
or exhaust stack/duct to satisfy the applicable regulation (e.g., a 
three-run boiler performance test, a single-or multiple-load nine-run 
relative accuracy test).
    3.5  Full Scale of Pressure-measuring Device. Full scale refers to 
the upper limit of the measurement range displayed by the device. For 
bi-directional pressure gauges, full scale includes the entire pressure 
range from the lowest negative value to the highest positive value on 
the pressure scale.
    3.6  Main probe. Refers to the probe head and that section of probe 
sheath directly attached to the probe head. The main probe sheath is 
distinguished from probe extensions, which are sections of sheath added 
onto the main probe to extend its reach.
    3.7  ``May,'' ``Must,'' ``Shall,'' ``Should,'' and the imperative 
form of verbs.
    3.7.1  ``May'' is used to indicate that a provision of this method 
is optional.
    3.7.2  ``Must,'' ``Shall,'' and the imperative form of verbs (such 
as ``record'' or ``enter'') are used to indicate that a provision of 
this method is mandatory.
    3.7.3  ``Should'' is used to indicate that a provision of this 
method is not mandatory, but is highly recommended as good practice.
    3.8  Method 1. Refers to 40 CFR part 60, appendix A, ``Method 1--
Sample and velocity traverses for stationary sources.''
    3.9  Method 2. Refers to 40 CFR part 60, appendix A, ``Method 2--
Determination of stack gas velocity and volumetric flow rate (Type S 
pitot tube).''
    3.10  Method 2G. Refers to 40 CFR part 60, appendix A, ``Method 2G--
Determination of stack gas velocity and volumetric flow rate with two-
dimensional probes.''
    3.11  Nominal Velocity. Refers to a wind tunnel velocity setting 
that approximates the actual wind tunnel velocity to within 
1.5 m/sec (5 ft/sec).
    3.12  Pitch Angle. The angle between the axis of the stack or duct 
and the pitch component of flow, i.e., the component of the total 
velocity vector in a plane defined by the traverse line and the axis of 
the stack or duct. (Figure 2F-1 illustrates the ``pitch plane.'') From 
the standpoint of a tester facing a test port in a vertical stack, the 
pitch component of flow is the vector of flow moving from the center of 
the stack toward or away from that test port. The pitch angle is the 
angle described by this pitch component of flow and the vertical axis of 
the stack.
    3.13  Readability. For the purposes of this method, readability for 
an analog measurement device is one half of the smallest scale division. 
For a digital measurement device, it is the number of decimals displayed 
by the device.
    3.14  Reference Scribe Line. A line permanently inscribed on the 
main probe sheath (in accordance with section 6.1.6.1) to serve

[[Page 624]]

as a reference mark for determining yaw angles.
    3.15  Reference Scribe Line Rotational Offset (RSLO). The 
rotational position of a probe's reference scribe line relative to the 
probe's yaw-null position, as determined during the yaw angle 
calibration described in section 10.5.
    3.16  Response Time. The time required for the measurement system to 
fully respond to a change from zero differential pressure and ambient 
temperature to the stable stack or duct pressure and temperature 
readings at a traverse point.
    3.17  Tested Probe. A 3-D probe that is being calibrated.
    3.18  Three-dimensional (3-D) Probe. A directional probe used to 
determine the velocity pressure and yaw and pitch angles in a flowing 
gas stream.
    3.19  Traverse Line. A diameter or axis extending across a stack or 
duct on which measurements of differential pressure and flow angles are 
made.
    3.20  Wind Tunnel Calibration Location. A point, line, area, or 
volume within the wind tunnel test section at, along, or within which 
probes are calibrated. At a particular wind tunnel velocity setting, the 
average velocity pressures at specified points at, along, or within the 
calibration location shall vary by no more than 2 percent or 0.3 mm 
H2O (0.01 in. H2O), whichever is less restrictive, 
from the average velocity pressure at the calibration pitot tube 
location. Air flow at this location shall be axial, i.e., yaw and pitch 
angles within 3 deg.. Compliance with these flow criteria 
shall be demonstrated by performing the procedures prescribed in 
sections 10.1.1 and 10.1.2. For circular tunnels, no part of the 
calibration location may be closer to the tunnel wall than 10.2 cm (4 
in.) or 25 percent of the tunnel diameter, whichever is farther from the 
wall. For elliptical or rectangular tunnels, no part of the calibration 
location may be closer to the tunnel wall than 10.2 cm (4 in.) or 25 
percent of the applicable cross-sectional axis, whichever is farther 
from the wall.
    3.21  Wind Tunnel with Documented Axial Flow. A wind tunnel facility 
documented as meeting the provisions of sections 10.1.1 (velocity 
pressure cross-check) and 10.1.2 (axial flow verification) using the 
procedures described in these sections or alternative procedures 
determined to be technically equivalent.
    3.22  Yaw Angle. The angle between the axis of the stack or duct and 
the yaw component of flow, i.e., the component of the total velocity 
vector in a plane perpendicular to the traverse line at a particular 
traverse point. (Figure 2F-1 illustrates the ``yaw plane.'') From the 
standpoint of a tester facing a test port in a vertical stack, the yaw 
component of flow is the vector of flow moving to the left or right from 
the center of the stack as viewed by the tester. (This is sometimes 
referred to as ``vortex flow,'' i.e., flow around the centerline of a 
stack or duct.) The yaw angle is the angle described by this yaw 
component of flow and the vertical axis of the stack. The algebraic sign 
convention is illustrated in Figure 2F-2.
    3.23  Yaw Nulling. A procedure in which a probe is rotated about its 
axis in a stack or duct until a zero differential pressure reading 
(``yaw null'') is obtained. When a 3-D probe is yaw-nulled, its impact 
pressure port (P1) faces directly into the direction of flow 
in the stack or duct and the differential pressure between pressure 
ports P2 and P3 is zero.
    4.0  Interferences. [Reserved]
    5.0  Safety.
    5.1  This test method may involve hazardous operations and the use 
of hazardous materials or equipment. This method does not purport to 
address all of the safety problems associated with its use. It is the 
responsibility of the user to establish and implement appropriate safety 
and health practices and to determine the applicability of regulatory 
limitations before using this test method.

                       6.0 Equipment and Supplies

    6.1  Three-dimensional Probes. The 3-D probes as specified in 
subsections 6.1.1 through 6.1.3 below qualify for use based on 
comprehensive wind tunnel and field studies involving both inter-and 
intra-probe comparisons by multiple test teams. Other types of probes 
shall not be used unless approved by the Administrator. Each 3-D probe 
shall have a unique identification number or code permanently marked on 
the main probe sheath. The minimum recommended diameter of the sensing 
head of any probe used under this method is 2.5 cm (1 in.). Each probe 
shall be calibrated prior to use according to the procedures in section 
10. Manufacturer-supplied calibration data shall be used as example 
information only, except when the manufacturer calibrates the 3-D probe 
as specified in section 10 and provides complete documentation.
    6.1.1  Five-hole prism-shaped probe. This type of probe consists of 
five pressure taps in the flat facets of a prism-shaped sensing head. 
The pressure taps are numbered 1 through 5, with the pressures measured 
at each hole referred to as P1, P2, P3, 
P4, and P5, respectively. Figure 2F-3 is an 
illustration of the placement of pressure taps on a commonly available 
five-hole prism-shaped probe, the 2.5-cm (1-in.) DAT probe. (Note: 
Mention of trade names or specific products does not constitute 
endorsement by the U.S. Environmental Protection Agency.) The numbering 
arrangement for the prism-shaped sensing head presented in Figure 2F-3 
shall be followed for correct operation of the probe. A brief 
description of the probe

[[Page 625]]

measurements involved is as follows: the differential pressure 
P2-P3 is used to yaw null the probe and determine 
the yaw angle; the differential pressure P4-P5 is 
a function of pitch angle; and the differential pressure P1-
P2 is a function of total velocity.
    6.1.2  Five-hole spherical probe. This type of probe consists of 
five pressure taps in a spherical sensing head. As with the prism-shaped 
probe, the pressure taps are numbered 1 through 5, with the pressures 
measured at each hole referred to as P1, P2, 
P3, P4, and P5, respectively. However, 
the P4 and P5 pressure taps are in the reverse 
location from their respective positions on the prism-shaped probe head. 
The differential pressure P2-P3 is used to yaw 
null the probe and determine the yaw angle; the differential pressure 
P4-P5 is a function of pitch angle; and the 
differential pressure P1-P2 is a function of total 
velocity. A diagram of a typical spherical probe sensing head is 
presented in Figure 2F-4. Typical probe dimensions are indicated in the 
illustration.
    6.1.3  A manual 3-D probe refers to a five-hole prism-shaped or 
spherical probe that is positioned at individual traverse points and yaw 
nulled manually by an operator. An automated 3-D probe refers to a 
system that uses a computer-controlled motorized mechanism to position 
the five-hole prism-shaped or spherical head at individual traverse 
points and perform yaw angle determinations.
    6.1.4  Other three-dimensional probes. [Reserved]
    6.1.5  Probe sheath. The probe shaft shall include an outer sheath 
to: (1) provide a surface for inscribing a permanent reference scribe 
line, (2) accommodate attachment of an angle-measuring device to the 
probe shaft, and (3) facilitate precise rotational movement of the probe 
for determining yaw angles. The sheath shall be rigidly attached to the 
probe assembly and shall enclose all pressure lines from the probe head 
to the farthest position away from the probe head where an angle-
measuring device may be attached during use in the field. The sheath of 
the fully assembled probe shall be sufficiently rigid and straight at 
all rotational positions such that, when one end of the probe shaft is 
held in a horizontal position, the fully extended probe meets the 
horizontal straightness specifications indicated in section 8.2 below.
    6.1.6  Scribe lines.
    6.1.6.1  Reference scribe line. A permanent line, no greater than 
1.6 mm (1/16 in.) in width, shall be inscribed on each manual probe that 
will be used to determine yaw angles of flow. This line shall be placed 
on the main probe sheath in accordance with the procedures described in 
section 10.4 and is used as a reference position for installation of the 
yaw angle-measuring device on the probe. At the discretion of the 
tester, the scribe line may be a single line segment placed at a 
particular position on the probe sheath (e.g., near the probe head), 
multiple line segments placed at various locations along the length of 
the probe sheath (e.g., at every position where a yaw angle-measuring 
device may be mounted), or a single continuous line extending along the 
full length of the probe sheath.
    6.1.6.2  Scribe line on probe extensions. A permanent line may also 
be inscribed on any probe extension that will be attached to the main 
probe in performing field testing. This allows a yaw angle-measuring 
device mounted on the extension to be readily aligned with the reference 
scribe line on the main probe sheath.
    6.1.6.3  Alignment specifications. This specification shall be met 
separately, using the procedures in section 10.4.1, on the main probe 
and on each probe extension. The rotational position of the scribe line 
or scribe line segments on the main probe or any probe extension must 
not vary by more than 2 deg.. That is, the difference between the 
minimum and maximum of all of the rotational angles that are measured 
along the full length of the main probe or the probe extension must not 
exceed 2 deg..
    6.1.7  Probe and system characteristics to ensure horizontal 
stability.
    6.1.7.1  For manual probes, it is recommended that the effective 
length of the probe (coupled with a probe extension, if necessary) be at 
least 0.9 m (3 ft.) longer than the farthest traverse point mark on the 
probe shaft away from the probe head. The operator should maintain the 
probe's horizontal stability when it is fully inserted into the stack or 
duct. If a shorter probe is used, the probe should be inserted through a 
bushing sleeve, similar to the one shown in Figure 2F-5, that is 
installed on the test port; such a bushing shall fit snugly around the 
probe and be secured to the stack or duct entry port in such a manner as 
to maintain the probe's horizontal stability when fully inserted into 
the stack or duct.
    6.1.7.2  An automated system that includes an external probe casing 
with a transport system shall have a mechanism for maintaining 
horizontal stability comparable to that obtained by manual probes 
following the provisions of this method. The automated probe assembly 
shall also be constructed to maintain the alignment and position of the 
pressure ports during sampling at each traverse point. The design of the 
probe casing and transport system shall allow the probe to be removed 
from the stack or duct and checked through direct physical measurement 
for angular position and insertion depth.
    6.1.8  The tubing that is used to connect the probe and the 
pressure-measuring device should have an inside diameter of at least 3.2 
mm (1/8 in.), to reduce the time required for

[[Page 626]]

pressure equilibration, and should be as short as practicable.
    6.2  Yaw Angle-measuring Device. One of the following devices shall 
be used for measurement of the yaw angle of flow.
    6.2.1  Digital inclinometer. This refers to a digital device capable 
of measuring and displaying the rotational position of the probe to 
within 1 deg.. The device shall be able to be locked into 
position on the probe sheath or probe extension, so that it indicates 
the probe's rotational position throughout the test. A rotational 
position collar block that can be attached to the probe sheath (similar 
to the collar shown in Figure 2F-6) may be required to lock the digital 
inclinometer into position on the probe sheath.
    6.2.2  Protractor wheel and pointer assembly. This apparatus, 
similar to that shown in Figure 2F-7, consists of the following 
components.
    6.2.2.1  A protractor wheel that can be attached to a port opening 
and set in a fixed rotational position to indicate the yaw angle 
position of the probe's scribe line relative to the longitudinal axis of 
the stack or duct. The protractor wheel must have a measurement ring on 
its face that is no less than 17.8 cm (7 in.) in diameter, shall be able 
to be rotated to any angle and then locked into position on the stack or 
duct port, and shall indicate angles to a resolution of 1 deg..
    6.2.2.2  A pointer assembly that includes an indicator needle 
mounted on a collar that can slide over the probe sheath and be locked 
into a fixed rotational position on the probe sheath. The pointer needle 
shall be of sufficient length, rigidity, and sharpness to allow the 
tester to determine the probe's angular position to within 1 deg. from 
the markings on the protractor wheel. Corresponding to the position of 
the pointer, the collar must have a scribe line to be used in aligning 
the pointer with the scribe line on the probe sheath.
    6.2.3  Other yaw angle-measuring devices. Other angle-measuring 
devices with a manufacturer's specified precision of 1 deg. or better 
may be used, if approved by the Administrator.
    6.3  Probe Supports and Stabilization Devices. When probes are used 
for determining flow angles, the probe head should be kept in a stable 
horizontal position. For probes longer than 3.0 m (10 ft.), the section 
of the probe that extends outside the test port shall be secured. Three 
alternative devices are suggested for maintaining the horizontal 
position and stability of the probe shaft during flow angle 
determinations and velocity pressure measurements: (1) Monorails 
installed above each port, (2) probe stands on which the probe shaft may 
be rested, or (3) bushing sleeves of sufficient length secured to the 
test ports to maintain probes in a horizontal position. Comparable 
provisions shall be made to ensure that automated systems maintain the 
horizontal position of the probe in the stack or duct. The physical 
characteristics of each test platform may dictate the most suitable type 
of stabilization device. Thus, the choice of a specific stabilization 
device is left to the judgment of the testers.
    6.4  Differential Pressure Gauges. The pressure (P) 
measuring devices used during wind tunnel calibrations and field testing 
shall be either electronic manometers (e.g., pressure transducers), 
fluid manometers, or mechanical pressure gauges (e.g., 
Magnehelic gauges). Use of electronic 
manometers is recommended. Under low velocity conditions, use of 
electronic manometers may be necessary to obtain acceptable 
measurements.
    6.4.1  Differential pressure-measuring device. This refers to a 
device capable of measuring pressure differentials and having a 
readability of 1 percent of full scale. The device shall be 
capable of accurately measuring the maximum expected pressure 
differential. Such devices are used to determine the following pressure 
measurements: velocity pressure, static pressure, yaw-null pressure, and 
pitch-angle pressure. For an inclined-vertical manometer, the 
readability specification of 1 percent shall be met 
separately using the respective full-scale upper limits of the inclined 
and vertical portions of the scales. To the extent practicable, the 
device shall be selected such that most of the pressure readings are 
between 10 and 90 percent of the device's full-scale measurement range 
(as defined in section 3.5). Typical velocity pressure (P1-
P2) ranges for both the prism-shaped probe and the spherical 
probe are 0 to 1.3 cm H2O (0 to 0.5 in. H2O), 0 to 
5.1 cm H2O (0 to 2 in. H2O), and 0 to 12.7 cm 
H2O (0 to 5 in. H2O). The pitch angle 
(P4-P5) pressure range is typically -6.4 to +6.4 
mm H2O (-0.25 to +0.25 in. H2O) or -12.7 to +12.7 
mm H2O (-0.5 to +0.5 in. H2O) for the prism-shaped 
probe, and -12.7 to +12.7 mm H2O (-0.5 to +0.5 in. 
H2O) or -5.1 to +5.1 cm H2O (-2 to +2 in. 
H2O) for the spherical probe. The pressure range for the yaw 
null (P2-P3) readings is typically -12.7 to +12.7 
mm H2O (-0.5 to +0.5 in. H2O) for both probe 
types. In addition, pressure-measuring devices should be selected such 
that the zero does not drift by more than 5 percent of the average 
expected pressure readings to be encountered during the field test. This 
is particularly important under low pressure conditions.
    6.4.2  Gauge used for yaw nulling. The differential pressure-
measuring device chosen for yaw nulling the probe during the wind tunnel 
calibrations and field testing shall be bi-directional, i.e., capable of 
reading both positive and negative differential pressures. If a 
mechanical, bi-directional pressure gauge is chosen, it shall have a 
full-scale range no greater than 2.6 cm H2O (1 in. 
H2O) [i.e., -1.3 to +1.3 cm H2O (-0.5 in. to +0.5 
in.)].

[[Page 627]]

    6.4.3  Devices for calibrating differential pressure-measuring 
devices. A precision manometer (e.g., a U-tube, inclined, or inclined-
vertical manometer, or micromanometer) or NIST (National Institute of 
Standards and Technology) traceable pressure source shall be used for 
calibrating differential pressure-measuring devices. The device shall be 
maintained under laboratory conditions or in a similar protected 
environment (e.g., a climate-controlled trailer). It shall not be used 
in field tests. The precision manometer shall have a scale gradation of 
0.3 mm H2O (0.01 in. H2O), or less, in the range 
of 0 to 5.1 cm H2O (0 to 2 in. H2O) and 2.5 mm 
H2O (0.1 in. H2O), or less, in the range of 5.1 to 
25.4 cm H2O (2 to 10 in. H2O). The manometer shall 
have manufacturer's documentation that it meets an accuracy 
specification of at least 0.5 percent of full scale. The NIST-traceable 
pressure source shall be recertified annually.
    6.4.4  Devices used for post-test calibration check. A precision 
manometer meeting the specifications in section 6.4.3, a pressure-
measuring device or pressure source with a documented calibration 
traceable to NIST, or an equivalent device approved by the Administrator 
shall be used for the post-test calibration check. The pressure-
measuring device shall have a readability equivalent to or greater than 
the tested device. The pressure source shall be capable of generating 
pressures between 50 and 90 percent of the range of the tested device 
and known to within 1 percent of the full scale of the 
tested device. The pressure source shall be recertified annually.
    6.5  Data Display and Capture Devices. Electronic manometers (if 
used) shall be coupled with a data display device (such as a digital 
panel meter, personal computer display, or strip chart) that allows the 
tester to observe and validate the pressure measurements taken during 
testing. They shall also be connected to a data recorder (such as a data 
logger or a personal computer with data capture software) that has the 
ability to compute and retain the appropriate average value at each 
traverse point, identified by collection time and traverse point.
    6.6  Temperature Gauges. For field tests, a thermocouple or 
resistance temperature detector (RTD) capable of measuring temperature 
to within 3 deg.C (5 deg.F) of the stack or duct 
temperature shall be used. The thermocouple shall be attached to the 
probe such that the sensor tip does not touch any metal and is located 
on the opposite side of the probe head from the pressure ports so as not 
to interfere with the gas flow around the probe head. The position of 
the thermocouple relative to the pressure port face openings shall be in 
the same configuration as used for the probe calibrations in the wind 
tunnel. Temperature gauges used for wind tunnel calibrations shall be 
capable of measuring temperature to within 0.6 deg.C 
(1 deg.F) of the temperature of the flowing gas stream in 
the wind tunnel.
    6.7  Stack or Duct Static Pressure Measurement. The pressure-
measuring device used with the probe shall be as specified in section 
6.4 of this method. The static tap of a standard (Prandtl type) pitot 
tube or one leg of a Type S pitot tube with the face opening planes 
positioned parallel to the gas flow may be used for this measurement. 
Also acceptable is the pressure differential reading of P1-
Pbar from a five-hole prism-shaped probe (e.g., Type DA or 
DAT probe) with the P1 pressure port face opening positioned 
parallel to the gas flow in the same manner as the Type S probe. 
However, the spherical probe, as specified in section 6.1.2, is unable 
to provide this measurement and shall not be used to take static 
pressure measurements. Static pressure measurement is further described 
in section 8.11.
    6.8  Barometer. Same as Method 2, section 2.5.
    6.9  Gas Density Determination Equipment. Method 3 or 3A shall be 
used to determine the dry molecular weight of the stack gas. Method 4 
shall be used for moisture content determination and computation of 
stack gas wet molecular weight. Other methods may be used, if approved 
by the Administrator.
    6.10  Calibration Pitot Tube. Same as Method 2, section 2.7.
    6.11  Wind Tunnel for Probe Calibration. Wind tunnels used to 
calibrate velocity probes must meet the following design specifications.
    6.11.1  Test section cross-sectional area. The flowing gas stream 
shall be confined within a circular, rectangular, or elliptical duct. 
The cross-sectional area of the tunnel must be large enough to ensure 
fully developed flow in the presence of both the calibration pitot tube 
and the tested probe. The calibration site, or ``test section,'' of the 
wind tunnel shall have a minimum diameter of 30.5 cm (12 in.) for 
circular or elliptical duct cross-sections or a minimum width of 30.5 cm 
(12 in.) on the shorter side for rectangular cross-sections. Wind 
tunnels shall meet the probe blockage provisions of this section and the 
qualification requirements prescribed in section 10.1. The projected 
area of the portion of the probe head, shaft, and attached devices 
inside the wind tunnel during calibration shall represent no more than 4 
percent of the cross-sectional area of the tunnel. The projected area 
shall include the combined area of the calibration pitot tube and the 
tested probe if both probes are placed simultaneously in the same cross-
sectional plane in the wind tunnel, or the larger projected area of the 
two probes if they are placed alternately in the wind tunnel.
    6.11.2  Velocity range and stability. The wind tunnel should be 
capable of maintaining velocities between 6.1 m/sec and 30.5 m/

[[Page 628]]

sec (20 ft/sec and 100 ft/sec). The wind tunnel shall produce fully 
developed flow patterns that are stable and parallel to the axis of the 
duct in the test section.
    6.11.3  Flow profile at the calibration location. The wind tunnel 
shall provide axial flow within the test section calibration location 
(as defined in section 3.20). Yaw and pitch angles in the calibration 
location shall be within 3 deg. of 0 deg.. The procedure for 
determining that this requirement has been met is described in section 
10.1.2.
    6.11.4  Entry ports in the wind tunnel test section.
    6.11.4.1  Port for tested probe. A port shall be constructed for the 
tested probe. The port should have an elongated slot parallel to the 
axis of the duct at the test section. The elongated slot should be of 
sufficient length to allow attaining all the pitch angles at which the 
probe will be calibrated for use in the field. To facilitate alignment 
of the probe during calibration, the test section should include a 
window constructed of a transparent material to allow the tested probe 
to be viewed. This port shall be located to allow the head of the tested 
probe to be positioned within the calibration location (as defined in 
section 3.20) at all pitch angle settings.
    6.11.4.2  Port for verification of axial flow. Depending on the 
equipment selected to conduct the axial flow verification prescribed in 
section 10.1.2, a second port, located 90 deg. from the entry port for 
the tested probe, may be needed to allow verification that the gas flow 
is parallel to the central axis of the test section. This port should be 
located and constructed so as to allow one of the probes described in 
section 10.1.2.2 to access the same test point(s) that are accessible 
from the port described in section 6.11.4.1.
    6.11.4.3  Port for calibration pitot tube. The calibration pitot 
tube shall be used in the port for the tested probe or a separate entry 
port. In either case, all measurements with the calibration pitot tube 
shall be made at the same point within the wind tunnel over the course 
of a probe calibration. The measurement point for the calibration pitot 
tube shall meet the same specifications for distance from the wall and 
for axial flow as described in section 3.20 for the wind tunnel 
calibration location.
    6.11.5  Pitch angle protractor plate. A protractor plate shall be 
attached directly under the port used with the tested probe and set in a 
fixed position to indicate the pitch angle position of the probe 
relative to the longitudinal axis of the wind tunnel duct (similar to 
Figure 2F-8). The protractor plate shall indicate angles in 5 deg. 
increments with a minimum resolution of 2 deg.. The tested 
probe shall be able to be locked into position at the desired pitch 
angle delineated on the protractor. The probe head position shall be 
maintained within the calibration location (as defined in section 3.20) 
in the test section of the wind tunnel during all tests across the range 
of pitch angles.

                 7.0  Reagents and Standards. [Reserved]

                   8.0 Sample Collection and Analysis

                  8.1  Equipment Inspection and Set-Up

    8.1.1 All probes, differential pressure-measuring devices, yaw 
angle-measuring devices, thermocouples, and barometers shall have a 
current, valid calibration before being used in a field test. (See 
sections 10.3.3, 10.3.4, and 10.5 through10.10 for the applicable 
calibration requirements.)
    8.1.2 Before each field use of a 3-D probe, perform a visual 
inspection to verify the physical condition of the probe head according 
to the procedures in section 10.2. Record the inspection results on a 
form similar to Table 2F-1. If there is visible damage to the 3-D probe, 
the probe shall not be used until it is recalibrated.
    8.1.3 After verifying that the physical condition of the probe head 
is acceptable, set up the apparatus using lengths of flexible tubing 
that are as short as practicable. Surge tanks installed between the 
probe and pressure-measuring device may be used to dampen pressure 
fluctuations provided that an adequate measurement response time (see 
section 8.8) is maintained.
    8.2 Horizontal Straightness Check. A horizontal straightness check 
shall be performed before the start of each field test, except as 
otherwise specified in this section. Secure the fully assembled probe 
(including the probe head and all probe shaft extensions) in a 
horizontal position using a stationary support at a point along the 
probe shaft approximating the location of the stack or duct entry port 
when the probe is sampling at the farthest traverse point from the stack 
or duct wall. The probe shall be rotated to detect bends. Use an angle-
measuring device or trigonometry to determine the bend or sag between 
the probe head and the secured end. (See Figure 2F-9.) Probes that are 
bent or sag by more than 5 deg. shall not be used. Although this check 
does not apply when the probe is used for a vertical traverse, care 
should be taken to avoid the use of bent probes when conducting vertical 
traverses. If the probe is constructed of a rigid steel material and 
consists of a main probe without probe extensions, this check need only 
be performed before the initial field use of the probe, when the probe 
is recalibrated, when a change is made to the the design or material of 
the probe assembly, and when the probe becomes bent. With such probes, a 
visual inspection shall be made of the fully assembled probe before each 
field test to determine if a bend is visible. The probe shall be rotated 
to detect bends. The inspection results shall be documented in the field 
test report. If a bend in the probe is visible, the horizontal

[[Page 629]]

straightness check shall be performed before the probe is used.
    8.3 Rotational Position Check. Before each field test, and each time 
an extension is added to the probe during a field test, a rotational 
position check shall be performed on all manually operated probes 
(except as noted in section 8.3.5, below) to ensure that, throughout 
testing, the angle-measuring device is either: aligned to within 
1 deg. of the rotational position of the reference scribe 
line; or is affixed to the probe such that the rotational offset of the 
device from the reference scribe line is known to within 
1 deg.. This check shall consist of direct measurements of 
the rotational positions of the reference scribe line and angle-
measuring device sufficient to verify that these specifications are met. 
Annex A in section 18 of this method gives recommended procedures for 
performing the rotational position check, and Table 2F-2 gives an 
example data form. Procedures other than those recommended in Annex A in 
section 18 may be used, provided they demonstrate whether the alignment 
specification is met and are explained in detail in the field test 
report.
    8.3.1 Angle-measuring device rotational offset. The tester shall 
maintain a record of the angle-measuring device rotational offset, 
RADO, as defined in section 3.1. Note that RADO is 
assigned a value of 0 deg. when the angle-measuring device is aligned to 
within 1 deg. of the rotational position of the reference 
scribe line. The RADO shall be used to determine the yaw 
angle of flow in accordance with section 8.9.4.
    8.3.2 Sign of angle-measuring device rotational offset. The sign of 
RADO is positive when the angle-measuring device (as viewed 
from the ``tail'' end of the probe) is positioned in a clockwise 
direction from the reference scribe line and negative when the device is 
positioned in a counterclockwise direction from the reference scribe 
line.
    8.3.3 Angle-measuring devices that can be independently adjusted 
(e.g., by means of a set screw), after being locked into position on the 
probe sheath, may be used. However, the RADO must also take 
into account this adjustment.
    8.3.4 Post-test check. If probe extensions remain attached to the 
main probe throughout the field test, the rotational position check 
shall be repeated, at a minimum, at the completion of the field test to 
ensure that the angle-measuring device has remained within 
2 deg. of its rotational position established prior to 
testing. At the discretion of the tester, additional checks may be 
conducted after completion of testing at any sample port or after any 
test run. If the 2 deg. specification is not met, all 
measurements made since the last successful rotational position check 
must be repeated. Section 18.1.1.3 of Annex A provides an example 
procedure for performing the post-test check.
    8.3.5 Exceptions.
    8.3.5.1 A rotational position check need not be performed if, for 
measurements taken at all velocity traverse points, the yaw angle-
measuring device is mounted and aligned directly on the reference scribe 
line specified in sections 6.1.6.1 and 6.1.6.3 and no independent 
adjustments, as described in section 8.3.3, are made to the device's 
rotational position.
    8.3.5.2 If extensions are detached and re-attached to the probe 
during a field test, a rotational position check need only be performed 
the first time an extension is added to the probe, rather than each time 
the extension is re-attached, if the probe extension is designed to be 
locked into a mechanically fixed rotational position (e.g., through use 
of interlocking grooves) that can re-establish the initial rotational 
position to within 1 deg..
    8.4  Leak Checks. A pre-test leak check shall be conducted before 
each field test. A post-test check shall be performed at the end of the 
field test, but additional leak checks may be conducted after any test 
run or group of test runs. The post-test check may also serve as the 
pre-test check for the next group of test runs. If any leak check is 
failed, all runs since the last passed leak check are invalid. While 
performing the leak check procedures, also check each pressure device's 
responsiveness to the changes in pressure.
    8.4.1  To perform the leak check, pressurize the probe's 
P1 pressure port until at least 7.6 cm H2O (3 in. 
H2O) pressure, or a pressure corresponding to approximately 
75 percent of the pressure-measuring device's measurement scale, 
whichever is less, registers on the device; then, close off the pressure 
port. The pressure shall remain stable [2.5 mm 
H2O (0.10 in. H2O)] for at least 15 
seconds. Check the P2, P3, P4, and 
P5 pressure ports in the same fashion. Other leak-check 
procedures may be used, if approved by the Administrator.
    8.5  Zeroing the Differential Pressure-measuring Device. Zero each 
differential pressure-measuring device, including the device used for 
yaw nulling, before each field test. At a minimum, check the zero after 
each field test. A zero check may also be performed after any test run 
or group of test runs. For fluid manometers and mechanical pressure 
gauges (e.g., Magnehelic gauges), the 
zero reading shall not deviate from zero by more than 0.8 mm 
H2O (0.03 in. H2O) or one minor scale 
division, whichever is greater, between checks. For electronic 
manometers, the zero reading shall not deviate from zero between checks 
by more than: 0.3 mm H2O (0.01 in. 
H2O), for full scales less than or equal to 5.1 cm 
H2O (2.0 in. H2O); or 0.8 mm 
H2O (0.03 in. H2O), for full scales 
greater than 5.1 cm H2O (2.0 in. H2O). (Note: If 
negative zero drift is not directly readable, estimate the reading based 
on the position of

[[Page 630]]

the gauge oil in the manometer or of the needle on the pressure gauge.) 
In addition, for all pressure-measuring devices except those used 
exclusively for yaw nulling, the zero reading shall not deviate from 
zero by more than 5 percent of the average measured differential 
pressure at any distinct process condition or load level. If any zero 
check is failed at a specific process condition or load level, all runs 
conducted at that process condition or load level since the last passed 
zero check are invalid.
    8.6  Traverse Point Verification. The number and location of the 
traverse points shall be selected based on Method 1 guidelines. The 
stack or duct diameter and port nipple lengths, including any extension 
of the port nipples into stack or duct, shall be verified the first time 
the test is performed; retain and use this information for subsequent 
field tests, updating it as required. Physically measure the stack or 
duct dimensions or use a calibrated laser device; do not use engineering 
drawings of the stack or duct. The probe length necessary to reach each 
traverse point shall be recorded to within 6.4 mm 
(1/4 in.) and, for manual probes, marked on the probe 
sheath. In determining these lengths, the tester shall take into account 
both the distance that the port flange projects outside of the stack and 
the depth that any port nipple extends into the gas stream. The 
resulting point positions shall reflect the true distances from the 
inside wall of the stack or duct, so that when the tester aligns any of 
the markings with the outside face of the stack port, the probe's impact 
port shall be located at the appropriate distance from the inside wall 
for the respective Method 1 traverse point. Before beginning testing at 
a particular location, an out-of-stack or duct verification shall be 
performed on each probe that will be used to ensure that these position 
markings are correct. The distances measured during the verification 
must agree with the previously calculated distances to within 
1/4 in. For manual probes, the traverse point positions 
shall be verified by measuring the distance of each mark from the 
probe's P1 pressure port. A comparable out-of-stack test 
shall be performed on automated probe systems. The probe shall be 
extended to each of the prescribed traverse point positions. Then, the 
accuracy of the positioning for each traverse point shall be verified by 
measuring the distance between the port flange and the probe's 
P1 pressure port.
    8.7  Probe Installation. Insert the probe into the test port. A 
solid material shall be used to seal the port.
    8.8  System Response Time. Determine the response time of the probe 
measurement system. Insert and position the ``cold'' probe (at ambient 
temperature and pressure) at any Method 1 traverse point. Read and 
record the probe's P1-P2 differential pressure, 
temperature, and elapsed time at 15-second intervals until stable 
readings for both pressure and temperature are achieved. The response 
time is the longer of these two elapsed times. Record the response time.
    8.9  Sampling.
    8.9.1  Yaw angle measurement protocol. With manual probes, yaw angle 
measurements may be obtained in two alternative ways during the field 
test, either by using a yaw angle-measuring device (e.g., digital 
inclinometer) affixed to the probe, or using a protractor wheel and 
pointer assembly. For horizontal traversing, either approach may be 
used. For vertical traversing, i.e., when measuring from on top or into 
the bottom of a horizontal duct, only the protractor wheel and pointer 
assembly may be used. With automated probes, curve-fitting protocols may 
be used to obtain yaw-angle measurements.
    8.9.1.1  If a yaw angle-measuring device affixed to the probe is to 
be used, lock the device on the probe sheath, aligning it either on the 
reference scribe line or in the rotational offset position established 
under section 8.3.1.
    8.9.1.2  If a protractor wheel and pointer assembly is to be used, 
follow the procedures in Annex B of this method.
    8.9.1.3  Other yaw angle-determination procedures. If approved by 
the Administrator, other procedures for determining yaw angle may be 
used, provided that they are verified in a wind tunnel to be able to 
perform the yaw angle calibration procedure as described in section 
10.5.
    8.9.2  Sampling strategy. At each traverse point, first yaw-null the 
probe, as described in section 8.9.3, below. Then, with the probe 
oriented into the direction of flow, measure and record the yaw angle, 
the differential pressures and the temperature at the traverse point, 
after stable readings are achieved, in accordance with sections 8.9.4 
and 8.9.5. At the start of testing in each port (i.e., after a probe has 
been inserted into the flue gas stream), allow at least the response 
time to elapse before beginning to take measurements at the first 
traverse point accessed from that port. Provided that the probe is not 
removed from the flue gas stream, measurements may be taken at 
subsequent traverse points accessed from the same test port without 
waiting again for the response time to elapse.
    8.9.3  Yaw-nulling procedure. In preparation for yaw angle 
determination, the probe must first be yaw nulled. After positioning the 
probe at the appropriate traverse point, perform the following 
procedures.
    8.9.3.1  Rotate the probe until a null differential pressure reading 
(the difference in pressures across the P2 and P3 
pressure ports is zero, i.e., P2 = P3) is 
indicated by the yaw angle pressure gauge. Read and record the

[[Page 631]]

angle displayed by the angle-measuring device.
    8.9.3.2  Sign of the measured angle. The angle displayed on the 
angle-measuring device is considered positive when the probe's impact 
pressure port (as viewed from the ``tail'' end of the probe) is oriented 
in a clockwise rotational position relative to the stack or duct axis 
and is considered negative when the probe's impact pressure port is 
oriented in a counterclockwise rotational position (see Figure 2F-10).
    8.9.4  Yaw angle determination. After performing the yaw-nulling 
procedure in section 8.9.3, determine the yaw angle of flow according to 
one of the following procedures. Special care must be observed to take 
into account the signs of the recorded angle and all offsets.
    8.9.4.1  Direct-reading. If all rotational offsets are zero or if 
the angle-measuring device rotational offset (RADO) 
determined in section 8.3 exactly compensates for the scribe line 
rotational offset (RSLO) determined in section 10.5, then the 
magnitude of the yaw angle is equal to the displayed angle-measuring 
device reading from section 8.9.3.1. The algebraic sign of the yaw angle 
is determined in accordance with section 8.9.3.2.

    Note: Under certain circumstances (e.g., testing of horizontal 
ducts), a 90 deg. adjustment to the angle-measuring device readings may 
be necessary to obtain the correct yaw angles.

    8.9.4.2  Compensation for rotational offsets during data reduction. 
When the angle-measuring device rotational offset does not compensate 
for reference scribe line rotational offset, the following procedure 
shall be used to determine the yaw angle:
    (a) Enter the reading indicated by the angle-measuring device from 
section 8.9.3.1.
    (b) Associate the proper algebraic sign from section 8.9.3.2 with 
the reading in step (a).
    (c) Subtract the reference scribe line rotational offset, 
RSLO, from the reading in step (b).
    (d) Subtract the angle-measuring device rotational offset, 
RADO, if any, from the result obtained in step (c).
    (e) The final result obtained in step (d) is the yaw angle of flow.

    Note: It may be necessary to first apply a 90 deg. adjustment to the 
reading in step (a), in order to obtain the correct yaw angle.

    8.9.4.3  Record the yaw angle measurements on a form similar to 
Table 2F-3.
    8.9.5  Velocity determination. Maintain the probe rotational 
position established during the yaw angle determination. Then, begin 
recording the pressure-measuring device readings for the impact pressure 
(P1-P2) and pitch angle pressure (P4-
P5). These pressure measurements shall be taken over a 
sampling period of sufficiently long duration to ensure representative 
readings at each traverse point. If the pressure measurements are 
determined from visual readings of the pressure device or display, allow 
sufficient time to observe the pulsation in the readings to obtain a 
sight-weighted average, which is then recorded manually. If an automated 
data acquisition system (e.g., data logger, computer-based data 
recorder, strip chart recorder) is used to record the pressure 
measurements, obtain an integrated average of all pressure readings at 
the traverse point. Stack or duct gas temperature measurements shall be 
recorded, at a minimum, once at each traverse point. Record all 
necessary data as shown in the example field data form (Table 2F-3).
    8.9.6  Alignment check. For manually operated probes, after the 
required yaw angle and differential pressure and temperature 
measurements have been made at each traverse point, verify (e.g., by 
visual inspection) that the yaw angle-measuring device has remained in 
proper alignment with the reference scribe line or with the rotational 
offset position established in section 8.3. If, for a particular 
traverse point, the angle-measuring device is found to be in proper 
alignment, proceed to the next traverse point; otherwise, re-align the 
device and repeat the angle and differential pressure measurements at 
the traverse point. In the course of a traverse, if a mark used to 
properly align the angle-measuring device (e.g., as described in section 
18.1.1.1) cannot be located, re-establish the alignment mark before 
proceeding with the traverse.
    8.10  Probe Plugging. Periodically check for plugging of the 
pressure ports by observing the responses on pressure differential 
readouts. Plugging causes erratic results or sluggish responses. Rotate 
the probe to determine whether the readouts respond in the expected 
direction. If plugging is detected, correct the problem and repeat the 
affected measurements.
    8.11  Static Pressure. Measure the static pressure in the stack or 
duct using the equipment described in section 6.7.
    8.11.1  If a Type DA or DAT probe is used for this measurement, 
position the probe at or between any traverse point(s) and rotate the 
probe until a null differential pressure reading is obtained at 
P2-P3. Rotate the probe 90 deg.. Disconnect the 
P2 pressure side of the probe and read the pressure 
P1-Pbar and record as the static pressure. (Note: 
The spherical probe, specified in section 6.1.2, is unable to provide 
this measurement and shall not be used to take static pressure 
measurements.)
    8.11.2  If a Type S probe is used for this measurement, position the 
probe at or between any traverse point(s) and rotate the probe until a 
null differential pressure reading is obtained. Disconnect the tubing 
from one of the pressure ports; read and record the

[[Page 632]]

P. For pressure devices with one-directional scales, if a 
deflection in the positive direction is noted with the negative side 
disconnected, then the static pressure is positive. Likewise, if a 
deflection in the positive direction is noted with the positive side 
disconnected, then the static pressure is negative.
    8.12  Atmospheric Pressure. Determine the atmospheric pressure at 
the sampling elevation during each test run following the procedure 
described in section 2.5 of Method 2.
    8.13  Molecular Weight. Determine the stack gas dry molecular 
weight. For combustion processes or processes that emit essentially 
CO2, O2, CO, and N2, use Method 3 or 
3A. For processes emitting essentially air, an analysis need not be 
conducted; use a dry molecular weight of 29.0. Other methods may be 
used, if approved by the Administrator.
    8.14  Moisture. Determine the moisture content of the stack gas 
using Method 4 or equivalent.
    8.15  Data Recording and Calculations. Record all required data on a 
form similar to Table 2F-3.
    8.15.1  Selection of appropriate calibration curves. Choose the 
appropriate pair of F1 and F2 versus pitch angle 
calibration curves, created as described in section 10.6.
    8.15.2  Pitch angle derivation. Use the appropriate calculation 
procedures in section 12.2 to find the pitch angle ratios that are 
applicable at each traverse point. Then, find the pitch angles 
corresponding to these pitch angle ratios on the ``F1 versus 
pitch angle'' curve for the probe.
    8.15.3  Velocity calibration coefficient derivation. Use the pitch 
angle obtained following the procedures described in section 8.15.2 to 
find the corresponding velocity calibration coefficients from the 
``F2 versus pitch angle'' calibration curve for the probe.
    8.15.4  Calculations. Calculate the axial velocity at each traverse 
point using the equations presented in section 12.2 to account for the 
yaw and pitch angles of flow. Calculate the test run average stack gas 
velocity by finding the arithmetic average of the point velocity results 
in accordance with sections 12.3 and 12.4, and calculate the stack gas 
volumetric flow rate in accordance with section 12.5 or 12.6, as 
applicable.

                          9.0  Quality Control

    9.1  Quality Control Activities. In conjunction with the yaw angle 
determination and the pressure and temperature measurements specified in 
section 8.9, the following quality control checks should be performed.
    9.1.1  Range of the differential pressure gauge. In accordance with 
the specifications in section 6.4, ensure that the proper differential 
pressure gauge is being used for the range of P values 
encountered. If it is necessary to change to a more sensitive gauge, 
replace the gauge with a gauge calibrated according to section 10.3.3, 
perform the leak check described in section 8.4 and the zero check 
described in section 8.5, and repeat the differential pressure and 
temperature readings at each traverse point.
    9.1.2  Horizontal stability check. For horizontal traverses of a 
stack or duct, visually check that the probe shaft is maintained in a 
horizontal position prior to taking a pressure reading. Periodically, 
during a test run, the probe's horizontal stability should be verified 
by placing a carpenter's level, a digital inclinometer, or other angle-
measuring device on the portion of the probe sheath that extends outside 
of the test port. A comparable check should be performed by automated 
systems.

                            10.0  Calibration

    10.1  Wind Tunnel Qualification Checks. To qualify for use in 
calibrating probes, a wind tunnel shall have the design features 
specified in section 6.11 and satisfy the following qualification 
criteria. The velocity pressure cross-check in section 10.1.1 and axial 
flow verification in section 10.1.2 shall be performed before the 
initial use of the wind tunnel and repeated immediately after any 
alteration occurs in the wind tunnel's configuration, fans, interior 
surfaces, straightening vanes, controls, or other properties that could 
reasonably be expected to alter the flow pattern or velocity stability 
in the tunnel. The owner or operator of a wind tunnel used to calibrate 
probes according to this method shall maintain records documenting that 
the wind tunnel meets the requirements of sections 10.1.1 and 10.1.2 and 
shall provide these records to the Administrator upon request.
    10.1.1  Velocity pressure cross-check. To verify that the wind 
tunnel produces the same velocity at the tested probe head as at the 
calibration pitot tube impact port, perform the following cross-check. 
Take three differential pressure measurements at the fixed calibration 
pitot tube location, using the calibration pitot tube specified in 
section 6.10, and take three measurements with the calibration pitot 
tube at the wind tunnel calibration location, as defined in section 
3.20. Alternate the measurements between the two positions. Perform this 
procedure at the lowest and highest velocity settings at which the 
probes will be calibrated. Record the values on a form similar to Table 
2F-4. At each velocity setting, the average velocity pressure obtained 
at the wind tunnel calibration location shall be within 2 
percent or 2.5 mm H2O (0.01 in. H2O), whichever is 
less restrictive, of the average velocity pressure obtained at the fixed 
calibration pitot tube location. This comparative check shall be 
performed at 2.5-cm (1-in.), or smaller, intervals across the full 
length, width,

[[Page 633]]

and depth (if applicable) of the wind tunnel calibration location. If 
the criteria are not met at every tested point, the wind tunnel 
calibration location must be redefined, so that acceptable results are 
obtained at every point. Include the results of the velocity pressure 
cross-check in the calibration data section of the field test report. 
(See section 16.1.4.)
    10.1.2  Axial flow verification. The following procedures shall be 
performed to demonstrate that there is fully developed axial flow within 
the calibration location and at the calibration pitot tube location. Two 
testing options are available to conduct this check.
    10.1.2.1  Using a calibrated 3-D probe. A 3-D probe that has been 
previously calibrated in a wind tunnel with documented axial flow (as 
defined in section 3.21) may be used to conduct this check. Insert the 
calibrated 3-D probe into the wind tunnel test section using the tested 
probe port. Following the procedures in sections 8.9 and 12.2 of this 
method, determine the yaw and pitch angles at all the point(s) in the 
test section where the velocity pressure cross-check, as specified in 
section 10.1.1, is performed. This includes all the points in the 
calibration location and the point where the calibration pitot tube will 
be located. Determine the yaw and pitch angles at each point. Repeat 
these measurements at the highest and lowest velocities at which the 
probes will be calibrated. Record the values on a form similar to Table 
2F-5. Each measured yaw and pitch angle shall be within 
3 deg. of 0 deg.. Exceeding the limits indicates 
unacceptable flow in the test section. Until the problem is corrected 
and acceptable flow is verified by repetition of this procedure, the 
wind tunnel shall not be used for calibration of probes. Include the 
results of the axial flow verification in the calibration data section 
of the field test report. (See section 16.1.4.)
    10.1.2.2  Using alternative probes. Axial flow verification may be 
performed using an uncalibrated prism-shaped 3-D probe (e.g., DA or DAT 
probe) or an uncalibrated wedge probe. (Figure 2F-11 illustrates a 
typical wedge probe.) This approach requires use of two ports: the 
tested probe port and a second port located 90 deg. from the tested 
probe port. Each port shall provide access to all the points within the 
wind tunnel test section where the velocity pressure cross-check, as 
specified in section 10.1.1, is conducted. The probe setup shall include 
establishing a reference yaw-null position on the probe sheath to serve 
as the location for installing the angle-measuring device. Physical 
design features of the DA, DAT, and wedge probes are relied on to 
determine the reference position. For the DA or DAT probe, this 
reference position can be determined by setting a digital inclinometer 
on the flat facet where the P1 pressure port is located and 
then identifying the rotational position on the probe sheath where a 
second angle-measuring device would give the same angle reading. The 
reference position on a wedge probe shaft can be determined either 
geometrically or by placing a digital inclinometer on each side of the 
wedge and rotating the probe until equivalent readings are obtained. 
With the latter approach, the reference position is the rotational 
position on the probe sheath where an angle-measuring device would give 
a reading of 0 deg.. After installing the angle-measuring device in the 
reference yaw-null position on the probe sheath, determine the yaw angle 
from the tested port. Repeat this measurement using the 90 deg. offset 
port, which provides the pitch angle of flow. Determine the yaw and 
pitch angles at all the point(s) in the test section where the velocity 
pressure cross-check, as specified in section 10.1.1, is performed. This 
includes all the points in the wind tunnel calibration location and the 
point where the calibration pitot tube will be located. Perform this 
check at the highest and lowest velocities at which the probes will be 
calibrated. Record the values on a form similar to Table 2F-5. Each 
measured yaw and pitch angle shall be within 3 deg. of 
0 deg.. Exceeding the limits indicates unacceptable flow in the test 
section. Until the problem is corrected and acceptable flow is verified 
by repetition of this procedure, the wind tunnel shall not be used for 
calibration of probes. Include the results in the probe calibration 
report.
    10.1.3  Wind tunnel audits.
    10.1.3.1  Procedure. Upon the request of the Administrator, the 
owner or operator of a wind tunnel shall calibrate a 3-D audit probe in 
accordance with the procedures described in sections 10.3 through 10.6. 
The calibration shall be performed at two velocities and over a pitch 
angle range that encompasses the velocities and pitch angles typically 
used for this method at the facility. The resulting calibration data and 
curves shall be submitted to the Agency in an audit test report. These 
results shall be compared by the Agency to reference calibrations of the 
audit probe at the same velocity and pitch angle settings obtained at 
two different wind tunnels.
    10.1.3.2  Acceptance criteria. The audited tunnel's calibration is 
acceptable if all of the following conditions are satisfied at each 
velocity and pitch setting for the reference calibration obtained from 
at least one of the wind tunnels. For pitch angle settings between 
-15 deg. and +15 deg., no velocity calibration coefficient (i.e., 
F2) may differ from the corresponding reference value by more 
than 3 percent. For pitch angle settings outside of this range (i.e., 
less than -15 deg. and greater than +15 deg.), no velocity calibration 
coefficient may differ by more than 5 percent from the corresponding 
reference value. If the acceptance criteria are not met, the audited 
wind

[[Page 634]]

tunnel shall not be used to calibrate probes for use under this method 
until the problems are resolved and acceptable results are obtained upon 
completion of a subsequent audit.
    10.2  Probe Inspection. Before each calibration of a 3-D probe, 
carefully examine the physical condition of the probe head. Particular 
attention shall be paid to the edges of the pressure ports and the 
surfaces surrounding these ports. Any dents, scratches, or asymmetries 
on the edges of the pressure ports and any scratches or indentations on 
the surfaces surrounding the pressure ports shall be noted because of 
the potential effect on the probe's pressure readings. If the probe has 
been previously calibrated, compare the current condition of the probe's 
pressure ports and surfaces to the results of the inspection performed 
during the probe's most recent wind tunnel calibration. Record the 
results of this inspection on a form and in diagrams similar to Table 
2F-1. The information in Table 2F-1 will be used as the basis for 
comparison during the probe head inspections performed before each 
subsequent field use.
    10.3  Pre-Calibration Procedures. Prior to calibration, a scribe 
line shall have been placed on the probe in accordance with section 
10.4. The yaw angle and velocity calibration procedures shall not begin 
until the pre-test requirements in sections 10.3.1 through 10.3.4 have 
been met.
    10.3.1  Perform the horizontal straightness check described in 
section 8.2 on the probe assembly that will be calibrated in the wind 
tunnel.
    10.3.2  Perform a leak check in accordance with section 8.4.
    10.3.3  Except as noted in section 10.3.3.3, calibrate all 
differential pressure-measuring devices to be used in the probe 
calibrations, using the following procedures. At a minimum, calibrate 
these devices on each day that probe calibrations are performed.
    10.3.3.1  Procedure. Before each wind tunnel use, all differential 
pressure-measuring devices shall be calibrated against the reference 
device specified in section 6.4.3 using a common pressure source. 
Perform the calibration at three reference pressures representing 30, 
60, and 90 percent of the full-scale range of the pressure-measuring 
device being calibrated. For an inclined-vertical manometer, perform 
separate calibrations on the inclined and vertical portions of the 
measurement scale, considering each portion of the scale to be a 
separate full-scale range. [For example, for a manometer with a 0- to 
2.5-cm H2O (0- to 1-in. H2O) inclined scale and a 
2.5- to 12.7-cm H2O (1- to 5-in. H2O) vertical 
scale, calibrate the inclined portion at 7.6, 15.2, and 22.9 mm 
H2O (0.3, 0.6, and 0.9 in. H2O), and calibrate the 
vertical portion at 3.8, 7.6, and 11.4 cm H2O (1.5, 3.0, and 
4.5 in. H2O).] Alternatively, for the vertical portion of the 
scale, use three evenly spaced reference pressures, one of which is 
equal to or higher than the highest differential pressure expected in 
field applications.
    10.3.3.2  Acceptance criteria. At each pressure setting, the two 
pressure readings made using the reference device and the pressure-
measuring device being calibrated shall agree to within 2 
percent of full scale of the device being calibrated or 0.5 mm 
H2O (0.02 in. H2O), whichever is less restrictive. 
For an inclined-vertical manometer, these requirements shall be met 
separately using the respective full-scale upper limits of the inclined 
and vertical portions of the scale. Differential pressure-measuring 
devices not meeting the #2 percent of full scale or 0.5 mm 
H2O (0.02 in. H2O) calibration requirement shall 
not be used.
    10.3.3.3  Exceptions. Any precision manometer that meets the 
specifications for a reference device in section 6.4.3 and that is not 
used for field testing does not require calibration, but must be leveled 
and zeroed before each wind tunnel use. Any pressure device used 
exclusively for yaw nulling does not require calibration, but shall be 
checked for responsiveness to rotation of the probe prior to each wind 
tunnel use.
    10.3.4  Calibrate digital inclinometers on each day of wind tunnel 
or field testing (prior to beginning testing) using the following 
procedures. Calibrate the inclinometer according to the manufacturer's 
calibration procedures. In addition, use a triangular block (illustrated 
in Figure 2F-12) with a known angle,  independently determined 
using a protractor or equivalent device, between two adjacent sides to 
verify the inclinometer readings.

    Note: If other angle-measuring devices meeting the provisions of 
section 6.2.3 are used in place of a digital inclinometer, comparable 
calibration procedures shall be performed on such devices.)

Secure the triangular block in a fixed position. Place the inclinometer 
on one side of the block (side A) to measure the angle of inclination 
(R1). Repeat this measurement on the adjacent side of the 
block (side B) using the inclinometer to obtain a second angle reading 
(R2). The difference of the sum of the two readings from 
180 deg. (i.e., 180 deg. -R1 -R2) shall be within 
2 deg. of the known angle, 
    10.4  Placement of Reference Scribe Line. Prior to the first 
calibration of a probe, a line shall be permanently inscribed on the 
main probe sheath to serve as a reference mark for determining yaw 
angles. Annex C in section 18 of this method gives a guideline for 
placement of the reference scribe line.
    10.4.1  This reference scribe line shall meet the specifications in 
sections 6.1.6.1 and 6.1.6.3 of this method. To verify that the 
alignment specification in section 6.1.6.3 is

[[Page 635]]

met, secure the probe in a horizontal position and measure the 
rotational angle of each scribe line and scribe line segment using an 
angle-measuring device that meets the specifications in section 6.2.1 or 
6.2.3. For any scribe line that is longer than 30.5 cm (12 in.), check 
the line's rotational position at 30.5-cm (12-in.) intervals. For each 
line segment that is 30.5 cm (12 in.) or less in length, check the 
rotational position at the two endpoints of the segment. To meet the 
alignment specification in section 6.1.6.3, the minimum and maximum of 
all of the rotational angles that are measured along the full length of 
the main probe must not differ by more than 2 deg..

    Note: A short reference scribe line segment [e.g., 15.2 cm (6 in.) 
or less in length] meeting the alignment specifications in section 
6.1.6.3 is fully acceptable under this method. See section 18.1.1.1 of 
Annex A for an example of a probe marking procedure, suitable for use 
with a short reference scribe line.

    10.4.2  The scribe line should be placed on the probe first and then 
its offset from the yaw-null position established (as specified in 
section 10.5). The rotational position of the reference scribe line 
relative to the yaw-null position of the probe, as determined by the yaw 
angle calibration procedure in section 10.5, is defined as the reference 
scribe line rotational offset, RSLO. The reference scribe 
line rotational offset shall be recorded and retained as part of the 
probe's calibration record.
    10.4.3  Scribe line for automated probes. A scribe line may not be 
necessary for an automated probe system if a reference rotational 
position of the probe is built into the probe system design. For such 
systems, a ``flat'' (or comparable, clearly identifiable physical 
characteristic) should be provided on the probe casing or flange plate 
to ensure that the reference position of the probe assembly remains in a 
vertical or horizontal position. The rotational offset of the flat (or 
comparable, clearly identifiable physical characteristic) needed to 
orient the reference position of the probe assembly shall be recorded 
and maintained as part of the automated probe system's specifications.
    10.5  Yaw Angle Calibration Procedure. For each probe used to 
measure yaw angles with this method, a calibration procedure shall be 
performed in a wind tunnel meeting the specifications in section 10.1 to 
determine the rotational position of the reference scribe line relative 
to the probe's yaw-null position. This procedure shall be performed on 
the main probe with all devices that will be attached to the main probe 
in the field [such as thermocouples or resistance temperature detectors 
(RTDs)] that may affect the flow around the probe head. Probe shaft 
extensions that do not affect flow around the probe head need not be 
attached during calibration. At a minimum, this procedure shall include 
the following steps.
    10.5.1  Align and lock the angle-measuring device on the reference 
scribe line. If a marking procedure (such as that described in section 
18.1.1.1) is used, align the angle-measuring device on a mark within 
1 deg. of the rotational position of the reference scribe 
line. Lock the angle-measuring device onto the probe sheath at this 
position.
    10.5.2  Zero the pressure-measuring device used for yaw nulling.
    10.5.3  Insert the probe assembly into the wind tunnel through the 
entry port, positioning the probe's impact port at the calibration 
location. Check the responsiveness of the pressure-measurement device to 
probe rotation, taking corrective action if the response is 
unacceptable.
    10.5.4  Ensure that the probe is in a horizontal position, using a 
carpenter's level.
    10.5.5  Rotate the probe either clockwise or counterclockwise until 
a yaw null (P2 = P3) is obtained.
    10.5.6  Use the reading displayed by the angle-measuring device at 
the yaw-null position to determine the magnitude of the reference scribe 
line rotational offset, RSLO, as defined in section 3.15. 
Annex D in section 18 of this method provides a recommended procedure 
for determining the magnitude of RSLO with a digital 
inclinometer and a second procedure for determining the magnitude of 
RSLO with a protractor wheel and pointer device. Table 2F-6 
presents an example data form and Table 2F-7 is a look-up table with the 
recommended procedure. Procedures other than those recommended in Annex 
D in section 18 may be used, if they can determine RSLO to 
within 1 deg. and are explained in detail in the field test 
report. The algebraic sign of RSLO will either be positive, 
if the rotational position of the reference scribe line (as viewed from 
the ``tail'' end of the probe) is clockwise, or negative, if 
counterclockwise with respect to the probe's yaw-null position. (This is 
illustrated in Figure 2F-13.)
    10.5.7  The steps in sections 10.5.3 through 10.5.6 shall be 
performed twice at each of the velocities at which the probe will be 
calibrated (in accordance with section 10.6). Record the values of 
RSLO.
    10.5.8  The average of all of the RSLO values shall be 
documented as the reference scribe line rotational offset for the probe.
    10.5.9  Use of reference scribe line offset. The reference scribe 
line rotational offset shall be used to determine the yaw angle of flow 
in accordance with section 8.9.4.
    10.6  Pitch Angle and Velocity Pressure Calibrations. Use the 
procedures in sections 10.6.1 through 10.6.16 to generate an appropriate 
set (or sets) of pitch angle and velocity pressure calibration curves 
for each probe. The calibration procedure shall be

[[Page 636]]

performed on the main probe and all devices that will be attached to the 
main probe in the field (e.g., thermocouple or RTDs) that may affect the 
flow around the probe head. Probe shaft extensions that do not affect 
flow around the probe head need not be attached during calibration. 
(Note: If a sampling nozzle is part of the assembly, a wind tunnel 
demonstration shall be performed that shows the probe's ability to 
measure velocity and yaw null is not impaired when the nozzle is drawing 
a sample.) The calibration procedure involves generating two calibration 
curves, F1 versus pitch angle and F2 versus pitch 
angle. To generate these two curves, F1 and F2 
shall be derived using Equations 2F-1 and 2F-2, below. Table 2F-8 
provides an example wind tunnel calibration data sheet, used to log the 
measurements needed to derive these two calibration curves.
    10.6.1  Calibration velocities. The tester may calibrate the probe 
at two nominal wind tunnel velocity settings of 18.3 m/sec and 27.4 m/
sec (60 ft/sec and 90 ft/sec) and average the results of these 
calibrations, as described in section 10.6.16.1, in order to generate a 
set of calibration curves. If this option is selected, this single set 
of calibration curves may be used for all field applications over the 
entire velocity range allowed by the method. Alternatively, the tester 
may customize the probe calibration for a particular field test 
application (or for a series of applications), based on the expected 
average velocity(ies) at the test site(s). If this option is selected, 
generate each set of calibration curves by calibrating the probe at two 
nominal wind tunnel velocity settings, at least one of which is greater 
than or equal to the expected average velocity(ies) for the field 
application(s), and average the results as described in section 
10.6.16.1. Whichever calibration option is selected, the probe 
calibration coefficients (F2 values) obtained at the two 
nominal calibration velocities shall, for the same pitch angle setting, 
meet the conditions specified in section 10.6.16.
    10.6.2  Pitch angle calibration curve (F1 versus pitch 
angle). The pitch angle calibration involves generating a calibration 
curve of calculated F1 values versus tested pitch angles, 
where F1 is the ratio of the pitch pressure to the velocity 
pressure, i.e.,
[GRAPHIC] [TIFF OMITTED] TR14MY99.049

See Figure 2F-14 for an example F1 versus pitch angle 
calibration curve.
    10.6.3  Velocity calibration curve (F2 versus pitch 
angle). The velocity calibration involves generating a calibration curve 
of the 3-D probe's F2 coefficient against the tested pitch 
angles, where
[GRAPHIC] [TIFF OMITTED] TR14MY99.050

and

Cp = calibration pitot tube coefficient, and
Pstd = velocity pressure from the calibration pitot 
          tube.

See Figure 2F-15 for an example F2 versus pitch angle 
calibration curve.
    10.6.4  Connect the tested probe and calibration pitot probe to 
their respective pressure-measuring devices. Zero the pressure-measuring 
devices. Inspect and leak-check all pitot lines; repair or replace, if 
necessary. Turn on the fan, and allow the wind tunnel air flow to 
stabilize at the first of the two selected nominal velocity settings.
    10.6.5  Position the calibration pitot tube at its measurement 
location (determined as outlined in section 6.11.4.3), and align the 
tube so that its tip is pointed directly into the flow. Ensure that the 
entry port surrounding the tube is properly sealed. The calibration 
pitot tube may either remain in the wind tunnel throughout the 
calibration, or be removed from the wind tunnel while measurements are 
taken with the probe being calibrated.
    10.6.6  Set up the pitch protractor plate on the tested probe's 
entry port to establish the pitch angle positions of the probe to within 
2 deg..
    10.6.7  Check the zero setting of each pressure-measuring device.
    10.6.8  Insert the tested probe into the wind tunnel and align it so 
that its P1 pressure port is pointed directly into the flow 
and is positioned within the calibration location (as defined in section 
3.20). Secure the probe at the 0 deg. pitch angle position. Ensure that 
the entry port surrounding the probe is properly sealed.
    10.6.9  Read the differential pressure from the calibration pitot 
tube (Pstd), and record its value. Read the 
barometric pressure to within 2.5 mm Hg (0.1 in. 
Hg) and the temperature in the wind tunnel to within 0.6 deg.C 
(1 deg.F). Record these values on a data form similar to Table 2F-8.
    10.6.10  After the tested probe's differential pressure gauges have 
had sufficient time to stabilize, yaw null the probe, then obtain 
differential pressure readings for (P1-P2) and 
(P4-P5). Record the yaw angle and differential 
pressure readings. After taking these readings, ensure that the tested 
probe has remained at the yaw-null position.
    10.6.11  Either take paired differential pressure measurements with 
both the calibration pitot tube and tested probe (according to sections 
10.6.9 and 10.6.10) or take readings only with the tested probe 
(according to section 10.6.10) in 5 deg. increments over the pitch-angle 
range for which the probe is

[[Page 637]]

to be calibrated. The calibration pitch-angle range shall be symmetric 
around 0 deg. and shall exceed the largest pitch angle expected in the 
field by 5 deg.. At a minimum, probes shall be calibrated over the range 
of -15 deg. to +15 deg.. If paired calibration pitot tube and tested 
probe measurements are not taken at each pitch angle setting, the 
differential pressure from the calibration pitot tube shall be read, at 
a minimum, before taking the tested probe's differential pressure 
reading at the first pitch angle setting and after taking the tested 
probe's differential pressure readings at the last pitch angle setting 
in each replicate.
    10.6.12  Perform a second replicate of the procedures in sections 
10.6.5 through 10.6.11 at the same nominal velocity setting.
    10.6.13  For each replicate, calculate the F1 and 
F2 values at each pitch angle. At each pitch angle, calculate 
the percent difference between the two F2 values using 
Equation 2F-3.
[GRAPHIC] [TIFF OMITTED] TR14MY99.051

    If the percent difference is less than or equal to 2 percent, 
calculate an average F1 value and an average F2 
value at that pitch angle. If the percent difference is greater than 2 
percent and less than or equal to 5 percent, perform a third repetition 
at that angle and calculate an average F1 value and an 
average F2 value using all three repetitions. If the percent 
difference is greater than 5 percent, perform four additional 
repetitions at that angle and calculate an average F1 value 
and an average F2 value using all six repetitions. When 
additional repetitions are required at any pitch angle, move the probe 
by at least 5 deg. and then return to the specified pitch angle before 
taking the next measurement. Record the average values on a form similar 
to Table 2F-9.
    10.6.14  Repeat the calibration procedures in sections 10.6.5 
through 10.6.13 at the second selected nominal wind tunnel velocity 
setting.
    10.6.15  Velocity drift check. The following check shall be 
performed, except when paired calibration pitot tube and tested probe 
pressure measurements are taken at each pitch angle setting. At each 
velocity setting, calculate the percent difference between consecutive 
differential pressure measurements made with the calibration pitot tube. 
If a measurement differs from the previous measurement by more than 2 
percent or 0.25 mm H2O (0.01 in. H2O), whichever 
is less restrictive, the calibration data collected between these 
calibration pitot tube measurements may not be used, and the 
measurements shall be repeated.
    10.6.16  Compare the averaged F2 coefficients obtained 
from the calibrations at the two selected nominal velocities, as 
follows. At each pitch angle setting, use Equation 2F-3 to calculate the 
difference between the corresponding average F2 values at the 
two calibration velocities. At each pitch angle in the -15 deg. to 
+15 deg. range, the percent difference between the average F2 
values shall not exceed 3.0 percent. For pitch angles outside this range 
(i.e., less than -15 deg.0 and greater than +15 deg.), the percent 
difference shall not exceed 5.0 percent.
    10.6.16.1  If the applicable specification in section 10.6.16 is met 
at each pitch angle setting, average the results obtained at the two 
nominal calibration velocities to produce a calibration record of 
F1 and F2 at each pitch angle tested. Record these 
values on a form similar to Table 2F-9. From these values, generate one 
calibration curve representing F1 versus pitch angle and a 
second curve representing F2 versus pitch angle. Computer 
spreadsheet programs may be used to graph the calibration data and to 
develop polynomial equations that can be used to calculate pitch angles 
and axial velocities.
    10.6.16.2  If the applicable specification in section 10.6.16 is 
exceeded at any pitch angle setting, the probe shall not be used unless: 
(1) the calibration is repeated at that pitch angle and acceptable 
results are obtained or (2) values of F1 and F2 
are obtained at two nominal velocities for which the specifications in 
section 10.6.16 are met across the entire pitch angle range.
    10.7  Recalibration. Recalibrate the probe using the procedures in 
section 10 either within 12 months of its first field use after its most 
recent calibration or after 10 field tests (as defined in section 3.4), 
whichever occurs later. In addition, whenever there is visible damage to 
the 3-D head, the probe shall be recalibrated before it is used again.
    10.8  Calibration of pressure-measuring devices used in field tests. 
Before its initial use in a field test, calibrate each pressure-
measuring device (except those used exclusively for yaw nulling) using 
the three-point calibration procedure described in section 10.3.3. The 
device shall be recalibrated according to the procedure in section 
10.3.3 no later than 90 days after its first field use following its 
most recent calibration. At the discretion of the tester, more frequent 
calibrations (e.g., after a field test) may be performed. No 
adjustments, other than adjustments to the zero setting, shall be made 
to the device between calibrations.
    10.8.1  Post-test calibration check. A single-point calibration 
check shall be performed on each pressure-measuring device after 
completion of each field test. At the discretion of the tester, more 
frequent single-point calibration checks (e.g., after one or more field 
test runs) may be performed. It is recommended that the post-test check 
be

[[Page 638]]

performed before leaving the field test site. The check shall be 
performed at a pressure between 50 and 90 percent of full scale by 
taking a common pressure reading with the tested device and a reference 
pressure-measuring device (as described in section 6.4.4) or by 
challenging the tested device with a reference pressure source (as 
described in section 6.4.4) or by performing an equivalent check using a 
reference device approved by the Administrator.
    10.8.2  Acceptance criterion. At the selected pressure setting, the 
pressure readings made using the reference device and the tested device 
shall agree to within 3 percent of full scale of the tested device or 
0.8 mm H2O (0.03 in. H2O), whichever is less 
restrictive. If this specification is met, the test data collected 
during the field test are valid. If the specification is not met, all 
test data collected since the last successful calibration or calibration 
check are invalid and shall be repeated using a pressure-measuring 
device with a current, valid calibration. Any device that fails the 
calibration check shall not be used in a field test until a successful 
recalibration is performed according to the procedures in section 
10.3.3.
    10.9  Temperature Gauges. Same as Method 2, section 4.3. The 
alternative thermocouple calibration procedures outlined in Emission 
Measurement Center (EMC) Approved Alternative Method (ALT-011) 
``Alternative Method 2 Thermocouple Calibration Procedure'' may be 
performed. Temperature gauges shall be calibrated no more than 30 days 
prior to the start of a field test or series of field tests and 
recalibrated no more than 30 days after completion of a field test or 
series of field tests.
    10.10  Barometer. Same as Method 2, section 4.4. The barometer shall 
be calibrated no more than 30 days prior to the start of a field test or 
series of field tests.

                       11.0  Analytical Procedure

    Sample collection and analysis are concurrent for this method (see 
section 8.0).

                  12.0  Data Analysis and Calculations

    These calculations use the measured yaw angle, derived pitch angle, 
and the differential pressure and temperature measurements at individual 
traverse points to derive the axial flue gas velocity (va(i)) 
at each of those points. The axial velocity values at all traverse 
points that comprise a full stack or duct traverse are then averaged to 
obtain the average axial flue gas velocity (va (avg)). Round 
off figures only in the final calculation of reported values.

                           12.1  Nomenclature

A = Cross-sectional area of stack or duct, m \2\ (ft \2\).
Bws = Water vapor in the gas stream (from Method 4 or 
          alternative), proportion by volume.
Kp Conversion factor (a constant),
[GRAPHIC] [TIFF OMITTED] TR14MY99.052

for the metric system, and
[GRAPHIC] [TIFF OMITTED] TR14MY99.053

for the English system.

Md = Molecular weight of stack or duct gas, dry basis (see 
          section 8.13), g/g-mole (lb/lb-mole).
Ms = Molecular weight of stack or duct gas, wet basis, g/g-
          mole (lb/lb-mole).
          [GRAPHIC] [TIFF OMITTED] TR14MY99.054
          
Pbar = Barometric pressure at measurement site, mm Hg (in. 
          Hg).
Pg = Stack or duct static pressure, mm H2O (in. 
          H2O).
Ps = Absolute stack or duct pressure, mm Hg (in. Hg),
[GRAPHIC] [TIFF OMITTED] TR14MY99.055

Pstd = Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
13.6 = Conversion from mm H2O (in. H2O) to mm Hg 
          (in. Hg).
Qsd = Average dry-basis volumetric stack or duct gas flow 
          rate corrected to standard conditions, dscm/hr (dscf/hr).
Qsw = Average wet-basis volumetric stack or duct gas flow 
          rate corrected to standard conditions, wscm/hr (wscf/hr).
Ts(avg) = Average absolute stack or duct gas temperature 
          across all traverse points.
ts(i) = Stack or duct gas temperature, C (F), at traverse 
          point i.
Ts(i) = Absolute stack or duct gas temperature, K (R), at 
          traverse point i,
          [GRAPHIC] [TIFF OMITTED] TR14MY99.056
          
for the metric system, and
[GRAPHIC] [TIFF OMITTED] TR14MY99.057

for the English system.
Tstd = Standard absolute temperature, 293 deg.K (528 deg.R).
F1(i) = Pitch angle ratio, applicable at traverse point i, 
          dimensionless.
F2(i) = 3-D probe velocity calibration coefficient, 
          applicable at traverse point i, dimensionless.

[[Page 639]]

(P4-P5)i = Pitch differential pressure 
          of stack or duct gas flow, mm H2O (in. 
          H2O), at traverse point i.
(P1-P2)i = Velocity head (differential 
          pressure) of stack or duct gas flow, mm H2O (in. 
          H2O), at traverse point i.
va(i) = Reported stack or duct gas axial velocity, m/sec (ft/
          sec), at traverse point i.
va(avg) = Average stack or duct gas axial velocity, m/sec 
          (ft/sec), across all traverse points.
3,600 = Conversion factor, sec/hr.
18.0 = Molecular weight of water, g/g-mole (lb/lb-mole).
y(i) = Yaw angle, degrees, at traverse point i.
p(i) = Pitch angle, degrees, at traverse point i.
n = Number of traverse points.

    12.2  Traverse Point Velocity Calculations. Perform the following 
calculations from the measurements obtained at each traverse point.
    12.2.1  Selection of calibration curves. Select calibration curves 
as described in section 10.6.1.
    12.2.2  Traverse point pitch angle ratio. Use Equation 2F-1, as 
described in section 10.6.2, to calculate the pitch angle ratio, 
F1(i), at each traverse point.
    12.2.3  Pitch angle. Use the pitch angle ratio, F1(i), to 
derive the pitch angle, p(i), at traverse point i 
from the F1 versus pitch angle calibration curve generated 
under section 10.6.16.1.
    12.2.4  Velocity calibration coefficient. Use the pitch angle, 
p(i), to obtain the probe velocity calibration 
coefficient, F2(i), at traverse point i from the ``velocity 
pressure calibration curve,'' i.e., the F2 versus pitch angle 
calibration curve generated under section 10.6.16.1.
    12.2.5  Axial velocity. Use the following equation to calculate the 
axial velocity, va(i), from the differential pressure 
(P1-P2)i and yaw angle, 
y(i), measured at traverse point i and the 
previously calculated values for the velocity calibration coefficient, 
F2(i), absolute stack or duct standard temperature, 
Ts(i), absolute stack or duct pressure, Ps, 
molecular weight, Ms, and pitch angle, 
``p(i).
[GRAPHIC] [TIFF OMITTED] TR14MY99.058

    12.2.6  Handling multiple measurements at a traverse point. For 
pressure or temperature devices that take multiple measurements at a 
traverse point, the multiple measurements (or where applicable, their 
square roots) may first be averaged and the resulting average values 
used in the equations above. Alternatively, the individual measurements 
may be used in the equations above and the resulting multiple calculated 
values may then be averaged to obtain a single traverse point value. 
With either approach, all of the individual measurements recorded at a 
traverse point must be used in calculating the applicable traverse point 
value.
    12.3  Average Axial Velocity in Stack or Duct. Use the reported 
traverse point axial velocity in the following equation.
[GRAPHIC] [TIFF OMITTED] TR14MY99.059

    12.4  Acceptability of Results. The test results are acceptable and 
the calculated value of va(avg) may be reported as the 
average axial velocity for the test run if the conditions in either 
section 12.4.1 or 12.4.2 are met.
    12.4.1  The calibration curves were generated at nominal velocities 
of 18.3 m/sec and 27.4 m/sec (60 ft/sec and 90 ft/sec).
    12.4.2  The calibration curves were generated at nominal velocities 
other than 18.3 m/sec and 27.4 m/sec (60 ft/sec and 90 ft/sec), and the 
value of va(avg) obtained using Equation 2F-9 is less than or 
equal to at least one of the nominal velocities used to derive the 
F1 and F2 calibration curves.
    12.4.3  If the conditions in neither section 12.4.1 nor section 
12.4.2 are met, the test results obtained in Equation 2F-9 are not 
acceptable, and the steps in sections 12.2 and 12.3 must be repeated 
using a set of F1 and F2 calibration curves that 
satisfies the conditions specified in section 12.4.1 or 12.4.2.
    12.5  Average Gas Wet Volumetric Flow Rate in Stack or Duct. Use the 
following equation to compute the average volumetric flow rate on a wet 
basis.

[[Page 640]]

[GRAPHIC] [TIFF OMITTED] TR14MY99.060

    12.6  Average Gas Dry Volumetric Flow Rate in Stack or Duct. Use the 
following equation to compute the average volumetric flow rate on a dry 
basis.
[GRAPHIC] [TIFF OMITTED] TR14MY99.061

                  13.0  Method Performance. [Reserved]

                 14.0  Pollution Prevention. [Reserved]

                   15.0  Waste Management. [Reserved]

                             16.0  Reporting

    16.1  Field Test Reports. Field test reports shall be submitted to 
the Agency according to applicable regulatory requirements. Field test 
reports should, at a minimum, include the following elements.
    16.1.1  Description of the source. This should include the name and 
location of the test site, descriptions of the process tested, a 
description of the combustion source, an accurate diagram of stack or 
duct cross-sectional area at the test site showing the dimensions of the 
stack or duct, the location of the test ports, and traverse point 
locations and identification numbers or codes. It should also include a 
description and diagram of the stack or duct layout, showing the 
distance of the test location from the nearest upstream and downstream 
disturbances and all structural elements (including breachings, baffles, 
fans, straighteners, etc.) affecting the flow pattern. If the source and 
test location descriptions have been previously submitted to the Agency 
in a document (e.g., a monitoring plan or test plan), referencing the 
document in lieu of including this information in the field test report 
is acceptable.
    16.1.2  Field test procedures. These should include a description of 
test equipment and test procedures. Testing conventions, such as 
traverse point numbering and measurement sequence (e.g., sampling from 
center to wall, or wall to center), should be clearly stated. Test port 
identification and directional reference for each test port should be 
included on the appropriate field test data sheets.
    16.1.3  Field test data.
    16.1.3.1  Summary of results. This summary should include the dates 
and times of testing and the average axial gas velocity and the average 
flue gas volumetric flow results for each run and tested condition.
    16.1.3.2  Test data. The following values for each traverse point 
should be recorded and reported:

    (a) P1-P2 and P4-P5 
differential pressures
    (b) Stack or duct gas temperature at traverse point i 
(ts(i))
    (c) Absolute stack or duct gas temperature at traverse point i 
(Ts(i))
    (d) Yaw angle at each traverse point i (y(i))
    (e) Pitch angle at each traverse point i (p(i))
    (f) Stack or duct gas axial velocity at traverse point i 
(va(i))

    16.1.3.3  The following values should be reported once per run:

    (a) Water vapor in the gas stream (from Method 4 or alternative), 
proportion by volume (Bws), measured at the frequency 
specified in the applicable regulation
    (b) Molecular weight of stack or duct gas, dry basis (Md)
    (c) Molecular weight of stack or duct gas, wet basis (Ms)
    (d) Stack or duct static pressure (Pg)
    (e) Absolute stack or duct pressure (Ps)
    (f) Carbon dioxide concentration in the flue gas, dry basis (\0/
0\d CO2)
    (g) Oxygen concentration in the flue gas, dry basis (\0/
0\d O2)
    (h) Average axial stack or duct gas velocity (va(avg)) 
across all traverse points
    (i) Gas volumetric flow rate corrected to standard conditions, dry 
or wet basis as required by the applicable regulation (Qsd or 
Qsw)

16.1.3.4  The following should be reported once per complete set of test 
runs:

    (a) Cross-sectional area of stack or duct at the test location (A)
    (b) Measurement system response time (sec)
    (c) Barometric pressure at measurement site (Pbar)

    16.1.4  Calibration data. The field test report should include 
calibration data for all probes and test equipment used in the field

[[Page 641]]

test. At a minimum, the probe calibration data reported to the Agency 
should include the following:

    (a) Date of calibration
    (b) Probe type
    (c) Probe identification number(s) or code(s)
    (d) Probe inspection sheets
    (e) Pressure measurements and intermediate calculations of 
F1 and F2 at each pitch angle used to obtain 
calibration curves in accordance with section 10.6 of this method
    (f) Calibration curves (in graphic or equation format) obtained in 
accordance with sections 10.6.11 of this method
    (g) Description and diagram of wind tunnel used for the calibration, 
including dimensions of cross-sectional area and position and size of 
the test section
    (h) Documentation of wind tunnel qualification tests performed in 
accordance with section 10.1 of this method

    16.1.5  Quality Assurance. Specific quality assurance and quality 
control procedures used during the test should be described.

                           17.0  Bibliography

    (1) 40 CFR Part 60, Appendix A, Method 1--Sample and velocity 
traverses for stationary sources.
    (2) 40 CFR Part 60, Appendix A, Method 2H--Determination of stack 
gas velocity taking into account velocity decay near the stack wall.
    (3) 40 CFR Part 60, Appendix A, Method 2--Determination of stack gas 
velocity and volumetric flow rate (Type S pitot tube).
    (4) 40 CFR Part 60, Appendix A, Method 3--Gas analysis for carbon 
dioxide, oxygen, excess air, and dry molecular weight.
    (5) 40 CFR Part 60, Appendix A, Method 3A--Determination of oxygen 
and carbon dioxide concentrations in emissions from stationary sources 
(instrumental analyzer procedure).
    (6) 40 CFR Part 60, Appendix A, Method 4--Determination of moisture 
content in stack gases.
    (7) Emission Measurement Center (EMC) Approved Alternative Method 
(ALT-011) ``Alternative Method 2 Thermocouple Calibration Procedure.''
    (8) Electric Power Research Institute, Interim Report EPRI TR-
106698, ``Flue Gas Flow Rate Measurement Errors,'' June 1996.
    (9) Electric Power Research Institute, Final Report EPRI TR-108110, 
``Evaluation of Heat Rate Discrepancy from Continuous Emission 
Monitoring Systems,'' August 1997.
    (10) Fossil Energy Research Corporation, Final Report, ``Velocity 
Probe Tests in Non-axial Flow Fields,'' November 1998, Prepared for the 
U.S. Environmental Protection Agency.
    (11) Fossil Energy Research Corporation, ``Additional Swirl Tunnel 
Tests: E-DAT and T-DAT Probes,'' February 24, 1999, Technical Memorandum 
Prepared for U.S. Environmental Protection Agency, P.O. No. 7W-1193-
NALX.
    (12) Massachusetts Institute of Technology, Report WBWT-TR-1317, 
``Calibration of Eight Wind Speed Probes Over a Reynolds Number Range of 
46,000 to 725,000 Per Foot, Text and Summary Plots,'' Plus appendices, 
October 15, 1998, Prepared for The Cadmus Group, Inc.
    (13) National Institute of Standards and Technology, Special 
Publication 250, ``NIST Calibration Services Users Guide 1991,'' Revised 
October 1991, U.S. Department of Commerce, p. 2.
    (14) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Four Prandtl Probes, Four 
S-Type Probes, Four French Probes, Four Modified Kiel Probes,'' Prepared 
for the U.S. Environmental Protection Agency under IAG #DW13938432-01-0.
    (15) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Five Autoprobes,'' 
Prepared for the U.S. Environmental Protection Agency under IAG 
#DW13938432-01-0.
    (16) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Eight Spherical Probes,'' 
Prepared for the U.S. Environmental Protection Agency under IAG 
#DW13938432-01-0.
    (17) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Four DAT Probes,'' 
Prepared for the U.S. Environmental Protection Agency under IAG 
#DW13938432-01-0.
    (18) Norfleet, S.K., ``An Evaluation of Wall Effects on Stack Flow 
Velocities and Related Overestimation Bias in EPA's Stack Flow Reference 
Methods,'' EPRI CEMS User's Group Meeting, New Orleans, Louisiana, May 
13-15, 1998.
    (19) Page, J.J., E.A. Potts, and R.T. Shigehara, ``3-D Pitot Tube 
Calibration Study,'' EPA Contract No. 68-D1-0009, Work Assignment No. I-
121, March 11, 1993.
    (20) Shigehara, R.T., W.F. Todd, and W.S. Smith, ``Significance of 
Errors in Stack Sampling Measurements,'' Presented at the Annual Meeting 
of the Air Pollution Control Association, St. Louis, Missouri, June 14-
19, 1970.
    (21) The Cadmus Group, Inc., May 1999, ``EPA Flow Reference Method 
Testing and Analysis: Findings Report,'' EPA/430-R-99-009.
    (22) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Texas Utilities,

[[Page 642]]

DeCordova Steam Electric Station, Volume I: Test Description and 
Appendix A (Data Distribution Package),'' EPA/430-R-98-015a.
    (23) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Texas Utilities, Lake Hubbard Steam 
Electric Station, Volume I: Test Description and Appendix A (Data 
Distribution Package),'' EPA/430-R-98-017a.
    (24) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Pennsylvania Electric Co., G.P.U. 
Genco Homer City Station: Unit 1, Volume I: Test Description and 
Appendix A (Data Distribution Package),'' EPA/430-R-98-018a.
    (25) The Cadmus Group, Inc., 1997, ``EPA Flow Reference Method 
Testing and Analysis: Wind Tunnel Experimental Results,'' EPA/430-R-97-
013.

                              18.0  Annexes

    Annex A, C, and D describe recommended procedures for meeting 
certain provisions in sections 8.3, 10.4, and 10.5 of this method. Annex 
B describes procedures to be followed when using the protractor wheel 
and pointer assembly to measure yaw angles, as provided under section 
8.9.1.
    18.1  Annex A--Rotational Position Check. The following are 
recommended procedures that may be used to satisfy the rotational 
position check requirements of section 8.3 of this method and to 
determine the angle-measuring device rotational offset RADO.
    18.1.1  Rotational position check with probe outside stack. Where 
physical constraints at the sampling location allow full assembly of the 
probe outside the stack and insertion into the test port, the following 
procedures should be performed before the start of testing. Two angle-
measuring devices that meet the specifications in section 6.2.1 or 6.2.3 
are required for the rotational position check. An angle measuring 
device whose position can be independently adjusted (e.g., by means of a 
set screw) after being locked into position on the probe sheath shall 
not be used for this check unless the independent adjustment is set so 
that the device performs exactly like a device without the capability 
for independent adjustment. That is, when aligned on the probe such a 
device must give the same reading as a device that does not have the 
capability of being independently adjusted. With the fully assembled 
probe (including probe shaft extensions, if any) secured in a horizontal 
position, affix one yaw angle-measuring device to the probe sheath and 
lock it into position on the reference scribe line specified in section 
6.1.6.1. Position the second angle-measuring device using the procedure 
in section 18.1.1.1 or 18.1.1.2.
    18.1.1.1  Marking procedure. The procedures in this section should 
be performed at each location on the fully assembled probe where the yaw 
angle-measuring device will be mounted during the velocity traverse. 
Place the second yaw angle-measuring device on the main probe sheath (or 
extension) at the position where a yaw angle will be measured during the 
velocity traverse. Adjust the position of the second angle-measuring 
device until it indicates the same angle (1 deg.) as the 
reference device, and affix the second device to the probe sheath (or 
extension). Record the angles indicated by the two angle-measuring 
devices on a form similar to Table 2F-2. In this position, the second 
angle-measuring device is considered to be properly positioned for yaw 
angle measurement. Make a mark, no wider than 1.6 mm (1/16 in.), on the 
probe sheath (or extension), such that the yaw angle-measuring device 
can be re-affixed at this same properly aligned position during the 
velocity traverse.
    18.1.1.2  Procedure for probe extensions with scribe lines. If, 
during a velocity traverse the angle-measuring device will be affixed to 
a probe extension having a scribe line as specified in section 6.1.6.2, 
the following procedure may be used to align the extension's scribe line 
with the reference scribe line instead of marking the extension as 
described in section 18.1.1.1. Attach the probe extension to the main 
probe. Align and lock the second angle-measuring device on the probe 
extension's scribe line. Then, rotate the extension until both measuring 
devices indicate the same angle (1 deg.). Lock the extension 
at this rotational position. Record the angles indicated by the two 
angle-measuring devices on a form similar to Table 2F-2. An angle-
measuring device may be aligned at any position on this scribe line 
during the velocity traverse, if the scribe line meets the alignment 
specification in section 6.1.6.3.
    18.1.1.3  Post-test rotational position check. If the fully 
assembled probe includes one or more extensions, the following check 
should be performed immediately after the completion of a velocity 
traverse. At the discretion of the tester, additional checks may be 
conducted after completion of testing at any sample port. Without 
altering the alignment of any of the components of the probe assembly 
used in the velocity traverse, secure the fully assembled probe in a 
horizontal position. Affix an angle-measuring device at the reference 
scribe line specified in section 6.1.6.1. Use the other angle-measuring 
device to check the angle at each location where the device was checked 
prior to testing. Record the readings from the two angle-measuring 
devices.
    18.1.2  Rotational position check with probe in stack. This section 
applies only to

[[Page 643]]

probes that, due to physical constraints, cannot be inserted into the 
test port as fully assembled with all necessary extensions needed to 
reach the inner-most traverse point(s).
    18.1.2.1  Perform the out-of-stack procedure in section 18.1.1 on 
the main probe and any attached extensions that will be initially 
inserted into the test port.
    18.1.2.2  Use the following procedures to perform additional 
rotational position check(s) with the probe in the stack, each time a 
probe extension is added. Two angle-measuring devices are required. The 
first of these is the device that was used to measure yaw angles at the 
preceding traverse point, left in its properly aligned measurement 
position. The second angle-measuring device is positioned on the added 
probe extension. Use the applicable procedures in section 18.1.1.1 or 
18.1.1.2 to align, adjust, lock, and mark (if necessary) the position of 
the second angle-measuring device to within 1 deg. of the 
first device. Record the readings of the two devices on a form similar 
to Table 2F-2.
    18.1.2.3  The procedure in section 18.1.2.2 should be performed at 
the first port where measurements are taken. The procedure should be 
repeated each time a probe extension is re-attached at a subsequent 
port, unless the probe extensions are designed to be locked into a 
mechanically fixed rotational position (e.g., through use of 
interlocking grooves), which can be reproduced from port to port as 
specified in section 8.3.5.2.
    18.2  Annex B--Angle Measurement Protocol for Protractor Wheel and 
Pointer Device. The following procedure shall be used when a protractor 
wheel and pointer assembly, such as the one described in section 6.2.2 
and illustrated in Figure 2F-7 is used to measure the yaw angle of flow. 
With each move to a new traverse point, unlock, re-align, and re-lock 
the probe, angle-pointer collar, and protractor wheel to each other. At 
each such move, particular attention is required to ensure that the 
scribe line on the angle pointer collar is either aligned with the 
reference scribe line on the main probe sheath or is at the rotational 
offset position established under section 8.3.1. The procedure consists 
of the following steps:
    18.2.1  Affix a protractor wheel to the entry port for the test 
probe in the stack or duct.
    18.2.2  Orient the protractor wheel so that the 0 deg. mark 
corresponds to the longitudinal axis of the stack or duct. For stacks, 
vertical ducts, or ports on the side of horizontal ducts, use a digital 
inclinometer meeting the specifications in section 6.2.1 to locate the 
0 deg. orientation. For ports on the top or bottom of horizontal ducts, 
identify the longitudinal axis at each test port and permanently mark 
the duct to indicate the 0 deg. orientation. Once the protractor wheel 
is properly aligned, lock it into position on the test port.
    18.2.3  Move the pointer assembly along the probe sheath to the 
position needed to take measurements at the first traverse point. Align 
the scribe line on the pointer collar with the reference scribe line or 
at the rotational offset position established under section 8.3.1. 
Maintaining this rotational alignment, lock the pointer device onto the 
probe sheath. Insert the probe into the entry port to the depth needed 
to take measurements at the first traverse point.
    18.2.4  Perform the yaw angle determination as specified in sections 
8.9.3 and 8.9.4 and record the angle as shown by the pointer on the 
protractor wheel. Then, take velocity pressure and temperature 
measurements in accordance with the procedure in section 8.9.5. Perform 
the alignment check described in section 8.9.6.
    18.2.5  After taking velocity pressure measurements at that traverse 
point, unlock the probe from the collar and slide the probe through the 
collar to the depth needed to reach the next traverse point.
    18.2.6  Align the scribe line on the pointer collar with the 
reference scribe line on the main probe or at the rotational offset 
position established under section 8.3.1. Lock the collar onto the 
probe.
    18.2.7  Repeat the steps in sections 18.2.4 through 18.2.6 at the 
remaining traverse points accessed from the current stack or duct entry 
port.
    18.2.8  After completing the measurement at the last traverse point 
accessed from a port, verify that the orientation of the protractor 
wheel on the test port has not changed over the course of the traverse 
at that port. For stacks, vertical ducts, or ports on the side of 
horizontal ducts, use a digital inclinometer meeting the specifications 
in section 6.2.1 to check the rotational position of the 0 deg. mark on 
the protractor wheel. For ports on the top or bottom of horizontal 
ducts, observe the alignment of the angle wheel 0 deg. mark relative to 
the permanent 0 deg. mark on the duct at that test port. If these 
observed comparisons exceed 2 deg. of 0 deg., all angle and 
pressure measurements taken at that port since the protractor wheel was 
last locked into position on the port shall be repeated.
    18.2.9  Move to the next stack or duct entry port and repeat the 
steps in sections 18.2.1 through 18.2.8.
    18.3  Annex C--Guideline for Reference Scribe Line Placement. Use of 
the following guideline is recommended to satisfy the requirements of 
section 10.4 of this method. The rotational position of the reference 
scribe line should be either 90 deg. or 180 deg. from the probe's impact 
pressure port.
    18.4  Annex D--Determination of Reference Scribe Line Rotational 
Offset. The following procedures are recommended for determining the 
magnitude and sign of a

[[Page 644]]

probe's reference scribe line rotational offset, RSLO. 
Separate procedures are provided for two types of angle-measuring 
devices: digital inclinometers and protractor wheel and pointer 
assemblies.
    18.4.1  Perform the following procedures on the main probe with all 
devices that will be attached to the main probe in the field [such as 
thermocouples or resistance temperature detectors (RTDs)] that may 
affect the flow around the probe head. Probe shaft extensions that do 
not affect flow around the probe head need not be attached during 
calibration.
    18.4.2  The procedures below assume that the wind tunnel duct used 
for probe calibration is horizontal and that the flow in the calibration 
wind tunnel is axial as determined by the axial flow verification check 
described in section 10.1.2. Angle-measuring devices are assumed to 
display angles in alternating 0 deg. to 90 deg. and 90 deg. to 0 deg. 
intervals. If angle-measuring devices with other readout conventions are 
used or if other calibration wind tunnel duct configurations are used, 
make the appropriate calculational corrections.
    18.4.2.1  Position the angle-measuring device in accordance with one 
of the following procedures.
    18.4.2.1.1  If using a digital inclinometer, affix the calibrated 
digital inclinometer to the probe. If the digital inclinometer can be 
independently adjusted after being locked into position on the probe 
sheath (e.g., by means of a set screw), the independent adjustment must 
be set so that the device performs exactly like a device without the 
capability for independent adjustment. That is, when aligned on the 
probe the device must give the same readings as a device that does not 
have the capability of being independently adjusted. Either align it 
directly on the reference scribe line or on a mark aligned with the 
scribe line determined according to the procedures in section 18.1.1.1. 
Maintaining this rotational alignment, lock the digital inclinometer 
onto the probe sheath.
    18.4.2.1.2  If using a protractor wheel and pointer device, orient 
the protractor wheel on the test port so that the 0 deg. mark is aligned 
with the longitudinal axis of the wind tunnel duct. Maintaining this 
alignment, lock the wheel into place on the wind tunnel test port. Align 
the scribe line on the pointer collar with the reference scribe line or 
with a mark aligned with the reference scribe line, as determined under 
section 18.1.1.1. Maintaining this rotational alignment, lock the 
pointer device onto the probe sheath.
    18.4.2.2  Zero the pressure-measuring device used for yaw nulling.
    18.4.2.3  Insert the probe assembly into the wind tunnel through the 
entry port, positioning the probe's impact port at the calibration 
location. Check the responsiveness of the pressure-measuring device to 
probe rotation, taking corrective action if the response is 
unacceptable.
    18.4.2.4  Ensure that the probe is in a horizontal position using a 
carpenter's level.
    18.4.2.5  Rotate the probe either clockwise or counterclockwise 
until a yaw null (P2=P3) is obtained.
    18.4.2.6  Read and record the value of null, 
the angle indicated by the angle-measuring device at the yaw-null 
position. Record the angle reading on a form similar to Table 2F-6. Do 
not associate an algebraic sign with this reading.
    18.4.2.7  Determine the magnitude and algebraic sign of the 
reference scribe line rotational offset, RSLO. The magnitude 
of RSLO will be equal to either null or 
(90 deg.-null), depending on the angle-measuring 
device used. (See Table 2F-7 for a summary.) The algebraic sign of 
RSLO will either be positive, if the rotational position of 
the reference scribe line is clockwise, or negative, if counterclockwise 
with respect to the probe's yaw-null position. Figure 2F-13 illustrates 
how the magnitude and sign of RSLO are determined.
    18.4.2.8  Perform the steps in sections 18.4.2.3 through 18.4.2.7 
twice at each of the two calibration velocities selected for the probe 
under section 10.6. Record the values of RSLO in a form 
similar to Table 2F-6.
    18.4.2.9  The average of all RSLO values is the reference 
scribe line rotational offset for the probe.


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[[Page 664]]



Method 2G--Determination of Stack Gas Velocity and Volumetric Flow Rate 
                       With Two-Dimensional Probes

    Note: This method does not include all of the specifications (e.g., 
equipment and supplies) and procedures (e.g., sampling) essential to its 
performance. Some material has been incorporated from other methods in 
this part. Therefore, to obtain reliable results, those using this 
method should have a thorough knowledge of at least the following 
additional test methods: Methods 1, 2, 3 or 3A, and 4.

                       1.0  Scope and Application

    1.1  This method is applicable for the determination of yaw angle, 
near-axial velocity, and the volumetric flow rate of a gas stream in a 
stack or duct using a two-dimensional (2-D) probe.

                         2.0  Summary of Method

2.1  A 2-D probe is used to measure the velocity pressure and the yaw 
angle of the flow velocity vector in a stack or duct. Alternatively, 
these measurements may be made by operating one of the three-dimensional 
(3-D) probes described in Method 2F, in yaw determination mode only. 
From these measurements and a determination of the stack gas density, 
the average near-axial velocity of the stack gas is calculated. The 
near-axial velocity accounts for the yaw, but not the pitch, component 
of flow. The average gas volumetric flow rate in the stack or duct is 
then determined from the average near-axial velocity.

                            3.0  Definitions

    3.1.  Angle-measuring Device Rotational Offset (RADO). 
The rotational position of an angle-measuring device relative to the 
reference scribe line, as determined during the pre-test rotational 
position check described in section 8.3.
    3.2  Calibration Pitot Tube. The standard (Prandtl type) pitot tube 
used as a reference when calibrating a probe under this method.
    3.3  Field Test. A set of measurements conducted at a specific unit 
or exhaust stack/duct to satisfy the applicable regulation (e.g., a 
three-run boiler performance test, a single-or multiple-load nine-run 
relative accuracy test).
    3.4  Full Scale of Pressure-measuring Device. Full scale refers to 
the upper limit of the measurement range displayed by the device. For 
bi-directional pressure gauges, full scale includes the entire pressure 
range from the lowest negative value to the highest positive value on 
the pressure scale.
    3.5  Main probe. Refers to the probe head and that section of probe 
sheath directly attached to the probe head. The main probe sheath is 
distinguished from probe extensions, which are sections of sheath added 
onto the main probe to extend its reach.
    3.6 ``May,'' ``Must,'' ``Shall,'' ``Should,'' and the imperative 
form of verbs.
    3.6.1 ``May'' is used to indicate that a provision of this method is 
optional.
    3.6.2 ``Must,'' ``Shall,'' and the imperative form of verbs (such as 
``record'' or ``enter'') are used to indicate that a provision of this 
method is mandatory.
    3.6.3 ``Should'' is used to indicate that a provision of this method 
is not mandatory, but is highly recommended as good practice.
    3.7 Method 1. Refers to 40 CFR part 60, appendix A, ``Method 1--
Sample and velocity traverses for stationary sources.''
    3.8 Method 2. Refers to 40 CFR part 60, appendix A, ``Method 2--
Determination of stack gas velocity and volumetric flow rate (Type S 
pitot tube).''
    3.9 Method 2F. Refers to 40 CFR part 60, appendix A, ``Method 2F--
Determination of stack gas velocity and volumetric flow rate with three-
dimensional probes.''
    3.10 Near-axial Velocity. The velocity vector parallel to the axis 
of the stack or duct that accounts for the yaw angle component of gas 
flow. The term ``near-axial'' is used herein to indicate that the 
velocity and volumetric flow rate results account for the measured yaw 
angle component of flow at each measurement point.
    3.11 Nominal Velocity. Refers to a wind tunnel velocity setting that 
approximates the actual wind tunnel velocity to within 1.5 
m/sec (5 ft/sec).
    3.12 Pitch Angle. The angle between the axis of the stack or duct 
and the pitch component of flow, i.e., the component of the total 
velocity vector in a plane defined by the traverse line and the axis of 
the stack or duct. (Figure 2G-1 illustrates the ``pitch plane.'') From 
the standpoint of a tester facing a test port in a vertical stack, the 
pitch component of flow is the vector of flow moving from the center of 
the stack toward or away from that test port. The pitch angle is the 
angle described by this pitch component of flow and the vertical axis of 
the stack.
    3.13  Readability. For the purposes of this method, readability for 
an analog measurement device is one half of the smallest scale division. 
For a digital measurement device, it is the number of decimals displayed 
by the device.
    3.14  Reference Scribe Line. A line permanently inscribed on the 
main probe sheath (in accordance with section 6.1.5.1) to serve as a 
reference mark for determining yaw angles.
    3.15  Reference Scribe Line Rotational Offset (RSLO). The 
rotational position of a probe's reference scribe line relative to the 
probe's yaw-null position, as determined during the yaw angle 
calibration described in section 10.5.

[[Page 665]]

    3.16  Response Time. The time required for the measurement system to 
fully respond to a change from zero differential pressure and ambient 
temperature to the stable stack or duct pressure and temperature 
readings at a traverse point.
    3.17  Tested Probe. A probe that is being calibrated.
    3.18  Three-dimensional (3-D) Probe. A directional probe used to 
determine the velocity pressure and the yaw and pitch angles in a 
flowing gas stream.
    3.19  Two-dimensional (2-D) Probe. A directional probe used to 
measure velocity pressure and yaw angle in a flowing gas stream.
    3.20  Traverse Line. A diameter or axis extending across a stack or 
duct on which measurements of velocity pressure and flow angles are 
made.
    3.21  Wind Tunnel Calibration Location. A point, line, area, or 
volume within the wind tunnel test section at, along, or within which 
probes are calibrated. At a particular wind tunnel velocity setting, the 
average velocity pressures at specified points at, along, or within the 
calibration location shall vary by no more than 2 percent or 0.3 mm 
H20 (0.01 in. H2O), whichever is less restrictive, 
from the average velocity pressure at the calibration pitot tube 
location. Air flow at this location shall be axial, i.e., yaw and pitch 
angles within 3 deg. of 0 deg.. Compliance with these flow 
criteria shall be demonstrated by performing the procedures prescribed 
in sections 10.1.1 and 10.1.2. For circular tunnels, no part of the 
calibration location may be closer to the tunnel wall than 10.2 cm (4 
in.) or 25 percent of the tunnel diameter, whichever is farther from the 
wall. For elliptical or rectangular tunnels, no part of the calibration 
location may be closer to the tunnel wall than 10.2 cm (4 in.) or 25 
percent of the applicable cross-sectional axis, whichever is farther 
from the wall.
    3.22  Wind Tunnel with Documented Axial Flow. A wind tunnel facility 
documented as meeting the provisions of sections 10.1.1 (velocity 
pressure cross-check) and 10.1.2 (axial flow verification) using the 
procedures described in these sections or alternative procedures 
determined to be technically equivalent.
    3.23  Yaw Angle. The angle between the axis of the stack or duct and 
the yaw component of flow, i.e., the component of the total velocity 
vector in a plane perpendicular to the traverse line at a particular 
traverse point. (Figure 2G-1 illustrates the ``yaw plane.'') From the 
standpoint of a tester facing a test port in a vertical stack, the yaw 
component of flow is the vector of flow moving to the left or right from 
the center of the stack as viewed by the tester. (This is sometimes 
referred to as ``vortex flow,'' i.e., flow around the centerline of a 
stack or duct.) The yaw angle is the angle described by this yaw 
component of flow and the vertical axis of the stack. The algebraic sign 
convention is illustrated in Figure 2G-2.
    3.24  Yaw Nulling. A procedure in which a Type-S pitot tube or a 3-D 
probe is rotated about its axis in a stack or duct until a zero 
differential pressure reading (``yaw null'') is obtained. When a Type S 
probe is yaw-nulled, the rotational position of its impact port is 
90 deg. from the direction of flow in the stack or duct and the 
 P reading is zero. When a 3-D probe is yaw-nulled, its impact 
pressure port (P1) faces directly into the direction of flow 
in the stack or duct and the differential pressure between pressure 
ports P2 and P3 is zero.

                     4.0  Interferences. [Reserved]

                               5.0  Safety

    5.1  This test method may involve hazardous operations and the use 
of hazardous materials or equipment. This method does not purport to 
address all of the safety problems associated with its use. It is the 
responsibility of the user to establish and implement appropriate safety 
and health practices and to determine the applicability of regulatory 
limitations before using this test method.

                       6.0  Equipment and Supplies

    6.1  Two-dimensional Probes. Probes that provide both the velocity 
pressure and the yaw angle of the flow vector in a stack or duct, as 
listed in sections 6.1.1 and 6.1.2, qualify for use based on 
comprehensive wind tunnel and field studies involving both inter-and 
intra-probe comparisons by multiple test teams. Each 2-D probe shall 
have a unique identification number or code permanently marked on the 
main probe sheath. Each probe shall be calibrated prior to use according 
to the procedures in section 10. Manufacturer-supplied calibration data 
shall be used as example information only, except when the manufacturer 
calibrates the probe as specified in section 10 and provides complete 
documentation.
    6.1.1  Type S (Stausscheibe or reverse type) pitot tube. This is the 
same as specified in Method 2, section 2.1, except for the following 
additional specifications that enable the pitot tube to accurately 
determine the yaw component of flow. For the purposes of this method, 
the external diameter of the tubing used to construct the Type S pitot 
tube (dimension Dt in Figure 2-2 of Method 2) shall be no 
less than 9.5 mm (3/8 in.). The pitot tube shall also meet the following 
alignment specifications. The angles 1, 
2, 1, and 2, 
as shown in Method 2, Figure 2-3, shall not exceed 2 deg.. 
The dimensions w and z, shown in Method 2, Figure 2-3 shall not exceed 
0.5 mm (0.02 in.).

[[Page 666]]

    6.1.1.1  Manual Type S probe. This refers to a Type S probe that is 
positioned at individual traverse points and yaw nulled manually by an 
operator.
    6.1.1.2  Automated Type S probe. This refers to a system that uses a 
computer-controlled motorized mechanism to position the Type S pitot 
head at individual traverse points and perform yaw angle determinations.
    6.1.2  Three-dimensional probes used in 2-D mode. A 3-D probe, as 
specified in sections 6.1.1 through 6.1.3 of Method 2F, may, for the 
purposes of this method, be used in a two-dimensional mode (i.e., 
measuring yaw angle, but not pitch angle). When the 3-D probe is used as 
a 2-D probe, only the velocity pressure and yaw-null pressure are 
obtained using the pressure taps referred to as P1, 
P2, and P3. The differential pressure 
P1-P2 is a function of total velocity and 
corresponds to the P obtained using the Type S probe. The 
differential pressure P2-P3 is used to yaw null 
the probe and determine the yaw angle. The differential pressure 
P4-P5, which is a function of pitch angle, is not 
measured when the 3-D probe is used in 2-D mode.
    6.1.3  Other probes. [Reserved]
    6.1.4  Probe sheath. The probe shaft shall include an outer sheath 
to: (1) provide a surface for inscribing a permanent reference scribe 
line, (2) accommodate attachment of an angle-measuring device to the 
probe shaft, and (3) facilitate precise rotational movement of the probe 
for determining yaw angles. The sheath shall be rigidly attached to the 
probe assembly and shall enclose all pressure lines from the probe head 
to the farthest position away from the probe head where an angle-
measuring device may be attached during use in the field. The sheath of 
the fully assembled probe shall be sufficiently rigid and straight at 
all rotational positions such that, when one end of the probe shaft is 
held in a horizontal position, the fully extended probe meets the 
horizontal straightness specifications indicated in section 8.2 below.
    6.1.5  Scribe lines.
    6.1.5.1  Reference scribe line. A permanent line, no greater than 
1.6 mm (1/16 in.) in width, shall be inscribed on each manual probe that 
will be used to determine yaw angles of flow. This line shall be placed 
on the main probe sheath in accordance with the procedures described in 
section 10.4 and is used as a reference position for installation of the 
yaw angle-measuring device on the probe. At the discretion of the 
tester, the scribe line may be a single line segment placed at a 
particular position on the probe sheath (e.g., near the probe head), 
multiple line segments placed at various locations along the length of 
the probe sheath (e.g., at every position where a yaw angle-measuring 
device may be mounted), or a single continuous line extending along the 
full length of the probe sheath.
    6.1.5.2  Scribe line on probe extensions. A permanent line may also 
be inscribed on any probe extension that will be attached to the main 
probe in performing field testing. This allows a yaw angle-measuring 
device mounted on the extension to be readily aligned with the reference 
scribe line on the main probe sheath.
    6.1.5.3  Alignment specifications. This specification shall be met 
separately, using the procedures in section 10.4.1, on the main probe 
and on each probe extension. The rotational position of the scribe line 
or scribe line segments on the main probe or any probe extension must 
not vary by more than 2 deg.. That is, the difference between the 
minimum and maximum of all of the rotational angles that are measured 
along the full length of the main probe or the probe extension must not 
exceed 2 deg..
    6.1.6  Probe and system characteristics to ensure horizontal 
stability.
    6.1.6.1  For manual probes, it is recommended that the effective 
length of the probe (coupled with a probe extension, if necessary) be at 
least 0.9 m (3 ft.) longer than the farthest traverse point mark on the 
probe shaft away from the probe head. The operator should maintain the 
probe's horizontal stability when it is fully inserted into the stack or 
duct. If a shorter probe is used, the probe should be inserted through a 
bushing sleeve, similar to the one shown in Figure 2G-3, that is 
installed on the test port; such a bushing shall fit snugly around the 
probe and be secured to the stack or duct entry port in such a manner as 
to maintain the probe's horizontal stability when fully inserted into 
the stack or duct.
    6.1.6.2  An automated system that includes an external probe casing 
with a transport system shall have a mechanism for maintaining 
horizontal stability comparable to that obtained by manual probes 
following the provisions of this method. The automated probe assembly 
shall also be constructed to maintain the alignment and position of the 
pressure ports during sampling at each traverse point. The design of the 
probe casing and transport system shall allow the probe to be removed 
from the stack or duct and checked through direct physical measurement 
for angular position and insertion depth.
    6.1.7  The tubing that is used to connect the probe and the 
pressure-measuring device should have an inside diameter of at least 3.2 
mm (\1/8\ in.), to reduce the time required for pressure equilibration, 
and should be as short as practicable.
    6.1.8  If a detachable probe head without a sheath [e.g., a pitot 
tube, typically 15.2 to 30.5 cm (6 to 12 in.) in length] is coupled with

[[Page 667]]

a probe sheath and calibrated in a wind tunnel in accordance with the 
yaw angle calibration procedure in section 10.5, the probe head shall 
remain attached to the probe sheath during field testing in the same 
configuration and orientation as calibrated. Once the detachable probe 
head is uncoupled or re-oriented, the yaw angle calibration of the probe 
is no longer valid and must be repeated before using the probe in 
subsequent field tests.
    6.2  Yaw Angle-measuring Device. One of the following devices shall 
be used for measurement of the yaw angle of flow.
    6.2.1  Digital inclinometer. This refers to a digital device capable 
of measuring and displaying the rotational position of the probe to 
within 1 deg.. The device shall be able to be locked into 
position on the probe sheath or probe extension, so that it indicates 
the probe's rotational position throughout the test. A rotational 
position collar block that can be attached to the probe sheath (similar 
to the collar shown in Figure 2G-4) may be required to lock the digital 
inclinometer into position on the probe sheath.
    6.2.2  Protractor wheel and pointer assembly. This apparatus, 
similar to that shown in Figure 2G-5, consists of the following 
components.
    6.2.2.1  A protractor wheel that can be attached to a port opening 
and set in a fixed rotational position to indicate the yaw angle 
position of the probe's scribe line relative to the longitudinal axis of 
the stack or duct. The protractor wheel must have a measurement ring on 
its face that is no less than 17.8 cm (7 in.) in diameter, shall be able 
to be rotated to any angle and then locked into position on the stack or 
duct test port, and shall indicate angles to a resolution of 1 deg..
    6.2.2.2  A pointer assembly that includes an indicator needle 
mounted on a collar that can slide over the probe sheath and be locked 
into a fixed rotational position on the probe sheath. The pointer needle 
shall be of sufficient length, rigidity, and sharpness to allow the 
tester to determine the probe's angular position to within 1 deg. from 
the markings on the protractor wheel. Corresponding to the position of 
the pointer, the collar must have a scribe line to be used in aligning 
the pointer with the scribe line on the probe sheath.
    6.2.3  Other yaw angle-measuring devices. Other angle-measuring 
devices with a manufacturer's specified precision of 1 deg. or better 
may be used, if approved by the Administrator.
    6.3  Probe Supports and Stabilization Devices. When probes are used 
for determining flow angles, the probe head should be kept in a stable 
horizontal position. For probes longer than 3.0 m (10 ft.), the section 
of the probe that extends outside the test port shall be secured. Three 
alternative devices are suggested for maintaining the horizontal 
position and stability of the probe shaft during flow angle 
determinations and velocity pressure measurements: (1) monorails 
installed above each port, (2) probe stands on which the probe shaft may 
be rested, or (3) bushing sleeves of sufficient length secured to the 
test ports to maintain probes in a horizontal position. Comparable 
provisions shall be made to ensure that automated systems maintain the 
horizontal position of the probe in the stack or duct. The physical 
characteristics of each test platform may dictate the most suitable type 
of stabilization device. Thus, the choice of a specific stabilization 
device is left to the judgement of the testers.
    6.4  Differential Pressure Gauges. The velocity pressure 
(P) measuring devices used during wind tunnel calibrations and 
field testing shall be either electronic manometers (e.g., pressure 
transducers), fluid manometers, or mechanical pressure gauges (e.g., 
Magnehelic gauges). Use of electronic 
manometers is recommended. Under low velocity conditions, use of 
electronic manometers may be necessary to obtain acceptable 
measurements.
    6.4.1  Differential pressure-measuring device. This refers to a 
device capable of measuring pressure differentials and having a 
readability of 1 percent of full scale. The device shall be 
capable of accurately measuring the maximum expected pressure 
differential. Such devices are used to determine the following pressure 
measurements: velocity pressure, static pressure, and yaw-null pressure. 
For an inclined-vertical manometer, the readability specification of 
1 percent shall be met separately using the respective full-
scale upper limits of the inclined anvertical portions of the scales. To 
the extent practicable, the device shall be selected such that most of 
the pressure readings are between 10 and 90 percent of the device's 
full-scale measurement range (as defined in section 3.4). In addition, 
pressure-measuring devices should be selected such that the zero does 
not drift by more than 5 percent of the average expected pressure 
readings to be encountered during the field test. This is particularly 
important under low pressure conditions.
    6.4.2  Gauge used for yaw nulling. The differential pressure-
measuring device chosen for yaw nulling the probe during the wind tunnel 
calibrations and field testing shall be bi-directional, i.e., capable of 
reading both positive and negative differential pressures. If a 
mechanical, bi-directional pressure gauge is chosen, it shall have a 
full-scale range no greater than 2.6 cm (i.e., -1.3 to +1.3 cm) [1 in. 
H2O (i.e., -0.5 in. to +0.5 in.)].
    6.4.3  Devices for calibrating differential pressure-measuring 
devices. A precision manometer (e.g., a U-tube, inclined, or inclined-
vertical manometer, or micromanometer) or NIST (National Institute of 
Standards and Technology) traceable pressure source shall be used for 
calibrating differential pressure-

[[Page 668]]

measuring devices. The device shall be maintained under laboratory 
conditions or in a similar protected environment (e.g., a climate-
controlled trailer). It shall not be used in field tests. The precision 
manometer shall have a scale gradation of 0.3 mm H2O (0.01 
in. H2O), or less, in the range of 0 to 5.1 cm H2O 
(0 to 2 in. H2O) and 2.5 mm H2O (0.1 in. 
H2O), or less, in the range of 5.1 to 25.4 cm H2O 
(2 to 10 in. H2O). The manometer shall have manufacturer's 
documentation that it meets an accuracy specification of at least 0.5 
percent of full scale. The NIST-traceable pressure source shall be 
recertified annually.
    6.4.4  Devices used for post-test calibration check. A precision 
manometer meeting the specifications in section 6.4.3, a pressure-
measuring device or pressure source with a documented calibration 
traceable to NIST, or an equivalent device approved by the Administrator 
shall be used for the post-test calibration check. The pressure-
measuring device shall have a readability equivalent to or greater than 
the tested device. The pressure source shall be capable of generating 
pressures between 50 and 90 percent of the range of the tested device 
and known to within 1 percent of the full scale of the 
tested device. The pressure source shall be recertified annually.
    6.5  Data Display and Capture Devices. Electronic manometers (if 
used) shall be coupled with a data display device (such as a digital 
panel meter, personal computer display, or strip chart) that allows the 
tester to observe and validate the pressure measurements taken during 
testing. They shall also be connected to a data recorder (such as a data 
logger or a personal computer with data capture software) that has the 
ability to compute and retain the appropriate average value at each 
traverse point, identified by collection time and traverse point.
    6.6  Temperature Gauges. For field tests, a thermocouple or 
resistance temperature detector (RTD) capable of measuring temperature 
to within 3 deg.C (5 deg.F) of the stack or duct 
temperature shall be used. The thermocouple shall be attached to the 
probe such that the sensor tip does not touch any metal. The position of 
the thermocouple relative to the pressure port face openings shall be in 
the same configuration as used for the probe calibrations in the wind 
tunnel. Temperature gauges used for wind tunnel calibrations shall be 
capable of measuring temperature to within 0.6 deg.C 
(1 deg.F) of the temperature of the flowing gas stream in 
the wind tunnel.
    6.7  Stack or Duct Static Pressure Measurement. The pressure-
measuring device used with the probe shall be as specified in section 
6.4 of this method. The static tap of a standard (Prandtl type) pitot 
tube or one leg of a Type S pitot tube with the face opening planes 
positioned parallel to the gas flow may be used for this measurement. 
Also acceptable is the pressure differential reading of P1-
Pbar from a five-hole prism-shaped 3-D probe, as specified in 
section 6.1.1 of Method 2F (such as the Type DA or DAT probe), with the 
P1 pressure port face opening positioned parallel to the gas 
flow in the same manner as the Type S probe. However, the 3-D spherical 
probe, as specified in section 6.1.2 of Method 2F, is unable to provide 
this measurement and shall not be used to take static pressure 
measurements. Static pressure measurement is further described in 
section 8.11.
    6.8  Barometer. Same as Method 2, section 2.5.
    6.9  Gas Density Determination Equipment. Method 3 or 3A shall be 
used to determine the dry molecular weight of the stack or duct gas. 
Method 4 shall be used for moisture content determination and 
computation of stack or duct gas wet molecular weight. Other methods may 
be used, if approved by the Administrator.
    6.10  Calibration Pitot Tube. Same as Method 2, section 2.7.
    6.11  Wind Tunnel for Probe Calibration. Wind tunnels used to 
calibrate velocity probes must meet the following design specifications.
    6.11.1  Test section cross-sectional area. The flowing gas stream 
shall be confined within a circular, rectangular, or elliptical duct. 
The cross-sectional area of the tunnel must be large enough to ensure 
fully developed flow in the presence of both the calibration pitot tube 
and the tested probe. The calibration site, or ``test section,'' of the 
wind tunnel shall have a minimum diameter of 30.5 cm (12 in.) for 
circular or elliptical duct cross-sections or a minimum width of 30.5 cm 
(12 in.) on the shorter side for rectangular cross-sections. Wind 
tunnels shall meet the probe blockage provisions of this section and the 
qualification requirements prescribed in section 10.1. The projected 
area of the portion of the probe head, shaft, and attached devices 
inside the wind tunnel during calibration shall represent no more than 4 
percent of the cross-sectional area of the tunnel. The projected area 
shall include the combined area of the calibration pitot tube and the 
tested probe if both probes are placed simultaneously in the same cross-
sectional plane in the wind tunnel, or the larger projected area of the 
two probes if they are placed alternately in the wind tunnel.
    6.11.2  Velocity range and stability. The wind tunnel should be 
capable of maintaining velocities between 6.1 m/sec and 30.5 m/sec (20 
ft/sec and 100 ft/sec). The wind tunnel shall produce fully developed 
flow patterns that are stable and parallel to the axis of the duct in 
the test section.
    6.11.3  Flow profile at the calibration location. The wind tunnel 
shall provide axial flow within the test section calibration location 
(as defined in section 3.21). Yaw and pitch angles in the calibration 
location shall

[[Page 669]]

be within 3 deg. of 0 deg.. The procedure for determining 
that this requirement has been met is described in section 10.1.2.
    6.11.4  Entry ports in the wind tunnel test section.
    6.11.4.1  Port for tested probe. A port shall be constructed for the 
tested probe. This port shall be located to allow the head of the tested 
probe to be positioned within the wind tunnel calibration location (as 
defined in section 3.21). The tested probe shall be able to be locked 
into the 0 deg. pitch angle position. To facilitate alignment of the 
probe during calibration, the test section should include a window 
constructed of a transparent material to allow the tested probe to be 
viewed.
    6.11.4.2  Port for verification of axial flow. Depending on the 
equipment selected to conduct the axial flow verification prescribed in 
section 10.1.2, a second port, located 90 deg. from the entry port for 
the tested probe, may be needed to allow verification that the gas flow 
is parallel to the central axis of the test section. This port should be 
located and constructed so as to allow one of the probes described in 
section 10.1.2.2 to access the same test point(s) that are accessible 
from the port described in section 6.11.4.1.
    6.11.4.3  Port for calibration pitot tube. The calibration pitot 
tube shall be used in the port for the tested probe or in a separate 
entry port. In either case, all measurements with the calibration pitot 
tube shall be made at the same point within the wind tunnel over the 
course of a probe calibration. The measurement point for the calibration 
pitot tube shall meet the same specifications for distance from the wall 
and for axial flow as described in section 3.21 for the wind tunnel 
calibration location.

                 7.0  Reagents and Standards. [Reserved]

                   8.0  Sample Collection and Analysis

                  8.1  Equipment Inspection and Set Up

    8.1.1  All 2-D and 3-D probes, differential pressure-measuring 
devices, yaw angle-measuring devices, thermocouples, and barometers 
shall have a current, valid calibration before being used in a field 
test. (See sections 10.3.3, 10.3.4, and 10.5 through 10.10 for the 
applicable calibration requirements.)
    8.1.2  Before each field use of a Type S probe, perform a visual 
inspection to verify the physical condition of the pitot tube. Record 
the results of the inspection. If the face openings are noticeably 
misaligned or there is visible damage to the face openings, the probe 
shall not be used until repaired, the dimensional specifications 
verified (according to the procedures in section 10.2.1), and the probe 
recalibrated.
    8.1.3  Before each field use of a 3-D probe, perform a visual 
inspection to verify the physical condition of the probe head according 
to the procedures in section 10.2 of Method 2F. Record the inspection 
results on a form similar to Table 2F-1 presented in Method 2F. If there 
is visible damage to the 3-D probe, the probe shall not be used until it 
is recalibrated.
    8.1.4  After verifying that the physical condition of the probe head 
is acceptable, set up the apparatus using lengths of flexible tubing 
that are as short as practicable. Surge tanks installed between the 
probe and pressure-measuring device may be used to dampen pressure 
fluctuations provided that an adequate measurement system response time 
(see section 8.8) is maintained.
    8.2  Horizontal Straightness Check. A horizontal straightness check 
shall be performed before the start of each field test, except as 
otherwise specified in this section. Secure the fully assembled probe 
(including the probe head and all probe shaft extensions) in a 
horizontal position using a stationary support at a point along the 
probe shaft approximating the location of the stack or duct entry port 
when the probe is sampling at the farthest traverse point from the stack 
or duct wall. The probe shall be rotated to detect bends. Use an angle-
measuring device or trigonometry to determine the bend or sag between 
the probe head and the secured end. (See Figure 2G-6.) Probes that are 
bent or sag by more than 5 deg. shall not be used. Although this check 
does not apply when the probe is used for a vertical traverse, care 
should be taken to avoid the use of bent probes when conducting vertical 
traverses. If the probe is constructed of a rigid steel material and 
consists of a main probe without probe extensions, this check need only 
be performed before the initial field use of the probe, when the probe 
is recalibrated, when a change is made to the design or material of the 
probe assembly, and when the probe becomes bent. With such probes, a 
visual inspection shall be made of the fully assembled probe before each 
field test to determine if a bend is visible. The probe shall be rotated 
to detect bends. The inspection results shall be documented in the field 
test report. If a bend in the probe is visible, the horizontal 
straightness check shall be performed before the probe is used.
    8.3  Rotational Position Check. Before each field test, and each 
time an extension is added to the probe during a field test, a 
rotational position check shall be performed on all manually operated 
probes (except as noted in section 8.3.5 below) to ensure that, 
throughout testing, the angle-measuring device is either: aligned to 
within 1 deg. of the rotational position of the reference 
scribe line; or is affixed to the probe such that the rotational offset 
of the device from the reference scribe line is known to within 
1 deg.. This check shall consist of direct measurements of 
the rotational positions of the reference scribe line and angle-
measuring device sufficient to verify that these specifications are met.

[[Page 670]]

Annex A in section 18 of this method gives recommended procedures for 
performing the rotational position check, and Table 2G-2 gives an 
example data form. Procedures other than those recommended in Annex A in 
section 18 may be used, provided they demonstrate whether the alignment 
specification is met and are explained in detail in the field test 
report.
    8.3.1  Angle-measuring device rotational offset. The tester shall 
maintain a record of the angle-measuring device rotational offset, 
RADO, as defined in section 3.1. Note that RADO is 
assigned a value of 0 deg. when the angle-measuring device is aligned to 
within 1 deg. of the rotational position of the reference 
scribe line. The RADO shall be used to determine the yaw 
angle of flow in accordance with section 8.9.4.
    8.3.2  Sign of angle-measuring device rotational offset. The sign of 
RADO is positive when the angle-measuring device (as viewed 
from the ``tail'' end of the probe) is positioned in a clockwise 
direction from the reference scribe line and negative when the device is 
positioned in a counterclockwise direction from the reference scribe 
line.
    8.3.3  Angle-measuring devices that can be independently adjusted 
(e.g., by means of a set screw), after being locked into position on the 
probe sheath, may be used. However, the RADO must also take 
into account this adjustment.
    8.3.4  Post-test check. If probe extensions remain attached to the 
main probe throughout the field test, the rotational position check 
shall be repeated, at a minimum, at the completion of the field test to 
ensure that the angle-measuring device has remained within 
2 deg. of its rotational position established prior to 
testing. At the discretion of the tester, additional checks may be 
conducted after completion of testing at any sample port or after any 
test run. If the 2 deg. specification is not met, all 
measurements made since the last successful rotational position check 
must be repeated. Section 18.1.1.3 of Annex A provides an example 
procedure for performing the post-test check.
    8.3.5  Exceptions.
    8.3.5.1  A rotational position check need not be performed if, for 
measurements taken at all velocity traverse points, the yaw angle-
measuring device is mounted and aligned directly on the reference scribe 
line specified in sections 6.1.5.1 and 6.1.5.3 and no independent 
adjustments, as described in section 8.3.3, are made to device's 
rotational position.
    8.3.5.2  If extensions are detached and re-attached to the probe 
during a field test, a rotational position check need only be performed 
the first time an extension is added to the probe, rather than each time 
the extension is re-attached, if the probe extension is designed to be 
locked into a mechanically fixed rotational position (e.g., through the 
use of interlocking grooves), that can re-establish the initial 
rotational position to within 1 deg..
    8.4  Leak Checks. A pre-test leak check shall be conducted before 
each field test. A post-test check shall be performed at the end of the 
field test, but additional leak checks may be conducted after any test 
run or group of test runs. The post-test check may also serve as the 
pre-test check for the next group of test runs. If any leak check is 
failed, all runs since the last passed leak check are invalid. While 
performing the leak check procedures, also check each pressure device's 
responsiveness to changes in pressure.
    8.4.1  To perform the leak check on a Type S pitot tube, pressurize 
the pitot impact opening until at least 7.6 cm H2O (3 in. 
H2O) velocity pressure, or a pressure corresponding to 
approximately 75 percent of the pressure device's measurement scale, 
whichever is less, registers on the pressure device; then, close off the 
impact opening. The pressure shall remain stable (2.5 mm 
H2O, 0.10 in. H2O) for at least 15 
seconds. Repeat this procedure for the static pressure side, except use 
suction to obtain the required pressure. Other leak-check procedures may 
be used, if approved by the Administrator.
    8.4.2  To perform the leak check on a 3-D probe, pressurize the 
probe's impact (P1) opening until at least 7.6 cm 
H2O (3 in. H2O) velocity pressure, or a pressure 
corresponding to approximately 75 percent of the pressure device's 
measurement scale, whichever is less, registers on the pressure device; 
then, close off the impact opening. The pressure shall remain stable 
(2.5 mm H2O, 0.10 in. H2O) 
for at least 15 seconds. Check the P2 and P3 
pressure ports in the same fashion. Other leak-check procedures may be 
used, if approved by the Administrator.
    8.5  Zeroing the Differential Pressure-measuring Device. Zero each 
differential pressure-measuring device, including the device used for 
yaw nulling, before each field test. At a minimum, check the zero after 
each field test. A zero check may also be performed after any test run 
or group of test runs. For fluid manometers and mechanical pressure 
gauges (e.g., Magnehelic gauges), the 
zero reading shall not deviate from zero by more than 0.8 mm 
H2O (0.03 in. H2O) or one minor scale 
division, whichever is greater, between checks. For electronic 
manometers, the zero reading shall not deviate from zero between checks 
by more than: 0.3 mm H2O (0.01 in. 
H2O), for full scales less than or equal to 5.1 cm 
H2O (2.0 in. H2O); or 0.8 mm 
H2O (0.03 in. H2O), for full scales 
greater than 5.1 cm H2O (2.0 in. H2O). (Note: If 
negative zero drift is not directly readable, estimate the reading based 
on the position of the gauge oil in the manometer or of the

[[Page 671]]

needle on the pressure gauge.) In addition, for all pressure-measuring 
devices except those used exclusively for yaw nulling, the zero reading 
shall not deviate from zero by more than 5 percent of the average 
measured differential pressure at any distinct process condition or load 
level. If any zero check is failed at a specific process condition or 
load level, all runs conducted at that process condition or load level 
since the last passed zero check are invalid.
    8.6  Traverse Point Verification. The number and location of the 
traverse points shall be selected based on Method 1 guidelines. The 
stack or duct diameter and port nipple lengths, including any extension 
of the port nipples into the stack or duct, shall be verified the first 
time the test is performed; retain and use this information for 
subsequent field tests, updating it as required. Physically measure the 
stack or duct dimensions or use a calibrated laser device; do not use 
engineering drawings of the stack or duct. The probe length necessary to 
reach each traverse point shall be recorded to within 6.4 mm 
(\1/4\ in.) and, for manual probes, marked on the probe 
sheath. In determining these lengths, the tester shall take into account 
both the distance that the port flange projects outside of the stack and 
the depth that any port nipple extends into the gas stream. The 
resulting point positions shall reflect the true distances from the 
inside wall of the stack or duct, so that when the tester aligns any of 
the markings with the outside face of the stack port, the probe's impact 
port shall be located at the appropriate distance from the inside wall 
for the respective Method 1 traverse point. Before beginning testing at 
a particular location, an out-of-stack or duct verification shall be 
performed on each probe that will be used to ensure that these position 
markings are correct. The distances measured during the verification 
must agree with the previously calculated distances to within 
\1/4\ in. For manual probes, the traverse point positions 
shall be verified by measuring the distance of each mark from the 
probe's impact pressure port (the P1 port for a 3-D probe). A 
comparable out-of-stack test shall be performed on automated probe 
systems. The probe shall be extended to each of the prescribed traverse 
point positions. Then, the accuracy of the positioning for each traverse 
point shall be verified by measuring the distance between the port 
flange and the probe's impact pressure port.
    8.7  Probe Installation. Insert the probe into the test port. A 
solid material shall be used to seal the port.
    8.8  System Response Time. Determine the response time of the probe 
measurement system. Insert and position the ``cold'' probe (at ambient 
temperature and pressure) at any Method 1 traverse point. Read and 
record the probe differential pressure, temperature, and elapsed time at 
15-second intervals until stable readings for both pressure and 
temperature are achieved. The response time is the longer of these two 
elapsed times. Record the response time.
    8.9  Sampling.
    8.9.1  Yaw angle measurement protocol. With manual probes, yaw angle 
measurements may be obtained in two alternative ways during the field 
test, either by using a yaw angle-measuring device (e.g., digital 
inclinometer) affixed to the probe, or using a protractor wheel and 
pointer assembly. For horizontal traversing, either approach may be 
used. For vertical traversing, i.e., when measuring from on top or into 
the bottom of a horizontal duct, only the protractor wheel and pointer 
assembly may be used. With automated probes, curve-fitting protocols may 
be used to obtain yaw-angle measurements.
    8.9.1.1  If a yaw angle-measuring device affixed to the probe is to 
be used, lock the device on the probe sheath, aligning it either on the 
reference scribe line or in the rotational offset position established 
under section 8.3.1.
    8.9.1.2  If a protractor wheel and pointer assembly is to be used, 
follow the procedures in Annex B of this method.
    8.9.1.3  Curve-fitting procedures. Curve-fitting routines sweep 
through a range of yaw angles to create curves correlating pressure to 
yaw position. To find the zero yaw position and the yaw angle of flow, 
the curve found in the stack is computationally compared to a similar 
curve that was previously generated under controlled conditions in a 
wind tunnel. A probe system that uses a curve-fitting routine for 
determining the yaw-null position of the probe head may be used, 
provided that it is verified in a wind tunnel to be able to determine 
the yaw angle of flow to within 1 deg..
    8.9.1.4  Other yaw angle determination procedures. If approved by 
the Administrator, other procedures for determining yaw angle may be 
used, provided that they are verified in a wind tunnel to be able to 
perform the yaw angle calibration procedure as described in section 
10.5.
    8.9.2  Sampling strategy. At each traverse point, first yaw-null the 
probe, as described in section 8.9.3, below. Then, with the probe 
oriented into the direction of flow, measure and record the yaw angle, 
the differential pressure and the temperature at the traverse point, 
after stable readings are achieved, in accordance with sections 8.9.4 
and 8.9.5. At the start of testing in each port (i.e., after a probe has 
been inserted into the flue gas stream), allow at least the response 
time to elapse before beginning to take measurements at the first 
traverse point accessed from that port. Provided that the probe is

[[Page 672]]

not removed from the flue gas stream, measurements may be taken at 
subsequent traverse points accessed from the same test port without 
waiting again for the response time to elapse.
    8.9.3  Yaw-nulling procedure. In preparation for yaw angle 
determination, the probe must first be yaw nulled. After positioning the 
probe at the appropriate traverse point, perform the following 
procedures.
    8.9.3.1  For Type S probes, rotate the probe until a null 
differential pressure reading is obtained. The direction of the probe 
rotation shall be such that the thermocouple is located downstream of 
the probe pressure ports at the yaw-null position. Rotate the probe 
90 deg. back from the yaw-null position to orient the impact pressure 
port into the direction of flow. Read and record the angle displayed by 
the angle-measuring device.
    8.9.3.2  For 3-D probes, rotate the probe until a null differential 
pressure reading (the difference in pressures across the P2 
and P3 pressure ports is zero, i.e., P2 = 
P3) is indicated by the yaw angle pressure gauge. Read and 
record the angle displayed by the angle-measuring device.
    8.9.3.3  Sign of the measured angle. The angle displayed on the 
angle-measuring device is considered positive when the probe's impact 
pressure port (as viewed from the ``tail'' end of the probe) is oriented 
in a clockwise rotational position relative to the stack or duct axis 
and is considered negative when the probe's impact pressure port is 
oriented in a counterclockwise rotational position (see Figure 2G-7).
    8.9.4  Yaw angle determination. After performing the applicable yaw-
nulling procedure in section 8.9.3, determine the yaw angle of flow 
according to one of the following procedures. Special care must be 
observed to take into account the signs of the recorded angle reading 
and all offsets.
    8.9.4.1  Direct-reading. If all rotational offsets are zero or if 
the angle-measuring device rotational offset (RADO) 
determined in section 8.3 exactly compensates for the scribe line 
rotational offset (RSLO) determined in section 10.5, then the 
magnitude of the yaw angle is equal to the displayed angle-measuring 
device reading from section 8.9.3.1 or 8.9.3.2. The algebraic sign of 
the yaw angle is determined in accordance with section 8.9.3.3. [Note: 
Under certain circumstances (e.g., testing of horizontal ducts) a 
90 deg. adjustment to the angle-measuring device readings may be 
necessary to obtain the correct yaw angles.]
    8.9.4.2  Compensation for rotational offsets during data reduction. 
When the angle-measuring device rotational offset does not compensate 
for reference scribe line rotational offset, the following procedure 
shall be used to determine the yaw angle:
    (a) Enter the reading indicated by the angle-measuring device from 
section 8.9.3.1 or 8.9.3.2.
    (b) Associate the proper algebraic sign from section 8.9.3.3 with 
the reading in step (a).
    (c) Subtract the reference scribe line rotational offset, 
RSLO, from the reading in step (b).
    (d) Subtract the angle-measuring device rotational offset, 
RADO, if any, from the result obtained in step (c).
    (e) The final result obtained in step (d) is the yaw angle of flow.

[Note: It may be necessary to first apply a 90 deg. adjustment to the 
reading in step (a), in order to obtain the correct yaw angle.]

    8.9.4.3  Record the yaw angle measurements on a form similar to 
Table 2G-3.
    8.9.5  Impact velocity determination. Maintain the probe rotational 
position established during the yaw angle determination. Then, begin 
recording the pressure-measuring device readings. These pressure 
measurements shall be taken over a sampling period of sufficiently long 
duration to ensure representative readings at each traverse point. If 
the pressure measurements are determined from visual readings of the 
pressure device or display, allow sufficient time to observe the 
pulsation in the readings to obtain a sight-weighted average, which is 
then recorded manually. If an automated data acquisition system (e.g., 
data logger, computer-based data recorder, strip chart recorder) is used 
to record the pressure measurements, obtain an integrated average of all 
pressure readings at the traverse point. Stack or duct gas temperature 
measurements shall be recorded, at a minimum, once at each traverse 
point. Record all necessary data as shown in the example field data form 
(Table 2G-3).
    8.9.6  Alignment check. For manually operated probes, after the 
required yaw angle and differential pressure and temperature 
measurements have been made at each traverse point, verify (e.g., by 
visual inspection) that the yaw angle-measuring device has remained in 
proper alignment with the reference scribe line or with the rotational 
offset position established in section 8.3. If, for a particular 
traverse point, the angle-measuring device is found to be in proper 
alignment, proceed to the next traverse point; otherwise, re-align the 
device and repeat the angle and differential pressure measurements at 
the traverse point. In the course of a traverse, if a mark used to 
properly align the angle-measuring device (e.g., as described in section 
18.1.1.1) cannot be located, re-establish the alignment mark before 
proceeding with the traverse.
    8.10  Probe Plugging. Periodically check for plugging of the 
pressure ports by observing the responses on the pressure differential

[[Page 673]]

readouts. Plugging causes erratic results or sluggish responses. Rotate 
the probe to determine whether the readouts respond in the expected 
direction. If plugging is detected, correct the problem and repeat the 
affected measurements.
    8.11  Static Pressure. Measure the static pressure in the stack or 
duct using the equipment described in section 6.7.
    8.11.1  If a Type S probe is used for this measurement, position the 
probe at or between any traverse point(s) and rotate the probe until a 
null differential pressure reading is obtained. Disconnect the tubing 
from one of the pressure ports; read and record the P. For 
pressure devices with one-directional scales, if a deflection in the 
positive direction is noted with the negative side disconnected, then 
the static pressure is positive. Likewise, if a deflection in the 
positive direction is noted with the positive side disconnected, then 
the static pressure is negative.
    8.11.2  If a 3-D probe is used for this measurement, position the 
probe at or between any traverse point(s) and rotate the probe until a 
null differential pressure reading is obtained at P2-
P3. Rotate the probe 90 deg.. Disconnect the P2 
pressure side of the probe and read the pressure P1-
Pbar and record as the static pressure. (Note: The spherical 
probe, specified in section 6.1.2 of Method 2F, is unable to provide 
this measurement and shall not be used to take static pressure 
measurements.)
    8.12  Atmospheric Pressure. Determine the atmospheric pressure at 
the sampling elevation during each test run following the procedure 
described in section 2.5 of Method 2.
    8.13  Molecular Weight. Determine the stack or duct gas dry 
molecular weight. For combustion processes or processes that emit 
essentially CO2, O2, CO, and N2, use 
Method 3 or 3A. For processes emitting essentially air, an analysis need 
not be conducted; use a dry molecular weight of 29.0. Other methods may 
be used, if approved by the Administrator.
    8.14  Moisture. Determine the moisture content of the stack gas 
using Method 4 or equivalent.
    8.15  Data Recording and Calculations. Record all required data on a 
form similar to Table 2G-3.
    8.15.1  2-D probe calibration coefficient. When a Type S pitot tube 
is used in the field, the appropriate calibration coefficient as 
determined in section 10.6 shall be used to perform velocity 
calculations. For calibrated Type S pitot tubes, the A-side coefficient 
shall be used when the A-side of the tube faces the flow, and the B-side 
coefficient shall be used when the B-side faces the flow.
    8.15.2  3-D calibration coefficient. When a 3-D probe is used to 
collect data with this method, follow the provisions for the calibration 
of 3-D probes in section 10.6 of Method 2F to obtain the appropriate 
velocity calibration coefficient (F2 as derived using 
Equation 2F-2 in Method 2F) corresponding to a pitch angle position of 
0 deg..
    8.15.3  Calculations. Calculate the yaw-adjusted velocity at each 
traverse point using the equations presented in section 12.2. Calculate 
the test run average stack gas velocity by finding the arithmetic 
average of the point velocity results in accordance with sections 12.3 
and 12.4, and calculate the stack gas volumetric flow rate in accordance 
with section 12.5 or 12.6, as applicable.

                          9.0  Quality Control

    9.1  Quality Control Activities. In conjunction with the yaw angle 
determination and the pressure and temperature measurements specified in 
section 8.9, the following quality control checks should be performed.
    9.1.1 Range of the differential pressure gauge. In accordance with 
the specifications in section 6.4, ensure that the proper differential 
pressure gauge is being used for the range of P values 
encountered. If it is necessary to change to a more sensitive gauge, 
replace the gauge with a gauge calibrated according to section 10.3.3, 
perform the leak check described in section 8.4 and the zero check 
described in section 8.5, and repeat the differential pressure and 
temperature readings at each traverse point.
    9.1.2  Horizontal stability check. For horizontal traverses of a 
stack or duct, visually check that the probe shaft is maintained in a 
horizontal position prior to taking a pressure reading. Periodically, 
during a test run, the probe's horizontal stability should be verified 
by placing a carpenter's level, a digital inclinometer, or other angle-
measuring device on the portion of the probe sheath that extends outside 
of the test port. A comparable check should be performed by automated 
systems.

                            10.0  Calibration

    10.1  Wind Tunnel Qualification Checks. To qualify for use in 
calibrating probes, a wind tunnel shall have the design features 
specified in section 6.11 and satisfy the following qualification 
criteria. The velocity pressure cross-check in section 10.1.1 and axial 
flow verification in section 10.1.2 shall be performed before the 
initial use of the wind tunnel and repeated immediately after any 
alteration occurs in the wind tunnel's configuration, fans, interior 
surfaces, straightening vanes, controls, or other properties that could 
reasonably be expected to alter the flow pattern or velocity stability 
in the tunnel. The owner or operator of a wind tunnel used to calibrate 
probes according to this method shall maintain records documenting that 
the wind tunnel meets the requirements of sections 10.1.1 and 10.1.2 and

[[Page 674]]

shall provide these records to the Administrator upon request.
    10.1.1  Velocity pressure cross-check. To verify that the wind 
tunnel produces the same velocity at the tested probe head as at the 
calibration pitot tube impact port, perform the following cross-check. 
Take three differential pressure measurements at the fixed calibration 
pitot tube location, using the calibration pitot tube specified in 
section 6.10, and take three measurements with the calibration pitot 
tube at the wind tunnel calibration location, as defined in section 
3.21. Alternate the measurements between the two positions. Perform this 
procedure at the lowest and highest velocity settings at which the 
probes will be calibrated. Record the values on a form similar to Table 
2G-4. At each velocity setting, the average velocity pressure obtained 
at the wind tunnel calibration location shall be within 2 
percent or 2.5 mm H2O (0.01 in. H2O), whichever is 
less restrictive, of the average velocity pressure obtained at the fixed 
calibration pitot tube location. This comparative check shall be 
performed at 2.5-cm (1-in.), or smaller, intervals across the full 
length, width, and depth (if applicable) of the wind tunnel calibration 
location. If the criteria are not met at every tested point, the wind 
tunnel calibration location must be redefined, so that acceptable 
results are obtained at every point. Include the results of the velocity 
pressure cross-check in the calibration data section of the field test 
report. (See section 16.1.4.)
    10.1.2  Axial flow verification. The following procedures shall be 
performed to demonstrate that there is fully developed axial flow within 
the wind tunnel calibration location and at the calibration pitot tube 
location. Two options are available to conduct this check.
    10.1.2.1  Using a calibrated 3-D probe. A probe that has been 
previously calibrated in a wind tunnel with documented axial flow (as 
defined in section 3.22) may be used to conduct this check. Insert the 
calibrated 3-D probe into the wind tunnel test section using the tested 
probe port. Following the procedures in sections 8.9 and 12.2 of Method 
2F, determine the yaw and pitch angles at all the point(s) in the test 
section where the velocity pressure cross-check, as specified in section 
10.1.1, is performed. This includes all the points in the calibration 
location and the point where the calibration pitot tube will be located. 
Determine the yaw and pitch angles at each point. Repeat these 
measurements at the highest and lowest velocities at which the probes 
will be calibrated. Record the values on a form similar to Table 2G-5. 
Each measured yaw and pitch angle shall be within 3 deg. of 
0 deg.. Exceeding the limits indicates unacceptable flow in the test 
section. Until the problem is corrected and acceptable flow is verified 
by repetition of this procedure, the wind tunnel shall not be used for 
calibration of probes. Include the results of the axial flow 
verification in the calibration data section of the field test report. 
(See section 16.1.4.)
    10.1.2.2  Using alternative probes. Axial flow verification may be 
performed using an uncalibrated prism-shaped 3-D probe (e.g., DA or DAT 
probe) or an uncalibrated wedge probe. (Figure 2G-8 illustrates a 
typical wedge probe.) This approach requires use of two ports: the 
tested probe port and a second port located 90 deg. from the tested 
probe port. Each port shall provide access to all the points within the 
wind tunnel test section where the velocity pressure cross-check, as 
specified in section 10.1.1, is conducted. The probe setup shall include 
establishing a reference yaw-null position on the probe sheath to serve 
as the location for installing the angle-measuring device. Physical 
design features of the DA, DAT, and wedge probes are relied on to 
determine the reference position. For the DA or DAT probe, this 
reference position can be determined by setting a digital inclinometer 
on the flat facet where the P1 pressure port is located and 
then identifying the rotational position on the probe sheath where a 
second angle-measuring device would give the same angle reading. The 
reference position on a wedge probe shaft can be determined either 
geometrically or by placing a digital inclinometer on each side of the 
wedge and rotating the probe until equivalent readings are obtained. 
With the latter approach, the reference position is the rotational 
position on the probe sheath where an angle-measuring device would give 
a reading of 0 deg.. After installation of the angle-measuring device in 
the reference yaw-null position on the probe sheath, determine the yaw 
angle from the tested port. Repeat this measurement using the 90 deg. 
offset port, which provides the pitch angle of flow. Determine the yaw 
and pitch angles at all the point(s) in the test section where the 
velocity pressure cross-check, as specified in section 10.1.1, is 
performed. This includes all the points in the wind tunnel calibration 
location and the point where the calibration pitot tube will be located. 
Perform this check at the highest and lowest velocities at which the 
probes will be calibrated. Record the values on a form similar to Table 
2G-5. Each measured yaw and pitch angle shall be within 
3 deg. of 0 deg.. Exceeding the limits indicates 
unacceptable flow in the test section. Until the problem is corrected 
and acceptable flow is verified by repetition of this procedure, the 
wind tunnel shall not be used for calibration of probes. Include the 
results in the probe calibration report.
    10.1.3  Wind tunnel audits.
    10.1.3.1  Procedure. Upon the request of the Administrator, the 
owner or operator of a wind tunnel shall calibrate a 2-D audit probe in 
accordance with the procedures described

[[Page 675]]

in sections 10.3 through 10.6. The calibration shall be performed at two 
velocities that encompass the velocities typically used for this method 
at the facility. The resulting calibration data shall be submitted to 
the Agency in an audit test report. These results shall be compared by 
the Agency to reference calibrations of the audit probe at the same 
velocity settings obtained at two different wind tunnels.
    10.1.3.2  Acceptance criterion. The audited tunnel's calibration 
coefficient is acceptable if it is within 3 percent of the 
reference calibrations obtained at each velocity setting by one (or 
both) of the wind tunnels. If the acceptance criterion is not met at 
each calibration velocity setting, the audited wind tunnel shall not be 
used to calibrate probes for use under this method until the problems 
are resolved and acceptable results are obtained upon completion of a 
subsequent audit.
    10.2  Probe Inspection.
    10.2.1  Type S probe. Before each calibration of a Type S probe, 
verify that one leg of the tube is permanently marked A, and the other, 
B. Carefully examine the pitot tube from the top, side, and ends. 
Measure the angles (1, 2, 
1, and 2) and the dimensions (w 
and z) illustrated in Figures 2-2 and 2-3 in Method 2. Also measure the 
dimension A, as shown in the diagram in Table 2G-1, and the external 
tubing diameter (dimension Dt, Figure 2-2b in Method 2). For 
the purposes of this method, Dt shall be no less than 9.5 mm 
(\3/8\ in.). The base-to-opening plane distances PA and 
PB in Figure 2-3 of Method 2 shall be equal, and the 
dimension A in Table 2G-1 should be between 2.10Dt and 
3.00Dt. Record the inspection findings and probe measurements 
on a form similar to Table CD2-1 of the ``Quality Assurance Handbook for 
Air Pollution Measurement Systems: Volume III, Stationary Source-
Specific Methods' (EPA/600/R-94/038c, September 1994). For reference, 
this form is reproduced herein as Table 2G-1. The pitot tube shall not 
be used under this method if it fails to meet the specifications in this 
section and the alignment specifications in section 6.1.1. All Type S 
probes used to collect data with this method shall be calibrated 
according to the procedures outlined in sections 10.3 through 10.6 
below. During calibration, each Type S pitot tube shall be configured in 
the same manner as used, or planned to be used, during the field test, 
including all components in the probe assembly (e.g., thermocouple, 
probe sheath, sampling nozzle). Probe shaft extensions that do not 
affect flow around the probe head need not be attached during 
calibration.
    10.2.2  3-D probe. If a 3-D probe is used to collect data with this 
method, perform the pre-calibration inspection according to procedures 
in Method 2F, section 10.2.
    10.3  Pre-Calibration Procedures. Prior to calibration, a scribe 
line shall have been placed on the probe in accordance with section 
10.4. The yaw angle and velocity calibration procedures shall not begin 
until the pre-test requirements in sections 10.3.1 through 10.3.4 have 
been met.
    10.3.1  Perform the horizontal straightness check described in 
section 8.2 on the probe assembly that will be calibrated in the wind 
tunnel.
    10.3.2  Perform a leak check in accordance with section 8.4.
    10.3.3  Except as noted in section 10.3.3.3, calibrate all 
differential pressure-measuring devices to be used in the probe 
calibrations, using the following procedures. At a minimum, calibrate 
these devices on each day that probe calibrations are performed.
    10.3.3.1  Procedure. Before each wind tunnel use, all differential 
pressure-measuring devices shall be calibrated against the reference 
device specified in section 6.4.3 using a common pressure source. 
Perform the calibration at three reference pressures representing 30, 
60, and 90 percent of the full-scale range of the pressure-measuring 
device being calibrated. For an inclined-vertical manometer, perform 
separate calibrations on the inclined and vertical portions of the 
measurement scale, considering each portion of the scale to be a 
separate full-scale range. [For example, for a manometer with a 0-to 
2.5-cm H2O (0-to 1-in. H2O) inclined scale and a 
2.5-to 12.7-cm H2O (1-to 5-in. H2O) vertical 
scale, calibrate the inclined portion at 7.6, 15.2, and 22.9 mm 
H2O (0.3, 0.6, and 0.9 in. H2O), and calibrate the 
vertical portion at 3.8, 7.6, and 11.4 cm H2O (1.5, 3.0, and 
4.5 in. H2O).] Alternatively, for the vertical portion of the 
scale, use three evenly spaced reference pressures, one of which is 
equal to or higher than the highest differential pressure expected in 
field applications.
    10.3.3.2  Acceptance criteria. At each pressure setting, the two 
pressure readings made using the reference device and the pressure-
measuring device being calibrated shall agree to within 2 
percent of full scale of the device being calibrated or 0.5 mm 
H2O (0.02 in. H2O), whichever is less restrictive. 
For an inclined-vertical manometer, these requirements shall be met 
separately using the respective full-scale upper limits of the inclined 
and vertical portions of the scale. Differential pressure-measuring 
devices not meeting the 2 percent of full scale or 0.5 mm 
H2O (0.02 in. H2O) calibration requirement shall 
not be used.
    10.3.3.3  Exceptions. Any precision manometer that meets the 
specifications for a reference device in section 6.4.3 and that is not 
used for field testing does not require calibration, but must be leveled 
and zeroed before each wind tunnel use. Any pressure device used 
exclusively for yaw nulling does not require calibration, but shall be 
checked

[[Page 676]]

for responsiveness to rotation of the probe prior to each wind tunnel 
use.
    10.3.4  Calibrate digital inclinometers on each day of wind tunnel 
or field testing (prior to beginning testing) using the following 
procedures. Calibrate the inclinometer according to the manufacturer's 
calibration procedures. In addition, use a triangular block (illustrated 
in Figure 2G-9) with a known angle , independently determined 
using a protractor or equivalent device, between two adjacent sides to 
verify the inclinometer readings. (Note: If other angle-measuring 
devices meeting the provisions of section 6.2.3 are used in place of a 
digital inclinometer, comparable calibration procedures shall be 
performed on such devices.) Secure the triangular block in a fixed 
position. Place the inclinometer on one side of the block (side A) to 
measure the angle of inclination (R1). Repeat this 
measurement on the adjacent side of the block (side B) using the 
inclinometer to obtain a second angle reading (R2). The 
difference of the sum of the two readings from 180 deg. (i.e., 180 deg.-
R1-R2) shall be within 2 deg. of the 
known angle, .
    10.4  Placement of Reference Scribe Line. Prior to the first 
calibration of a probe, a line shall be permanently inscribed on the 
main probe sheath to serve as a reference mark for determining yaw 
angles. Annex C in section 18 of this method gives a guideline for 
placement of the reference scribe line.
    10.4.1  This reference scribe line shall meet the specifications in 
sections 6.1.5.1 and 6.1.5.3 of this method. To verify that the 
alignment specification in section 6.1.5.3 is met, secure the probe in a 
horizontal position and measure the rotational angle of each scribe line 
and scribe line segment using an angle-measuring device that meets the 
specifications in section 6.2.1 or 6.2.3. For any scribe line that is 
longer than 30.5 cm (12 in.), check the line's rotational position at 
30.5-cm (12-in.) intervals. For each line segment that is 12 in. or less 
in length, check the rotational position at the two endpoints of the 
segment. To meet the alignment specification in section 6.1.5.3, the 
minimum and maximum of all of the rotational angles that are measured 
along the full length of main probe must not differ by more than 2 deg.. 
(Note: A short reference scribe line segment [e.g., 15.2 cm (6 in.) or 
less in length] meeting the alignment specifications in section 6.1.5.3 
is fully acceptable under this method. See section 18.1.1.1 of Annex A 
for an example of a probe marking procedure, suitable for use with a 
short reference scribe line.)
    10.4.2  The scribe line should be placed on the probe first and then 
its offset from the yaw-null position established (as specified in 
section 10.5). The rotational position of the reference scribe line 
relative to the yaw-null position of the probe, as determined by the yaw 
angle calibration procedure in section 10.5, is the reference scribe 
line rotational offset, RSLO. The reference scribe line 
rotational offset shall be recorded and retained as part of the probe's 
calibration record.
    10.4.3  Scribe line for automated probes. A scribe line may not be 
necessary for an automated probe system if a reference rotational 
position of the probe is built into the probe system design. For such 
systems, a ``flat'' (or comparable, clearly identifiable physical 
characteristic) should be provided on the probe casing or flange plate 
to ensure that the reference position of the probe assembly remains in a 
vertical or horizontal position. The rotational offset of the flat (or 
comparable, clearly identifiable physical characteristic) needed to 
orient the reference position of the probe assembly shall be recorded 
and maintained as part of the automated probe system's specifications.
    10.5  Yaw Angle Calibration Procedure. For each probe used to 
measure yaw angles with this method, a calibration procedure shall be 
performed in a wind tunnel meeting the specifications in section 10.1 to 
determine the rotational position of the reference scribe line relative 
to the probe's yaw-null position. This procedure shall be performed on 
the main probe with all devices that will be attached to the main probe 
in the field [such as thermocouples, resistance temperature detectors 
(RTDs), or sampling nozzles] that may affect the flow around the probe 
head. Probe shaft extensions that do not affect flow around the probe 
head need not be attached during calibration. At a minimum, this 
procedure shall include the following steps.
    10.5.1  Align and lock the angle-measuring device on the reference 
scribe line. If a marking procedure (such as described in section 
18.1.1.1) is used, align the angle-measuring device on a mark within 
1 deg. of the rotational position of the reference scribe 
line. Lock the angle-measuring device onto the probe sheath at this 
position.
    10.5.2  Zero the pressure-measuring device used for yaw nulling.
    10.5.3  Insert the probe assembly into the wind tunnel through the 
entry port, positioning the probe's impact port at the calibration 
location. Check the responsiveness of the pressure-measurement device to 
probe rotation, taking corrective action if the response is 
unacceptable.
    10.5.4  Ensure that the probe is in a horizontal position, using a 
carpenter's level.
    10.5.5  Rotate the probe either clockwise or counterclockwise until 
a yaw null [zero P for a Type S probe or zero (P2-
P3) for a 3-D probe] is obtained. If using a Type S probe 
with an attached thermocouple, the direction of the probe rotation shall 
be such that the thermocouple is located downstream of the probe 
pressure ports at the yaw-null position.

[[Page 677]]

    10.5.6  Use the reading displayed by the angle-measuring device at 
the yaw-null position to determine the magnitude of the reference scribe 
line rotational offset, RSLO, as defined in section 3.15. 
Annex D in section 18 of this method gives a recommended procedure for 
determining the magnitude of RSLO with a digital inclinometer 
and a second procedure for determining the magnitude of RSLO 
with a protractor wheel and pointer device. Table 2G-6 gives an example 
data form and Table 2G-7 is a look-up table with the recommended 
procedure. Procedures other than those recommended in Annex D in section 
18 may be used, if they can determine RSLO to within 1 deg. 
and are explained in detail in the field test report. The algebraic sign 
of RSLO will either be positive if the rotational position of 
the reference scribe line (as viewed from the ``tail'' end of the probe) 
is clockwise, or negative, if counterclockwise with respect to the 
probe's yaw-null position. (This is illustrated in Figure 2G-10.)
    10.5.7  The steps in sections 10.5.3 through 10.5.6 shall be 
performed twice at each of the velocities at which the probe will be 
calibrated (in accordance with section 10.6). Record the values of 
RSLO.
    10.5.8  The average of all of the RSLO values shall be 
documented as the reference scribe line rotational offset for the probe.
    10.5.9  Use of reference scribe line offset. The reference scribe 
line rotational offset shall be used to determine the yaw angle of flow 
in accordance with section 8.9.4.
    10.6  Velocity Calibration Procedure. When a 3-D probe is used under 
this method, follow the provisions for the calibration of 3-D probes in 
section 10.6 of Method 2F to obtain the necessary velocity calibration 
coefficients (F2 as derived using Equation 2F-2 in Method 2F) 
corresponding to a pitch angle position of 0 deg.. The following 
procedure applies to Type S probes. This procedure shall be performed on 
the main probe and all devices that will be attached to the main probe 
in the field (e.g., thermocouples, RTDs, sampling nozzles) that may 
affect the flow around the probe head. Probe shaft extensions that do 
not affect flow around the probe head need not be attached during 
calibration. (Note: If a sampling nozzle is part of the assembly, two 
additional requirements must be satisfied before proceeding. The 
distance between the nozzle and the pitot tube shall meet the minimum 
spacing requirement prescribed in Method 2, and a wind tunnel 
demonstration shall be performed that shows the probe's ability to yaw 
null is not impaired when the nozzle is drawing sample.) To obtain 
velocity calibration coefficient(s) for the tested probe, proceed as 
follows.
    10.6.1  Calibration velocities. The tester may calibrate the probe 
at two nominal wind tunnel velocity settings of 18.3 m/sec and 27.4 m/
sec (60 ft/sec and 90 ft/sec) and average the results of these 
calibrations, as described in sections 10.6.12 through 10.6.14, in order 
to generate the calibration coefficient, Cp. If this option 
is selected, this calibration coefficient may be used for all field 
applications where the velocities are 9.1 m/sec (30 ft/sec) or greater. 
Alternatively, the tester may customize the probe calibration for a 
particular field test application (or for a series of applications), 
based on the expected average velocity(ies) at the test site(s). If this 
option is selected, generate the calibration coefficients by calibrating 
the probe at two nominal wind tunnel velocity settings, one of which is 
less than or equal to and the other greater than or equal to the 
expected average velocity(ies) for the field application(s), and average 
the results as described in sections 10.6.12 through 10.6.14. Whichever 
calibration option is selected, the probe calibration coefficient(s) 
obtained at the two nominal calibration velocities shall meet the 
conditions specified in sections 10.6.12 through 10.6.14.
    10.6.2  Connect the tested probe and calibration pitot tube to their 
respective pressure-measuring devices. Zero the pressure-measuring 
devices. Inspect and leak-check all pitot lines; repair or replace them, 
if necessary. Turn on the fan, and allow the wind tunnel air flow to 
stabilize at the first of the selected nominal velocity settings.
    10.6.3  Position the calibration pitot tube at its measurement 
location (determined as outlined in section 6.11.4.3), and align the 
tube so that its tip is pointed directly into the flow. Ensure that the 
entry port surrounding the tube is properly sealed. The calibration 
pitot tube may either remain in the wind tunnel throughout the 
calibration, or be removed from the wind tunnel while measurements are 
taken with the probe being calibrated.
    10.6.4  Check the zero setting of each pressure-measuring device.
    10.6.5  Insert the tested probe into the wind tunnel and align it so 
that the designated pressure port (e.g., either the A-side or B-side of 
a Type S probe) is pointed directly into the flow and is positioned 
within the wind tunnel calibration location (as defined in section 
3.21). Secure the probe at the 0 deg. pitch angle position. Ensure that 
the entry port surrounding the probe is properly sealed.
    10.6.6  Read the differential pressure from the calibration pitot 
tube (Pstd), and record its value. Read the 
barometric pressure to within 2.5 mm Hg (0.1 in. 
Hg) and the temperature in the wind tunnel to within 0.6 deg.C 
(1 deg.F). Record these values on a data form similar to Table 2G-8.
    10.6.7  After the tested probe's differential pressure gauges have 
had sufficient time to stabilize, yaw null the probe (and then rotate it 
back 90 deg. for Type S probes), then obtain the differential pressure 
reading (P). Record

[[Page 678]]

the yaw angle and differential pressure readings.
    10.6.8  Take paired differential pressure measurements with the 
calibration pitot tube and tested probe (according to sections 10.6.6 
and 10.6.7). The paired measurements in each replicate can be made 
either simultaneously (i.e., with both probes in the wind tunnel) or by 
alternating the measurements of the two probes (i.e., with only one 
probe at a time in the wind tunnel).
    10.6.9  Repeat the steps in sections 10.6.6 through 10.6.8 at the 
same nominal velocity setting until three pairs of P readings 
have been obtained from the calibration pitot tube and the tested probe.
    10.6.10  Repeat the steps in sections 10.6.6 through 10.6.9 above 
for the A-side and B-side of the Type S pitot tube. For a probe assembly 
constructed such that its pitot tube is always used in the same 
orientation, only one side of the pitot tube need be calibrated (the 
side that will face the flow). However, the pitot tube must still meet 
the alignment and dimension specifications in section 6.1.1 and must 
have an average deviation () value of 0.01 or less as provided 
in section 10.6.12.4.
    10.6.11  Repeat the calibration procedures in sections 10.6.6 
through 10.6.10 at the second selected nominal wind tunnel velocity 
setting.
    10.6.12  Perform the following calculations separately on the A-side 
and B-side values.
    10.6.12.1  Calculate a Cp value for each of the three 
replicates performed at the lower velocity setting where the 
calibrations were performed using Equation 2-2 in section 4.1.4 of 
Method 2.
    10.6.12.2  Calculate the arithmetic average, Cp(avg-low), 
of the three Cp values.
    10.6.12.3  Calculate the deviation of each of the three individual 
values of Cp from the A-side average Cp(avg-low) 
value using Equation 2-3 in Method 2.
    10.6.12.4  Calculate the average deviation () of the three 
individual Cp values from Cp(avg-low) using 
Equation 2-4 in Method 2. Use the Type S pitot tube only if the values 
of  (side A) and  (side B) are less than or equal to 
0.01. If both A-side and B-side calibration coefficients are calculated, 
the absolute value of the difference between Cp(avg-low) 
(side A) and Cp(avg-low) (side B) must not exceed 0.01.
    10.6.13  Repeat the calculations in section 10.6.12 using the data 
obtained at the higher velocity setting to derive the arithmetic 
Cp values at the higher velocity setting, 
Cp(avg-high), and to determine whether the conditions in 
10.6.12.4 are met by both the A-side and B-side calibrations at this 
velocity setting.
    10.6.14  Use equation 2G-1 to calculate the percent difference of 
the averaged Cp values at the two calibration velocities.
[GRAPHIC] [TIFF OMITTED] TR14MY99.062

The percent difference between the averaged Cp values shall 
not exceed 3 percent. If the specification is met, average 
the A-side values of Cp(avg-low) and Cp(avg-high) 
to produce a single A-side calibration coefficient, Cp. 
Repeat for the B-side values if calibrations were performed on that side 
of the pitot. If the specification is not met, make necessary 
adjustments in the selected velocity settings and repeat the calibration 
procedure until acceptable results are obtained.
    10.6.15  If the two nominal velocities used in the calibration were 
18.3 and 27.4 m/sec (60 and 90 ft/sec), the average Cp from 
section 10.6.14 is applicable to all velocities 9.1 m/sec (30 ft/sec) or 
greater. If two other nominal velocities were used in the calibration, 
the resulting average Cp value shall be applicable only in 
situations where the velocity calculated using the calibration 
coefficient is neither less than the lower nominal velocity nor greater 
than the higher nominal velocity.
    10.7  Recalibration. Recalibrate the probe using the procedures in 
section 10 either within 12 months of its first field use after its most 
recent calibration or after 10 field tests (as defined in section 3.3), 
whichever occurs later. In addition, whenever there is visible damage to 
the probe head, the probe shall be recalibrated before it is used again.
    10.8  Calibration of pressure-measuring devices used in the field. 
Before its initial use in a field test, calibrate each pressure-
measuring device (except those used exclusively for yaw nulling) using 
the three-point calibration procedure described in section 10.3.3. The 
device shall be recalibrated according to the procedure in section 
10.3.3 no later than 90 days after its first field use following its 
most recent calibration. At the discretion of the tester, more frequent 
calibrations (e.g., after a field test) may be performed. No 
adjustments, other than adjustments to the zero setting, shall be made 
to the device between calibrations.

[[Page 679]]

    10.8.1  Post-test calibration check. A single-point calibration 
check shall be performed on each pressure-measuring device after 
completion of each field test. At the discretion of the tester, more 
frequent single-point calibration checks (e.g., after one or more field 
test runs) may be performed. It is recommended that the post-test check 
be performed before leaving the field test site. The check shall be 
performed at a pressure between 50 and 90 percent of full scale by 
taking a common pressure reading with the tested probe and a reference 
pressure-measuring device (as described in section 6.4.4) or by 
challenging the tested device with a reference pressure source (as 
described in section 6.4.4) or by performing an equivalent check using a 
reference device approved by the Administrator.
    10.8.2  Acceptance criterion. At the selected pressure setting, the 
pressure readings made using the reference device and the tested device 
shall agree to within 3 percent of full scale of the tested 
device or 0.8 mm H2O (0.03 in. H2O), whichever is 
less restrictive. If this specification is met, the test data collected 
during the field test are valid. If the specification is not met, all 
test data collected since the last successful calibration or calibration 
check are invalid and shall be repeated using a pressure-measuring 
device with a current, valid calibration. Any device that fails the 
calibration check shall not be used in a field test until a successful 
recalibration is performed according to the procedures in section 
10.3.3.
    10.9  Temperature Gauges. Same as Method 2, section 4.3. The 
alternative thermocouple calibration procedures outlined in Emission 
Measurement Center (EMC) Approved Alternative Method (ALT-011) 
``Alternative Method 2 Thermocouple Calibration Procedure'' may be 
performed. Temperature gauges shall be calibrated no more than 30 days 
prior to the start of a field test or series of field tests and 
recalibrated no more than 30 days after completion of a field test or 
series of field tests.
    10.10  Barometer. Same as Method 2, section 4.4. The barometer shall 
be calibrated no more than 30 days prior to the start of a field test or 
series of field tests.

                       11.0  Analytical Procedure

    Sample collection and analysis are concurrent for this method (see 
section 8.0).

                  12.0  Data Analysis and Calculations

    These calculations use the measured yaw angle and the differential 
pressure and temperature measurements at individual traverse points to 
derive the near-axial flue gas velocity (va(i)) at each of 
those points. The near-axial velocity values at all traverse points that 
comprise a full stack or duct traverse are then averaged to obtain the 
average near-axial stack or duct gas velocity (va(avg)).

                           12.1  Nomenclature

A = Cross-sectional area of stack or duct at the test port location, m 
          \2\ (ft \2\).
Bws = Water vapor in the gas stream (from Method 4 or 
          alternative), proportion by volume.
Cp = Pitot tube calibration coefficient, dimensionless.
F2(i) = 3-D probe velocity coefficient at 0 pitch, applicable 
          at traverse point i.
Kp = Pitot tube constant,
[GRAPHIC] [TIFF OMITTED] TR14MY99.063

for the metric system, and
[GRAPHIC] [TIFF OMITTED] TR14MY99.064

for the English system.

Md = Molecular weight of stack or duct gas, dry basis (see 
          section 8.13), g/g-mole (lb/lb-mole).
Ms = Molecular weight of stack or duct gas, wet basis, g/g-
          mole (lb/lb-mole).
          [GRAPHIC] [TIFF OMITTED] TR14MY99.065
          
Pbar = Barometric pressure at velocity measurement site, mm 
          Hg (in. Hg).
Pg = Stack or duct static pressure, mm H2O (in. 
          H2O).
Ps = Absolute stack or duct pressure, mm Hg (in. Hg),
[GRAPHIC] [TIFF OMITTED] TR14MY99.066

Pstd = Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
13.6 = Conversion from mm H2O (in. H2O) to mm Hg 
          (in. Hg).
Qsd = Average dry-basis volumetric stack or duct gas flow 
          rate corrected to standard conditions, dscm/hr (dscf/hr).
Qsw = Average wet-basis volumetric stack or duct gas flow 
          rate corrected to standard conditions, wscm/hr (wscf/hr).
ts(i) = Stack or duct temperature,  deg.C ( deg.F), at 
          traverse point i.
Ts(i) = Absolute stack or duct temperature,  deg.K ( deg.R), 
          at traverse point i.
          [GRAPHIC] [TIFF OMITTED] TR14MY99.067
          
for the metric system, and
[GRAPHIC] [TIFF OMITTED] TR14MY99.068

for the English system.


[[Page 680]]


Ts(avg)=Average absolute stack or duct gas temperature across 
          all traverse points.
Tstd=Standard absolute temperature, 293 deg.K (528 deg.R).
va(i)=Measured stack or duct gas impact velocity, m/sec (ft/
          sec), at traverse point i.
va(avg)=Average near-axial stack or duct gas velocity, m/sec 
          (ft/sec) across all traverse points.
Pi=Velocity head (differential pressure) of stack or 
          duct gas, mm H2O (in. H2O), applicable 
          at traverse point i.
(P1-P2)=Velocity head (differential pressure) of 
          stack or duct gas measured by a 3-D probe, mm H2O 
          (in. H2O), applicable at traverse point i.
3,600=Conversion factor, sec/hr.
18.0=Molecular weight of water, g/g-mole (lb/lb-mole).
y(i)=Yaw angle of the flow velocity vector, at 
          traverse point i.
n=Number of traverse points.

    12.2  Traverse Point Velocity Calculations. Perform the following 
calculations from the measurements obtained at each traverse point.
    12.2.1  Selection of calibration coefficient. Select the calibration 
coefficient as described in section 10.6.1.
    12.2.2  Near-axial traverse point velocity. When using a Type S 
probe, use the following equation to calculate the traverse point near-
axial velocity (va(i)) from the differential pressure 
(Pi), yaw angle (y(i)), 
absolute stack or duct standard temperature (Ts(i)) measured 
at traverse point i, the absolute stack or duct pressure 
(Ps), and molecular weight (Ms).
[GRAPHIC] [TIFF OMITTED] TR14MY99.069

Use the following equation when using a 3-D probe.
[GRAPHIC] [TIFF OMITTED] TR14MY99.070

    12.2.3  Handling multiple measurements at a traverse point. For 
pressure or temperature devices that take multiple measurements at a 
traverse point, the multiple measurements (or where applicable, their 
square roots) may first be averaged and the resulting average values 
used in the equations above. Alternatively, the individual measurements 
may be used in the equations above and the resulting calculated values 
may then be averaged to obtain a single traverse point value. With 
either approach, all of the individual measurements recorded at a 
traverse point must be used in calculating the applicable traverse point 
value.
    12.3  Average Near-Axial Velocity in Stack or Duct. Use the reported 
traverse point near-axial velocity in the following equation.
[GRAPHIC] [TIFF OMITTED] TR14MY99.071

    12.4  Acceptability of Results. The acceptability provisions in 
section 12.4 of Method 2F apply to 3-D probes used under Method 2G. The 
following provisions apply to Type S probes. For Type S probes, the test 
results are acceptable and the calculated value of va(avg) 
may be reported as the average near-axial velocity for the test run if 
the conditions in either section 12.4.1 or 12.4.2 are met.
    12.4.1  The average calibration coefficient Cp used in 
Equation 2G-6 was generated at nominal velocities of 18.3 and 27.4 m/sec 
(60 and 90 ft/sec) and the value of va(avg) calculated using 
Equation 2G-8 is greater than or equal to 9.1 m/sec (30 ft/sec).
    12.4.2  The average calibration coefficient Cp used in 
Equation 2G-6 was generated at nominal velocities other than 18.3 or 
27.4 m/sec (60 or 90 ft/sec) and the value of va(avg) 
calculated using Equation 2G-8 is greater than or equal to the lower 
nominal velocity and less than or equal to the higher nominal velocity 
used to derive the average Cp.
    12.4.3  If the conditions in neither section 12.4.1 nor section 
12.4.2 are met, the test results obtained from Equation 2G-8 are not

[[Page 681]]

acceptable, and the steps in sections 12.2 and 12.3 must be repeated 
using an average calibration coefficient Cp that satisfies 
the conditions in section 12.4.1 or 12.4.2.
    12.5  Average Gas Volumetric Flow Rate in Stack or Duct (Wet Basis). 
Use the following equation to compute the average volumetric flow rate 
on a wet basis.
[GRAPHIC] [TIFF OMITTED] TR14MY99.072

    12.6  Average Gas Volumetric Flow Rate in Stack or Duct (Dry Basis). 
Use the following equation to compute the average volumetric flow rate 
on a dry basis.
[GRAPHIC] [TIFF OMITTED] TR14MY99.073

                  13.0  Method Performance. [Reserved]

                 14.0  Pollution Prevention. [Reserved]

                   15.0  Waste Management. [Reserved]

                            16.0  Reporting.

    16.1  Field Test Reports. Field test reports shall be submitted to 
the Agency according to applicable regulatory requirements. Field test 
reports should, at a minimum, include the following elements.
    16.1.1  Description of the source. This should include the name and 
location of the test site, descriptions of the process tested, a 
description of the combustion source, an accurate diagram of stack or 
duct cross-sectional area at the test site showing the dimensions of the 
stack or duct, the location of the test ports, and traverse point 
locations and identification numbers or codes. It should also include a 
description and diagram of the stack or duct layout, showing the 
distance of the test location from the nearest upstream and downstream 
disturbances and all structural elements (including breachings, baffles, 
fans, straighteners, etc.) affecting the flow pattern. If the source and 
test location descriptions have been previously submitted to the Agency 
in a document (e.g., a monitoring plan or test plan), referencing the 
document in lieu of including this information in the field test report 
is acceptable.
    16.1.2  Field test procedures. These should include a description of 
test equipment and test procedures. Testing conventions, such as 
traverse point numbering and measurement sequence (e.g., sampling from 
center to wall, or wall to center), should be clearly stated. Test port 
identification and directional reference for each test port should be 
included on the appropriate field test data sheets.
    16.1.3  Field test data.
    16.1.3.1  Summary of results. This summary should include the dates 
and times of testing, and the average near-axial gas velocity and the 
average flue gas volumetric flow results for each run and tested 
condition.
    16.1.3.2  Test data. The following values for each traverse point 
should be recorded and reported:

    (a) Differential pressure at traverse point i 
(Pi)
    (b) Stack or duct temperature at traverse point i (ts(i))
    (c) Absolute stack or duct temperature at traverse point i 
(Ts(i))
    (d) Yaw angle at traverse point i (y(i))
    (e) Stack gas near-axial velocity at traverse point i 
(va(i))

    16.1.3.3  The following values should be reported once per run:

    (a) Water vapor in the gas stream (from Method 4 or alternative), 
proportion by volume (Bws), measured at the frequency 
specified in the applicable regulation
    (b) Molecular weight of stack or duct gas, dry basis (Md)
    (c) Molecular weight of stack or duct gas, wet basis (Ms)
    (d) Stack or duct static pressure (Pg)
    (e) Absolute stack or duct pressure (Ps)
    (f) Carbon dioxide concentration in the flue gas, dry basis 
(%d CO2)
    (g) Oxygen concentration in the flue gas, dry basis (%d 
O2)
    (h) Average near-axial stack or duct gas velocity 
(va(avg)) across all traverse points

[[Page 682]]

    (i) Gas volumetric flow rate corrected to standard conditions, dry 
or wet basis as required by the applicable regulation (Qsd or 
Qsw)

    16.1.3.4  The following should be reported once per complete set of 
test runs:

    (a) Cross-sectional area of stack or duct at the test location (A)
    (b) Pitot tube calibration coefficient (Cp)
    (c) Measurement system response time (sec)
    (d) Barometric pressure at measurement site (Pbar)

    16.1.4  Calibration data. The field test report should include 
calibration data for all probes and test equipment used in the field 
test. At a minimum, the probe calibration data reported to the Agency 
should include the following:

    (a) Date of calibration
    (b) Probe type
    (c) Probe identification number(s) or code(s)
    (d) Probe inspection sheets
    (e) Pressure measurements and calculations used to obtain 
calibration coefficients in accordance with section 10.6 of this method
    (f) Description and diagram of wind tunnel used for the calibration, 
including dimensions of cross-sectional area and position and size of 
the test section
    (g) Documentation of wind tunnel qualification tests performed in 
accordance with section 10.1 of this method

    16.1.5  Quality assurance. Specific quality assurance and quality 
control procedures used during the test should be described.

                          17.0   Bibliography.

    (1) 40 CFR Part 60, Appendix A, Method 1--Sample and velocity 
traverses for stationary sources.
    (2) 40 CFR Part 60, Appendix A, Method 2--Determination of stack gas 
velocity and volumetric flow rate (Type S pitot tube) .
    (3) 40 CFR Part 60, Appendix A, Method 2F--Determination of stack 
gas velocity and volumetric flow rate with three-dimensional probes.
    (4) 40 CFR Part 60, Appendix A, Method 2H--Determination of stack 
gas velocity taking into account velocity decay near the stack wall.
    (5) 40 CFR Part 60, Appendix A, Method 3--Gas analysis for carbon 
dioxide, oxygen, excess air, and dry molecular weight.
    (6) 40 CFR Part 60, Appendix A, Method 3A--Determination of oxygen 
and carbon dioxide concentrations in emissions from stationary sources 
(instrumental analyzer procedure).
    (7) 40 CFR Part 60, Appendix A, Method 4--Determination of moisture 
content in stack gases.
    (8) Emission Measurement Center (EMC) Approved Alternative Method 
(ALT-011) ``Alternative Method 2 Thermocouple Calibration Procedure.''
    (9) Electric Power Research Institute, Interim Report EPRI TR-
106698, ``Flue Gas Flow Rate Measurement Errors,'' June 1996.
    (10) Electric Power Research Institute, Final Report EPRI TR-108110, 
``Evaluation of Heat Rate Discrepancy from Continuous Emission 
Monitoring Systems,'' August 1997.
    (11) Fossil Energy Research Corporation, Final Report, ``Velocity 
Probe Tests in Non-axial Flow Fields,'' November 1998, Prepared for the 
U.S. Environmental Protection Agency.
    (12) Fossil Energy Research Corporation, ``Additional Swirl Tunnel 
Tests: E-DAT and T-DAT Probes,'' February 24, 1999, Technical Memorandum 
Prepared for U.S. Environmental Protection Agency, P.O. No. 7W-1193-
NALX.
    (13) Massachusetts Institute of Technology, Report WBWT-TR-1317, 
``Calibration of Eight Wind Speed Probes Over a Reynolds Number Range of 
46,000 to 725,000 Per Foot, Text and Summary Plots,'' Plus appendices, 
October 15, 1998, Prepared for The Cadmus Group, Inc.
    (14) National Institute of Standards and Technology, Special 
Publication 250, ``NIST Calibration Services Users Guide 1991,'' Revised 
October 1991, U.S. Department of Commerce, p. 2.
    (15) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Four Prandtl Probes, Four 
S-Type Probes, Four French Probes, Four Modified Kiel Probes,'' Prepared 
for the U.S. Environmental Protection Agency under IAG #DW13938432-01-0.
    (16) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed In-strumentation, Five Autoprobes,'' 
Prepared for the U.S. Environmental Protection Agency under IAG 
#DW13938432-01-0.
    (17) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Eight Spherical Probes,'' 
Prepared for the U.S. Environmental Protection Agency under IAG 
#DW13938432-01-0.
    (18) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Four DAT Probes, `` 
Prepared for the U.S. Environmental Protection Agency under IAG 
#DW13938432-01-0.
    (19) Norfleet, S.K., ``An Evaluation of Wall Effects on Stack Flow 
Velocities and Related Overestimation Bias in EPA's Stack Flow Reference 
Methods,'' EPRI CEMS User's Group Meeting, New Orleans, Louisiana, May 
13-15, 1998.

[[Page 683]]

    (20) Page, J.J., E.A. Potts, and R.T. Shigehara, ``3-D Pitot Tube 
Calibration Study,'' EPA Contract No. 68D10009, Work Assignment No. I-
121, March 11, 1993.
    (21) Shigehara, R.T., W.F. Todd, and W.S. Smith, ``Significance of 
Errors in Stack Sampling Measurements,'' Presented at the Annual Meeting 
of the Air Pollution Control Association, St. Louis, Missouri, June 
1419, 1970.
    (22) The Cadmus Group, Inc., May 1999, ``EPA Flow Reference Method 
Testing and Analysis: Findings Report,'' EPA/430-R-99-009.
    (23) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Texas Utilities, DeCordova Steam 
Electric Station, Volume I: Test Description and Appendix A (Data 
Distribution Package),'' EPA/430-R-98-015a.
    (24) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Texas Utilities, Lake Hubbard Steam 
Electric Station, Volume I: Test Description and Appendix A (Data 
Distribution Package),'' EPA/430-R-98-017a.
    (25) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Pennsylvania Electric Co., G.P.U. 
Genco Homer City Station: Unit 1, Volume I: Test Description and 
Appendix A (Data Distribution Package),'' EPA/430-R-98-018a.
    (26) The Cadmus Group, Inc., 1997, ``EPA Flow Reference Method 
Testing and Analysis: Wind Tunnel Experimental Results,'' EPA/430-R-97-
013.

                              18.0  Annexes

    Annex A, C, and D describe recommended procedures for meeting 
certain provisions in sections 8.3, 10.4, and 10.5 of this method. Annex 
B describes procedures to be followed when using the protractor wheel 
and pointer assembly to measure yaw angles, as provided under section 
8.9.1.
    18.1  Annex A--Rotational Position Check. The following are 
recommended procedures that may be used to satisfy the rotational 
position check requirements of section 8.3 of this method and to 
determine the angle-measuring device rotational offset 
(RADO).
    18.1.1  Rotational position check with probe outside stack. Where 
physical constraints at the sampling location allow full assembly of the 
probe outside the stack and insertion into the test port, the following 
procedures should be performed before the start of testing. Two angle-
measuring devices that meet the specifications in section 6.2.1 or 6.2.3 
are required for the rotational position check. An angle measuring 
device whose position can be independently adjusted (e.g., by means of a 
set screw) after being locked into position on the probe sheath shall 
not be used for this check unless the independent adjustment is set so 
that the device performs exactly like a device without the capability 
for independent adjustment. That is, when aligned on the probe such a 
device must give the same reading as a device that does not have the 
capability of being independently adjusted. With the fully assembled 
probe (including probe shaft extensions, if any) secured in a horizontal 
position, affix one yaw angle-measuring device to the probe sheath and 
lock it into position on the reference scribe line specified in section 
6.1.5.1. Position the second angle-measuring device using the procedure 
in section 18.1.1.1 or 18.1.1.2.
    18.1.1.1  Marking procedure. The procedures in this section should 
be performed at each location on the fully assembled probe where the yaw 
angle-measuring device will be mounted during the velocity traverse. 
Place the second yaw angle-measuring device on the main probe sheath (or 
extension) at the position where a yaw angle will be measured during the 
velocity traverse. Adjust the position of the second angle-measuring 
device until it indicates the same angle (1 deg.) as the 
reference device, and affix the second device to the probe sheath (or 
extension). Record the angles indicated by the two angle-measuring 
devices on a form similar to table 2G-2. In this position, the second 
angle-measuring device is considered to be properly positioned for yaw 
angle measurement. Make a mark, no wider than 1.6 mm (\1/16\ in.), on 
the probe sheath (or extension), such that the yaw angle-measuring 
device can be re-affixed at this same properly aligned position during 
the velocity traverse.
    18.1.1.2  Procedure for probe extensions with scribe lines. If, 
during a velocity traverse the angle-measuring device will be affixed to 
a probe extension having a scribe line as specified in section 6.1.5.2, 
the following procedure may be used to align the extension's scribe line 
with the reference scribe line instead of marking the extension as 
described in section 18.1.1.1. Attach the probe extension to the main 
probe. Align and lock the second angle-measuring device on the probe 
extension's scribe line. Then, rotate the extension until both measuring 
devices indicate the same angle (1 deg.). Lock the extension 
at this rotational position. Record the angles indicated by the two 
angle-measuring devices on a form similar to table 2G-2. An angle-
measuring device may be aligned at any position on this scribe line 
during the velocity traverse, if the scribe line meets the alignment 
specification in section 6.1.5.3.
    18.1.1.3  Post-test rotational position check. If the fully 
assembled probe includes one or more extensions, the following check 
should be performed immediately after the completion of a velocity 
traverse. At the discretion of the tester, additional checks may be 
conducted after completion of testing at

[[Page 684]]

any sample port. Without altering the alignment of any of the components 
of the probe assembly used in the velocity traverse, secure the fully 
assembled probe in a horizontal position. Affix an angle-measuring 
device at the reference scribe line specified in section 6.1.5.1. Use 
the other angle-measuring device to check the angle at each location 
where the device was checked prior to testing. Record the readings from 
the two angle-measuring devices.
    18.1.2  Rotational position check with probe in stack. This section 
applies only to probes that, due to physical constraints, cannot be 
inserted into the test port as fully assembled with all necessary 
extensions needed to reach the inner-most traverse point(s).
    18.1.2.1  Perform the out-of-stack procedure in section 18.1.1 on 
the main probe and any attached extensions that will be initially 
inserted into the test port.
    18.1.2.2  Use the following procedures to perform additional 
rotational position check(s) with the probe in the stack, each time a 
probe extension is added. Two angle-measuring devices are required. The 
first of these is the device that was used to measure yaw angles at the 
preceding traverse point, left in its properly aligned measurement 
position. The second angle-measuring device is positioned on the added 
probe extension. Use the applicable procedures in section 18.1.1.1 or 
18.1.1.2 to align, adjust, lock, and mark (if necessary) the position of 
the second angle-measuring device to within 1 deg. of the 
first device. Record the readings of the two devices on a form similar 
to Table 2G-2.
    18.1.2.3  The procedure in section 18.1.2.2 should be performed at 
the first port where measurements are taken. The procedure should be 
repeated each time a probe extension is re-attached at a subsequent 
port, unless the probe extensions are designed to be locked into a 
mechanically fixed rotational position (e.g., through use of 
interlocking grooves), which can be reproduced from port to port as 
specified in section 8.3.5.2.
    18.2  Annex B--Angle Measurement Protocol for Protractor Wheel and 
Pointer Device. The following procedure shall be used when a protractor 
wheel and pointer assembly, such as the one described in section 6.2.2 
and illustrated in Figure 2G-5 is used to measure the yaw angle of flow. 
With each move to a new traverse point, unlock, re-align, and re-lock 
the probe, angle-pointer collar, and protractor wheel to each other. At 
each such move, particular attention is required to ensure that the 
scribe line on the angle pointer collar is either aligned with the 
reference scribe line on the main probe sheath or is at the rotational 
offset position established under section 8.3.1. The procedure consists 
of the following steps:
    18.2.1  Affix a protractor wheel to the entry port for the test 
probe in the stack or duct.
    18.2.2  Orient the protractor wheel so that the 0 deg. mark 
corresponds to the longitudinal axis of the stack or duct. For stacks, 
vertical ducts, or ports on the side of horizontal ducts, use a digital 
inclinometer meeting the specifications in section 6.2.1 to locate the 
0 deg. orientation. For ports on the top or bottom of horizontal ducts, 
identify the longitudinal axis at each test port and permanently mark 
the duct to indicate the 0 deg. orientation. Once the protractor wheel 
is properly aligned, lock it into position on the test port.
    18.2.3  Move the pointer assembly along the probe sheath to the 
position needed to take measurements at the first traverse point. Align 
the scribe line on the pointer collar with the reference scribe line or 
at the rotational offset position established under section 8.3.1. 
Maintaining this rotational alignment, lock the pointer device onto the 
probe sheath. Insert the probe into the entry port to the depth needed 
to take measurements at the first traverse point.
    18.2.4  Perform the yaw angle determination as specified in sections 
8.9.3 and 8.9.4 and record the angle as shown by the pointer on the 
protractor wheel. Then, take velocity pressure and temperature 
measurements in accordance with the procedure in section 8.9.5. Perform 
the alignment check described in section 8.9.6.
    18.2.5  After taking velocity pressure measurements at that traverse 
point, unlock the probe from the collar and slide the probe through the 
collar to the depth needed to reach the next traverse point.
    18.2.6  Align the scribe line on the pointer collar with the 
reference scribe line on the main probe or at the rotational offset 
position established under section 8.3.1. Lock the collar onto the 
probe.
    18.2.7  Repeat the steps in sections 18.2.4 through 18.2.6 at the 
remaining traverse points accessed from the current stack or duct entry 
port.
    18.2.8  After completing the measurement at the last traverse point 
accessed from a port, verify that the orientation of the protractor 
wheel on the test port has not changed over the course of the traverse 
at that port. For stacks, vertical ducts, or ports on the side of 
horizontal ducts, use a digital inclinometer meeting the specifications 
in section 6.2.1 to check the rotational position of the 0 deg. mark on 
the protractor wheel. For ports on the top or bottom of horizontal 
ducts, observe the alignment of the angle wheel 0 deg. mark relative to 
the permanent 0 deg. mark on the duct at that test port. If these 
observed comparisons exceed 2 deg. of 0 deg., all angle and 
pressure measurements taken at that port since the protractor wheel was 
last locked into position on the port shall be repeated.
    18.2.9  Move to the next stack or duct entry port and repeat the 
steps in sections 18.2.1 through 18.2.8.

[[Page 685]]

    18.3  Annex C--Guideline for Reference Scribe Line Placement. Use of 
the following guideline is recommended to satisfy the requirements of 
section 10.4 of this method. The rotational position of the reference 
scribe line should be either 90 deg. or 180 deg. from the probe's impact 
pressure port. For Type-S probes, place separate scribe lines, on 
opposite sides of the probe sheath, if both the A and B sides of the 
pitot tube are to be used for yaw angle measurements.
    18.4  Annex D--Determination of Reference Scribe Line Rotational 
Offset. The following procedures are recommended for determining the 
magnitude and sign of a probe's reference scribe line rotational offset, 
RSLO. Separate procedures are provided for two types of 
angle-measuring devices: digital inclinometers and protractor wheel and 
pointer assemblies.
    18.4.1  Perform the following procedures on the main probe with all 
devices that will be attached to the main probe in the field [such as 
thermocouples, resistance temperature detectors (RTDs), or sampling 
nozzles] that may affect the flow around the probe head. Probe shaft 
extensions that do not affect flow around the probe head need not be 
attached during calibration.
    18.4.2  The procedures below assume that the wind tunnel duct used 
for probe calibration is horizontal and that the flow in the calibration 
wind tunnel is axial as determined by the axial flow verification check 
described in section 10.1.2. Angle-measuring devices are assumed to 
display angles in alternating 0 deg. to 90 deg. and 90 deg. to 0 deg. 
intervals. If angle-measuring devices with other readout conventions are 
used or if other calibration wind tunnel duct configurations are used, 
make the appropriate calculational corrections. For Type-S probes, 
calibrate the A-side and B-sides separately, using the appropriate 
scribe line (see section 18.3, above), if both the A and B sides of the 
pitot tube are to be used for yaw angle determinations.
    18.4.2.1  Position the angle-measuring device in accordance with one 
of the following procedures.
    18.4.2.1.1  If using a digital inclinometer, affix the calibrated 
digital inclinometer to the probe. If the digital inclinometer can be 
independently adjusted after being locked into position on the probe 
sheath (e.g., by means of a set screw), the independent adjustment must 
be set so that the device performs exactly like a device without the 
capability for independent adjustment. That is, when aligned on the 
probe the device must give the same readings as a device that does not 
have the capability of being independently adjusted. Either align it 
directly on the reference scribe line or on a mark aligned with the 
scribe line determined according to the procedures in section 18.1.1.1. 
Maintaining this rotational alignment, lock the digital inclinometer 
onto the probe sheath.
    18.4.2.1.2  If using a protractor wheel and pointer device, orient 
the protractor wheel on the test port so that the 0 deg. mark is aligned 
with the longitudinal axis of the wind tunnel duct. Maintaining this 
alignment, lock the wheel into place on the wind tunnel test port. Align 
the scribe line on the pointer collar with the reference scribe line or 
with a mark aligned with the reference scribe line, as determined under 
section 18.1.1.1. Maintaining this rotational alignment, lock the 
pointer device onto the probe sheath.
    18.4.2.2  Zero the pressure-measuring device used for yaw nulling.
    18.4.2.3  Insert the probe assembly into the wind tunnel through the 
entry port, positioning the probe's impact port at the calibration 
location. Check the responsiveness of the pressure-measuring device to 
probe rotation, taking corrective action if the response is 
unacceptable.
    18.4.2.4  Ensure that the probe is in a horizontal position using a 
carpenter's level.
    18.4.2.5  Rotate the probe either clockwise or counterclockwise 
until a yaw null [zero P for a Type S probe or zero 
(P2-P3) for a 3-D probe] is obtained. If using a 
Type S probe with an attached thermocouple, the direction of the probe 
rotation shall be such that the thermocouple is located downstream of 
the probe pressure ports at the yaw-null position.
    18.4.2.6  Read and record the value of null, 
the angle indicated by the angle-measuring device at the yaw-null 
position. Record the angle reading on a form similar to Table 2G-6. Do 
not associate an algebraic sign with this reading.
    18.4.2.7  Determine the magnitude and algebraic sign of the 
reference scribe line rotational offset, RSLO. The magnitude 
of RSLO will be equal to either null or 
(90 deg.-null), depending on the type of probe 
being calibrated and the type of angle-measuring device used. (See Table 
2G-7 for a summary.) The algebraic sign of RSLO will either 
be positive if the rotational position of the reference scribe line is 
clockwise or negative if counterclockwise with respect to the probe's 
yaw-null position. Figure 2G-10 illustrates how the magnitude and sign 
of RSLO are determined.
    18.4.2.8  Perform the steps in sections 18.3.2.3 through 18.3.2.7 
twice at each of the two calibration velocities selected for the probe 
under section 10.6. Record the values of RSLO in a form 
similar to Table 2G-6.
    18.4.2.9  The average of all RSLO values is the reference 
scribe line rotational offset for the probe.


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   Method 2H--Determination of Stack Gas Velocity Taking Into Account 
                   Velocity Decay Near the Stack Wall

                       1.0  Scope and Application

    1.1  This method is applicable in conjunction with Methods 2, 2F, 
and 2G (40 CFR Part 60, Appendix A) to account for velocity decay near 
the wall in circular stacks and ducts.
    1.2  This method is not applicable for testing stacks and ducts less 
than 3.3 ft (1.0 m) in diameter.
    1.3  Data Quality Objectives. Adherence to the requirements of this 
method will enhance the quality of the data obtained from air pollutant 
sampling methods.

                         2.0  Summary of Method

    2.1  A wall effects adjustment factor is determined. It is used to 
adjust the average stack gas velocity obtained under Method 2, 2F, or 2G 
of this appendix to take into account velocity decay near the stack or 
duct wall.
    2.2  The method contains two possible procedures: a calculational 
approach which derives an adjustment factor from velocity measurements 
and a default procedure which assigns a generic adjustment factor based 
on the construction of the stack or duct.
    2.2.1  The calculational procedure derives a wall effects adjustment 
factor from velocity measurements taken using Method 2, 2F, or 2G at 16 
(or more) traverse points specified under Method 1 of this appendix and 
a total of eight (or more) wall effects traverse points specified under 
this method. The calculational procedure based on velocity measurements 
is not applicable for horizontal circular ducts where build-up of 
particulate matter or other material in the bottom of the duct is 
present.
    2.2.2  A default wall effects adjustment factor of 0.9900 for brick 
and mortar stacks and 0.9950 for all other types of stacks and ducts may 
be used without taking wall effects measurements in a stack or duct.
    2.3  When the calculational procedure is conducted as part of a 
relative accuracy test audit (RATA) or other multiple-run test 
procedure, the wall effects adjustment factor derived from a single 
traverse (i.e., single RATA run) may be applied to all runs of the same 
RATA without repeating the wall effects measurements. Alternatively, 
wall effects adjustment factors may be derived for several traverses and 
an average wall effects adjustment factor applied to all runs of the 
same RATA.
    3.0  Definitions.
    3.1  Complete wall effects traverse means a traverse in which 
measurements are taken at drem (see section 3.3) and at 1-in. 
intervals in each of the four Method 1 equal-area sectors closest to the 
wall, beginning not farther than 4 in. (10.2 cm) from the wall and 
extending either (1) across the entire width of the Method 1 equal-area 
sector or (2) for stacks or ducts where this width exceeds 12 in. (30.5 
cm) (i.e., stacks or ducts greater than or equal to 15.6 ft [4.8 m] in 
diameter), to a distance of not less than 12 in. (30.5 cm) from the 
wall. Note: Because this method specifies that measurements must be 
taken at whole number multiples of 1 in. from a stack or duct wall, for 
clarity numerical quantities in this method are expressed in English 
units followed by metric units in parentheses. To enhance readability, 
hyphenated terms such as ``1-in. intervals'' or ``1-in. incremented,'' 
are expressed in English units only.
    3.2  dlast Depending on context, dlast means 
either (1) the distance from the wall of the last 1-in. incremented wall 
effects traverse point or (2) the traverse point located at that 
distance (see Figure 2H-2).
    3.3  drem Depending on context, drem means 
either (1) the distance from the wall of the centroid of the area 
between dlast and the interior edge of the Method 1 equal-
area sector closest to the wall or (2) the traverse point located at 
that distance (see Figure 2H-2).
    3.4  ``May,'' ``Must,'' ``Shall,'' ``Should,'' and the imperative 
form of verbs.
    3.4.1  ``May'' is used to indicate that a provision of this method 
is optional.
    3.4.2  ``Must,'' ``Shall,'' and the imperative form of verbs (such 
as ``record'' or ``enter'') are used to indicate that a provision of 
this method is mandatory.
    3.4.3  ``Should'' is used to indicate that a provision of this 
method is not mandatory but is highly recommended as good practice.
    3.5  Method 1 refers to 40 CFR part 60, appendix A, ``Method 1--
Sample and velocity traverses for stationary sources.''
    3.6  Method 1 exterior equal-area sector and Method 1 equal-area 
sector closest to the wall mean any one of the four equal-area sectors 
that are closest to the wall for a circular stack or duct laid out in 
accordance with section 2.3.1 of Method 1 (see Figure 2H-1).
    3.7  Method 1 interior equal-area sector means any of the equal-area 
sectors other than the Method 1 exterior equal-area sectors (as defined 
in section 3.6) for a circular stack or duct laid out in accordance with 
section 2.3.1 of Method 1 (see Figure 2H-1).
    3.8  Method 1 traverse point and Method 1 equal-area traverse point 
mean a traverse point located at the centroid of an equal-area sector of 
a circular stack laid out in accordance with section 2.3.1 of Method 1.
    3.9  Method 2 refers to 40 CFR part 60, appendix A, ``Method 2--
Determination of stack gas velocity and volumetric flow rate (Type S 
pitot tube).''
    3.10  Method 2F refers to 40 CFR part 60, appendix A, ``Method 2F--
Determination of stack gas velocity and volumetric flow rate with three-
dimensional probes.''

[[Page 702]]

    3.11  Method 2G refers to 40 CFR part 60, appendix A, ``Method 2G--
Determination of stack gas velocity and volumetric flow rate with two-
dimensional probes.''
    3.12  1-in. incremented wall effects traverse point means any of the 
wall effects traverse points that are located at 1-in. intervals, i.e., 
traverse points d1 through dlast (see Figure 2H-
2).
    3.13  Partial wall effects traverse means a traverse in which 
measurements are taken at fewer than the number of traverse points 
required for a ``complete wall effects traverse'' (as defined in section 
3.1), but are taken at a minimum of two traverse points in each Method 1 
equal-area sector closest to the wall, as specified in section 8.2.2.
    3.14  Relative accuracy test audit (RATA) is a field test procedure 
performed in a stack or duct in which a series of concurrent 
measurements of the same stack gas stream is taken by a reference method 
and an installed monitoring system. A RATA usually consists of series of 
9 to 12 sets of such concurrent measurements, each of which is referred 
to as a RATA run. In a volumetric flow RATA, each reference method run 
consists of a complete traverse of the stack or duct.
    3.15  Wall effects-unadjusted average velocity means the average 
stack gas velocity, not accounting for velocity decay near the wall, as 
determined in accordance with Method 2, 2F, or 2G for a Method 1 
traverse consisting of 16 or more points.
    3.16  Wall effects-adjusted average velocity means the average stack 
gas velocity, taking into account velocity decay near the wall, as 
calculated from measurements at 16 or more Method 1 traverse points and 
at the additional wall effects traverse points specified in this method.
    3.17  Wall effects traverse point means a traverse point located in 
accordance with sections 8.2.2 or 8.2.3 of this method.

                     4.0  Interferences. [Reserved]

                               5.0  Safety

    5.1  This method may involve hazardous materials, operations, and 
equipment. This method does not purport to address all of the health and 
safety considerations associated with its use. It is the responsibility 
of the user of this method to establish appropriate health and safety 
practices and to determine the applicability of occupational health and 
safety regulatory requirements prior to performing this method.

                       6.0  Equipment and Supplies

    6.1  The provisions pertaining to equipment and supplies in the 
method that is used to take the traverse point measurements (i.e., 
Method 2, 2F, or 2G) are applicable under this method.

                 7.0  Reagents and Standards. [Reserved]

                   8.0  Sample Collection and Analysis

    8.1  Default Wall Effects Adjustment Factors. A default wall effects 
adjustment factor of 0.9900 for brick and mortar stacks and 0.9950 for 
all other types of stacks and ducts may be used without conducting the 
following procedures.
    8.2  Traverse Point Locations. Determine the location of the Method 
1 traverse points in accordance with section 8.2.1 and the location of 
the traverse points for either a partial wall effects traverse in 
accordance with section 8.2.2 or a complete wall effects traverse in 
accordance with section 8.2.3.
    8.2.1  Method 1 equal-area traverse point locations. Determine the 
location of the Method 1 equal-area traverse points for a traverse 
consisting of 16 or more points using Table 1-2 (Location of Traverse 
Points in Circular Stacks) of Method 1.
    8.2.2  Partial wall effects traverse. For a partial wall effects 
traverse, measurements must be taken at a minimum of the following two 
wall effects traverse point locations in all four Method 1 equal-area 
sectors closest to the wall: (1) 1 in. (2.5 cm) from the wall (except as 
provided in section 8.2.2.1) and (2) drem, as determined 
using Equation 2H-1 or 2H-2 (see section 8.2.2.2).
    8.2.2.1  If the probe cannot be positioned at 1 in. (2.5 cm) from 
the wall (e.g., because of insufficient room to withdraw the probe 
shaft) or if velocity pressure cannot be detected at 1 in. (2.5 cm) from 
the wall (for any reason other than build-up of particulate matter in 
the bottom of a duct), take measurements at the 1-in. incremented wall 
effects traverse point closest to the wall where the probe can be 
positioned and velocity pressure can be detected.

[[Page 703]]

    8.2.2.2  Calculate the distance of drem from the wall to 
within \1/4\ in. (6.4 mm) using Equation 2H-1 or Equation 
2H-2 (for a 16-point traverse).
[GRAPHIC] [TIFF OMITTED] TR14MY99.074

Where:

r = the stack or duct radius determined from direct measurement of the 
          stack or duct diameter in accordance with section 8.6 of 
          Method 2F or Method 2G, in. (cm);
p = the number of Method 1 equal-area traverse points on a diameter, p 
           8 (e.g., for a 16-point traverse, p = 8); 
          dlast and drem are defined in sections 
          3.2 and 3.3 respectively, in. (cm).

For a 16-point Method 1 traverse, Equation 2H-1 becomes:
[GRAPHIC] [TIFF OMITTED] TR14MY99.075

    8.2.2.3  Measurements may be taken at any number of additional wall 
effects traverse points, with the following provisions.
    (a) dlast must not be closer to the center of the stack 
or duct than the distance of the interior edge (boundary), 
db, of the Method 1 equal-area sector closest to the wall 
(see Figure 2H-2 or 2H-3). That is,

Where:
[GRAPHIC] [TIFF OMITTED] TR14MY99.076

Table 2H-1 shows db as a function of the stack or duct 
radius, r, for traverses ranging from 16 to 48 points (i.e., for values 
of p ranging from 8 to 24).
    (b) Each point must be located at a distance that is a whole number 
(e.g., 1, 2, 3) multiple of 1 in. (2.5 cm).
    (c) Points do not have to be located at consecutive 1-in. intervals. 
That is, one or more 1-in. incremented points may be skipped. For 
example, it would be acceptable for points to be located at 1 in. (2.5 
cm), 3 in. (7.6 cm), 5 in. (12.7 cm), dlast, and 
drem; or at 1 in. (2.5 cm), 2 in. (5.1 cm), 4 in. (10.2 cm), 
7 in. (17.8 cm), dlast, and drem. Follow the 
instructions in section 8.7.1.2 of this method for recording results for 
wall effects traverse points that are skipped. It should be noted that 
the full extent of velocity decay may not be accounted for if 
measurements are not taken at all 1-in. incremented points close to the 
wall.
    8.2.3  Complete wall effects traverse. For a complete wall effects 
traverse, measurements must be taken at the following points in all four 
Method 1 equal-area sectors closest to the wall.
    (a) The 1-in. incremented wall effects traverse point closest to the 
wall where the probe can be positioned and velocity can be detected, but 
no farther than 4 in. (10.2 cm) from the wall.
    (b) Every subsequent 1-in. incremented wall effects traverse point 
out to the interior edge of the Method 1 equal-area sector or to 12 in. 
(30.5 cm) from the wall, whichever comes first. Note: In stacks or ducts 
with diameters greater than 15.6 ft (4.8 m) the interior edge of the 
Method 1 equal-area sector is farther from the wall than 12 in. (30.5 
cm).
    (c) drem, as determined using Equation 2H-1 or 2H-2 (as 
applicable). Note: For a complete traverse of a stack or duct with a 
diameter less than 16.5 ft (5.0 m), the distance between 
drem and dlast is less than or equal to \1/2\ in. 
(12.7 mm). As discussed in section 8.2.4.2, when the distance between 
drem and dlast is less than or equal to \1/2\ in. 
(12.7 mm), the velocity measured at dlast may be used for 
drem. Thus, it is not necessary to calculate the distance of 
drem or to take measurements at drem when 
conducting a complete traverse of a stack or duct with a diameter less 
than 16.5 ft (5.0 m).
    8.2.4  Special considerations. The following special considerations 
apply when the distance between traverse points is less than or equal to 
\1/2\ in. (12.7 mm).
    8.2.4.1  A wall effects traverse point and the Method 1 traverse 
point. If the distance between a wall effects traverse point and the 
Method 1 traverse point is less than or equal to \1/2\ in. (12.7 mm), 
taking measurements at

[[Page 704]]

both points is allowed but not required or recommended; if measurements 
are taken at only one point, take the measurements at the point that is 
farther from the wall and use the velocity obtained at that point as the 
value for both points (see sections 8.2.3 and 9.2 for related 
requirements).
    8.2.4.2  drem and dlast. If the distance 
between drem and dlast is less than or equal to 
\1/2\ in. (12.7 mm), taking measurements at drem is allowed 
but not required or recommended; if measurements are not taken at 
drem, the measured velocity value at dlast must be 
used as the value for both dlast and drem.
    8.3  Traverse Point Sampling Order and Probe Selection. Determine 
the sampling order of the Method 1 and wall effects traverse points and 
select the appropriate probe for the measurements, taking into account 
the following considerations.
    8.3.1  Traverse points on any radius may be sampled in either 
direction (i.e., from the wall toward the center of the stack or duct, 
or vice versa).
    8.3.2  To reduce the likelihood of velocity variations during the 
time of the traverse and the attendant potential impact on the wall 
effects-adjusted and unadjusted average velocities, the following 
provisions of this method shall be met.
    8.3.2.1  Each complete set of Method 1 and wall effects traverse 
points accessed from the same port shall be sampled without 
interruption. Unless traverses are performed simultaneously in all ports 
using separate probes at each port, this provision disallows first 
sampling all Method 1 points at all ports and then sampling all the wall 
effects points.
    8.3.2.2  The entire integrated Method 1 and wall effects traverse 
across all test ports shall be as short as practicable, consistent with 
the measurement system response time (see section 8.4.1.1) and sampling 
(see section 8.4.1.2) provisions of this method.
    8.3.3  It is recommended but not required that in each Method 1 
equal-area sector closest to the wall, the Method 1 equal-area traverse 
point should be sampled in sequence between the adjacent wall effects 
traverse points. For example, for the traverse point configuration shown 
in Figure 2H-2, it is recommended that the Method 1 equal-area traverse 
point be sampled between dlast and drem. In this 
example, if the traverse is conducted from the wall toward the center of 
the stack or duct, it is recommended that measurements be taken at 
points in the following order: d1, d2, 
dlast, the Method 1 traverse point, drem, and then 
at the traverse points in the three Method 1 interior equal-area 
sectors.
    8.3.4  The same type of probe must be used to take measurements at 
all Method 1 and wall effects traverse points. However, different copies 
of the same type of probe may be used at different ports (e.g., Type S 
probe 1 at port A, Type S probe 2 at port B) or at different traverse 
points accessed from a particular port (e.g., Type S probe 1 for Method 
1 interior traverse points accessed from port A, Type S probe 2 for wall 
effects traverse points and the Method 1 exterior traverse point 
accessed from port A). The identification number of the probe used to 
obtain measurements at each traverse point must be recorded.
    8.4  Measurements at Method 1 and Wall Effects Traverse Points. 
Conduct measurements at Method 1 and wall effects traverse points in 
accordance with Method 2, 2F, or 2G and in accordance with the 
provisions of the following subsections (some of which are included in 
Methods 2F and 2G but not in Method 2), which are particularly important 
for wall effects testing.
    8.4.1  Probe residence time at wall effects traverse points. Due to 
the steep temperature and pressure gradients that can occur close to the 
wall, it is very important for the probe residence time (i.e., the total 
time spent at a traverse point) to be long enough to ensure collection 
of representative temperature and pressure measurements. The provisions 
of Methods 2F and 2G in the following subsections shall be observed.
    8.4.1.1  System response time. Determine the response time of each 
probe measurement system by inserting and positioning the ``cold'' probe 
(at ambient temperature and pressure) at any Method 1 traverse point. 
Read and record the probe differential pressure, temperature, and 
elapsed time at 15-second intervals until stable readings for both 
pressure and temperature are achieved. The response time is the longer 
of these two elapsed times. Record the response time.
    8.4.1.2  Sampling. At the start of testing in each port (i.e., after 
a probe has been inserted into the stack gas stream), allow at least the 
response time to elapse before beginning to take measurements at the 
first traverse point accessed from that port. Provided that the probe is 
not removed from the stack gas stream, measurements may be taken at 
subsequent traverse points accessed from the same test port without 
waiting again for the response time to elapse.
    8.4.2  Temperature measurement for wall effects traverse points. 
Either (1) take temperature measurements at each wall effects traverse 
point in accordance with the applicable provisions of Method 2, 2F, or 
2G; or (2) use the temperature measurement at the Method 1 traverse 
point closest to the wall as the temperature measurement for all the 
wall effects traverse points in the corresponding equal-area sector.
    8.4.3  Non-detectable velocity pressure at wall effects traverse 
points. If the probe cannot be positioned at a wall effects traverse 
point or if no velocity pressure can be detected at a wall effects 
point, measurements shall be taken at the first subsequent wall

[[Page 705]]

effects traverse point farther from the wall where velocity can be 
detected. Follow the instructions in section 8.7.1.2 of this method for 
recording results for wall effects traverse points where velocity 
pressure cannot be detected. It should be noted that the full extent of 
velocity decay may not be accounted for if measurements are not taken at 
the 1-in. incremented wall effects traverse points closest to the wall.
    8.5  Data Recording. For each wall effects and Method 1 traverse 
point where measurements are taken, record all pressure, temperature, 
and attendant measurements prescribed in section 3 of Method 2 or 
section 8.0 of Method 2F or 2G, as applicable.
    8.6  Point Velocity Calculation. For each wall effects and Method 1 
traverse point, calculate the point velocity value (vi) in 
accordance with sections 12.1 and 12.2 of Method 2F for tests using 
Method 2F and in accordance with sections 12.1 and 12.2 of Method 2G for 
tests using Method 2 and Method 2G. (Note that the term (vi) 
in this method corresponds to the term (va(i)) in Methods 2F 
and 2G.) When the equations in the indicated sections of Method 2G are 
used in deriving point velocity values for Method 2 tests, set the value 
of the yaw angles appearing in the equations to 0 deg..
    8.7  Tabulating Calculated Point Velocity Values for Wall Effects 
Traverse Points. Enter the following values in a hardcopy or electronic 
form similar to Form 2H-1 (for 16-point Method 1 traverses) or Form 2H-2 
(for Method 1 traverses consisting of more than 16 points). A separate 
form must be completed for each of the four Method 1 equal-area sectors 
that are closest to the wall.
    (a) Port ID (e.g., A, B, C, or D)
    (b) Probe type
    (c) Probe ID
    (d) Stack or duct diameter in ft (m) (determined in accordance with 
section 8.6 of Method 2F or Method 2G)
    (e) Stack or duct radius in in. (cm)
    (f) Distance from the wall of wall effects traverse points at 1-in. 
intervals, in ascending order starting with 1 in. (2.5 cm) (column A of 
Form 2H-1 or 2H-2)
    (g) Point velocity values (vd) for 1-in. incremented 
traverse points (see section 8.7.1), including dlast (see 
section 8.7.2)
    (h) Point velocity value (vdrem) at drem (see 
section 8.7.3).

    8.7.1   Point velocity values at wall effects traverse points other 
than dlast. For every 1-in. incremented wall effects traverse 
point other than dlast, enter in column B of Form 2H-1 or 2H-
2 either the velocity measured at the point (see section 8.7.1.1) or the 
velocity measured at the first subsequent traverse point farther from 
the wall (see section 8.7.1.2). A velocity value must be entered in 
column B of Form 2H-1 or 2H-2 for every 1-in. incremented traverse point 
from d1 (representing the wall effects traverse point 1 in. 
[2.5 cm] from the wall) to dlast.
    8.7.1.1  For wall effects traverse points where the probe can be 
positioned and velocity pressure can be detected, enter the value 
obtained in accordance with section 8.6.
    8.7.1.2  For wall effects traverse points that were skipped [see 
section 8.2.2.3(c)] and for points where the probe cannot be positioned 
or where no velocity pressure can be detected, enter the value obtained 
at the first subsequent traverse point farther from the wall where 
velocity pressure was detected and measured and follow the entered value 
with a ``flag,'' such as the notation ``NM,'' to indicate that ``no 
measurements'' were actually taken at this point.
    8.7.2  Point velocity value at dlast. For 
dlast, enter in column B of Form 2H-1 or 2H-2 the measured 
value obtained in accordance with section 8.6.
    8.7.3  Point velocity value (vdrem) at drem. 
Enter the point velocity value obtained at drem in column G 
of row 4a in Form 2H-1 or 2H-2. If the distance between drem 
and dlast is less than or equal to \1/2\ in. (12.7 mm), the 
measured velocity value at dlast may be used as the value at 
drem (see section 8.2.4.2).
    9.0  Quality Control.
    9.1  Particulate Matter Build-up in Horizontal Ducts. Wall effects 
testing of horizontal circular ducts should be conducted only if build-
up of particulate matter or other material in the bottom of the duct is 
not present.
    9.2  Verifying Traverse Point Distances. In taking measurements at 
wall effects traverse points, it is very important for the probe impact 
pressure port to be positioned as close as practicable to the traverse 
point locations in the gas stream. For this reason, before beginning 
wall effects testing, it is important to calculate and record the 
traverse point positions that will be marked on each probe for each 
port, taking into account the distance that each port nipple (or probe 
mounting flange for automated probes) extends out of the stack and any 
extension of the port nipple (or mounting flange) into the gas stream. 
To ensure that traverse point positions are properly identified, the 
following procedures should be performed on each probe used.
    9.2.1  Manual probes. Mark the probe insertion distance of the wall 
effects and Method 1 traverse points on the probe sheath so that when a 
mark is aligned with the outside face of the stack port, the probe 
impact port is located at the calculated distance of the traverse point 
from the stack inside wall. The use of different colored marks is 
recommended for designating the wall effects and Method 1 traverse 
points. Before the first use of each probe, check to ensure that the 
distance of each mark from the center of the probe impact pressure port 
agrees with

[[Page 706]]

the previously calculated traverse point positions to within 
\1/4\ in. (6.4 mm).
    9.2.2  Automated probe systems. For automated probe systems that 
mechanically position the probe head at prescribed traverse point 
positions, activate the system with the probe assemblies removed from 
the test ports and sequentially extend the probes to the programmed 
location of each wall effects traverse point and the Method 1 traverse 
points. Measure the distance between the center of the probe impact 
pressure port and the inside of the probe assembly mounting flange for 
each traverse point. The measured distances must agree with the 
previously calculated traverse point positions to within \1/
4\ in. (6.4 mm).
    9.3  Probe Installation. Properly sealing the port area is 
particularly important in taking measurements at wall effects traverse 
points. For testing involving manual probes, the area between the probe 
sheath and the port should be sealed with a tightly fitting flexible 
seal made of an appropriate material such as heavy cloth so that leakage 
is minimized. For automated probe systems, the probe assembly mounting 
flange area should be checked to verify that there is no leakage.
    9.4  Velocity Stability. This method should be performed only when 
the average gas velocity in the stack or duct is relatively constant 
over the duration of the test. If the average gas velocity changes 
significantly during the course of a wall effects test, the test results 
should be discarded.

                            10.0  Calibration

    10.1  The calibration coefficient(s) or curves obtained under Method 
2, 2F, or 2G and used to perform the Method 1 traverse are applicable 
under this method.

                       11.0  Analytical Procedure

    11.1  Sample collection and analysis are concurrent for this method 
(see section 8).

                  12.0  Data Analysis and Calculations

    12.1  The following calculations shall be performed to obtain a wall 
effects adjustment factor (WAF) from (1) the wall effects-unadjusted 
average velocity (T4avg), (2) the replacement velocity (vej) 
for each of the four Method 1 sectors closest to the wall, and (3) the 
average stack gas velocity that accounts for velocity decay near the 
wall (vavg).
    12.2  Nomenclature. The following terms are listed in the order in 
which they appear in Equations 2H-5 through 2H-21.

vavg=the average stack gas velocity, unadjusted for wall 
effects, actual ft/sec (m/sec);
vii=stack gas point velocity value at Method 1 interior 
equal-area sectors, actual ft/sec (m/sec);
vej=stack gas point velocity value, unadjusted for wall 
effects, at Method 1 exterior equal-area sectors, actual ft/sec (m/sec);
i=index of Method 1 interior equal-area traverse points;
j=index of Method 1 exterior equal-area traverse points;
n=total number of traverse points in the Method 1 traverse;
vdecd=the wall effects decay velocity for a sub-sector 
located between the traverse points at distances d-1 (in metric units, 
d-2.5) and d from the wall, actual ft/sec (m/sec);
vd=the measured stack gas velocity at distance d from the 
wall, actual ft/sec (m/sec); Note: v0=0;
d=the distance of a 1-in. incremented wall effects traverse point from 
the wall, for traverse points d1 through dlast, 
in. (cm);
Ad=the cross-sectional area of a sub-sector located between 
the traverse points at distances d-1 (in metric units, d-2.5) and d from 
the wall, in.\2\ (cm \2\) ( e.g., sub-sector A2 shown in 
Figures 2H-3 and 2H-4);
r=the stack or duct radius, in. (cm);
Qd=the stack gas volumetric flow rate for a sub-sector 
located between the traverse points at distances d-1 (in metric units, 
d-2.5) and d from the wall, actual ft-in.\2\/sec (m-cm \2\/sec);
Qd1dlast= the total stack gas volumetric flow rate for all sub-sectors located between the wall and 
dlast, 
actual ft-in.\2\/sec (m-cm}\2\/sec)
dlast=the distance from the wall of the last 1-in. 
incremented wall effects traverse point, in. (cm);
Adrem=the cross-sectional area of the sub-sector located 
between dlast and the interior edge of the Method 1 equal-
area sector closest to the wall, in.\2\ (cm \2\) (see Figure 2H-4);
p=the number of Method 1 traverse points per diameter, p8 
(e.g., for a 16-point traverse, p=8);
drem=the distance from the wall of the centroid of the area 
between dlast and the interior edge of the Method 1 equal-
area sector closest to the wall, in. (cm);
Qdrem=the total stack gas volumetric flow rate for the sub-
sector located between dlast and the interior edge of the 
Method 1 equal-area sector closest to the wall, actual ft-in.\2\/sec (m-
cm \2\/sec);
vdrem=the measured stack gas velocity at distance drem 
from the wall, actual ft/sec (m/sec);
QT=the total stack gas volumetric flow rate for the Method 1 
equal-area sector closest to the wall, actual ft-in.\2\/sec (m-cm \2\/
sec);
vej=the replacement stack gas velocity for the Method 1 
equal-area sector closest to the wall, i.e., the stack gas point 
velocity value, adjusted for wall effects, for the jth Method 
1 equal-area sector closest to the wall, actual ft/sec (m/sec);

[[Page 707]]

vavg=the average stack gas velocity that accounts for 
velocity decay near the wall, actual ft/sec (m/sec);
WAF=the wall effects adjustment factor derived from vavg and 
vavg for a single traverse, dimensionless;
vfinal=the final wall effects-adjusted average stack gas 
velocity that replaces the unadjusted average stack gas velocity 
obtained using Method 2, 2F, or 2G for a field test consisting of a 
single traverse, actual ft/sec (m/sec);
WAF=the wall effects adjustment factor that is applied to the average 
velocity, unadjusted for wall effects, in order to obtain the final wall 
effects-adjusted stack gas velocity, vfinal or, 
vfinal(k), dimensionless;
vfinal(k)=the final wall effects-adjusted average stack gas 
velocity that replaces the unadjusted average stack gas velocity 
obtained using Method 2, 2F, or 2G on run k of a RATA or other multiple-
run field test procedure, actual ft/sec (m/sec);
vavg(k)=the average stack gas velocity, obtained on run k of 
a RATA or other multiple-run procedure, unadjusted for velocity decay 
near the wall, actual ft/sec (m/sec);
k=index of runs in a RATA or other multiple-run procedure.

    12.3  Calculate the average stack gas velocity that does not account 
for velocity decay near the wall (vavg) using Equation 2H-5.
[GRAPHIC] [TIFF OMITTED] TR14MY99.077

(Note that vavg in Equation 2H-5 is the same as v(a)avg 
in Equations 2F-9 and 2G-8 in Methods 2F and 2G, respectively.)
    For a 16-point traverse, Equation 2H-5 may be written as follows:
    [GRAPHIC] [TIFF OMITTED] TR14MY99.078
    
    12.4  Calculate the replacement velocity, vej, for each 
of the four Method 1 equal-area sectors closest to the wall using the 
procedures described in sections 12.4.1 through 12.4.8. Forms 2H-1 and 
2H-2 provide sample tables that may be used in either hardcopy or 
spreadsheet format to perform the calculations described in sections 
12.4.1 through 12.4.8. Forms 2H-3 and 2H-4 provide examples of Form 2H-1 
filled in for partial and complete wall effects traverses.
    12.4.1  Calculate the average velocity (designated the ``decay 
velocity,'' vdecd) for each sub-sector located between the 
wall and dlast (see Figure 2H-3) using Equation 2H-7.
[GRAPHIC] [TIFF OMITTED] TR14MY99.079

For each line in column A of Form 2H-1 or 2H-2 that contains a value of 
d, enter the corresponding calculated value of vdecd in 
column C.
    12.4.2  Calculate the cross-sectional area between the wall and the 
first 1-in. incremented wall effects traverse point and between 
successive 1-in. incremented wall effects traverse points, from the wall 
to dlast (see Figure 2H-3), using Equation 2H-8.
[GRAPHIC] [TIFF OMITTED] TR14MY99.080

For each line in column A of Form 2H-1 or 2H-2 that contains a value of 
d, enter the value of the expression \1/4\ (r-d+1)2 
in column D, the value of the expression \1/4\ 
(r-d)2 in column E, and the value of Ad 
in column F. Note that Equation 2H-8 is designed for use only with 
English units (in.). If metric units (cm) are used, the first term, \1/
4\ (r-d+1)2, must be changed to \1/4\ 
(r-d+2.5)2. This change must also be made in column 
D of Form 2H-1 or 2H-2.
    12.4.3  Calculate the volumetric flow through each cross-sectional 
area derived in section 12.4.2 by multiplying the values of 
vdecd, derived according to section 12.4.1, by the cross-
sectional areas derived in section 12.4.2 using Equation 2H-9.
[GRAPHIC] [TIFF OMITTED] TR14MY99.081

For each line in column A of Form 2H-1 or 2H-2 that contains a value of 
d, enter the corresponding calculated value of Qd in column 
G.
    12.4.4  Calculate the total volumetric flow through all sub-sectors 
located between the wall and dlast, using Equation 2H-10.

[[Page 708]]

[GRAPHIC] [TIFF OMITTED] TN09JY99.003

Enter the calculated value of 
Qd1dlast in line 3 of column G of Form 2H-1 or 2H-2.

    12.4.5  Calculate the cross-sectional area of the sub-sector located 
between dlast and the interior edge of the Method 1 equal-
area sector (e.g., sub-sector Adrem shown in Figures 2H-3 and 
2H-4) using Equation 2H-11.
[GRAPHIC] [TIFF OMITTED] TR14MY99.083

For a 16-point traverse (eight points per diameter), Equation 2H-11 may 
be written as follows:
[GRAPHIC] [TIFF OMITTED] TR14MY99.084

Enter the calculated value of Adrem in line 4b of column G of 
Form 2H-1 or 2H-2.
    12.4.6  Calculate the volumetric flow for the sub-sector located 
between dlast and the interior edge of the Method 1 equal-
area sector, using Equation 2H-13.
[GRAPHIC] [TIFF OMITTED] TR14MY99.085

In Equation 2H-13, vdrem is either (1) the measured velocity 
value at drem or (2) the measured velocity at 
dlast, if the distance between drem and 
dlast is less than or equal to \1/2\ in. (12.7 mm) and no 
velocity measurement is taken at drem (see section 8.2.4.2). 
Enter the calculated value of Qdrem in line 4c of column G of 
Form 2H-1 or 2H-2.
    12.4.7  Calculate the total volumetric flow for the Method 1 equal-
area sector closest to the wall, using Equation 2H-14.
[GRAPHIC] [TIFF OMITTED] TR14MY99.086

Enter the calculated value of QT in line 5a of column G of 
Form 2H-1 or 2H-2.
    12.4.8  Calculate the wall effects-adjusted replacement velocity 
value for the Method 1 equal-area sector closest to the wall, using 
Equation 2H-15.
[GRAPHIC] [TIFF OMITTED] TR14MY99.087

For a 16-point traverse (eight points per diameter), Equation 2H-15 may 
be written as follows:
[GRAPHIC] [TIFF OMITTED] TR14MY99.088

Enter the calculated value of vej in line 5B of column G of 
Form 2H-1 or 2H-2.
    12.5  Calculate the wall effects-adjusted average velocity, 
vavg, by replacing the four values of vej shown in 
Equation 2H-5 with the four wall effects-adjusted replacement velocity 
values,vej, calculated according to section 12.4.8, using 
Equation 2H-17.
[GRAPHIC] [TIFF OMITTED] TR14MY99.089

For a 16-point traverse, Equation 2H-17 may be written as follows:
[GRAPHIC] [TIFF OMITTED] TR14MY99.090

    12.6  Calculate the wall effects adjustment factor, WAF, using 
Equation 2H-19.

[[Page 709]]

[GRAPHIC] [TIFF OMITTED] TR14MY99.091

    12.6.1  Partial wall effects traverse. If a partial wall effects 
traverse (see section 8.2.2) is conducted, the value obtained from 
Equation 2H-19 is acceptable and may be reported as the wall effects 
adjustment factor provided that the value is greater than or equal to 
0.9800. If the value is less than 0.9800, it shall not be used and a 
wall effects adjustment factor of 0.9800 may be used instead.
    12.6.2  Complete wall effects traverse. If a complete wall effects 
traverse (see section 8.2.3) is conducted, the value obtained from 
Equation 2H-19 is acceptable and may be reported as the wall effects 
adjustment factor provided that the value is greater than or equal to 
0.9700. If the value is less than 0.9700, it shall not be used and a 
wall effects adjustment factor of 0.9700 may be used instead. If the 
wall effects adjustment factor for a particular stack or duct is less 
than 0.9700, the tester may (1) repeat the wall effects test, taking 
measurements at more Method 1 traverse points and (2) recalculate the 
wall effects adjustment factor from these measurements, in an attempt to 
obtain a wall effects adjustment factor that meets the 0.9700 
specification and completely characterizes the wall effects.
    12.7  Applying a Wall Effects Adjustment Factor. A default wall 
effects adjustment factor, as specified in section 8.1, or a calculated 
wall effects adjustment factor meeting the requirements of section 
12.6.1 or 12.6.2 may be used to adjust the average stack gas velocity 
obtained using Methods 2, 2F, or 2G to take into account velocity decay 
near the wall of circular stacks or ducts. Default wall effects 
adjustment factors specified in section 8.1 and calculated wall effects 
adjustment factors that meet the requirements of section 12.6.1 and 
12.6.2 are summarized in Table 2H-2.
    12.7.1  Single-run tests. Calculate the final wall effects-adjusted 
average stack gas velocity for field tests consisting of a single 
traverse using Equation 2H-20.
[GRAPHIC] [TIFF OMITTED] TR14MY99.092

The wall effects adjustment factor, WAF, shown in Equation 2H-20, may be 
(1) a default wall effects adjustment factor, as specified in section 
8.1, or (2) a calculated adjustment factor that meets the specifications 
in sections 12.6.1 or 12.6.2. If a calculated adjustment factor is used 
in Equation 2H-20, the factor must have been obtained during the same 
traverse in which vavg was obtained.
    12.7.2  RATA or other multiple run test procedure. Calculate the 
final wall effects-adjusted average stack gas velocity for any run k of 
a RATA or other multiple-run procedure using Equation 2H-21.
[GRAPHIC] [TIFF OMITTED] TR14MY99.093

The wall effects adjustment factor, WAF, shown in Equation 2H-21 may be 
(1) a default wall effects adjustment factor, as specified in section 
8.1; (2) a calculated adjustment factor (meeting the specifications in 
sections 12.6.1 or 12.6.2) obtained from any single run of the RATA that 
includes run k; or (3) the arithmetic average of more than one WAF (each 
meeting the specifications in sections 12.6.1 or 12.6.2) obtained 
through wall effects testing conducted during several runs of the RATA 
that includes run k. If wall effects adjustment factors (meeting the 
specifications in sections 12.6.1 or 12.6.2) are determined for more 
than one RATA run, the arithmetic average of all of the resulting 
calculated wall effects adjustment factors must be used as the value of 
WAF and applied to all runs of that RATA. If a calculated, not a 
default, wall effects adjustment factor is used in Equation 2H-21, the 
average velocity unadjusted for wall effects, vavg(k) must be 
obtained from runs in which the number of Method 1 traverse points 
sampled does not exceed the number of Method 1 traverse points in the 
runs used to derive the wall effects adjustment factor, WAF, shown in 
Equation 2H-21.
    12.8  Calculating Volumetric Flow Using Final Wall Effects-Adjusted 
Average Velocity Value. To obtain a stack gas flow rate that accounts 
for velocity decay near the wall of circular stacks or ducts, replace 
vs in Equation 2-10 in Method 2, or va(avg) in 
Equations 2F-10 and 2F-11 in Method 2F, or va(avg) in 
Equations 2G-9 and 2G-10 in Method 2G with one of the following.
    12.8.1  For single-run test procedures, use the final wall effects-
adjusted average stack gas velocity, vfinal, calculated 
according to Equation 2H-20.
    12.8.2  For RATA and other multiple run test procedures, use the 
final wall effects-adjusted average stack gas velocity, 
vfinal(k), calculated according to Equation 2H-21.

                  13.0  Method Performance. [Reserved]

                 414.0  Pollution Prevention. [Reserved]

                   15.0  Waste Management. [Reserved]

                             16.0  Reporting

    16.1  Field Test Reports. Field test reports shall be submitted to 
the Agency according to the applicable regulatory requirements. When 
Method 2H is performed in conjunction with Method 2, 2F, or 2G to derive 
a wall effects adjustment factor, a single consolidated Method 2H/2F (or 
2H/2G) field test report should be prepared. At a minimum, the 
consolidated field test report should contain

[[Page 710]]

(1) all of the general information, and data for Method 1 points, 
specified in section 16.0 of Method 2F (when Method 2H is used in 
conjunction with Method 2F) or section 16.0 of Method 2G (when Method 2H 
is used in conjunction with Method 2 or 2G) and (2) the additional 
general information, and data for Method 1 points and wall effects 
points, specified in this section (some of which are included in section 
16.0 of Methods 2F and 2G and are repeated in this section to ensure 
complete reporting for wall effects testing).
    16.1.1  Description of the source and site. The field test report 
should include the descriptive information specified in section 16.1.1 
of Method 2F (when using Method 2F) or 2G (when using either Method 2 or 
2G). It should also include a description of the stack or duct's 
construction material along with the diagram showing the dimensions of 
the stack or duct at the test port elevation prescribed in Methods 2F 
and 2G. The diagram should indicate the location of all wall effects 
traverse points where measurements were taken as well as the Method 1 
traverse points. The diagram should provide a unique identification 
number for each wall effects and Method 1 traverse point, its distance 
from the wall, and its location relative to the probe entry ports.
    16.1.2  Field test forms. The field test report should include a 
copy of Form 2H-1, 2H-2, or an equivalent for each Method 1 exterior 
equal-area sector.
    16.1.3  Field test data. The field test report should include the 
following data for the Method 1 and wall effects traverse.
    16.1.3.1  Data for each traverse point. The field test report should 
include the values specified in section 16.1.3.2 of Method 2F (when 
using Method 2F) or 2G (when using either Method 2 or 2G) for each 
Method 1 and wall effects traverse point. The provisions of section 
8.4.2 of Method 2H apply to the temperature measurements reported for 
wall effects traverse points. For each wall effects and Method 1 
traverse point, the following values should also be included in the 
field test report.
    (a) Traverse point identification number for each Method 1 and wall 
effects traverse point.
    (b) Probe type.
    (c) Probe identification number.
    (d) Probe velocity calibration coefficient (i.e., Cp when 
Method 2 or 2G is used; F2 when Method 2F is used).

    For each Method 1 traverse point in an exterior equal-area sector, 
the following additional value should be included.
    (e) Calculated replacement velocity, vej, accounting for 
wall effects.
    16.1.3.2  Data for each run. The values specified in section 
16.1.3.3 of Method 2F (when using Method 2F) or 2G (when using either 
Method 2 or 2G) should be included in the field test report once for 
each run. The provisions of section 12.8 of Method 2H apply for 
calculating the reported gas volumetric flow rate. In addition, the 
following Method 2H run values should also be included in the field test 
report.
    (a) Average velocity for run, accounting for wall effects, 
vavg.
    (b) Wall effects adjustment factor derived from a test run, WAF.
    16.1.3.3  Data for a complete set of runs. The values specified in 
section 16.1.3.4 of Method 2F (when using Method 2F) or 2G (when using 
either Method 2 or 2G) should be included in the field test report once 
for each complete set of runs. In addition, the field test report should 
include the wall effects adjustment factor, WAF, that is applied in 
accordance with section 12.7.1 or 12.7.2 to obtain the final wall 
effects-adjusted average stack gas velocity vfinal or 
vfinal(k).
    16.1.4  Quality assurance and control. Quality assurance and control 
procedures, specifically tailored to wall effects testing, should be 
described.
    16.2  Reporting a Default Wall Effects Adjustment Factor. When a 
default wall effects adjustment factor is used in accordance with 
section 8.1 of this method, its value and a description of the stack or 
duct's construction material should be reported in lieu of submitting a 
test report.
    17.0  References.
    (1) 40 CFR Part 60, Appendix A, Method 1'Sample and velocity 
traverses for stationary sources.
    (2) 40 CFR Part 60, Appendix A, Method 2'Determination of stack gas 
velocity and volumetric flow rate (Type S pitot tube).
    (3) 40 CFR Part 60, Appendix A, Method 2F'Determination of stack gas 
velocity and volumetric flow rate with three-dimensional probes.
    (4) 40 CFR Part 60, Appendix A, Method 2G'Determination of stack gas 
velocity and volumetric flow rate with two-dimensional probes.
    (5) 40 CFR Part 60, Appendix A, Method 3'Gas analysis for carbon 
dioxide, oxygen, excess air, and dry molecular weight.
    (6) 40 CFR Part 60, Appendix A, Method 3A--Determination of oxygen 
and carbon dioxide concentrations in emissions from stationary sources 
(instrumental analyzer procedure).
    (7) 40 CFR Part 60, Appendix A, Method 4--Determination of moisture 
content in stack gases.
    (8) Emission Measurement Center (EMC) Approved Alternative Method 
(ALT-011) ``Alternative Method 2 Thermocouple Calibration Procedure.''
    (9) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Texas Utilities, DeCordova Steam 
Electric Station, Volume I: Test Description and Appendix A (Data 
Distribution Package),'' EPA/430-R-98-015a.

[[Page 711]]

    (10) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Texas Utilities, Lake Hubbard Steam 
Electric Station, Volume I: Test Description and Appendix A (Data 
Distribution Package),'' EPA/430-R-98-017a.
    (11) The Cadmus Group, Inc., 1998, ``EPA Flow Reference Method 
Testing and Analysis: Data Report, Pennsylvania Electric Co., G.P.U. 
Genco Homer City Station: Unit 1, Volume I: Test Description and 
Appendix A (Data Distribution Package),'' EPA/430-R-98-018a.
    (12) The Cadmus Group, Inc., May 1999, ``EPA Flow Reference Method 
Testing and Analysis: Findings Report,'' EPA/430-R-99-009.
    (13) The Cadmus Group, Inc., 1997, ``EPA Flow Reference Method 
Testing and Analysis: Wind Tunnel Experimental Results,'' EPA/430-R-97-
013.
    (14) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Four Prandtl Probes, Four 
S-Type Probes, Four French Probes, Four Modified Kiel Probes,'' Prepared 
for the U.S. Environmental Protection Agency under IAG No. DW13938432-
01-0.
    (15) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Five Autoprobes,'' 
Prepared for the U.S. Environmental Protection Agency under IAG No. 
DW13938432-01-0.
    (16) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Eight Spherical Probes,'' 
Prepared for the U.S. Environmental Protection Agency under IAG No. 
DW13938432-01-0.
    (17) National Institute of Standards and Technology, 1998, ``Report 
of Special Test of Air Speed Instrumentation, Four DAT Probes,'' 
Prepared for the U.S. Environmental Protection Agency under IAG No. 
DW13938432-01-0.
    (18) Massachusetts Institute of Technology (MIT), 1998, 
``Calibration of Eight Wind Speed Probes Over a Reynolds Number Range of 
46,000 to 725,000 per Foot, Text and Summary Plots,'' Plus Appendices, 
WBWT-TR-1317, Prepared for The Cadmus Group, Inc., under EPA Contract 
68-W6-0050, Work Assignment 0007AA-3.
    (19) Fossil Energy Research Corporation, Final Report, ``Velocity 
Probe Tests in Non-axial Flow Fields,'' November 1998, Prepared for the 
U.S. Environmental Protection Agency.
    (20) Fossil Energy Research Corporation, ``Additional Swirl Tunnel 
Tests: E-DAT and T-DAT Probes,'' February 24, 1999, Technical Memorandum 
Prepared for U.S. Environmental Protection Agency, P.O. No. 7W-1193-
NALX.


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[[Page 721]]



  Method 3--Gas Analysis for the Determination of Dry Molecular Weight

                     1. Applicability and Principle

                           1.1 Applicability.

    1.1.1 This method is applicable for determining carbon dioxide 
(CO2) and oxygen (O2) concentrations and dry 
molecular weight of a sample from a gas stream of a fossil-fuel 
combustion process. The method may also be applicable to other processes 
where it has been determined that compounds other than CO2, 
O2, carbon monoxide (CO), and nitrogen (N2) are 
not present in concentrations sufficient to affect the results.
    1.1.2 Other methods, as well as modifications to the procedure 
described herein, are also applicable for some or all of the above 
determinations. Examples of specific methods and modifications include: 
(1) A multi-point sampling method using an Orsat analyzer to analyze 
individual grab samples obtained at each point; (2) a method using 
CO2 or O2 and stoichiometric calculations to 
determine dry molecular weight; and (3) assigning a value of 30.0 for 
dry molecular weight, in lieu of actual measurements, for processes 
burning natural gas, coal, or oil. These methods and modifications may 
be used, but are subject to the approval of the Administrator, U.S. 
Environmental Protection Agency (EPA).
    1.1.3 Note. Mention of trade names or specific products does not 
constitute endorsements by EPA.
    1.2 Principle. A gas sample is extracted from a stack by one of the 
following methods: (1) Single-point, grab sampling; (2) single-point, 
integrated sampling; or (3) multi-point, integrated sampling. The gas 
sample is analyzed for pecent CO2, percent O2, and 
if necessary, for percent CO. For dry molecular weight determination, 
either an Orsat or a Fyrite analyzer may be used for the analysis.

                              2. Apparatus

    As an alternative to the sampling apparatus and systems described 
herein, other sampling systems (e.g., liquid displacement) may be used, 
provided such systems are capable of obtaining a representative sample 
and maintaining a constant sampling rate, and are, otherwise, capable of 
yielding acceptable results. Use of such systems is subject to the 
approval of the Administrator.

                     2.1 Grab Sampling (Figure 3-1).

    2.1.1 Probe. Stainless steel or borosilicate glass tubing equipped 
with an in-stack or out-stack filter to remove particulate matter (a 
plug of glass wool is satisfactory for this purpose). Any other 
materials, inert to O2, CO2, CO, and N2 
and resistant to temperature at sampling conditions, may be used for the 
probe. Examples of such materials are aluminum, copper, quartz glass, 
and Teflon.
    2.1.2 Pump. A one-way squeeze bulb, or equivalent, to transport the 
gas sample to the analyzer.
    2.2 Integrated Sampling (Figure 3-2).
    2.2.1 Probe. Same as in Section 2.1.1.
    2.2.2 Condenser. An air-cooled or water-cooled condenser, or other 
condenser no greater than 250 ml that will not remove O2, 
CO2, CO, and N2, to remove excess moisture which 
would interfere with the operation of the pump and flowmeter.
    2.2.3 Valve. A needle valve, to adjust sample gas flow rate.

[[Page 722]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.096

    2.2.4 Pump. A leaf-free, diaphragm-type pump, or equivalent, to 
transport sample gas to the flexible bag. Install a small surge tank 
between the pump and rate meter to eliminate the pulsation effect of the 
diaphragm pump on the rotameter.
    2.2.5 Rate Meter. A rotameter, or equivalent rate meter, capable of 
measuring flow rate to within 2 percent of the selected flow rate. A 
flow rate range of 500 to 1000 cc/min is suggested.
    2.2.6 Flexible Bag. Any leak-free plastic (e.g., Tedlar, Mylar, 
Teflon) or plastic-coated aluminum (e.g., aluminized Mylar) bag, or 
equivalent, having a capacity consistent with the selected flow rate and 
time length of the test run. A capacity in the range of 55 to 90 liters 
is suggested. To leak check the

[[Page 723]]

bag, connect it to a water manometer, and pressurize the bag to 5 to 10 
cm H2O (2 to 4 in. H2O). Allow to stand for 10 
minutes. Any displacement in the water manometer indicates a leak. An 
alternative leak-check method is to pressurize the bag to 5 to 10 cm (2 
to 4 in.) H2O and allow to stand overnight. A deflated bag 
indicates a leak.
    2.2.7 Pressure Gauge. A water-filled U-tube manometer, or 
equivalent, of about 30 cm (12 in.), for the flexible bag leak check.
    2.2.8 Vacuum Gauge. A mercury manometer, or equivalent, of at least 
760 mm (30 in.) Hg, for the sampling train leak check.
    2.3 Analysis. An Orsat or Fyrite type combustion gas analyzer. For 
Orsat and Fyrite analyzer maintenance and operation procedures, follow 
the instructions recommended by the manufacturer, unless otherwise 
specified herein.

         3. Single-Point, Grab Sampling and Analytical Procedure

    3.1 The sampling point in the duct shall either be at the centroid 
of the cross section or at a point no closer to the walls than 1.00 m 
(3.3 ft), unless otherwise specified by the Administrator.
    3.2 Set up the equipment as shown in Figure 3-1, making sure all 
connections ahead of the analyzer are tight. If an Orsat analyzer is 
used, it is recommended that the analyzer be leak checked by following 
the procedure in Section 6; however, the leak check is optional.
    3.3 Place the probe in the stack, with the tip of the probe 
positioned at the sampling point; purge the sampling line long enough to 
allow at least five exchanges. Draw a sample into the analyzer, and 
immediately analyze it for percent CO2 and percent 
O2. Determine the percentage of the gas that is N2 
and CO by subtracting the sum of the percent CO2 and percent 
02 O from 100 percent. Calculate the dry molecular weight as 
indicated in Section 7.2.
    3.4 Repeat the sampling, analysis, and calculation procedures until 
the dry molecular weights of any three grab samples differ from their 
mean by no more than 0.3 g/g-mole (0.3 lb/lb-mole). Average these three 
molecular weights, and report the results to the nearest 0.1 g/g-mole 
(0.1 lb/lb-mole).

      4. Single-Point, Integrated Sampling and Analytical Procedure

    4.1 The sampling point in the duct shall be located as specified in 
Section 3.1.
    4.2 Leak check (optional) the flexible bag as in Section 2.2.6. Set 
up the equipment as shown in Figure 3-2. Just before sampling, leak 
check (optional) the train by placing a vacuum gauge at the condenser 
inlet, pulling a vacuum of at least 250 mm Hg (10 in. Hg), plugging the 
outlet at the quick disconnect, and then turning off the pump. The 
vacuum should remain stable for at least 0.5 minute. Evacuate the 
flexible bag. Connect the probe, and place it in the stack, with the tip 
of the probe positioned at the sampling point; purge the sampling line. 
Next, connect the bag, and make sure that all connections are tight.
    4.3 Sample at a constant rate. The sampling run should be 
simultaneous with, and for the same total length of time as, the 
pollutant emission rate determination. Collection of at least 30 liters 
(1.00 ft3) of sample gas is recommended; however, smaller 
volumes may be collected, if desired.
    4.4 Obtain one integrated flue gas sample during each pollutant 
emission rate determination. Within 8 hours after the sample is taken, 
analyze it for percent CO2 and percent O2 using 
either an Orsat analyzer or a Fyrite type combustion gas analyzer. If an 
Orsat analyzer is used, it is recommended that Orsat leak check 
described in Section 6, be performed before this determination; however, 
the check is optional. Determine the percentage of the gas that is 
N2 and CO by subtracting the sum of the percent 
CO2 and percent 0 from 100 percent. Calculate the dry 
molecular weight as indicated in Section 7.2.
    4.5 Repeat the analysis and calculation procedures until the 
individual dry molecular weights for any three analyses differ from 
their mean by no more than 0.3 g/g-mole (0.3 lb/lb-mole). Average these 
three molecular weights, and report the results to the nearest 0.1 g/g-
mole (0.1 lb/lb-mole).

      5. Multi-Point, Integrated Sampling and Analytical Procedure

    5.1 Unless otherwise specified by the Administrator, a minimum of 
eight traverse points shall be used for circular stacks having diameters 
less than 0.61 m (24 in.), a minimum of nine shall be used for 
rectangular stacks having equivalent diameters less than 0.61 m (24 
in.), and a minimum of 12 traverse points shall be used for all other 
cases. The traverse points shall be located according to Method 1. The 
use of fewer points is subject to approval of the Administrator.
    5.2 Follow the procedures outlined in Sections 4.2 through 4.5, 
except for the following: Traverse all sampling points, and sample at 
each point for an equal length of time. Record sampling data as shown in 
Figure 3-3.

------------------------------------------------------------------------
                                         Traverse  Q, liter/
                 Time                      pt.        min       % dev.a
------------------------------------------------------------------------
 
------------------------------------------------------------------------
 
------------------------------------------------------------------------
 
------------------------------------------------------------------------
 
------------------------------------------------------------------------
Average
------------------------------------------------------------------------
a % dev.=(Q--Qavg)/Qavg X 100 (Must be >10%)
 

[[Page 724]]

 
Figure 3-3. Sampling rate data.

               6. Leak-Check Procedure for Orsat Analyzer

    Moving an Orsat analyzer frequently causes it to leak. Therefore, an 
Orsat analyzer should be thoroughly leak checked on site before the flue 
gas sample is introduced into it. The procedure for leak checking an 
Orsat analyzer is as follows:
    6.1 Bring the liquid level in each pipette up to the reference mark 
on the capillary tubing, and then close the pipette stopcock.
    6.2 Raise the leveling bulb sufficiently to bring the confining 
liquid meniscus onto the graduated portion of the burette, and then 
close the manifold stopcock.

                    6.3 Record the meniscus position.

    6.4 Observe the menisus in the burette and the liquid level in the 
pipette for movement over the next 4 minutes.
    6.5 For the Orsat analyzer to pass the leak check, two conditions 
must be met:
    6.5.1 The liquid level in each pipette must not fall below the 
botton of the capillary tubing during this 4-minute interval.
    6.5.2 The menisus in the burette must not change by more than 0.2 ml 
during this 4-minute interval.
    6.6 If the anlyzer fails the leak-check procedure, check all rubber 
connections and stopcocks to determine whether they might be the cause 
of the leak. Disassemble, clean, and regrease leaking stopcocks. Replace 
leaking rubber connections. After the analyzer is reassembled, repeat 
the lead-check procedure.

                             7. Calculations

                            7.1 Nomenclature

Md = Dry molecular weight, g/g-mole (1b/1b-mole).
%CO2 = Percent CO2 by volume, dry basis.
%O2 = Percent O2 by volume, dry basis.
%CO = Percent CO by volume, dry basis.
%N2 = Percent N2 by volume, dry basis.
0.280 = Molecular weight of N2 or CO, divided by 100.
0.320 = Molecular wight of O2 divided by 100.
0.440 = Molecular weight of CO2 divided by 100.

    7.2 Dry Molecular Weight. Use Equation 3-1 to calculate the dry 
molecular weight of the stack gas.

Md = 0.440(%CO2) + 0.320 (%O2) + 
          0.280(%N2 + %CO)      Eq. 3-1
    Note. The above equation does not consider argon in air (about 0.9 
percent, molecular weight of 39.9). A negative error of about 0.4 
percent is introduced. The tester may choose to include argon in the 
analysis using procedures subject to approval of the Administrator.

                             8. Bibliography

    1. Altshuller, A.P. Storage of Gases and Vapors in Plastic Bags. 
International Journal of Air and Water Pollution. 6:75-81. 1963.
    2. Conner, William D. and J.S. Nader. Air Sampling with Plastic 
Bags. Journal of the American Industrial Hygiene Association. 25:292-
297. 1964.
    3. Burrell Manual for Gas Analysts, Seventh edition. Burrell 
Corporation, 2223 Fifth Avenue, Pittsburgh, PA. 15219. 1951.
    4. Mitchell, W.J. and M.R. Midgett, Field Reliability of the Orsat 
Analyzer. Journal of Air Pollution Control Association. 26:491-495. May 
1976.
    5. Shigehara, R.T., R. M. Neulicht, and W.S. Smith. Validating Orsat 
Analysis Data from Fossil Fuel-Fired Units. Stack Sampling News. 
4(2):21-26. August 1976.

Method 3A--Determination of Oxygen and Carbon Dioxide Concentrations in 
   Emissions From Stationary Sources (Instrumental Analyzer Procedure)

1. Applicability and Principle

    1.1  Applicability.  This method is applicable to the determination 
of oxygen (O2) and carbon dioxide (CO2) 
concentrations in emissions from stationary sources only when specified 
within the regulations.
    1.2 Principle.  A sample is continuously extracted from the effluent 
stream: a portion of the sample stream is conveyed to an instrumental 
analyzer(s) for determination of O2 and CO2 
concentration(s). Performance specifications and test procedures are 
provided to ensure reliable data.

2. Range and Sensitivity

    Same as Method 6C, Sections 2.1 and 2.2, except that the span of the 
monitoring system shall be selected such that the average O2 
or CO2 concentration is not less than 20 percent of the span.

3. Definitions

    3.1  Measurement System. The total equipment required for the 
determination of the O2 or CO2 concentration. The 
measurement system consists of the same major subsystems as defined in 
Method 6C, Sections 3.1.1, 3.1.2, and 3.1.3.
    3.2  Span, Calibration Gas, Analyzer Calibration Error, Sampling 
System Bias, Zero Drift, Calibration Drift, Response Time, and 
Calibration Curve.  Same as Method 6C, Sections 3.2 through 3.8, and 
3.10.
    3.3  Interference Response. The output response of the measurement 
system to a component in the sample gas, other than the gas component 
being measured.

4. Measurement System Performance Specifications

    Same as Method 6C, Sections 4.1 through 4.4.

5. Apparatus and Reagents


[[Page 725]]


    5.1  Measurement System. Any measurement system for O2 or 
CO2 that meets the specifications of this method. A schematic 
of an acceptable measurement system is shown in Figure 6C-1 of Method 
6C. The essential components of the measurement system are described 
below:
    5.1.1  Sample Probe. A leak-free probe, of sufficient length to 
traverse the sample points.
    5.1.2  Sample Line. Tubing, to transport the sample gas from the 
probe to the moisture removal system. A heated sample line is not 
required for systems that measure the O2 or CO2 
concentration on a dry basis, or transport dry gases.
    5.1.3  Sample Transport Line, Calibration Value Assembly, Moisture 
Removal System, Particulate Filter, Sample Pump, Sample Flow Rate 
Control, Sample Gas Manifold, and Data Recorder. Same as Method 6C, 
Sections 5.1.3 through 5.1.9, and 5.1.11, except that the requirements 
to use stainless steel, Teflon, and nonreactive glass filters do not 
apply.
    5.1.4  Gas Analyzer. An analyzer to determine continuously the 
O2 or CO2 concentration in the sample gas stream. 
The analyzer shall meet the applicable performance specifications of 
Section 4. A means of controlling the analyzer flow rate and a device 
for determining proper sample flow rate (e.g., precision rotameter, 
pressure gauge downstream of all flow controls, etc.) shall be provided 
at the analyzer. The requirements for measuring and controlling the 
analyzer flow rate are not applicable if data are presented that 
demonstrate the analyzer is insensitive to flow variations over the 
range encountered during the test.
    5.2  Calibration Gases. The calibration gases for CO2 
analyzers shall be CO2 in N2 or CO2 in 
air. Alternatively, CO2/SO2, O2/
SO2 , or O2/CO2/SO2 gas 
mixtures in N2 may be used. Three calibration gases, as 
specified Section 5.3.1 through 5.3.3 of Method 6C, shall be used. For 
O2 monitors that cannot analyze zero gas, a calibration gas 
concentration equivalent to less than 10 percent of the span may be used 
in place of zero gas.

6. Measurement System Performance Test Procedures

    Perform the following procedures before measurement of emissions 
(Section 7).
    6.1  Calibration Concentration Verification. Follow Section 6.1 of 
Method 6C, except if calibration gas analysis is required, use Method 3 
and change the acceptance criteria for agreement among Method 3 results 
to 5 percent (or 0.2 percent by volume, whichever is greater).
    6.2  Interference Response. Conduct an interference response test of 
the analyzer prior to its initial use in the field. Thereafter, recheck 
the measurement system if changes are made in the instrumentation that 
could alter the interference response (e.g., changes in the type of gas 
detector). Conduct the interference response in accordance with Section 
5.4 of Method 20.
    6.3  Measurement System Preparation, Analyzer Calibration Error, and 
Sampling System Bias Check. Follow Sections 6.2 through 6.4 of Method 
6C.

7. Emission Test Procedure

    7.1  Selection of Sampling Site and Sampling Points. Select a 
measurement site and sampling points using the same criteria that are 
applicable to tests performed using Method 3.
    7.2  Sample Collection. Position the sampling probe at the first 
measurement point, and begin sampling at the same rate as used during 
the sampling system bias check. Maintain constant rate sampling (i.e., 
10 percent) during the entire run. The sampling time per run 
shall be the same as for tests conducted using Method 3 plus twice the 
system response time. For each run, use only those measurements obtained 
after twice the response time of the measurement system has elapsed to 
determine the average effluent concentration.
    7.3  Zero and Calibration Drift Test. Follow Section 7.4 of Method 
6C.

8. Quality Control Procedures

    The following quality control procedures are recommended when the 
results of this method are used for an emission rate correction factor, 
or excess air determination. The tester should select one of the 
following options for validating measurement results:
    8.1  If both O2 and CO2 are measured using 
Method 3A, the procedures described in Section 4.4 of Method 3 should be 
followed to validate the O2 and CO2 measurement 
results.
    8.2  If only O2 is measured using Method 3A, measurements 
of the sample stream CO2 concentration should be obtained at 
the sample by-pass vent discharge using an Orsat or Fyrite analyzer, or 
equivalent. Duplicate samples should be obtained concurrent with at 
least one run. Average the duplicate Orsat or Fyrite analysis results 
for each run. Use the average CO2 values for comparison with 
the O2 measurements in accordance with the procedures 
described in Section 4.4 of Method 3.
    8.3  If only CO2 is measured using Method 3A, concurrent 
measurements of the sample stream CO2 concentration should be 
obtained using an Orsat or Fyrite analyzer as described in Section 8.2. 
For each run, differences greater than 0.5 percent between the Method 3A 
results and the average of the duplicate Fyrite analysis should be 
investigated.

9. Emission Calculation

    For all CO2 analyzers, and for O2 analyzers 
that can be calibrated with zero gas, follow

[[Page 726]]

Section 8 of Method 6C, except express all concentrations as percent, 
rather than ppm.
    For O2 analyzers that use a low-level calibration gas in 
place of a zero gas, calculate the effluent gas concentration using 
Equation 3A-1.
[GRAPHIC] [TIFF OMITTED] TC16NO91.116

Where:

Cgas=Effluent gas concentration, dry basis, percent.
Cma=Actual concentration of the upscale calibration gas, 
          percent.
Coa=Actual concentration of the low-level calibration gas, 
          percent.
Cm=Average of initial and final system calibration bias check 
          responses for the upscale calibration gas, percent.
Co=Average of initial and final system calibration bias check 
          responses for the low-level gas, percent.
C=Average gas concentration indicated by the gas analyzer, dry basis, 
          percent.

10. Bibliography

    Same as bibliography of Method 6C.

     Method 3B--Gas Analysis for the Determination of Emission Rate 
                     Correction Factor or Excess Air

                     1. Applicability and Principle

                            1.1 Applicability

    1.1.1 This method is applicable for determining carbon dioxide 
(CO2), oxygen (O2), and carbon monoxide (CO) 
concentrations of a sample from a gas stream of a fossil-fuel combustion 
provess for excess air or emission rate correction factor calculations.
    1.1.2 Other methods, as well as modifications to the procedure 
described herein, are also applicable for all of the above 
determinations. Examples of specific methods and modifications include: 
(1) A multi-point sampling method using an Orsat analyzer to analyze 
individual grab samples obtained at each point, and (2) a method using 
CO2 or O2 and stoichiometric calculations to 
determine excess air. These methods and modifications may be used, but 
are subject to the approval of the Administrator, U.S. Environmental 
Protection Agency (FPA).
    1.1.3 Note. Mention of trade names or specific products does not 
constitute endorsement by EPA.
    1.2 Principle. A gas sample is extracted from a stack by one of the 
following methods: (1) Single-point, grab sampling; (2) single-point, 
integrated sampling; or (3) multi-point, integrated sampling. The gas 
sample is analyzed for percent CO2 percent O2, 
and, if necessary, percent CO. An Orsat analyzer must be used for excess 
air or emission rate correction factor determinations.

                              2. Apparatus

    The alternative sampling systems are the same as those mentioned in 
Section 2 of Method 3.
    2.1 Grab Sampling and Integrated Sampling. Same as in Sections 2.1 
and 2.2, respectively, of Method 3.
    2.2 Analysis. An Orsat analyzer only. For low CO2 (less 
than 4.0 percent) or high O2 (greater than 15.0 percent) 
concentrations, the measuring burette of the Orsat must have at least 
0.1 percent subdivisions. For Orsat maintenance and operation 
procedures, follow the instructions recommended by the manufacturer, 
unless otherwise specified herein.

                              3. Procedures

    Each of the three procedures below shall be used only when specified 
in an applicable subpart of the standards. The use of these procedures 
for other purposes must have specific prior approval of the 
Adminsitrator.
    Note .--A Fyrite-type combustion gas analyzer is not acceptable for 
excess air or emission rate correction factor determinations, unless 
approved by the Administrator. If both percent CO2 and 
percent O2 are measured, the analytical results of any of the 
three procedures given below may be used for calculating the dry 
molecular weight (see Method 3).

        3.1 Single-Point, Grab Sampling and Analytical Procedure.

    3.1.1 The sampling point in the duct shall be as described in 
Section 3.1 of Method 3.
    3.1.2 Set up the equipment as shown in Figure 3-1 of Method 3, 
making sure all connections ahead of the analyzer are tight. Leak check 
the Orsat analyzer according to the procedure described in Section 6 of 
Method 3. This leak check is mandatory.
    3.1.3  Place the probe in the stack, with the tip of the probe 
positioned at the sampling point; purge the sampling line long enough to 
allow at least five exchanges. Draw a sample into the analyzer. For 
emission rate correction factor determinations, immediately analyze the 
sample, as outlined

[[Page 727]]

in Sections 3.1.4 and 3.1.5, for percent CO2 or percent 
O2. If excess air is desired, proceed as follows: (1) 
immediately analyze the sample, as in Sections 3.1.4 and 3.1.5, for 
percent CO2, O2, and CO; (2) determine the 
percentage of the gas that is N2 by subtracting the sum of 
the percent CO2, percent O2, and percent CO from 
100 percent, and (3) calculate percent excess air as outlined in Section 
4.2.
    3.1.4  To ensure complete absorption of the CO2, 
O2, or if applicable, CO, make repeated passes through each 
absorbing solution until two consecutive readings are the same. Several 
passes (three or four) should be made between readings. (If constant 
readings cannot be obtained after three consecutive readings, replace 
the absorbing solution.)
    Note. --Since this single-point, grab sampling and analytical 
procedure is normally conducted in conjunction with a single-point, grab 
sampling and analytical procedure for a pollutant, only one analysis is 
ordinarily conducted. Therefore, great care must be taken to obtain a 
valid sample and analysis. Although in most cases, only CO2 
or O2 is required, it is recommended that both CO2 
and O2 be measured, and that Section 3.4 be used to validate 
the analytical data.

    3.1.5  After the analysis is completed, leak check (mandatory) the 
Orsat analyzer once again, as described in Section 6 of Method 3. For 
the results of the analysis to be valid, the Orsat analyzer must pass 
this leak test before and after the analysis.

    3.2  Single-Point, Integrated Sampling and Analytical Procedure.

    3.2.1  The sampling point in the duct shall be located as specified 
in Section 3.1.1.
    3.2.2 Leak check (mandatory) the flexible bag as in Section 2.2.6 of 
Method 3. Set up the equipment as shown in Figure 3-2 of Method 3. Just 
before sampling, leak check (mandatory) the train as described in 
Section 4.2 of Method 3.
    3.2.3  Sample at a constant rate, or as specified by the 
Administrator. The sampling run must be simultaneous with, and for the 
same total length of time as, the pollutant emission rate determination. 
Collect at least 30 liters (1.00 ft\3\) of sample gas. Smaller volumes 
may be collected, subject to approval of the Administrator.
    3.2.4  Obtain one integrated flue gas sample during each pollutant 
emission rate determination. For emission rate correction factor 
determination, analyze the sample within 4 hours after it is taken for 
percent CO2 or percent O2 (as outlined in Sections 
3.2.5 through 3.2.7). The Orsat analyzer must be leak checked (see 
Section 6 of Method 3) before the analysis. If excess air is desired, 
procede as follows: (1) within 4 hours after the sample is taken, 
analyze it (as in Sections 3.2.5 through 3.2.7) for percent 
CO2, O2, and CO; (2) determine the percentage of 
the gas that is N2 by subtracting the sum of the percent 
CO2, percent O2, and percent CO from 100 percent; 
and (3) calculate percent excess air, as outlined in Section 4.2.
    3.2.5  To ensure complete absorption of the CO2, 
O2, or if applicable, CO, follow the procedure described in 
Section 3.1.4.
    Note. --Although in most instances only CO2 or 
O2 is required, it is recommended that both CO2 
and O2 be measured, and that Section 3.4.1 be used to 
validate the analytical data.
    3.2.6  Repeat the analysis until the following criteria are met:
    3.2.6.1  For percent CO2, repeat the analytical procedure 
until the results of any three analyses differ by no more than (a) 0.3 
percent by volume when CO2 is greater than 4.0 percent or (b) 
0.2 percent by volume when CO2 is less than or equal to 4.0 
percent. Average three acceptable values of percent CO2, and 
report the results to the nearest 0.2 percent.
    3.2.6.2  For percent O2, repeat the analytical procedure 
until the results of any three analyses differ by no more than (a) 0.3 
percent by volume when O2 is less than 15.0 percent or (b) 
0.2 percent by volume when O2 is greater than or equal to 
15.0 percent. Average the three acceptable values of percent 
O2, and report the results to the nearest 0.1 percent.
    3.2.6.3  For percent CO, repeat the analytical procedure until the 
results of any three analyses differ by no more than 0.3 percent. 
Average the three acceptable values of percent CO, and report the 
results to the nearest 0.1 percent.
    3.2.7  After the analysis is completed, leak check (mandatory) the 
Orsat analyzer once again, as described in Section 6 of Method 3. For 
the results of the analysis to be valid, the Orsat analyzer must pass 
this leak test before and after the analysis.

     3.3  Multi-Point, Integrated Sampling and Analytical Procedure.

    3.3.1 The sampling points shall be determined as specified in 
Section 5.3 of Method 3.
    3.3.2  Follow the procedures outlined in Sections 3.2.2 through 
3.2.7, except for the following: Traverse all sampling points, and 
sample at each point for an equal length of time. Record sampling data 
as shown in Figure 3-3 of Method 3.

                     3.4  Quality Control Procedure.

    3.4.1  Data Validation When Both CO2 and O2 
Are Measured. Although in most instances, only CO2 or 
O2 measurement is required, it is recommended that both 
CO2 and O2 be measured to provide a check on the 
quality of the data. The following quality control procedure is 
suggested.

[[Page 728]]

    Note. --Since the method for validating the CO2 and 
O2 analyses is based on combustion of organic and fossil 
fuels and dilution of the gas stream with air, this method does not 
apply to sources that (1) remove CO2 or O2 through 
processes other than combustion, (2) add O2 (e.g., oxygen 
enrichment) and N2 in proportions different from that of air, 
(3) add CO2 (e.g., cement or lime kilns) or (4) have no fuel 
factor, Fo, values obtainable (e.g., extremely variable waste 
mixtures). This method validates the measured proportions of 
CO2 and O2 for fuel type, but the method does not 
detect sample dilution resulting from leaks during or after sample 
collection. The method is applicable for samples collected downstream of 
most lime or limestone flue-gas desulfurization units as the 
CO2 added or removed from the gas stream is not significant 
in relation to the total CO2 concentration. The 
CO2 concentrations from other types of scrubbers using only 
water or basic slurry can be significantly affected and would render the 
Fo check minimally useful.

    3.4.1.1  Calculate a fuel factor, Fo, using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.117

where:

%O2=Percent O2 by volume, dry basis.
%CO2=Percent CO2 by volume, dry basis.
20.9=Percent O2 by volume in ambient air.
    If CO present in quantities measurable by this method, adjust the 
O2 and CO2 values before performing the 
calculation for F0 as follows:

%CO2 (adj) = %CO2 + %CO
%O2 (adj) = %O2 - 0.5 %CO
where:

%5CO = Percent CO by volume, dry basis.
    3.4.1.2 Compare the calculated F0 factor with the 
expected F0 values. The following table may be used in 
establishing acceptable ranges for the expected F0 if the 
fuel being burned is known. When fuels are burned in combinations, 
calculate the combined fuel Fd and Fc factors (as 
defined in Method 19) according to the procedure in Method 19, Section 
5.2.3. Then calculate the F0 factor as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.247


------------------------------------------------------------------------
                         Fuel type                             F0 range
------------------------------------------------------------------------
Coal:
    Anthracite and lignite.................................  1.016-1.130
    Bituminous.............................................  1.083-1.230
Oil:
    Distillate.............................................  1.260-1.413
    Residual...............................................  1.210-1.370
Gas:
    Natural................................................  1.600-1.836
    Propane................................................  1.434-1.586
    Butane.................................................  1.405-1.553
Wood.......................................................  1.000-1.120
Wood bark..................................................  1.003-1.130
------------------------------------------------------------------------

    3.4.1.3 Calculated F0 values, beyond the acceptable 
ranges shown in this table, should be investigated before accepting the 
test results. For example, the strength of the solutions in the gas 
analyzer and the analyzing technique should be checked by sampling and 
analyzing a known concentration, such as air; the fuel factor should be 
reviewed and verified. An acceptability range of 12 percent 
is appropriate for the F0 factor of mixed fuels with variable 
fuel ratios. The level of the emission rate relative to the compliance 
level should be considered in determining if a retest is appropriate, 
i.e., if the measured emissions are much lower or much greater than the 
compliance limit, repetition of the test would not significantly change 
the compliance status of the source and would be unnecessarily time 
consuming and costly.

                             4. Calculations

    4.1 Nomenclature. Same as Section 5 of Method 3 with the addition of 
the following:

%EA = Percent excess air.
0.264 = Ratio of O2 to N2 in air, v/v.
    4.2 Percent Excess Air. Calculate the percent excess air (if 
applicable) by substituting the appropriate values of percent 
O2, CO, and N2 (obtained from Section 3.1.3 or 
3.2.4) into Equation 3B-3.
[GRAPHIC] [TIFF OMITTED] TC16NO91.118

    Note. The equation above assumes that ambient air is used as the 
source of O2 and that the fuel does not contain appreciable 
amounts of N2 (as do coke oven or blast furnace gases). For 
those cases when appreciable amounts of N2 are present (coal, 
oil and natural gas do not contain appreciable amounts of N2) 
or when oxygen enrichment is used, alternative methods, subject to 
approval of the Administrator, are required.

[[Page 729]]

                             5. Bibliography

    Same as Method 3.

   Method 3C--Determination of Carbon Dioxide, Methane, Nitrogen, and 
                     Oxygen From Stationary Sources

                     1. Applicability and Principle

    1.1  Applicability. This method applies to the analysis of carbon 
dioxide (CO2), methane (CH4), nitrogen 
(N2), and oxygen (O2) in samples from municipal 
solid waste landfills and other sources when specified in an applicable 
subpart.
    1.2  Principle. A portion of the sample is injected into a gas 
chromatograph (GC) and the CO2, CH4, 
N2, and O2 concentrations are determined by using 
a thermal conductivity detector (TCD) and integrator.

                        2. Range and Sensitivity

    2.1  Range. The range of this method depends upon the concentration 
of samples. The analytical range of TCD's is generally between 
approximately 10 ppmv and the upper percent range.
    2.2  Sensitivity. The sensitivity limit for a compound is defined as 
the minimum detectable concentration of that compound, or the 
concentration that produces a signal-to-noise ratio of three to one. For 
CO2, CH4, N2, and O2, the 
sensitivity limit is in the low ppmv range.

                            3. Interferences

    Since the TCD exhibits universal response and detects all gas 
components except the carrier, interferences may occur. Choosing the 
appropriate GC or shifting the retention times by changing the column 
flow rate may help to eliminate resolution interferences.
    To assure consistent detector response, helium is used to prepare 
calibration gases. Frequent exposure to samples or carrier gas 
containing oxygen may gradually destroy filaments.

                              4. Apparatus

    4.1  Gas Chromatograph. GC having at least the following components:
    4.1.1  Separation Column. Appropriate column(s) to resolve 
CO2, CH4, N2, O2, and other 
gas components that may be present in the sample.
    4.1.2  Sample Loop. Teflon or stainless steel tubing of the 
appropriate diameter. Note: Mention of trade names or specific products 
does not constitute endorsement or recommendation by the U. S. 
Environmental Protection Agency.
    4.1.3  Conditioning System. To maintain the column and sample loop 
at constant temperature.
    4.1.4  Thermal Conductivity Detector.
    4.2  Recorder. Recorder with linear strip chart. Electronic 
integrator (optional) is recommended.
    4.3  Teflon Tubing. Diameter and length determined by connection 
requirements of cylinder regulators and the GC.
    4.4  Regulators. To control gas cylinder pressures and flow rates.
    4.5  Adsorption Tubes. Applicable traps to remove any O2 
from the carrier gas.

                               5. Reagents

    5.1  Calibration and Linearity Gases. Standard cylinder gas mixtures 
for each compound of interest with at least three concentration levels 
spanning the range of suspected sample concentrations. The calibration 
gases shall be prepared in helium.
    5.2  Carrier Gas. Helium, high-purity.

                               6. Analysis

    6.1  Sample Collection. Use the sample collection procedures 
described in Methods 3 or 25C to collect a sample of landfill gas (LFG).
    6.2  Preparation of GC. Before putting the GC analyzer into routine 
operation, optimize the operational conditions according to the 
manufacturer's specifications to provide good resolution and minimum 
analysis time. Establish the appropriate carrier gas flow and set the 
detector sample and reference cell flow rates at exactly the same 
levels. Adjust the column and detector temperatures to the recommended 
levels. Allow sufficient time for temperature stabilization. This may 
typically require 1 hour for each change in temperature.
    6.3  Analyzer Linearity Check and Calibration. Perform this test 
before sample analysis. Using the gas mixtures in section 5.1, verify 
the detector linearity over the range of suspected sample concentrations 
with at least three points per compound of interest. This initial check 
may also serve as the initial instrument calibration. All subsequent 
calibrations may be performed using a single-point standard gas provided 
the calibration point is within 20 percent of the sample component 
concentration. For each instrument calibration, record the carrier and 
detector flow rates, detector filament and block temperatures, 
attenuation factor, injection time, chart speed, sample loop volume, and 
component concentrations. Plot a linear regression of the standard 
concentrations versus area values to obtain the response factor of each 
compound. Alternatively, response factors of uncorrected component 
concentrations (wet basis) may be generated using instrumental 
integration. Note: Peak height may be used instead of peak area 
throughout this method.
    6.4  Sample Analysis. Purge the sample loop with sample, and allow 
to come to atmospheric pressure before each injection.

[[Page 730]]

Analyze each sample in duplicate, and calculate the average sample area 
(A). The results are acceptable when the peak areas for two consecutive 
injections agree within 5 percent of their average. If they do not 
agree, run additional samples until consistent area data are obtained. 
Determine the tank sample concentrations according to section 7.2.

                             7. Calculations

    Carry out calculations retaining at least one extra decimal figure 
beyond that of the acquired data. Round off results only after the final 
calculation.
    7.1  Nomenclature.

A = average sample area
Bw = moisture content in the sample, fraction
C = component concentration in the sample, dry basis, ppmv
Ct = calculated NMOC concentration, ppmv C equivalent
Ctm = measured NMOC concentration, ppmv C equivalent
Pbar = barometric pressure, mm Hg
Pti = gas sample tank pressure after evacuation, mm Hg 
          absolute
Pt = gas sample tank pressure after sampling, but before 
          pressurizing, mm Hg absolute
Ptf = final gas sample tank pressure after pressurizing, mm 
          Hg absolute
Pw = vapor pressure of H2O (from table 3C-1), mm 
          Hg
Tti = sample tank temperature before sampling,  deg.K
Tt = sample tank temperature at completion of sampling, 
          deg.K
Ttf = sample tank temperature after pressurizing,  deg.K
r = total number of analyzer injections of sample tank during analysis 
          (where j = injection number, 1 . . . r)
R = Mean calibration response factor for specific sample component, 
          area/ppmv

                    Table 3C-1.--Moisture Correction
------------------------------------------------------------------------
                                                                Vapor
                     Temperature  deg.C                      Pressure of
                                                              H2O, mm Hg
------------------------------------------------------------------------
4..........................................................          6.1
6..........................................................          7.0
8..........................................................          8.0
10.........................................................          9.2
12.........................................................         10.5
14.........................................................         12.0
16.........................................................         13.6
18.........................................................         15.5
20.........................................................         17.5
22.........................................................         19.8
24.........................................................         22.4
26.........................................................         25.2
28.........................................................         28.3
30.........................................................         31.8
------------------------------------------------------------------------

    7.2  Concentration of Sample Components. Calculate C for each 
compound using Equations 3C-1 and 3C-2. Use the temperature and 
barometric pressure at the sampling site to calculate Bw. If the sample 
was diluted with helium using the procedures in Method 25C, use Equation 
3C-3 to calculate the concentration.
[GRAPHIC] [TIFF OMITTED] TR12MR96.031

                             8. Bibliography

    1. McNair, H.M., and E.J. Bonnelli. Basic Gas Chromatography. 
Consolidated Printers, Berkeley, CA. 1969.

       Method 4--Determination of Moisture Content in Stack Gases

1. Principle and Applicability

    1.1  Principle. A gas sample is extracted at a constant rate from 
the source; moisture is removed from the sample stream and determined 
either volumetrically or gravimetrically.
    1.2  Applicability. This method is applicable for determining the 
moisture content of stack gas.
    Two procedures are given. The first is a reference method, for 
accurate determinations of moisture content (such as are needed to 
calculate emission data). The second is an approximation method, which 
provides estimates of percent moisture to aid in setting isokinetic 
sampling rates prior to a pollutant emission measurement run. The 
approximation method described herein is only a suggested approach; 
alternative means for approximating the moisture content, e.g., drying 
tubes, wet bulb-dry bulb techniques, condensation techniques, 
stoichiometric calculations, previous experience, etc., are also 
acceptable.
    The reference method is often conducted simultaneously with a 
pollutant emission measurement run; when it is, calculation of percent 
isokinetic, pollutant emission rate, etc., for the run shall be based 
upon the results of the reference method or its equivalent; these 
calculations shall not be based

[[Page 731]]

upon the results of the approximation method, unless the approximation 
method is shown, to the satisfaction of the Administrator, U.S. 
Environmental Protection Agency, to be capable of yielding results 
within 1 percent H2O of the reference method.
    Note: The reference method may yield questionable results when 
applied to saturated gas streams or to streams that contain water 
droplets. Therefore, when these conditions exist or are suspected, a 
second determination of the moisture content shall be made 
simultaneously with the reference method, as follows: Assume that the 
gas stream is saturated. Attach a temperature sensor [capable of 
measuring to plus-minus1  deg.C (2  deg.F)] to the reference 
method probe. Measure the stack gas temperature at each traverse point 
(see Section 2.2.1) during the reference method traverse; calculate the 
average stack gas temperature. Next, determine the moisture percentage, 
either by: (1) using a psychrometric chart and making appropriate 
corrections if stack pressure is different from that of the chart, or 
(2) using saturation vapor pressure tables. In cases where the 
pyschrometric chart or the saturation vapor pressure tables are not 
applicable (based on evaluation of the process), alternative methods, 
subject to the approval of the Administrator, shall be used.

2. Reference Method

    The procedure described in Method 5 for determining moisture content 
is acceptable as a reference method.
    2.1  Apparatus. A schematic of the sampling train used in this 
reference method is shown in Figure 4-1. All components shall be 
maintained and calibrated according to the procedure outlined in Method 
5.

[[Page 732]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.097

    2.1.1  Probe. The probe is constructed of stainless steel or glass 
tubing, sufficiently heated to prevent water condensation, and is 
equipped with a filter, either in-stack (e.g., a plug of glass wool 
inserted into the end of the probe) or heated out-stack (e.g., as 
described in Method 5), to remove particular matter.
    When stack conditions permit, other metals or plastic tubing may be 
used for the probe, subject to the approval of the Administrator.
    2.1.2  Condenser. The condenser consists of four impingers connected 
in series with ground glass, leak-free fittings or any similarly leak-
free non-contaminating fittings. The first, third, and fourth impingers 
shall

[[Page 733]]

be of the Greenburg-Smith design, modified by replacing the tip with a 
1.3 centimeter (\1/2\ inch) ID glass tube extending to about 1.3 cm (\1/
2\ in.) from the bottom of the flask. The second impinger shall be of 
the Greenburg-Smith design with the standard tip. Modifications (e.g., 
using flexible connections between the impingers, using materials other 
than glass, or using flexible vacuum lines to connect the filter holder 
to the condenser) may be used, subject to the approval of the 
Administrator.
    The first two impingers shall contain known volumes of water, the 
third shall be empty, and the fourth shall contain a known weight of 6- 
to 16-mesh indicating type silica gel, or equivalent desiccant. If the 
silica gel has been previously used, dry at 175  deg.C (350  deg.F) for 
2 hours. New silica gel may be used as received. A thermometer, capable 
of measuring temperature to within 1  deg.C (2  deg.F), shall be placed 
at the outlet of the fourth impinger, for monitoring purposes.
    Alternatively, any system may be used (subject to the approval of 
the Administrator) that cools the sample gas stream and allows 
measurement of both the water that has been condensed and the moisture 
leaving the condenser, each to within 1 ml or 1 g. Acceptable means are 
to measure the condensed water, either gravimetrically or 
volumetrically, and to measure the moisture leaving the condenser by: 
(1) monitoring the temperature and pressure at the exit of the condenser 
and using Dalton's law of partial pressures, or (2) passing the sample 
gas stream through a tared silica gel (or equivalent desiccant) trap, 
with exit gases kept below 20  deg.C (68  deg.F), and determining the 
weight gain.
    If means other than silica gel are used to determine the amount of 
moisture leaving the condenser, it is recommended that silica gel (or 
equivalent) still be used between the condenser system and pump, to 
prevent moisture condensation in the pump and metering devices and to 
avoid the need to make corrections for moisture in the metered volume.
    2.1.3  Cooling System. An ice bath container and crushed ice (or 
equivalent) are used to aid in condensing moisture.
    2.1.4  Metering System. This system includes a vacuum gauge, leak-
free pump, thermometers capable of measuring temperature to within 3 
deg.C (5.4  deg.F), dry gas meter capable of measuring volume to within 
2 percent, and related equipment as shown in Figure 4-1. Other metering 
systems, capable of maintaining a constant sampling rate and determining 
sample gas volume, may be used, subject to the approval of the 
Administrator.
    2.1.5  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg) may be 
used. In many cases, the barometric reading may be obtained from a 
nearby National Weather Service station, in which case the station value 
(which is the absolute barometric pressure) shall be requested and an 
adjustment for elevation differences between the weather station and the 
sampling point shall be applied at a rate of minus 2.5 mm Hg (0.1 in. 
Hg) per 30 m (100 ft) elevation increase or vice versa for elevation 
decrease.
    2.1.6  Graduated Cylinder and/or Balance. These items are used to 
measure condensed water and moisture caught in the silica gel to within 
1 ml or 0.5 g. Graduated cylinders shall have subdivisions no greater 
than 2 ml. Most laboratory balances are capable of weighing to the 
nearest 0.5 g or less. These balances are suitable for use here.
    2.2  Procedure. The following procedure is written for a condenser 
system (such as the impinger system described in Section 2.1.2) 
incorporating volumetric analysis to measure the condensed moisture, and 
silica gel and gravimetric analysis to measure the moisture leaving the 
condenser.
    2.2.1  Unless otherwise specified by the Administrator, a minimum of 
eight traverse points shall be used for circular stacks having diameters 
less than 0.61 m (24 in.), a minimum of nine points shall be used for 
rectangular stacks having equivalent diameters less than 0.61 m (24 
in.), and a minimum of twelve traverse points shall be used in all other 
cases. The traverse points shall be located according to Method 1. The 
use of fewer points is subject to the approval of the Administrator. 
Select a suitable probe and probe length such that all traverse points 
can be sampled. Consider sampling from opposite sides of the stack (four 
total sampling ports) for large stacks, to permit use of shorter probe 
lengths. Mark the probe with heat resistant tape or by some other method 
to denote the proper distance into the stack or duct for each sampling 
point. Place known volumes of water in the first two impingers. Weigh 
and record the weight of the silica gel to the nearest 0.5 g, and 
transfer the silica gel to the fourth impinger; alternatively, the 
silica gel may first be transferred to the impinger, and the weight of 
the silica gel plus impinger recorded.
    2.2.2  Select a total sampling time such that a minimum total gas 
volume of 0.60 scm (21 scf) will be collected, at a rate no greater than 
0.021 m3/min (0.75 cfm). When both moisture content and 
pollutant emission rate are to be determined, the moisture determination 
shall be simultaneous with, and for the same total length of time as, 
the pollutant emission rate run, unless otherwise specified in an 
applicable subpart of the standards.
    2.2.3  Set up the sampling train as shown in Figure 4-1. Turn on the 
probe heater and (if applicable) the filter heating system to

[[Page 734]]

temperatures of about 120  deg.C (248  deg.F), to prevent water 
condensation ahead of the condenser; allow time for the temperatures to 
stabilize. Place crushed ice in the ice bath container. It is 
recommended, but not required, that a leak check be done, as follows: 
Disconnect the probe from the first impinger or (if applicable) from the 
filter holder. Plug the inlet to the first impinger (or filter holder) 
and pull a 380 mm (15 in.) Hg vacuum; a lower vacuum may be used, 
provided that it is not exceeded during the test. A leakage rate in 
excess of 4 percent of the average sampling rate or 0.00057 
m3/min (0.02 cfm), whichever is less, is unacceptable. 
Following the leak check, reconnect the probe to the sampling train.
    2.2.4  During the sampling run, maintain a sampling rate within 10 
percent of constant rate, or as specified by the Administrator. For each 
run, record the data required on the example data sheet shown in Figure 
4-2. Be sure to record the dry gas meter reading at the beginning and 
end of each sampling time increment and whenever sampling is halted. 
Take other appropriate readings at each sample point, at least once 
during each time increment.
    2.2.5  To begin sampling, position the probe tip at the first 
traverse point. Immediately start the pump and adjust the flow to the 
desired rate. Traverse the cross section, sampling at each traverse 
point for an equal length of time. Add more ice and, if necessary, salt 
to maintain a temperature of less 20  deg.C (68  deg.F) at the silica 
gel outlet.
    2.2.6  After collecting the sample, disconnect the probe from the 
filter holder (or from the first impinger) and conduct a leak check 
(mandatory) as described in Section 2.2.3. Record the leak rate. If the 
leakage rate exceeds the allowable rate, the tester shall either reject 
the test results or shall correct the sample volume as in Section 6.3 of 
Method 5. Next, measure the volume of the moisture condensed to the 
nearest ml. Determine the increase in weight of the silica gel (or 
silica gel plus impinger) to the nearest 0.5 g. Record this information 
(see example data sheet, Figure 4-3) and calculate the moisture 
percentage, as described in 2.3 below.
    2.2.7  A quality control check of the volume metering system at the 
field site is suggested before collecting the sample following the 
procedure in Method 5, Section 4.4
    2.3  Calculations. Carry out the following calculations, retaining 
at least one extra decimal figure beyond that of the acquired data. 
Round off figures after final calculation.

[[Page 735]]



                                                Figure 4-2--Field Moisture Determination reference method
 
                                           -----------------------------------------------
Plant.....................................  .............................................  .............................................................
Location..................................  .............................................  .............................................................
Operator..................................  .............................................  .............................................................
Date......................................  .............................................  .............................................................
Run No....................................  .............................................  .............................................................
Ambient temperature.......................  .............................................  .............................................................
Barometric pressure.......................  .............................................  .............................................................
Probe length m (ft).......................  .............................................  .............................................................
 
                                           ------------------------------------------------
                                                            Schematic of Stack Cross Section


------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                               Pressure                                                  Gas Sample temperature at dry gas      Temperaturem of
                                                                             differential      Meter reading gas                                       meter                      gas leaving
      Traverse point number          Sampling time     Stack temperature    across orifice       sample volume        Vm    ----------------------------------------  condenser or last
                                                                           meter                                                    Inlet              Outlet             impinger
-----------------------------------------------------------------------------------H------------------------------------------------------------------------------------------------------------
                                  (), min.    deg.C (  deg.F).  mm (in.) H2O......  m\3\ (ft\3\)......  m\3\ (ft\3\)......  (Tmin),  deg.C (    (Tmout),  deg.C (     deg.C (  deg.F)
                                                                                                                                       deg.F).             deg.F).
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Total...........................                                                                                                      Avg.                Avg.
Average.............................................                                                              Avg.


[[Page 736]]


              Figure 4-3--Analytical Data--Reference Method
------------------------------------------------------------------------
                                      Impinger volume,     Silica gel
                                             ml             weight, g
------------------------------------------------------------------------
Final..............................  .................  ................
Initial............................  .................  ................
Difference.........................  .................  ................
------------------------------------------------------------------------

2.3.1  Nomenclature.

B ws=Proportion of water vapor, by volume, in the gas stream.
M w=Molecular weight of water, 18.0 g/g-mole (18.0 lb/lb-
          mole).
P m=Absolute pressure (for this method, same as barometric 
          pressure) at the dry gas meter, mm Hg (in. Hg).
P std=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
R=Ideal gas constant, 0.06236 (mm Hg) (m3)/(g-mole) ( deg.K) 
          for metric units and 21.85 (in. Hg) (ft3)/(lb-mole) 
          ( deg.R) for English units.
T m=Absolute temperature at meter,  deg.K ( deg.R).
T std=Standard absolute temperature, 293 deg.K (528 deg.R).
V m=Dry gas volume measured by dry gas meter, dcm (dcf).
V m=Incremental dry gas volume measured by dry gas 
          meter at each traverse point, dcm (dcf).
V m(std)=Dry gas volume measured by the dry gas meter, 
          corrected to standard conditions, dscm (dscf).
V wc(std)=Volume of water vapor condensed corrected to 
          standard conditions, scm (scf).
V wsg(std)=Volume of water vapor collected in silica gel 
          corrected to standard conditions, scm (scf).
V f=Final volume of condenser water, ml.
V i=Initial volume, if any, of condenser water, ml.
W f=Final weight of silica gel or silica gel plus impinger, 
          g.
W i=Initial weight of silica gel or silica gel plus impinger, 
          g.
Y =Dry gas meter calibration factor.
!w=Density of water, 0.9982 g/ml (0.002201 lb/ml).
2.3.2  Volume of Water Vapor Condensed.
[GRAPHIC] [TIFF OMITTED] TC16NO91.119

Where:

K1=0.001333 m3/ml for metric units
   =0.04707 ft3/ml for English units
2.3.3  Volume of Water Vapor Collected in Silica Gel.
[GRAPHIC] [TIFF OMITTED] TC16NO91.120

Where:
K 2=0.001335 m3/g for metric units
   =0.04715 ft3/g for English units
2.3.4  Sample Gas Volume.
[GRAPHIC] [TIFF OMITTED] TC16NO91.121

Where:
K 3=0.3858  deg.K/mm Hg for metric units
   =17.64  deg.R/in. Hg for English units
    Note: If the post-test leak rate (Section 2.2.6) exceeds the 
allowable rate, correct the value of V m in Equation 4-3, as 
described in Section 6.3 of Method 5.
    2.3.5  Moisture Content.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.122
    
    Note: In saturated or moisture droplet-laden gas streams, two 
calculations of the moisture content of the stack gas shall be made, one 
using a value based upon the saturated conditions (see Section 1.2), and 
another based upon the results of the impinger analysis. The lower of 
these two values of B ws shall be considered correct.
    2.3.6  Verification of Constant Sampling Rate. For each time 
increment, determine the V!m. Calculate the average. 
If the value for any time increment differs from the average by more 
than 10 percent, reject the results and repeat the run.
3. Approximation Method

    The approximation method described below is presented only as a 
suggested method (see Section 1.2).
    3.1  Apparatus.

[[Page 737]]

    3.1.1  Probe. Stainless steel glass tubing, sufficiently heated to 
prevent water condensation and equipped with a filter (either in-stack 
or heated out-stack) to remove particulate matter. A plug of glass wool, 
inserted into the end of the probe, is a satisfactory filter.
    3.1.2  Impingers. Two midget impingers, each with 30 ml capacity, or 
equivalent.
    3.1.3  Ice Bath. Container and ice, to aid in condensing moisture in 
impingers.
    3.1.4  Drying Tube. Tube packed with new or regenerated 6- to 16-
mesh indicating-type silica gel (or equivalent desiccant), to dry the 
sample gas and to protect the meter and pump.
    3.1.5  Valve. Needle valve, to regulate the sample gas flow rate.
    3.1.6  Pump. Leak-free, diaphragm type, or equivalent, to pull the 
gas sample through the train.
    3.1.7  Volume Meter. Dry gas meter, sufficiently accurate to measure 
the sample volume within 2%, and calibrated over the range of flow rates 
and conditions actually encountered during sampling.
    3.1.8  Rate Meter. Rotameter, to measure the flow range from 0 to 3 
lpm (0 to 0.11 cfm).
    3.1.9  Graduated Cylinder. 25 ml.
    3.1.10  Barometer. Mercury, aneroid, or other barometer, as 
described in Section 2.1.5 above.
    3.1.11  Vacuum Gauge. At least 760 mm Hg (30 in. Hg) gauge, to be 
used for the sampling leak check.
    3.2  Procedure.
    3.2.1  Place exactly 5 ml distilled water in each impinger.

Leak check the sampling train as follows: Temporarily insert a vacuum 
gauge at or near the probe inlet; then, plug the probe inlet and pull a 
vacuum of at least 250 mm Hg (10 in. Hg). Note the time rate of change 
of the dry gas meter dial; alternatively, a rotameter (0-40 cc/min) may 
be temporarily attached to the dry gas meter outlet to determine the 
leakage rate. A leak rate not in excess of 2 percent of the average 
sampling rate is acceptable.
    Note: Carefully release the probe inlet plug before turning off the 
pump.

[[Page 738]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.098


[[Page 739]]



     Figure 4-5--Field Moisture Determination--Approximation Method

     Figure 4-5--Field Moisture Determination--Approximation Method
Location..................................  Comments:
Test......................................
Date......................................
Operator..................................
Barometric pressure.......................
 


----------------------------------------------------------------------------------------------------------------
                                          Gas volume through
              Clock time                  meter, (Vm), m\3\     Rate meter setting m\3\/    Meter temperature,
                                               (ft\3\)              min (ft\3\/min)          deg. C (  deg.F)
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------

    3.2.2  Connect the probe, insert it into the stack, and sample at a 
constant rate of 2 lpm (0.071 cfm). Continue sampling until the dry gas 
meter registers about 30 liters (1.1 ft3) or until visible 
liquid droplets are carried over from the first impinger to the second. 
Record temperature, pressure, and dry gas meter readings as required by 
Figure 4-5.
    3.2.3  After collecting the sample, combine the contents of the two 
impingers and measure the volume to the nearest 0.5 ml.
    3.3  Calculations. The calculation method presented is designed to 
estimate the moisture in the stack gas; therefore, other data, which are 
only necessary for accurate moisture determinations, are not collected. 
The following equations adequately estimate the moisture content, for 
the purpose of determining isokinetic sampling rate settings.
    3.3.1  Nomenclature.

Bwm=Approximate proportion, by volume, of water vapor in the 
          gas stream leaving the second impinger, 0.025.
Bws=Water vapor in the gas stream, proportion by volume.
Mw=Molecular weight of water, 18.0 g/g-mole (18.0 lb/lb-
          mole).
Pm=Absolute pressure (for this method, same as barometric 
          pressure) at the dry gas meter.
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
R=Ideal gas constant, 0.06236 (mm Hg) (m3)/(g-mole) ( deg.K) 
          for metric units and 21.85 (in. Hg) (ft3)/lb-mole) 
          ( deg.R) for English units.
Tm=Absolute temperature at meter,  deg.K ( deg.R).
Tstd=Standard absolute temperature, 293 deg.K (528 deg. R).
Vf=Final volume of impinger contents, ml.
Vi=Initial volume of impinger contents, ml.
Vm=Dry gas volume measured by dry gas meter, dcm (dcf).
Vm(std)=Dry gas volume measured by dry gas meter, corrected 
          to standard conditions, dscm (dscf).
Vwc(std)=Volume of water vapor condensed, corrected to 
          standard conditions, scm (scf).
w=Density of water, 0.9982 g/ml (0.002201 lb/ml).
Y=Dry gas meter calibration factor.
    3.3.2  Volume of Water Vapor Collected.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.123
    
Where:
K1=0.001333 m3/ml for metric units
   =0.04707 ft3/ml for English units.

    3.3.3  Gas Volume.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.099
    
where:
K2=0.3858  deg.K/mm Hg for metric units
   =17.64  deg.R/in. Hg for English units

    3.3.4  Approximate Moisture Content.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.100
    
4. Calibration

    4.1  For the reference method, calibrate equipment as specified in 
the following sections of Method 5: Section 5.3 (metering system); 
Section 5.5 (temperature gauges); and Section 5.7 (barometer). The 
recommended leak check of the metering system (Section 5.6 of Method 5) 
also applies to the reference method. For the approximation method, use 
the procedures outlined in Section 5.1.1 of Method 6 to calibrate the 
metering system, and the procedure of Method 5, Section 5.7 to calibrate 
the barometer.

5. Bibliography

    1. Air Pollution Engineering Manual (Second Edition). Danielson, J. 
A. (ed.). U.S. Environmental Protection Agency, Office of Air Quality 
Planning and Standards. Research Triangle Park, NC. Publication No. AP-
40. 1973.

[[Page 740]]

    2. Devorkin, Howard. et al. Air Pollution Source Testing Manual. Air 
Pollution Control District, Los Angeles, CA. November, 1963.
    3. Methods for Determination of Velocity, Volume, Dust and Mist 
Content of Gases. Western Precipitation Division of Joy Manufacturing 
Co., Los Angeles, CA. Bulletin WP-50. 1968.

Method 5--Determination of Particulate Emissions from Stationary Sources

1. Principle and Applicability

    1.1  Principle. Particulate matter is withdrawn isokinetically from 
the source and collected on a glass fiber filter maintained at a 
temperature in the range of 120plus-minus14  deg.C 
(248plus-minus25  deg.F) or such other temperature as 
specified by an applicable subpart of the standards or approved by 
Administrator, U.S. Environmental Protection Agency, for a particular 
application. The particulate mass, which includes any material that 
condenses at or above the filtration temperature, is determined 
gravimetrically after removal of uncombined water.
    1.2  Applicability. This method is applicable for the determination 
of particulate emissions from stationary sources.

2. Apparatus

    2.1  Sampling Train. A schematic of the sampling train used in this 
method is shown in Figure 5-1. Complete construction details are given 
in APTD-0581 (Citation 2 in Bibliography); commercial models of this 
train are also available. For changes from APTD-0581 and for allowable 
modifications of the train shown in Figure 5-1, see the following 
subsections.
    The operating and maintenance procedures for the sampling train are 
described in APTD-0576 (Citation 3 in Bibliography). Since correct usage 
is important in obtaining valid results, all users should read APTD-0576 
and adopt the operating and maintenance procedures outlined in it, 
unless otherwise specified herein. The sampling train consists of the 
following components:

[[Page 741]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.101

    2.1.1  Probe Nozzle. Stainless steel (316) or glass with sharp, 
tapered leading edge. The angle of taper shall be 30 deg. and 
the taper shall be on the outside to preserve a constant internal 
diameter. The probe nozzle shall be of the button-hook or elbow design, 
unless otherwise specified by the Administrator. If made of stainless 
steel, the nozzle

[[Page 742]]

shall be constructed from seamless tubing; other materials of 
construction may be used, subject to the approval of the Administrator.
    A range of nozzle sizes suitable for isokinetic sampling should be 
available, e.g., 0.32 to 1.27 cm (\1/8\ to \1/2\ in.)--or larger if 
higher volume sampling trains are used--inside diameter (ID) nozzles in 
increments of 0.16 cm (\1/16\ in.). Each nozzle shall be calibrated 
according to the procedures outlined in Section 5.
    2.1.2  Probe Liner. Borosilicate or quartz glass tubing with a 
heating system capable of maintaining a gas temperature at the exit end 
during sampling of 120plus-minus14  deg.C 
(248plus-minus25  deg.F), or such other temperature as 
specified by an applicable subpart of the standards or approved by the 
Administrator for a particular application. (The tester may opt to 
operate the equipment at a temperature lower than that specified.) Since 
the actual temperature at the outlet of the probe is not usually 
monitored during sampling, probes constructed according to APTD-0581 and 
utilizing the calibration curves of APTD-0576 (or calibrated according 
to the procedure outlined in APTD-0576) will be considered acceptable.
    Either borosilicate or quartz glass probe liners may be used for 
stack temperatures up to about 480  deg.C (900  deg.F); quartz liners 
shall be used for temperatures between 480 and 900  deg.C (900 and 1,650 
 deg.F). Both types of liners may be used at higher temperatures than 
specified for short periods of time, subject to the approval of the 
Administrator. The softening temperature for borosilicate is 820  deg.C 
(1,508  deg.F), and for quartz it is 1,500  deg.C (2,732  deg.F).
    Whenever practical, every effort should be made to use borosilicate 
or quartz glass probe liners. Alternatively, metal liners (e.g., 316 
stainless steel, Incoloy 825,2or other corrosion resistant 
metals) made of seamless tubing may be used, subject to the approval of 
the Administrator.
---------------------------------------------------------------------------

    2 Mention of trade names or specific product does not 
constitute endorsement by the Environmental Protection Agency.
---------------------------------------------------------------------------

    2.1.3  Pitot Tube. Type S, as described in Section 2.1 of Method 2, 
or other device approved by the Administrator. The pitot tube shall be 
attached to the probe (as shown in Figure 5-1) to allow constant 
monitoring of the stack gas velocity. The impact (high pressure) opening 
plane of the pitot tube shall be even with or above the nozzle entry 
plane (see Method 2, Figure 2-6b) during sampling. The Type S pitot tube 
assembly shall have a known coefficient, determined as outlined in 
Section 4 of Method 2.
    2.1.4  Differential Pressure Gauge. Inclined manometer or equivalent 
device (two), as described in Section 2.2 of Method 2. One manometer 
shall be used or velocity head () readings, and the 
other, for orifice differential pressure readings.
    2.1.5  Filter Holder. Borosilicate glass, with a glass frit filter 
support and a silicone rubber gasket. Other materials of construction 
(e.g., stainless steel, Teflon, Viton) may be used, subject to approval 
of the Administrator. The holder design shall provide a positive seal 
against leakage from the outside or around the filter. The holder shall 
be attached immediately at the outlet of the probe (or cyclone, it 
used).
    2.1.6  Filter Heating System. Any heating system capable of 
maintaining a temperature around the filter holder during sampling of 
120plus-minus14  deg.C (248plus-minus25  deg.F), 
or such other temperature as specified by an applicable subpart of the 
standards or approved by the Administrator for a particular application. 
Alternatively, the tester may opt to operate the equipment at a 
temperature lower than that specified. A temperature gauge capable of 
measuring temperature to within 3  deg.C (5.4  deg.F) shall be installed 
so that the temperature around the filter holder can be regulated and 
monitored during sampling. Heating systems other than the one shown in 
APTD-0581 may be used.
    2.1.7  Condenser. The following system shall be used to determine 
the stack gas moisture content: Four impingers connected in series with 
leak-free ground glass fittings or any similar leak-free non-
contaminating fittings. The first, third, and fourth impingers shall be 
of the Greenburg-Smith design, modified by replacing the tip with 1.3 cm 
(\1/2\ in.) ID glass tube extending to about 1.3 cm (\1/2\ in.) from the 
bottom of the flask. The second impinger shall be of the Greenburg-Smith 
design with the standard tip. Modifications (e.g., using flexible 
connections between the impingers, using materials other than glass, or 
using flexible vacuum lines to connect the filter holder to the 
condenser) may be used, subject to the approval of the Administrator. 
The first and second impingers shall contain known quantities of water 
(Section 4.1.3), the third shall be empty, and the fourth shall contain 
a known weight of silica gel, or equivalent desiccant. A thermometer, 
capable of measuring temperature to within 1  deg.C (2  deg.F) shall be 
placed at the outlet of the fourth impinger for monitoring purposes.
    Alternatively, any system that cools the sample gas stream and 
allows measurement of the water condensed and moisture leaving the 
condenser, each to within 1 ml or 1 g may be used, subject to the 
approval of the Administrator. Acceptable means are to measure the 
condensed water either gravimetrically or volumetrically and to measure 
the moisture leaving the condenser by: (1) monitoring the temperature 
and pressure at the exit of the condenser and using Dalton's law of 
partial pressures; or (2) passing the sample has stream through a tared 
silica gel (or equivalent desiccant) trap with exit gases

[[Page 743]]

kept below 20  deg.C (68  deg.F) and determining the weight gain.
    If means other than silica gel are used to determine the amount of 
moisture leaving the condenser, it is recommended that silica gel (or 
equivalent) still be used between the condenser system and pump to 
prevent moisture condensation in the pump and metering devices and to 
avoid the need to make corrections for moisture in the metered volume.
    Note: If a determination of the particulate matter collected in the 
impingers is desired in addition to moisture content, the impinger 
system described above shall be used, without modification. Individual 
States or control agencies requiring this information shall be contacted 
as to the sample recovery and analysis of the impinger contents.
    2.1.8  Metering System. Vacuum gauge, leak-free pump, thermometers 
capable of measuring temperature to within 3  deg.C (5.4  deg.F), dry 
gas meter capable of measuring volume to within 2 percent, and related 
equipment, as shown in Figure 5-1. Other metering systems capable of 
maintaining sampling rates within 10 percent of isokinetic and of 
determining sample volumes to within 2 percent may be used, subject to 
the approval of the Administrator. When the metering system is used in 
conjunction with a pitot tube, the system shall enable checks of 
isokinetic rates.
    Sampling trains utilizing metering systems designed for higher flow 
rates than that decribed in APTD-0581 or APDT-0576 may be used provided 
that the specifications of this method are met.
    2.1.9  Barometer. Mercury aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg). In many 
cases the barometric reading may be obtained from a nearby National 
Weather Service station, in which case the station value (which is the 
absolute barometric pressure) shall be requested and an adjustment for 
elevation differences between the weather station and sampling point 
shall be applied at a rate of minus 2.5 mm Hg (0.1 in. Hg) per 30 m (100 
ft) elevation increase or vice versa for elevation decrease.
    2.1.10  Gas Density Determination Equipment. Temperature sensor and 
pressure gauge, as described in Sections 2.3 and 2.4 of Method 2, and 
gas analyzer, if necessary, as described in Method 3. The temperature 
sensor shall, preferably, be permanently attached to the pitot tube or 
sampling probe in a fixed configuration, such that the tip of the sensor 
extends beyond the leading edge of the probe sheath and does not touch 
any metal. Alternatively, the sensor may be attached just prior to use 
in the field. Note, however, that if the temperature sensor is attached 
in the field, the sensor must be placed in an interference-free 
arrangement with respect to the Type S pitot tube openings (see Method 
2, Figure 2-7). As a second alternative, if a difference of not more 
than 1 percent in the average velocity measurement is to be introduced, 
the temperature gauge need not be attached to the probe or pitot tube. 
(This alternative is subject to the approval of the Administrator.)
    2.2  Sample Recovery. The following items are needed.
    2.2.1  Probe-Liner and Probe-Nozzle Brushes. Nylon bristle brushes 
with stainless steel wire handles. The probe brush shall have extensions 
(at least as long as the probe) of stainless steel, Nylon, Teflon, or 
similarly inert material. The brushes shall be properly sized and shaped 
to brush out the probe liner and nozzle.
    2.2.2  Wash Bottles--Two. Glass wash bottles are recommended; 
polyethylene wash bottles may be used at the option of the tester. It is 
recommended that acetone not be stored in polyethylene bottles for 
longer than a month.
    2.2.3  Glass Sample Storage Containers. Chemically resistant, 
borosilicate glass bottles, for acetone washes, 500 ml or 1000 ml. Screw 
cap liners shall either be rubber-backed Teflon or shall be constructed 
so as to be leak-free and resistant to chemical attack by acetone. 
(Narrow mouth glass bottles have been found to be less prone to 
leakage.) Alternatively, polyethylene bottles may be used.
    2.2.4  Petri Dishes. For filter samples, glass or polyethylene, 
unless otherwise specified by the Administrator.
    2.2.5  Graduated Cylinder and/or Balance. To measure condensed water 
to within 1 ml or 1 g. Graduated cylinders shall have subdivisions no 
greater than 2 ml. Most laboratory balances are capable of weighing to 
the nearest 0.5 g or less. Any of these balances is suitable or use here 
and in Section 2.3.4.
    2.2.6  Plastic Storage Containers. Air-tight containers to store 
silica gel.
    2.2.7  Funnel and Rubber Policeman. To aid in transfer of silica gel 
to container; not necessary if silica gel is weighed in the field.
    2.2.8  Funnel. Glass or polyethylene, to aid in sample recovery.
    2.3  Analysis. For analysis, the following equipment is needed.
    2.3.1  Glass Weighing Dishes.
    2.3.2  Desiccator.
    2.3.3  Analytical Balance. To measure to within 0.1 mg.
    2.3.4  Balance. To measure to within 0.5 g.
    2.3.5  Beakers. 250 ml.
    2.3.6  Hygrometer. To measure the relative humidity of the 
laboratory environment.
    2.3.7  Temperature Gauge. To measure the temperature of the 
laboratory environment.

3. Reagents

    3.1  Sampling. The reagents used in sampling are as follows:

[[Page 744]]

    3.1.1  Filters. Glass fiber filters, without organic binder, 
exhibiting at least 99.95 percent efficiency (<0.05 percent penetration) 
on 0.3-micron dioctyl phthalate smoke particles. The filter efficiency 
test shall be conducted in accordance with ASTM Standard Method D2986-71 
(Reapproved 1978) (incorporated by reference--see Sec. 60.17). Test data 
from the supplier's quality control program are sufficient for this 
purpose. In sources containing SO2 or SO3, the 
filter material must be of a type that is unreactive to SO2 
or SO3. Citation 10 in Bibliography, may be used to select 
the appropriate filter.
    3.1.2  Silica Gel. Indicating type, 6 to 16 mesh. If previously 
used, dry at 175  deg.C (350  deg.F) for 2 hours. New silica gel may be 
used as received. Alternatively, other types of desiccants (equivalent 
or better) may be used, subject to the approval of the Administrator.
    3.1.3  Water. When analysis of the material caught in the impingers 
is required, deionized distilled water shall be used. Run blanks prior 
to field use to eliminate a high blank on test samples.
    3.1.4  Crushed Ice.
    3.1.5  Stopcock Grease. Acetone-insoluble, heat-stable silicone 
grease. This is not necessary if screw-on connectors with Teflon 
sleeves, or similar, are used. Alternatively, other types of stopcock 
grease may be used, subject to the approval of the Administrator.
    3.2  Sample Recovery. Acetone-reagent grade, 0.001 
percent residue, in glass bottles--is required. Acetone from metal 
containers generally has a high residue blank and should not be used. 
Sometimes, suppliers transfer acetone to glass bottles from metal 
containers; thus, acetone blanks shall be run prior to field use and 
only acetone with low blank values (0.001 percent) shall be 
used. In no case shall a blank value of greater than 0.001 percent of 
the weight of acetone used be subtracted from the sample weight.
    3.3  Analysis. Two reagents are required for the analysis:
    3.3.1  Acetone. Same as 3.2.
    3.3.2  Desiccant. Anhydrous calcium sulfate, indicating type. 
Alternatively, other types of desiccants may be used, subject to the 
approval of the Administrator.

4. Procedure

    4.1  Sampling. The complexity of this method is such that, in order 
to obtain reliable results, testers should be trained and experienced 
with the test procedures.
    4.1.1  Pretest Preparation. It is suggested that sampling equipment 
be maintained according to the procedure described in APTD-0576.
    Weigh several 200 to 300 g portions of silica gel in air-tight 
containers to the nearest 0.5 g. Record the total weight of the silica 
gel plus container, on each container. As an alternative, the silica gel 
need not be preweighed, but may be weighed directly in the impinger or 
sampling holder just prior to train assembly.
    Check filters visually against light for irregularities and flaws or 
pinhole leaks. Label filters of the proper diameter on the back side 
near the edge using numbering machine ink. As an alternative, label the 
shipping containers (glass or plastic petri dishes) and keep the filters 
in these containers at all times except during sampling and weighing.
    Desiccate the filters at 20plus-minus5.6  deg.C 
(68plus-minus10  deg.F) and ambient pressure for at least 24 
hours and weigh at intervals of at least 6 hours to a constant weight, 
i.e., 0.5 mg change from previous weighing; record results to the 
nearest 0.1 mg. During each weighing the filter must not be exposed to 
the laboratory atmosphere for a period greater than 2 minutes and a 
relative humidity above 50 percent. Alternatively (unless otherwise 
specified by the Administrator), the filters may be oven dried at 105 
deg.C (220  deg.F) for 2 to 3 hours, desiccated for 2 hours, and 
weighed. Procedures other than those described, which account for 
relative humidity effects, may be used, subject to the approval of the 
Administrator.
    4.1.2  Preliminary Determinations. Select the sampling site and the 
minimum number of sampling points according to Method 1 or as specified 
by the Administrator. Determine the stack pressure, temperature, and the 
range of velocity heads using Method 2; it is recommended that a leak-
check of the pitot lines (see Method 2, Section 3.1) be performed. 
Determine the moisture content using Approximation Method 4 or its 
alternatives for the purpose of making isokinetic sampling rate 
settings. Determine the stack gas dry molecular weight, as described in 
Method 2, Section 3.6; if integrated Method 3 sampling is used for 
molecular weight determination, the integrated bag sample shall be taken 
simultaneously with, and for the same total length of time as, the 
particulate sample run.
    Select a nozzle size based on the range of velocity heads, such that 
it is not necessary to change the nozzle size in order to maintain 
isokinetic sampling rates. During the run, do not change the nozzle 
size. Ensure that the proper differential pressure gauge is chosen for 
the range of velocity heads encountered (see Section 2.2 of Method 2).
    Select a suitable probe liner and probe length such that all 
traverse points can be sampled. For large stacks, consider sampling from 
opposite sides of the stack to reduce the length of probes.
    Select a total sampling time greater than or equal to the minimum 
total sampling time specified in the test procedures for the specific 
industry such that (1) the sampling time per point is not less than 2 
min (or some greater time interval as specified by the Administrator), 
and (2) the sample volume taken (corrected to standard conditions)

[[Page 745]]

will exceed the required minimum total gas sample volume. The latter is 
based on an approximate average sampling rate.
    It is recommended that the number of minutes sampled at each point 
be an integer or an integer plus one-half minute, in order to avoid 
timekeeping errors. The sampling time at each point shall be the same.
    In some circumstances, e.g., batch cycles, it may be necessary to 
sample for shorter times at the traverse points and to obtain smaller 
gas sample volumes. In these cases, the Administrator's approval must 
first be obtained.
    4.1.3  Preparation of Collection Train. During preparation and 
assembly of the sampling train, keep all openings where contamination 
can occur covered until just prior to assembly or until sampling is 
about to begin.
    Place 100 ml of water in each of the first two impingers, leave the 
third impinger empty, and transfer approximately 200 to 300 g of 
preweighed silica gel from its container to the fourth impinger. More 
silica gel may be used, but care should be taken to ensure that it is 
not entrained and carried out from the impinger during sampling. Place 
the container in a clean place for later use in the sample recovery. 
Alternatively, the weight of the silica gel plus impinger may be 
determined to the nearest 0.5 g and recorded.
    Using a tweezer or clean disposable surgical gloves, place a labeled 
(identified) and weighed filter in the filter holder. Be sure that the 
filter is properly centered and the gasket properly placed so as to 
prevent the sample gas stream from circumventing the filter. Check the 
filter for tears after assembly is completed.
    When glass liners are used, install the selected nozzle using a 
Viton A O-ring when stack temperatures are less than 260  deg.C (500 
deg.F) and an asbestos string gasket when temperatures are higher. See 
APTD-0576 for details. Other connecting systems using either 316 
stainless steel or Teflon ferrules may be used. When metal liners are 
used, install the nozzle as above or by a leak-free direct mechanical 
connection. Mark the probe with heat resistant tape or by some other 
method to denote the proper distance into the stack or duct for each 
sampling point.
    Set up the train as in Figure 5-1, using (if necessary) a very light 
coat of silicone grease on all ground glass joints, greasing only the 
outer portion (see APTD-0576) to avoid possibility of contamination by 
the silicone grease. Subject to the approval of the Administrator, a 
glass cyclone may be used between the probe and filter holder when the 
total particulate catch is expected to exceed 100 mg or when water 
droplets are present in the stack gas.
    Place crushed ice around the impingers.
    4.1.4  Leak-Check Procedures.
    4.1.4.1  Pretest Leak-Check. A pretest leak-check is recommended, 
but not required. If the tester opts to conduct the pretest leak-check, 
the following procedure shall be used.
    After the sampling train has been assembled, turn on and set the 
filter and probe heating systems at the desired operating temperatures. 
Allow time for the temperatures to stabilize. If a Viton A O-ring or 
other leak-free connection is used in assembling the probe nozzle to the 
probe liner, leak-check the train at the sampling site by plugging the 
nozzle and pulling a 380 mm Hg (15 in. Hg) vacuum.
    Note: A lower vacuum may be used, provided that it is not exceeded 
during the test.
    If an asbestos string is used, do not connect the probe to the train 
during the leak-check. Instead, leak-check the train by first plugging 
the inlet to the filter holder (cyclone, if applicable) and pulling a 
380 mm Hg (15 in. Hg) vacuum (see Note immediately above). Then connect 
the probe to the train and leak-check at about 25 mm Hg (1 in. Hg) 
vacuum; alternatively, the probe may be leak-checked with the rest of 
the sampling train, in one step, at 380 mm Hg (15 in. Hg) vacuum. 
Leakage rates in excess of 4 percent of the average sampling rate or 
0.00057 m3/min (0.02 cfm), whichever is less, are 
unacceptable.
    The following leak-check instructions for the sampling train 
described in APTD-0576 and APTD-0581 may be helpful. Start the pump with 
bypass valve fully open and coarse adjust valve, completely closed. 
Partially open the coarse adjust valve and slowly close the bypass valve 
until the desired vacuum is reached. Do not reverse direction of bypass 
valve; this will cause water to back up into the filter holder. If the 
desired vacuum is exceeded, either leak-check at this higher vacuum or 
end the leak-check as shown below and start over.
    When the leak-check is completed, first slowly remove the plug from 
the inlet to the probe, filter holder, or cyclone (if applicable) and 
immediately turn off the vacuum pump. This prevents the water in the 
impingers from being forced backward into the filter holder and silica 
gel from being entrained backward into the third impinger.
    4.1.4.2  Leak-Checks During Sample Run. If, during the sampling run, 
a component (e.g., filter assembly or impinger) change becomes 
necessary, a leak-check shall be conducted immediately before the change 
is made. The leak-check shall be done according to the procedure 
outlined in Section 4.1.4.1 above, except that it shall be done at a 
vacuum equal to or greater than the maximum value recorded up to that 
point in the test. If the leakage rate is found to be no greater than 
0.00057 m3/min (0.02 cfm) or 4 percent of the average 
sampling rate (whichever is less), the results are acceptable, and

[[Page 746]]

no correction will need to be applied to the total volume of dry gas 
metered; if, however, a higher leakage rate is obtained, the tester 
shall either record the leakage rate and plan to correct the sample 
volume as shown in Section 6.3 of this method, or shall void the 
sampling run.
    Immediately after component changes, leak-checks are optional; if 
such leak-checks are done, the procedure outlined in Section 4.1.4.1 
above shall be used.
    4.1.4.3  Post-test Leak-Check. A leak-check is mandatory at the 
conclusion of each sampling run. The leak-check shall be done in 
accordance with the procedures outlined in Section 4.1.4.1, except that 
it shall be conducted at a vacuum equal to or greater than the maximum 
value reached during the sampling run. If the leakage rate is found to 
be no greater than 0.00057 m3/min (0.02 cfm) or 4 percent of 
the average sampling rate (whichever is less), the results are 
acceptable, and no correction need be applied to the total volume of dry 
gas metered. If, however, a higher leakage rate is obtained, the tester 
shall either record the leakage rate and correct the sample volume as 
shown in Section 6.3 of this method, or shall void the sampling run.
    4.1.5  Particulate Train Operation. During the sampling run, 
maintain an isokinetic sampling rate (within 10 percent of true 
isokinetic unless otherwise specified by the Administrator) and a 
temperature around the filter of 120plus-minus14  deg.C 
(248plus-minus25  deg.F), or such other temperature as 
specified by an applicable subpart of the standards or approved by the 
Administrator.
    For each run, record the data required on a data sheet such as the 
one shown in Figure 5-2. Be sure to record the initial dry gas meter 
reading. Record the dry gas meter readings at the beginning and end of 
each sampling time increment, when changes in flow rates are made, 
before and after each leak-check, and when sampling is halted. Take 
other readings required by Figure 5-2 at least once at each sample point 
during each time increment and additional readings when significant 
changes (20 percent variation in velocity head readings) necessitate 
additional adjustments in flow rate. Level and zero the manometer. 
Because the manometer level and zero may drift due to vibrations and 
temperature changes, make periodic checks during the traverse.
    Clean the portholes prior to the test run to minimize the chance of 
sampling deposited material. To begin sampling, remove the nozzle cap, 
verify that the filter and probe heating systems are up to temperature, 
and that the pitot tube and probe are properly positioned. Position the 
nozzle at the first traverse point with the tip pointing directly into 
the gas stream. Immediately start the pump and adjust the flow to 
isokinetic conditions. Nomographs are available, which aid in the rapid 
adjustment of the isokinetic sampling rate without excessive 
computations. These nomographs are designed for use when the Type S 
pitot tube coefficient is 0.85plus-minus0.02, and the stack 
gas equivalent density (dry molecular weight) is equal to 
29plus-minus4. APTD-0576 details the procedure for using the 
nomographs. If Cp and Md are outside the above 
stated ranges do not use the nomographs unless appropriate steps (see 
Citation 7 in Bibliography) are taken to compensate for the deviations.

[[Page 747]]



                                       Figure 5-2--Particulate field data
 
                                  --------------------------------------
                  Plant..........  ....................................  Ambient temperature..............  ....
                  Location.......  ....................................  Barometric pressure..............  ....
                  Operator.......  ....................................  Assumed moisture, %..............  ....
                  Date...........  ....................................  Probe length, m. (ft.)...........  ....
                  Run No.........  ....................................  Nozzle identification No.........  ....
                  Sample box No..  ....................................  Average calibrated nozzle          ....
                                                                          diameter, cm (in.).
                  Meter box No...  ....................................  Probe heater setting.............  ....
                  Meter   ....................................  Leak rate, m\3\/min, (cfm).......  ....
                   H@.
                  C factor.......  ....................................  Probe liner material.............  ....
                  Pitot tube       ....................................  Static pressure, mm. Hg (in. Hg).  ....
                   coefficient,
                   Cp.
                                   ....................................  Filter No........................  ....
                                  --------------------------------------
   Schematic of Stack Cross Section


----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                                                       Pressure                              Gas sample temperature at dry gas
                                                                                                                     differential                                          meter                     Filter holder    Temperature of gas
      Traverse point number          Sampling time          Vacuum         Stack temperature     Velocity head      across orifice     Gas sample volume ----------------------------------------     temperature      leaving condenser
                                                                                                                         meter                                   Inlet              Outlet                             or last impinger
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                  (e). min..........  mm Hg (in. Hg)....  (TS).  deg.C (      ( PS). mm  mm H20 (in. H20)..  m\3\ (ft\3\)......    deg.C (  deg.F).    deg.C (  deg.F).    deg.C (  deg.F).    deg.C (  deg.F)
                                                                           deg.F).             (in.) H20.
========================================================================================================================================================================================================================================
 
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Total                                                                                                                                                     Avg.                Avg.
----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Average                                                                                                                                                   Avg.


[[Page 748]]

    When the stack is under significant negative pressure (height of 
impinger stem), take care to close the coarse adjust valve before 
inserting the probe into the stack to prevent water from backing into 
the filter holder. If necessary, the pump may be turned on with the 
coarse adjust valve closed.
    When the probe is in position, block off the openings around the 
probe and porthole to prevent unrepresentative dilution of the gas 
stream.
    Traverse the stack cross-section, as required by Method 1 or as 
specified by the Administrator, being careful not to bump the probe 
nozzle into the stack walls when sampling near the walls or when 
removing or inserting the probe through the portholes; this minimizes 
the chance of extracting deposited material.
    During the test run, make periodic adjustments to keep the 
temperature around the filter holder at the proper level; add more ice 
and, if necessary, salt to maintain a temperature of less than 20  deg.C 
(68  deg.F) at the condenser/silica gel outlet. Also, periodically check 
the level and zero of the manometer.
    If the pressure drop across the filter becomes too high, making 
isokinetic sampling difficult to maintain, the filter may be replaced in 
the midst of a sample run. It is recommended that another complete 
filter assembly be used rather than attempting to change the filter 
itself. Before a new filter assembly is installed, conduct a leak-check 
(see Section 4.1.4.2). The total particulate weight shall include the 
summation of all filter assembly catches.
    A single train shall be used for the entire sample run, except in 
cases where simultaneous sampling is required in two or more separate 
ducts or at two or more different locations within the same duct, or, in 
cases where equipment failure necessitates a change of trains. In all 
other situations, the use of two or more trains will be subject to the 
approval of the Administrator.
    Note that when two or more trains are used, separate analyses of the 
front-half and (if applicable) impinger catches from each train shall be 
performed, unless identical nozzle sizes were used on all trains, in 
which case, the front-half catches from the individual trains may be 
combined (as may the impinger catches) and one analysis of front-half 
catch and one analysis of impinger catch may be performed. Consult with 
the Administrator for details concerning the calculation of results when 
two or more trains are used.
    At the end of the sample run, turn off the coarse adjust valve, 
remove the probe and nozzle from the stack, turn off the pump, record 
the final dry gas meter reading, and conduct a post-test leak-check, as 
outlined in Section 4.1.4.3. Also, leak-check the pitot lines as 
described in Method 2, Section 3.1; the lines must pass this leak-check, 
in order to validate the velocity head data.
    4.1.6  Calculation of Percent Isokinetic. Calculate percent 
isokinetic (see Calculations, Section 6) to determine whether the run 
was valid or another test run should be made. If there was difficulty in 
maintaining isokinetic rates due to source conditions, consult with the 
Administrator for possible variance on the isokinetic rates.
    4.2  Sample Recovery. Proper cleanup procedure begins as soon as the 
probe is removed from the stack at the end of the sampling period. Allow 
the probe to cool.
    When the probe can be safely handled, wipe off all external 
particulate matter near the tip of the probe nozzle and place a cap over 
it to prevent losing or gaining particulate matter. Do not cap off the 
probe tip tightly while the sampling train is cooling down as this would 
create a vacuum in the filter holder, thus drawing water from the 
impingers into the filter holder.
    Before moving the sample train to the cleanup site, remove the probe 
from the sample train, wipe off the silicone grease, and cap the open 
outlet of the probe. Be careful not to lose any condensate that might be 
present. Wipe off the silicone grease from the filter inlet where the 
probe was fastened and cap it. Remove the umbilical cord from the last 
impinger and cap the impinger. If a flexible line is used between the 
first impinger or condenser and the filter holder, disconnect the line 
at the filter holder and let any condensed water or liquid drain into 
the impingers or condenser. After wiping off the silicone grease, cap 
off the filter holder outlet and impinger inlet. Either ground-glass 
stoppers, plastic caps, or serum caps may be used to close these 
openings.
    Transfer the probe and filter-impinger assembly to the cleanup area. 
This area should be clean and protected from the wind so that the 
chances of contaminating or losing the sample will be minimized.
    Save a portion of the acetone used for cleanup as a blank. Take 200 
ml of this acetone directly from the wash bottle being used and place it 
in a glass sample container labeled ``acetone blank.''
    Inspect the train prior to and during disassembly and note any 
abnormal conditions. Treat the samples as follows:
    Container No. 1. Carefully remove the filter from the filter holder 
and place it in its identified petri dish container. Use a pair of 
tweezers and/or clean disposable surgical gloves to handle the filter. 
If it is necessary to fold the filter, do so such that the particulate 
cake is inside the fold. Carefully transfer to the petri dish any 
particulate matter and/or filter fibers which adhere to the filter 
holder gasket, by using a dry Nylon bristle brush and/or a sharp-edged 
blade. Seal the container.

[[Page 749]]

    Container No. 2. Taking care to see that dust on the outside of the 
probe or other exterior surfaces does not get into the sample, 
quantitatively recover particulate matter or any condensate from the 
probe nozzle, probe fitting, probe liner, and front half of the filter 
holder by washing these components with acetone and placing the wash in 
a glass container. Distilled water may be used instead of acetone when 
approved by the Administrator and shall be used when specified by the 
Administrator; in these cases, save a water blank and follow the 
Administrator's directions on analysis. Perform the acetone rinses as 
follows:
    Carefully remove the probe nozzle and clean the inside surface by 
rinsing with acetone from a wash bottle and brushing with a Nylon 
bristle brush. Brush until the acetone rinse shows no visible particles, 
after which make a final rinse of the inside surface with acetone.
    Brush and rinse the inside parts of the Swagelok fitting with 
acetone in a similar way until no visible particles remain.
    Rinse the probe liner with acetone by tilting and rotating the probe 
while squirting acetone into its upper end so that all inside surfaces 
will be wetted with acetone. Let the acetone drain from the lower end 
into the sample container. A funnel (glass or polyethylene) may be used 
to aid on transferring liquid washes to the container. Follow the 
acetone rinse with a probe brush. Hold the probe in an inclined 
position, squirt acetone into the upper end as the probe brush is being 
pushed with a twisting action through the probe; hold a sample container 
underneath the lower end of the probe, and catch any acetone and 
particulate matter which is brushed from the probe. Run the brush 
through the probe three times or more until no visible particulate 
matter is carried out with the acetone or until none remains in the 
probe liner on visual inspection. With stainless steel or other metal 
probes, run the brush through in the above prescribed manner at least 
six times since metal probes have small crevices in which particulate 
matter can be entrapped. Rinse the brush with acetone, and 
quantitatively collect these washings in the sample container. After the 
brushing, make a final acetone rinse of the probe as described above.
    It is recommended that two people clean the probe to minimize sample 
losses. Between sampling runs, keep brushes clean and protected from 
contaminations.
    After ensuring that all joints have been wiped clean of silicone 
grease, clean the inside of the front half of the filter holder by 
rubbing the surfaces with a Nylon bristle brush and rinsing with 
acetone. Rinse each surface three times or more if needed to remove 
visible particulate. Make a final rinse of the brush and filter holder. 
Carefully rinse out the glass cyclone, also (if applicable). After all 
acetone washings and particulate matter have been collected in the 
sample container, tighten the lid on the sample container so that 
acetone will not leak out when it is shipped to the laboratory. Mark the 
height of the fluid level to determine whether or not leakage occured 
during transport. Label the container to clearly identify its contents.
    Container No. 3. Note the color of the indicating silica gel to 
determine if it has been completely spent and make a notation of its 
condition. Transfer the silica gel from the fourth impinger to its 
original container and seal. A funnel may make it easier to pour the 
silica gel without spilling. A rubber policeman may be used as an aid in 
removing the silica gel from the impinger. It is not necessary to remove 
the small amount of dust particles that may adhere to the impinger wall 
and are difficult to remove. Since the gain in weight is to be used for 
moisture calculations, do not use any water or other liquids to transfer 
the silica gel. If a balance is available in the field, follow the 
procedure for container No. 3 in Section 4.3.
    Impinger Water. Treat the impingers as follows; Make a notation of 
any color or film in the liquid catch. Measure the liquid which is in 
the first three impingers to within plus-minus1 ml by using a 
graduated cylinder or by weighing it to within plus-minus0.5 
g by using a balance (if one is available). Record the volume or weight 
of liquid present. This information is required to calculate the 
moisture content of the effluent gas.
    Discard the liquid after measuring and recording the volume or 
weight, unless analysis of the impinger catch is required (see Note, 
Section 2.1.7).
    If a different type of condenser is used, measure the amount of 
moisture condensed either volumetrically or gravimetrically.
    Whenever possible, containers should be shipped in such a way that 
they remain upright at all times.
    4.3  Analysis. Record the data required on a sheet such as the one 
shown in Figure 5-3. Handle each sample container as follows:

                       Figure 5-3--Analytical Data

Plant___________________________________________________________________
Date____________________________________________________________________
Run No._________________________________________________________________
Filter No.______________________________________________________________
Amount liquid lost during transport_____________________________________
Acetone blank volume, ml________________________________________________
Acetone wash volume, ml_________________________________________________
Acetone blank concentration, mg/mg (Equation 5-4)_______________________
Acetone wash blank, mg (Equation 5-5)___________________________________

----------------------------------------------------------------------------------------------------------------
                                                          Weight of particulate collected, mg
           Container number           --------------------------------------------------------------------------
                                             Final weight             Tare weight              Weight gain
----------------------------------------------------------------------------------------------------------------
1....................................
----------------------------------------------------------------------------------------------------------------
 

[[Page 750]]

 
2....................................
----------------------------------------------------------------------------------------------------------------
 
  Total..............................
                                      --------------------------
 
    Less acetone blank...............
                                      --------------------------
    Weight of particulate matter.....
                                                                                        ------------------------


------------------------------------------------------------------------
                                     Volume of liquid water collected
                                 ---------------------------------------
                                   Impinger volume,   Silica gel weight,
                                          ml                   g
------------------------------------------------------------------------
Final...........................
Initial.........................
Liquid collected................
Total volume collected..........                        g*      ml
------------------------------------------------------------------------
*Convert weight of water to volume by dividing total weight increase by
  density of water (1 g/ml).

  [GRAPHIC] [TIFF OMITTED] TC16NO91.124
  
    Container No. 1. Leave the contents in the shipping container or 
transfer the filter and any loose particulate from the sample container 
to a tared glass weighing dish. Desiccate for 24 hours in a desiccator 
containing anhydrous calcium sulfate. Weigh to a constant weight and 
report the results to the nearest 0.1 mg. For purposes of this Section, 
4.3, the term ``constant weight'' means a difference of no more than 0.5 
mg or 1 percent of total weight less tare weight, whichever is greater, 
between two consecutive weighings, with no less than 6 hours of 
desiccation time between weighings.
    Alternatively, the sample may be oven dried at 105  deg.C (220 
deg.F) for 2 to 3 hours, cooled in the desiccator, and weighed to a 
constant weight, unless otherwise specified by the Administrator. The 
tester may also opt to oven dry the sample at 105  deg.C (220  deg.F) 
for 2 to 3 hours, weigh the sample, and use this weight as a final 
weight.
    Container No. 2. Note the level of liquid in the container and 
confirm on the analysis sheet whether or not leakage occurred during 
transport. If a noticeable amount of leakage has occurred, either void 
the sample or use methods, subject to the approval of the Administrator, 
to correct the final results. Measure the liquid in this container 
either volumetrically to plus-minus1 ml or gravimetrically to 
plus-minus0.5 g. Transfer the contents to a tared 250-ml 
beaker and evaporate to dryness at ambient temperature and pressure. 
Desiccate for 24 hours and weigh to a constant weight. Report the 
results to the nearest 0.1 mg.
    Container No. 3. Weigh the spent silica gel (or silica gel plus 
impinger) to the nearest 0.5 g using a balance. This step may be 
conducted in the field.
    ``Acetone Blank'' Container. Measure acetone in this container 
either volumetrically or gravimetrically. Transfer the acetone to a 
tared 250-ml beaker and evaporate to dryness at ambient temperature and 
pressure. Desiccate for 24 hours and weigh to a constant weight. Report 
the results to the nearest 0.1 mg.
    Note: At the option of the tester, the contents of Container No. 2 
as well as the acetone blank container may be evaporated at temperatures 
higher than ambient. If evaporation is done at an elevated temperature, 
the temperature must be below the boiling point of the solvent; also, to 
prevent ``bumping,'' the evaporation process must be closely supervised, 
and the contents of the beaker must be swirled occasionally to maintain 
an even temperature. Use extreme care, as acetone is highly flammable 
and has a low flash point.
    4.4  Quality Control Procedures. The following quality control 
procedures are suggested to check the volume metering system calibration 
values at the field test site prior to sample collection. These 
procedures are optional for the tester.
    4.4.1  Meter Orifice Check. Using the calibration data obtained 
during the calibration procedure described in Section 5.3, determine the 
 H@ for the metering system orifice. The  H@ is the 
orifice pressure differential in units of in. H2O that 
correlates to 0.75 cfm of air at 528 deg. R and 29.92 in. Hg. The 
 H@ is calculated as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.125

Where:

H=Average pressure differential across the orifice meter, in. 
          H2O.
Tm=Absolute average dry gas meter temperature,  deg. R.
Pbar=Barometric pressure, in. Hg.
=Total sampling time, min.
Y=Dry gas meter calibration factor, dimensionless.
Vm=Volume of gas sample as measured by dry gas meter, dcf.
0.0319=(0.0567 in. Hg/ deg. R) x (0.75 cfm)2.

Before beginning the field test (a set of three runs usually constitutes 
a field test), operate the metering system (i.e., pump, volume meter, 
and orifice) at the  H@ pressure differential for 10 minutes. 
Record the volume collected, the dry gas meter temperature, and the 
barometric pressure. Calculate a dry gas meter calibration check value, 
Yc, as follows:

[[Page 751]]

[GRAPHIC] [TIFF OMITTED] TN30AU93.032

                                                                Eq. 5-10
Where:

Yc=Dry gas meter calibration check value, dimensionless.
10=10 minutes of run time.

Compare the Yc value with the dry gas meter calibration 
factor Y to determine that:

0.97Y< Yc<1.03Y

If the Yc value is not within this range, the volume metering 
system should be investigated before beginning the test.
    4.4.2  Calibrated Critical Orifice. A calibrated critical orifice, 
calibrated against a wet test meter or spirometer and designed to be 
inserted at the inlet of the sampling meter box may be used as a quality 
control check by following the procedure of Section 7.2.

5. Calibration

    Maintain a laboratory log of all calibrations.
    5.1  Probe Nozzle. Probe nozzles shall be calibrated before their 
initial use in the field. Using a micrometer, measure the inside 
diameter of the nozzle to the nearest 0.025 mm (0.001 in.). Make three 
separate measurements using different diameters each time, and obtain 
the average of the measurements. The difference between the high and low 
numbers shall not exceed 0.1 mm (0.004 in.). When nozzles become nicked, 
dented, or corroded, they shall be reshaped, sharpened, and recalibrated 
before use. Each nozzle shall be permanently and uniquely identified.
    5.2  Pitot Tube. The Type S pitot tube assembly shall be calibrated 
according to the procedure outlined in Section 4 of Method 2.
    5.3  Metering System.
    5.3.1  Calibration Prior to Use. Before its initial use in the 
field, the metering system shall be calibrated as follows: Connect the 
metering system inlet to the outlet of a wet test meter that is accurate 
to within 1 percent. Refer to Figure 5.5. The wet test meter should have 
a capacity of 30 liters/rev (1 ft\3\/rev). A spirometer of 400 liters 
(14 ft\3\) or more capacity, or equivalent, may be used for this 
calibration, although a wet test meter is usually more practical. The 
wet test meter should be periodically calibrated with a spirometer or a 
liquid displacement meter to ensure the accuracy of the wet test meter. 
Spirometers or wet test meters of other sizes may be used, provided that 
the specified accuracies of the procedure are maintained. Run the 
metering system pump for about 15 minutes with the orifice manometer 
indicating a median reading as expected in field use to allow the pump 
to warm up and to permit the interior surface of the wet test meter to 
be thoroughly wetted. Then, at each of a minimum of three orifice 
manometer settings, pass an exact quantity of gas through the wet test 
meter and note the gas volume indicated by the dry gas meter. Also note 
the barometric pressure, and the temperatures of the wet test meter, the 
inlet of the dry gas meter, and the outlet of the dry gas meter. Select 
the highest and lowest orifice settings to bracket the expected field 
operating range of the orifice. Use a minimum volume of 0.15 m\3\ (5 cf) 
at all orifice settings. Record all the data on a form similar to Figure 
5.6, and calculate Y, the dry gas meter calibration factor, and 
H@, the orifice calibration factor, at each orifice setting as 
shown on Figure 5.6. Allowable tolerances for individual Y and 
H@, values are given in Figure 5.6. Use the average of the Y 
values in the calculations in Section 6.

[[Page 752]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.102


[[Page 753]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.103

    Before calibrating the metering system, it is suggested that a leak-
check be conducted. For metering systems having diaphragm pumps, the 
normal leak-check procedure will not detect leakages within the pump. 
For these cases the following leak-check procedure is suggested: make a 
10-minute calibration run at 0.00057m\3\/min (0.02 cfm); at the end of 
the run, take the difference of the measured wet test meter and dry gas 
meter volumes; divide the difference by 10, to get the leak rate. The 
leak rate should not exceed 0.00057 m\3\/min (0.02 cfm).

[[Page 754]]

    5.3.2  Calibration After Use. After each field use, the calibration 
of the metering system shall be checked by performing three calibration 
runs at a single, intermediate orifice setting (based on the previous 
field test), with the vacuum set at the maximum value reached during the 
test series. To adjust the vacuum, insert a valve between the wet test 
meter and the inlet of the metering system. Calculate the average value 
of the dry gas meter calibration factor. If the value has changed by 
more than 5 percent, recalibrate the meter over the full range of 
orifice settings, as previously detailed.
    Alternative procedures, e.g., rechecking the orifice meter 
coefficient may be used, subject to the approval of the Administrator.
    5.3.3  Acceptable Variation in Calibration. If the dry gas meter 
coefficient values obtained before and after a test series differ by 
more than 5 percent, the test series shall either be voided, or 
calculations for the test series shall be performed using whichever 
meter coefficient value (i.e., before or after) gives the lower value of 
total sample volume.
    5.4  Probe Heater Calibration. The probe heating system shall be 
calibrated before its initial use in the field.
    Use a heat source to generate air heated to selected temperatures 
that approximate those expected to occur in the sources to be sampled. 
Pass this air through the probe at a typical simple flow rate while 
measuring the probe inlet and outlet temperatures at various probe 
heater settings. For each air temperature generated, construct a graph 
of probe heating system setting versus probe outlet temperature. The 
procedure outlined in APTD-0576 can also be used. Probes constructed 
according to APTD-0581 need not be calibrated if the calibration curves 
in APTD-0576 are used. Also, probes with outlet temperature monitoring 
capabilities do not require calibration.
    5.5  Temperature Gauges. Use the procedure in Section 4.3 of Method 
2 to calibrate in-stack temperature gauges. Dial thermometers, such as 
are used for the dry gas meter and condenser outlet, shall be calibrated 
against mercury-in-glass thermometers.
    5.6  Leak Check of Metering System Shown in Figure 5-1. That portion 
of the sampling train from the pump to the orifice meter should be leak 
checked prior to initial use and after each shipment. Leakage after the 
pump will result in less volume being recorded than is actually sampled. 
The following procedure is suggested (see Figure 5-4): Close the main 
valve on the meter box. Insert a one-hole rubber stopper with rubber 
tubing attached into the orifice exhaust pipe. Disconnect and vent the 
low side of the orifice manometer. Close off the low side orifice tap. 
Pressurize the system to 13 to 18 cm (5 to 7 in.) water column by 
blowing into the rubber tubing. Pinch off the tubing and observe the 
manometer for one minute. A loss of pressure on the manometer indicates 
a leak in the meter box; leaks, if present, must be corrected.
    5.7  Barometer. Calibrate against a mercury barometer.

6. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after the final 
calculation. Other forms of the equations may be used as long as they 
give equivalent results.

[[Page 755]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.104

    6.1 Nomenclature.

An=Cross-sectional area of nozzle, 
          m2(ft2).
Bws=Water vapor in the gas stream, proportion by volume.
Ca=Acetone blank residue concentration, mg/mg.

[[Page 756]]

cs=Concentration of particulate matter in stack gas, dry 
          basis, corrected to standard conditions, g/dscm (g/dscf).
I=Percent of isokinetic sampling.
La=Maximum acceptable leakage rate for either a pretest leak 
          check or for a leak check following a component change; equal 
          to 0.00057 m3/min (0.02 cfm) or 4 percent of the 
          average sampling rate, whichever is less.
Li=Individual leakage rate observed during the leak check 
          conducted prior to the ``ith'' component change 
          (i=1, 2, 3....n), m3/min (cfm).
Lp=Leakage rate observed during the post-test leak check, 
          m3/min (cfm).
ma=Mass of residue of acetone after evaporation, mg.
mn=Total amount of particulate matter collected, mg.
Mw=Molecular weight of water, 18.0 g/g-mole (18.0lb/lb-mole).
Pbar=Barometric pressure at the sampling site, mm Hg (in. 
          Hg).
Ps=Absolute stack gas pressure, mm Hg (in. Hg).
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
R=Ideal gas constant, 0.06236 mm Hg-m3/ deg.K-g-mole (21.85 
          in. Hg-ft3/ deg.R-lb-mole).
Tm=Absolute average dry gas meter temperature (see Figure 5-
          2),  deg.K ( deg.R).
Ts=Absolute average stack gas temperature (see Figure 5-2), 
          deg.K ( deg.R).
Tstd=Standard absolute temperature, 293 deg.K (528 deg. R).
Va=Volume of acetone blank, ml.
Vaw=Volume of acetone used in wash, ml.
Vlc=Total volume of liquid collected in impingers and silica 
          gel (see Figure 5-3), ml.
Vm=Volume of gas sample as measured by dry gas meter, dcm 
          (dscf).
Vm(std)=Volume of gas sample measured by the dry gas meter, 
          corrected to standard conditions, dscm (dscf).
Vw(std)=Volume of water vapor in the gas sample, corrected to 
          standard conditions, scm (scf).
vs=Stack gas velocity, calculated by Method 2, Equation 2-9, 
          using data obtained from Method 5, m/sec (ft/sec).
Wa=Weight of residue in acetone wash, mg.
Y=Dry gas meter calibration factor.
H=Average pressure differential across the orifice meter (see 
          Figure 5-2), mm H2O (in. H2O).
a=Density of acetone, mg/ml (see label on bottle).
w=Density of water, 0.9982 g/ml (0.002201 lb/ml).
1=Sampling time interval, from the beginning of a run 
          until the first component change, min.
i=Sampling time interval, between two successive 
          component changes, beginning with the interval between the 
          first and second changes, min.
p=Sampling time interval, from the final 
          (nth) component change until the end of the 
          sampling run, min.
13.6=Specific gravity of mercury.
60=Sec/min.
100=Conversion to percent.
    6.2  Average Dry Gas Meter Temperature and Average Orifice Pressure 
Drop. See data sheet (Figure 5-2).
    6.3  Dry Gas Volume. Correct the sample volume measured by the dry 
gas meter to standard conditions (20  deg.C, 760 mm Hg or 68  deg.F, 
29.92 in. Hg) by using Equation 5-1.
[GRAPHIC] [TIFF OMITTED] TC01JN92.105

Where;
K1=0.3858  deg.K/mm Hg for metric units
  =17.64  deg.R/in. Hg for English units
    Note: Equation 5-1 can be used as written unless the leakage rate 
observed during any of the mandatory leak checks (i.e., the post-test 
leak check or leak checks conducted prior to component changes) exceeds 
La. If Lp or i exceeds La, 
Equation 5-1 must be modified as follows:
    (a) Case I. No component changes made during sampling run. In this 
case, replace Vm in Equation 5-1 with the expression:

[Vm--(Lp--La)]

    (b) Case II. One or more component changes made during the sampling 
run. In this case, replace Vm in Equation 5-1 by the 
expression:
[GRAPHIC] [TIFF OMITTED] TC01JN92.106

and substitute only for those leakage rates (Li or 
Lp) which exceed La.
    6.4  Volume of Water Vapor.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.107
    
Where:
K2=0.001333 m3/ml for metric units
  =0.04707 ft3/ml for English units.

6.5 Moisture Content.

[[Page 757]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.126

    Note: In saturated or water droplet-laden gas streams, two 
calculations of the moisture content of the stack gas shall be made, one 
from the impinger analysis (Equation 5-3), and a second from the 
assumption of saturated conditions. The lower of the two values of 
Bws shall be considered correct. The procedure for 
determining the moisture content based upon assumption of saturated 
conditions is given in the Note of Section 1.2 of Method 4. For the 
purposes of this method, the average stack gas temperature from Figure 
5-2 may be used to make this determination, provided that the accuracy 
of the in-stack temperature sensor is plus-minus1  deg.C (2 
deg.F).
    6.6  Acetone Blank Concentration.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.127
    
    6.7 Acetone Wash Blank.

    [GRAPHIC] [TIFF OMITTED] TC16NO91.128
    
    6.8  Total Particulate Weight. Determine the total particulate catch 
from the sum of the weights obtained from Containers 1 and 2 less the 
acetone blank (see Figure 5-3).
    Note: Refer to Section 4.1.5 to assist in calculation of results 
involving two or more filter assemblies or two or more sampling trains.
    6.9  Particulate Concentration.
cs=(0.001 g/mg) (mn/Vm(std))
                                                                 Eq. 5-6
    6.10  Conversion Factors:

------------------------------------------------------------------------
              From                       To              Multiply by
------------------------------------------------------------------------
scf............................  m3................  0.02832.
g..............................  mg................  0.001
g/ft3..........................  gr/ft3............  15.43.
g/ft3..........................  lb/ft3............  2.205 x 10-3.
g/ft3..........................  g/m3..............  35.31.
------------------------------------------------------------------------

    6.11 Isokinetic Variation.
    6.11.1 Calculation From Raw Data.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.129
    
Where:

K3=0.003454 mm Hg-m3/ml- deg.K for metric units.
   =0.002669-in. Hg-ft3/ml- deg.R for English units.
    6.11.2  Calculation From Intermediate Values.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.108
    
Where:

K4=4.320 for metric units
   =0.09450 for English units.
    6.12  Acceptable Results. If 90 percent  I  
110 percent, the results are acceptable. If the particulate results are 
low in comparison to the standard, and I is over 110 percent or less 
than 90 percent, the Administrator may accept the results. Citation 4 in 
the bibliography section can be used to make acceptability judgments. If 
I is judged to be unacceptable, reject the particulate results and 
repeat the test.
    6.13  Stack Gas Velocity and Volumetric Flow Rate. Calculate the 
average stack gas velocity and volumetric flow rate, if needed, using 
data obtained in this method and the equations in Sections 5.2 and 5.3 
of Method 2.

7. Alternative Procedures
    7.1  Dry Gas Meter as a Calibration Standard. A dry gas meter may be 
used as a calibration standard for volume measurements in place of the 
wet test meter specified in Section 5.3, provided that it is calibrated 
initially and recalibrated periodically as follows:
    7.1.1  Standard Dry Gas Meter Calibration.
    7.1.1.1  The dry gas meter to be calibrated and used as a secondary 
reference meter should be of high quality and have an appropriately 
sized capacity, e.g., 3 liters/rev (0.1 ft \3\/rev). A spirometer (400 
liters or more capacity), or equivalent, may be used for this 
calibration, although a wet test meter is usually more practical. The 
wet test meter should have a capacity of 30 liters/rev      (1 ft \3\/
rev) and capable of measuring volume to within 1.0 percent; 
wet test meters should be checked against a spirometer or a liquid 
displacement meter to ensure the accuracy of the wet test meter. 
Spirometers or wet test meters of other sizes may be used, provided that 
the specified accuracies of the procedure are maintained.
    7.1.1.2  Set up the components as shown in Figure 5.7. A spirometer, 
or equivalent, may

[[Page 758]]

be used in place of the wet test meter in the system. Run the pump for 
at least 5 minutes at a flow rate of about 10 liters/min (0.35 cfm) to 
condition the interior surface of the wet test meter. The pressure drop 
indicated by the manometer at the inlet side of the dry gas meter should 
be minimized [no greater than 100 mm H2O (4 in. 
H2O) at a flow rate of 30 liters/min (1 cfm)]. This can be 
accomplished by using large diameter tubing connections and straight 
pipe fittings.
[GRAPHIC] [TIFF OMITTED] TC01JN92.109

    7.1.1.3  Collect the data as shown in the example data sheet (see 
Figure 5-8). Make triplicate runs at each of the flow rates and at no 
less than five different flow rates. The range of flow rates should be 
between 10 and 34 liters/min (0.35 and 1.2 cfm) or over the expected 
operating range.

[[Page 759]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.110

    7.1.1.4  Calculate flow rate, Q, for each run using the wet test 
meter gas volume, Vw, and the run time, . Calculate 
the dry gas meter coefficient, Yds, for each run. These 
calculations are as follows:
  

[[Page 760]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.130

Where:

Kl=0.3858 for international system of units (SI); 17.64 for 
          English units.
Vw=Wet test meter volume, liters (ft 3).
Vds=Dry gas meter volume, liters (ft 3).
tds=Average dry gas meter temperature,  deg. C ( deg. F).
tstd=273 deg. C for SI units; 460 deg. F for English units.
tw=Average wet test meter temperature,  deg. C ( deg. F).
Pbar=Barometric pressure, mm Hg (in. Hg).
p=Dry gas meter inlet differential pressure, mm H2O 
          (in. H2O).
=Run time, min.
    7.1.1.5  Compare the three Yds values at each of the flow 
rates and determine the maximum and minimum values. The difference 
between the maximum and minimum values at each flow rate should be no 
greater than 0.030. Extra sets of triplicate runs may be made in order 
to complete this requirement. In addition, the meter coefficients should 
be between 0.95 and 1.05. If these specifications cannot be met in three 
sets of successive triplicate runs, the meter is not suitable as a 
calibration standard and should not be used as such. If these 
specifications are met, average the three Yds values at each 
flow rate resulting in five average meter coefficients, Yds.
    7.1.1.6  Prepare a curve of meter coefficient, Yds, 
versus flow rate, Q, for the dry gas meter. This curve shall be used as 
a reference when the meter is used to calibrate other dry gas meters and 
to determine whether recalibration is required.
    7.1.2  Standard Dry Gas Meter Recalibration.
    7.1.2.1  Recalibrate the standard dry gas meter against a wet test 
meter or spirometer annually or after every 200 hours of operation, 
whichever comes first. This requirement is valid provided the standard 
dry gas meter is kept in a laboratory and, if transported, cared for as 
any other laboratory instrument. Abuse to the standard meter may cause a 
change in the calibration and will require more frequent recalibrations.
    7.1.2.2  As an alternative to full recalibration, a two-point 
calibration check may be made. Follow the same procedure and equipment 
arrangement as for a full recalibration, but run the meter at only two 
flow rates [suggested rates are 14 and 28 liters/min (0.5 and 1.0 cfm)]. 
Calculate the meter coefficients for these two points, and compare the 
values with the meter calibration curve. If the two coefficients are 
within 1.5 percent of the calibration curve values at the 
same flow rates, the meter need not be recalibrated until the next date 
for a recalibration check.
    7.2  Critical Orifices As Calibration Standards. Critical orifices 
may be used as calibration standards in place of the wet test meter 
specified in Section 5.3, provided that they are selected, calibrated, 
and used as follows:
    7.2.1  Section of Critical Orifices.
    7.2.1.1  The procedure that follows describes the use of hypodermic 
needles or stainless steel needle tubings which have been found suitable 
for use as critical orifices. Other materials and critical orifice 
designs may be used provided the orifices act as true critical orifices; 
i.e., a critical vacuum can be obtained, as described in Section 
7.2.2.2.3. Select five critical orifices that are appropriately sized to 
cover the range of flow rates between 10 and 34 liters/min or the 
expected operating range. Two of the critical orifices should bracket 
the expected operating range.
    A minimum of three critical orifices will be needed to calibrate a 
Method 5 dry gas meter (DGM); the other two critical orifices can serve 
as spares and provide better selection for bracketing the range of 
operating flow rates. The needle sizes and tubing lengths shown below 
give the following approximate flow rates:

------------------------------------------------------------------------
                   Flow rate (liters/                       Flow rate
     Gauge/cm             min)            Gauge/cm        (liters/min)
------------------------------------------------------------------------
       12/7.6              32.56             14/2.5             19.54
      12/10.2              30.02             14/5.1             17.27
       13/2.5              25.77             14/7.6             16.14
       13/5.1              23.50             15/3.2             14.16
       13/7.6              22.37             15/7.6             11.61
      13/10.2              20.67            15/10.2             10.48
------------------------------------------------------------------------

    7.2.1.2  These needles can be adapted to a Method 5 type sampling 
train as follows: Insert a serum bottle stopper, 13- by 20-mm sleeve 
type, into a \1/2\-inch Swagelok quick connect. Insert the needle into 
the stopper as shown in Figure 5-9.

[[Page 761]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.111

    7.2.2  Critical Orifice Calibration. The procedure described in this 
section uses the Method 5 meter box configuration with a DGM as 
described in Section 2.1.8 to calibrate the critical orifices. Other 
schemes may be used, subject to the approval of the Administrator.
    7.2.2.1  Calibration of Meter Box. The critical orifices must be 
calibrated in the same configuration as they will be used; i.e., there 
should be no connections to the inlet of the orifice.
    7.2.2.1.1  Before calibrating the meter box, leak check the system 
as follows: Fully open the coarse adjust valve, and completely close the 
by-pass valve. Plug the inlet. Then trun on the pump, and determine 
whether there is any leakage. The leakage rate shall be zero; i.e., no 
detectable movement of the DGM dial shall be seen for 1 minute.
    7.2.2.1.2  Check also for leakages in that portion of the sampling 
train between the pump and the orifice meter. See Section 5.6 for the 
procedure; make any corrections, if necessary. If leakage is detected, 
check for cracked gaskets, loose fittings, worn O-rings, etc., and make 
the necessary repairs.
    7.2.2.1.3  After determining that the meter box is leakless, 
calibrate the meter box according to the procedure given in Section 5.3. 
Make sure that the wet test meter meets the requirements stated in 
Section 7.1.1.1. Check the water level in the wet test meter. Record the 
DGM calibration factor, Y.
    7.2.2.2  Calibration of Critical Orifices. Set up the apparatus as 
shown in Figure 5-10.

[[Page 762]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.112

    7.2.2.2.1  Allow a warm-up time of 15 minutes. This step is 
important to equilibrate the temperature conditions through the DGM.
    7.2.2.2.2  Leak check the system as in Section 7.2.2.1.1. The 
leakage rate shall be zero.
    7.2.2.2.3  Before calibrating the critical orifice, determine its 
suitability and the appropriate operating vacuum as follows: Turn on the 
pump, fully open the coarse adjust valve, and adjust the by-pass valve 
to give a vacuum reading corresponding to about half of atmospheric 
pressure. Observe the meter box orifice manometer reading, H. Slowly 
increase the vacuum reading until a stable reading is obtained on the 
meter box orifice manometer. Record the critical vacuum for each 
orifice.
    Orifices that do not reach a critical value shall not be used.
    7.2.2.2.4  Obtain the barometric pressure using a barometer as 
described in Section 2.1.9. Record the barometric pressure, 
Pbar, in mm Hg (in. Hg).
    7.2.2.2.5  Conduct duplicate runs at a vacuum of 25 to 50 mm Hg (1 
to 2 in. Hg) above the critical vacuum. The runs shall be at least 5 
minutes each. The DGM volume readings shall be in increments of 0.00283 
m3 (0.1 ft3) or in increments of complete 
revolutions of the DGM. As a guideline, the times should not differ by 
more than 3.0 seconds (this includes allowance for changes in the DGM 
temperatures) to achieve  0.5 percent in K'. Record the 
information listed in Figure 5-11.
    7.2.2.2.6  Calculate K' using Equation 5-9.

[[Page 763]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.131

Where:
[GRAPHIC] [TIFF OMITTED] TC16NO91.132

Tamb=Absolute ambient temperature,  deg.K ( deg.R).
    Average the K' values. The individual K' values should not differ by 
more than 0.5 percent from the average.
    7.2.3  Using the Critical Orifices as Calibration Standards.
    7.2.3.1  Record the barometric pressure.
Date ________ Train ID ________ DGM cal. factor ________ Critical 
orifice ID ________

------------------------------------------------------------------------
                                                           Run number
          Dry gas meter                                -----------------
                                                           1        2
------------------------------------------------------------------------
Final reading....................  m3 (ft3)...........  .......  .......
Initial reading..................  m3 (ft3)...........  .......  .......
Difference, Vm...................  m3 (ft3)...........  .......  .......
Inlet/Outlet temperatures:
  Initial........................    deg.C (  deg.F)..     /        /
  Final..........................    deg.C (  deg.F)..     /        /
  Avg. Temperature, tm...........    deg.C (  deg.F)..  .......  .......
Time, ..................  min/sec............     /        /
                                   min................  .......  .......
Orifice man. rdg., H...  mm (in.) H2O.......  .......  .......
Bar. pressure, Pbar..............  mm (in.) Hg........  .......  .......
Ambient temperature, tamb........    deg.C (  deg.F)..  .......  .......
Pump vacuum......................  mm (in.) Hg........  .......  .......
K' factor........................  ...................  .......  .......
    Average......................  ...................  .......  .......
------------------------------------------------------------------------

    Figure 5-11. Data sheet for determining K' factor.
    7.2.3.2  Calibrate the metering system according to the procedure 
outlined in Sections 7.2.2.2.1 to 7.2.2.2.5. Record the information 
listed in Figure 5.12.
    7.2.3.3  Calculate the standard volumes of air passed through the 
DGM and the critical orifices, and calculate the DGM calibration factor, 
Y, using the equations below:
[GRAPHIC] [TIFF OMITTED] TC16NO91.133

[GRAPHIC] [TIFF OMITTED] TC16NO91.249

[GRAPHIC] [TIFF OMITTED] TC16NO91.250

where:
Vcr(std)=Volume of gas sample passed through the critical 
          orifice, corrected to standard conditions, dsm3 
          (dscf).
K1=0.3858  deg.K/mm Hg for metric units
     =17.64  deg.R/in. Hg for English units.

    7.2.3.4  Average the DGM calibration values for each of the flow 
rates. The calibration factor, Y, at each of the flow rates should not 
differ by more than 2 percent from the average.
    7.2.3.5  To determine the need for recalibrating the critical 
orifices, compare the DGM Y factors obtained from two adjacent orifices 
each time a DGM is calibrated; for example, when checking 13/2.5, use 
orifices 12/10.2 and 13/5.1. If any critical orifice yields a DGM Y 
factor differing by more than 2 percent from the others, recalibrate the 
critical orifice according to Section 7.2.2.2.
Date ________ Train ID ________ Critical orifice ID ________ Critical 
orifice K' factor ________

[[Page 764]]


------------------------------------------------------------------------
                                                            Run number
            Dry gas meter                                ---------------
                                                             1       2
------------------------------------------------------------------------
Final reading.......................  m3 (ft3)..........  ......  ......
Initial reading.....................  m3 (ft3)..........  ......  ......
Difference, Vm......................  m3 (ft3)..........  ......  ......
Inlet/outlet temperatures:
  Initial...........................    deg.C (  deg.F).       /       /
 
  Final.............................    deg.C (  deg.F).       /       /
 
  Avg. Temperature, tm..............    deg.C (  deg.F).  ......  ......
Time, .....................  min/sec...........       /       /
 
                                      min...............  ......  ......
Orifice man. rdg., H......  mm (in.) H2O......  ......  ......
Bar. pressure, Pbar.................  mm (in.) Hg.......  ......  ......
Ambient temperature, tamb...........    deg.C (  deg.F).  ......  ......
Pump vacuum.........................  mm (in.) Hg.......  ......  ......
Vm(std).............................  m3 (ft3)..........  ......  ......
Vcr(std)............................  m3 (ft3)..........  ......  ......
DGM cal. factor, Y..................  ..................  ......  ......
------------------------------------------------------------------------

    Figure 5-12. Data sheet for determining DGM Y factor.

8. Bibliography

    1. Addendum to Specifications for Incinerator Testing at Federal 
Facilities. PHS, NCAPC. Dec. 6, 1967.
    2. Martin, Robert M. Construction Details of Isokinetic Source-
Sampling Equipment. Environmental Protection Agency. Research Triangle 
Park, NC. APTD-0581. April 1971.
    3. Rom, Jerome J. Maintenance, Calibration, and Operation of 
Isokinetic Source Sampling Equipment. Environmental Protection Agency. 
Research Triangle Park, NC. APTD-0576. March, 1972.
    4. Smith, W. S., R. T. Shigehara, and W. F. Todd. A Method of 
Interpreting Stack Sampling Data. Paper Presented at the 63d Annual 
Meeting of the Air Pollution Control Association, St. Louis, MO, June 
14-19, 1970.
    5. Smith, W. S., et al. Stack Gas Sampling Improved and Simplified 
With New Equipment. APCA Paper No. 67-119. 1967.
    6. Specifications for Incinerator Testing at Federal Facilities. 
PHS, NCAPC. 1967.
    7. Shigehara, R. T. Adjustments in the EPA Nomograph for Different 
Pitot Tube Coefficients and Dry Molecular Weights. Stack Sampling News 
2:4-11, October, 1974.
    8. Vollaro, R. F. A Survey of Commercially Available Instrumentation 
For the Measurement of Low-Range Gas Velocities. U.S. Environmental 
Protection Agency, Emission Measurement Branch. Research Triangle Park, 
NC. November, 1976 (unpublished paper).
    9. Annual Book of ASTM Standards. Part 26. Gaseous Fuels; Coal and 
Coke; Atmospheric Analysis. American Society for Testing and Materials. 
Philadelphia, PA. 1974. pp. 617-622.
    10. Felix, L. G., G. I. Clinard, G. E. Lacey, and J. D. McCain. 
Inertial Cascade Impactor Substrate Media for Flue Gas Sampling. U.S. 
Environmental Protection Agency. Research Triangle Park, NC 27711, 
Publication No. EPA-600/7-77-060. June 1977. 83 p.
    11. Westlin, P. R. and R. T. Shigehara. Procedure for Calibrating 
and Using Dry Gas Volume Meters as Calibration Standards. Source 
Evaluation Society Newsletter. 3(1):17-30. February 1978.
    12. Lodge, J.P., Jr., J.B. Pate, B.E. Ammons, and G.A. Swanson. The 
Use of Hypodermic Needles as Critical Orifices in Air Sampling. J. Air 
Pollution Control Association. 16:197-200. 1966.

   Method 5A--Determination of Particulate Emissions from the Asphalt 
                 Processing and Asphalt Roofing Industry

1. Applicability and Principle

    1.1  Applicability. This method applies to the determination of 
particulate emissions from asphalt roofing industry process saturators, 
blowing stills, and other sources as specified in the regulations.
    1.2  Principle. Particulate matter is withdrawn isokinetically from 
the source and collected on a glass filter fiber maintained at a 
temperature of 42 deg.plus-minus10  deg.C 
(108 deg.plus-minus18  deg.F). The particulate mass, which 
includes any material that condenses at or above the filtration 
temperature, is determined gravimetrically after removal of uncombined 
water.

2. Apparatus

    2.1  Sampling Train. The sampling train configuration is the same as 
shown in Figure 5-1 of Method 5. The sampling train consists of the 
following components:
    2.1.1  Probe Nozzle, Pitot Tube, Differential Pressure Gauge, Filter 
Holder, Condenser, Metering System, Barometer, and Gas Density 
Determination Equipment. Same as Method 5, Sections 2.1.1, 2.1.3 to 
2.1.5, and 2.1.7 to 2.1.10, respectively.
    2.1.2  Probe Liner. Same as in Method 5, Section 2.1.2, with the 
note that at high stack gas temperatures (greater than 250  deg.C (480 
deg.F)), water-cooled probes may be required to control the probe exit 
temperature to 42 deg.plus-minus10  deg.C 
(108plus-minus18  deg.F).
    2.1.3  Precollector Cyclone. Borosilicate glass following the 
construction details shown in Air Pollution Technical Document-0581, 
``Construction Details of Isokinetic Source-Sampling Equipment''.
    Note: The tester shall use the cyclone when the stack gas moisture 
is greater than 10 percent. The tester shall not use the precollector 
cyclone under other, less severe conditions.
    2.1.4  Filter Heating System. Any heating (or cooling) system 
capable of maintaining a sample gas temperature at the exit end of the 
filter holder during sampling at 42 deg.10 deg. C 
(108 deg.18 deg. F). Install a temperature gauge capable of 
measuring temperature within 3 deg. C (5.4 deg. F) at the exit side of 
the filter holder so that the sensing tip of the temperature

[[Page 765]]

gauge is in direct contact with the sample gas, and the sample gas 
temperature can be regulated and monitored during sampling. The 
temperature gauge shall comply with the calibration specifications 
defined in Section 5. The tester may use systems other than the one 
shown in APTD-0581.
    2.2  Sample Recovery. The equipment required for sample recovery is 
as follows:
    2.2.1  Probe-Liner and Probe-Nozzle Brushes, Graduated Cylinder and/
or Balance, Plastic Storage Containers, and Funnel and Rubber Policeman. 
Same as Method 5, Sections 2.2.1, 2.2.5, 2.2.6, and 2.2.7, respectively.
    2.2.2  Wash Bottles. Glass.
    2.2.3  Sample Storage Containers. Chemically resistant, borosilicate 
glass bottles, with rubber-backed Teflon screw cap liners or caps that 
are constructed so as to be leak-free and resistant to chemical attack 
by 1,1,1-trichloroethane (TCE), 500-ml or 1000-ml. (Narrow mouth glass 
bottles have been found to be less prone to leakage.)
    2.2.4  Petri Dishes. Glass, unless otherwise specified by the 
Administrator.
    2.2.5  Funnel. Glass.
    2.3  Analysis. For analysis, the following equipment is needed:
    2.3.1  Glass Weighing Dishes, Desiccator, Analytical Balance, 
Balance, Hygrometer, and Temperature Gauge. Same as Method 5, Sections 
2.3.1 to 2.3.4, 2.3.6, and 2.3.7, respectively.
    2.3.2  Beakers. Glass, 250-ml and 500-ml.
    2.3.3  Separatory Funnel. 100-ml or greater.

3.  Reagents

    3.1  Sampling. The reagents used in sampling are as follows:
    3.1.1.  Filters, Silica Gel, and Crushed Ice. Same as Method 5, 
Sections 3.1.1, 3.1.2, and 3.1.4, respectively.
    3.1.2  Stopcock Grease. TCE-insoluble, heat-stable grease (if 
needed). This is not necessary if screw-on connectors with Teflon 
sleeves, or similar, are used.
    3.2  Sample Recovery. Reagent grade 1,1,1-trichloroethane (TCE), 
0.001 percent residue and stored in glass bottles, is 
required. Run TCE blanks prior to field use and use only TCE with low 
blank values (0.001 percent). The tester shall in no case 
subtract a blank value of greater than 0.001 percent of the weight of 
TCE used from the sample weight.
    3.3  Analysis. Two reagents are required for the analysis:
    3.3.1  TCE. Same as 3.2.
    3.3.2  Desiccant. Same as Method 5, Section 3.3.2.

4.  Procedure

    4.1  Sampling Train Operation. The complexity of this method is such 
that in order to obtain reliable results, testers should be trained and 
experienced with Method 5 test procedures.
    4.1.1  Pretest Preparation. Unless otherwise specified, maintain and 
calibrate all components according to the procedure described in Air 
Pollution Technical Document-0576, ``Maintenance, Calibration, and 
Operation of Isokinetic Source-Sampling Equipment''.
    Prepare probe liners and sampling nozzles as needed for use. 
Thoroughly clean each component with soap and water followed by a 
minimum of three TCE rinses. Use the probe and nozzle brushes during at 
least one of the TCE rinses (refer to Section 4.2 for rinsing 
techniques). Cap or seal the open ends of the probe liners and nozzles 
to prevent contamination during shipping.
    Prepare silica gel portions and glass filters as specified in Method 
5, Section 4.1.1.
    4.1.2  Preliminary Determinations. Select the sampling site, probe 
nozzle, and probe length as specified in Method 5, Section 4.1.2.
    Select a total sampling time greater than or equal to the minimum 
total sampling time specified in the test procedures section of the 
applicable regulation. Follow the guidelines outlined in Method 5, 
Section 4.1.2, for sampling time per point and total sample volume 
collected.
    4.1.3  Preparation of Collection Train. Prepare the collection train 
as specified in Method 5, Section 4.1.3, with the addition of the 
following:
    Set up the sampling train as shown in Figure 5-1 of Method 5 with 
the addition of the precollector cyclone, if used, between the probe and 
filter holder. The temperature of the precollector cyclone, if used, 
should be about the same as for the filter, i.e., 
42 deg.plus-minus10  deg.C (108 deg.plus-minus18 
deg.F). Use no stopcock grease on ground glass joints unless the grease 
is insoluble in TCE.
    4.1.4  Leak Check Procedures. Follow the procedures given in Method 
5, Sections 4.1.4.1 (Pretest Leak Check), 4.1.4.2 (Leak Check During 
Sample Run), and 4.1.4.3 (Post-Test Leak Check).
    4.1.5  Particulate Train Operation. Operate the sampling train as 
described in Method 5, Section 4.1.5, except maintain the gas 
temperature exiting the filter at 42 deg.plus-minus10  deg.C 
(108 deg.plus-minus18  deg.F).
    4.1.6  Calculation of Percent Isokinetic. Same as in Method 5, 
Section 4.1.6.
    4.2  Sample Recovery. Using the procedures and techniques described 
in Method 5, Section 4.2, quantitatively recover any particulate matter 
into the following containers (additions and deviations to the stated 
procedures are as noted):
    4.2.1  Container No. 1 (Filter). Same instructions as Method 5, 
Section 4.2, ``Container No. 1.'' If it is necessary to fold the filter, 
do so such that the film of oil is inside the fold.
    4.2.2  Container No. 2 (Probe to Filter Holder). Taking care to see 
that material on the outside of the probe or other exterior

[[Page 766]]

surfaces does not get into the sample, quantitatively recover 
particulate matter or any condensate from the probe nozzle, probe 
fitting, probe liner, precollector cyclone and collector flask (if 
used), and front half of the filter holder by washing these components 
with TCE and placing the wash in a glass container. Carefully measure 
the total amount of TCE used in the rinses. Perform the TCE rinses as 
described in Method 5, Section 4.2, ``Container No. 2,'' using TCE 
instead of acetone.
    Brush and rinse the inside of the cyclone, cyclone collection flask, 
and the front half of the filter holder. Brush and rinse each surface 
three times or more, if necessary, to remove visible particulate.
    4.2.3  Container No. 3 (Silica Gel). Same procedure as in Method 5, 
Section 4.2, ``Container No. 3.''
    4.2.4  Impinger Water. Treat the impingers as follows: Make a 
notation of any color or film in the liquid catch. Follow the same 
procedure as in Method 5, Section 4.2, ``Impinger Water.''
    4.2.5  Blank. Save a portion of the TCE used for cleanup as a blank. 
Take 200 ml of this TCE directly from the wash bottle being used and 
place it in a glass sample container labeled ``TCE blank.''
    4.3  Analysis. Record the data required on a sheet such as the one 
shown in Figure 5A-1. Handle each sample container as follows:
    4.3.1  Container No. 1 (Filter). Transfer the filter from the sample 
container to a tared glass weighing dish and desiccate for 24 hours in a 
desiccator containing anhydrous calcium sulfate. Rinse Container No. 1 
with a measured amount of TCE and analyze this rinse with the contents 
of Container No. 2. Weigh the filter to a constant weight. For the 
purpose of Section 4.3, the term ``constant weight'' means a difference 
of no more than 10 percent or 2 mg (whichever is greater) between two 
consecutive weighings made 24 hours apart. Report the ``final weight'' 
to the nearest 0.1 mg as the average of these two values.
    4.3.2  Container No. 2 (Probe to Filter Holder). Before adding the 
rinse from Container No. 1 to Container No. 2, note the level of liquid 
in the container and confirm on the analysis sheet whether or not 
leakage occurred during transport. If noticeable leakage occurred, 
either void the sample or take steps, subject to the approval of the 
Administrator, to correct the final results.
    Measure the liquid in this container either volumetrically to 
plus-minus1 ml or gravimetrically to plus-minus0.5 
g. Check to see if there is any appreciable quantity of condensed water 
present in the TCE rinse (look for a boundary layer or phase 
separation). If the volume of condensed water appears larger than 5 ml, 
separate the oil-TCE fraction from the water fraction using a separatory 
funnel. Measure the volume of the water phase to the nearest ml; adjust 
the stack gas moisture content, if necessary (see Sections 6.4 and 6.5). 
Next, extract the water phase with several 25-ml portions of TCE until, 
by visual observation, the TCE does not remove any additional organic 
material. Evaporate the remaining water fraction to dryness at 93  deg.C 
(200  deg.F), desiccate for 24 hours, and weigh to the nearest 0.1 mg.
    Treat the total TCE fraction (including TCE from the filter 
container rinse and water phase extractions) as follows: Transfer the 
TCE and oil to a tared beaker and evaporate at ambient temperature and 
pressure. The evaporation of TCE from the solution may take several 
days. Do not desiccate the sample until the solution reaches an apparent 
constant volume or until the odor of TCE is not detected. When it 
appears that the TCE has evaporated, desiccate the sample and weigh it 
at 24-hour intervals to obtain a ``constant weight'' (as defined for 
Container No. 1 above). The ``total weight'' for Container No. 2 is the 
sum of the evaporated particulate weight of the TCE-oil and water phase 
fractions. Report the results to the nearest 0.1 mg.
    4.3.3  Container No. 3 (Silica Gel). This step may be conducted in 
the field. Weigh the spent silica gel (or silica gel plus impinger) to 
the nearest 0.5 g using a balance.
    4.3.4  ``TCE Blank'' Container. Measure TCE in this container either 
volumetrically or gravimetrically. Transfer the TCE to a tared 250-ml 
beaker and evaporate to dryness at ambient temperature and pressure. 
Desiccate for 24 hours and weigh to a constant weight. Report the 
results to the nearest 0.1 mg.
    Note: In order to facilitate the evaporation of TCE liquid samples, 
these samples may be dried in a controlled temperature oven at 
temperatures up to 38  deg.C (100  deg.F) until the liquid is 
evaporated.
    4.4  Quality Control Procedures. A quality control (QC) check of the 
volume metering system at the field site is suggested before collecting 
the sample. Use the procedure defined in Method 5, Section 4.4.

5. Calibration

    Calibrate the sampling train components according to the indicated 
sections of Method 5: Probe Nozzle (5.1), Pitot Tube Assembly (5.2), 
Metering System (5.3), Probe Heater (5.4), Temperature Gauges (5.5), 
Leak Check of Metering System (5.6), and Barometer (5.7).

6. Calculations

    6.1  Nomenclature. Same as in Method 5, Section 6.1, with the 
following additions:

Ct=TCE blank residue concentration, mg/mg.
mt=Mass of residue of TCE after evaporation, mg.
Vpc=Volume of water collected in precollector, ml.
Vt=Volume of TCE blank, ml.
Vtw=Volume of TCE used in wash, ml.

[[Page 767]]

Wt=Weight of residue in TCE wash, mg.
t=Density of TCE, mg/ml (see label on bottle).
    6.2  Dry Gas Meter Temperature and Orifice Pressure Drop. Using the 
data obtained in this test, calculate the average dry gas meter 
temperature and average orifice pressure drop (see Figure 5-2 of Method 
5).
    6.3  Dry Gas Volume. Using the data from this test, calculate 
Vm(std) by using Equation 5-1 of Method 5. If necessary, 
adjust the volume for leakages.
    6.4  Volume of Water Vapor.
Vw(std)=Kl(Vlc+Vpc)
                                                                Eq. 5A-1
Where:

Kl=0.00133 m\3\/ml for metric units.
  =0.04707 ft \3\/ml for English units.
    6.5  Moisture Content.
Bws=Vw(std)/[Vm(std)+Vw(std)]
                                                          Eq. 5A-2
    Note: In saturated or water droplet-laden gas streams, two 
calculations of the moisture content of the stack gas shall be made, one 
from the impinger and precollector analysis (Equations 5A-1 and 5A-2) 
and a second from the assumption of saturated conditions. The lower of 
the two values of moisture content shall be considered correct. The 
procedure for determining the moisture content based upon assumption of 
saturated conditions is given in the note of Section 1.2 of Method 4. 
For the purpose of this method, the average stack gas temperature from 
Figure 5-2 of Method 5 may be used to make this determination, provided 
that the accuracy of the in-stack temperature sensor is within 
plus-minus1  deg.C (2  deg.F).
    6.6 TCE Blank Concentration.
Ct=mt/Vtt
                                                          Eq. 5A-3
    6.7 TCE Wash Blank.
Wt=Ct Vtwt
                                                          Eq. 5A-4
    6.8  Total Particulate Weight. Determine the total particulate catch 
from the sum of the weights obtained from Containers 1, 2, and 3, less 
the TCE blank.
    6.9  Particulate Concentration.
cs=K2mn/Vm(std)
                                                          Eq. 5A-5
Where:

K2=0.001 g/mg.
    6.10  Isokinetic Variation and Acceptable Results. Same as in Method 
5, Sections 6.11 and 6.12, respectively.

7. Bibliography

    The bibliography for Method 5A is the same as that for Method 5.

  Method 5B--Determination of Nonsulfuric Acid Particulate Matter From 
                           Stationary Sources

    1.  Applicability and Principle.
    1.1  Applicability. This method is to be used for determining 
nonsulfuric acid particulate matter from stationary sources. Use of this 
method must be specified by an applicable subpart, or approved by the 
Administrator, U.S. Environmental Protection Agency, for a particular 
application.
    1.2  Principle. Particulate matter is withdrawn isokinetically from 
the source using the Method 5 train at 160   deg.C (320   deg.F). The 
collected sample is then heated in the oven at 160   deg.C (320   deg.F) 
for 6 hours to volatilize any condensed sulfuric acid that may have been 
collected, and the nonsulfuric acid particulate mass is determined 
gravimetrically.
    2.  Procedure.
    The procedure is identical to EPA Method 5 except for the following:
    2.1  Initial Filter Tare. Oven dry the filter at 1605  
deg.C (320 10   deg.F) for 2 to 3 hours, cool in a 
desiccator for 2 hours, and weigh. Desiccate to constant weight to 
obtain the initial tare. Use the applicable specifications and 
techniques of Section 4.1.1 of Method 5 for this determination.
    2.2  Probe and Filter Temperatures. Maintain the probe outlet and 
filter temperatures at 16014   deg.C (32025  
deg.F).
    2.3  Analysis. Dry the probe sample at ambient temperature. Then 
oven-dry the probe and filter samples at a temperature of 
1605   deg.C (32010   deg.F) for 6 hours. Cool 
in a desiccator for 2 hours, and weigh to constant weight. Use the 
applicable specifications and techniques of Section 4.3 of Method 5 for 
this determination.

                          Method 5C--[Reserved]

 Method 5D--Determination of Particulate Matter Emissions From Positive 
                         Pressure Fabric Filters

1. Applicability and Principle

    1.1  Applicability. This method applies to the determination of 
particulate matter emissions from positive pressure fabric filters. 
Emissions are determined in terms of concentration (mg/m\3\) and 
emission rate (kg/h).
    The General Provisions of 40 CFR Part 60, Sec. 60.8(e), require that 
the owner or operator of an affected facility shall provide performance 
testing facilities. Such performance testing facilities include sampling 
ports, safe sampling platforms, safe access to sampling sites, and 
utilities for testing. It is intended that affected facilities also 
provide sampling locations that meet the specification for adequate 
stack length and minimal flow disturbances as described in Method 1. 
Provisions for testing are often overlooked factors in designing fabric 
filters or are extremely

[[Page 768]]

costly. The purpose of this procedure is to identify appropriate 
alternative locations and procedures for sampling the emissions from 
positive pressure fabric filters. The requirements that the affected 
facility owner or operator provide adequate access to performance 
testing facilities remain in effect.
    1.2  Principle. Particulate matter is withdrawn isokinetically from 
the source and collected on a glass fiber filter maintained at a 
temperature at or above the exhaust gas temperature up to a nominal 120  
deg.C (120plus-minus14  deg.C or 248 plus-minus25  
deg.F). The particulate mass, which includes any material that condenses 
at or above the filtration temperature, is determined gravimetrically 
after removal of uncombined water.

2. Apparatus

    The equipment requirements for the sampling train, sample recovery, 
and analysis are the same as specified in Sections 2.1, 2.2, and 2.3, 
respectively, of Method 5 or Method 17.

3. Reagents
    The reagents used in sampling, sample recovery, and analysis are the 
same as specified in Sections 3.1, 3.2, and 3.3, respectively, of Method 
5 or Method 17.

4. Procedure

    4.1  Determination of Measurement Site. The configurations of 
positive pressure fabric filter structures frequently are not amenable 
to emission testing according to the requirements of Method 1. Following 
are several alternatives for determining measurement sites for positive 
pressure fabric filters.
    4.1.1  Stacks Meeting Method 1 Criteria. Use a measurement site as 
specified in Method 1, Section 2.1.
    4.1.2  Short Stacks Not Meeting Method 1 Criteria. Use stack 
extensions and the procedures in Method 1. Alternatively, use flow 
straightening vanes of the ``egg-crate'' type (see Figure 5D-1). Locate 
the measurement site downstream of the straightening vanes at a distance 
equal to or greater than two times the average equivalent diameter of 
the vane openings and at least one-half of the overall stack diameter 
upstream of the stack outlet.
    4.1.3  Roof Monitor or Monovent. (See Figure 5D-2.) For a positive 
pressure fabric filter equipped with a peaked roof monitor, ridge vent, 
or other type of monovent, use a measurement site at the base of the 
monovent. Examples of such locations are shown in Figure 5D-2. The 
measurement site must be upstream of any exhaust point (e.g., louvered 
vent).
    4.1.4  Compartment Housing. Sample immediately downstream of the 
filter bags directly above the tops of the bags as shown in the examples 
in Figure 5D-2. Depending on the housing design, use sampling ports in 
the housing walls or locate the sampling equipment within the 
compartment housing.
    4.2  Determination of Number and Location of Traverse Points. Locate 
the traverse points according to Method 1, Section 2.3. Because a 
performance test consists of at least three test runs and because of the 
varied configurations of positive pressure fabric filters, there are 
several schemes by which the number of traverse points can be determined 
and the three test runs can be conducted.
    4.2.1  Single Stacks Meeting Method 1 Criteria. Select the number of 
traverse points according to Method 1. Sample all traverse points for 
each test run.
    4.2.2  Other Single Measurement Sites. For a roof monitor or 
monovent, single compartment housing, or other stack not meeting Method 
1 criteria, use at least 24 traverse points. For example, for a 
rectangular measurement site, such as a monovent, use a balanced 5 x 5 
traverse point matrix. Sample all traverse points for each test run.
    4.2.3  Multiple Measurement Sites. Sampling from two or more stacks 
or measurement sites may be combined for a test run, provided the 
following guidelines are met:
    (a) All measurement sites up to 12 must be sampled. For more than 12 
measurement sites, conduct sampling on at least 12 sites or 50 percent 
of the sites, whichever is greater. The measurement sites sampled should 
be evenly, or nearly evenly, distributed among the available sites; if 
not, all sites are to be sampled.
    (b) The same number of measurement sites must be sampled for each 
test run.
    (c) The minimum number of traverse points per test run is 24. An 
exception to the 24-point minimum would be a test combining the sampling 
from two stacks meeting Method 1 criteria for acceptable stack length, 
and Method 1 specifies fewer than 12 points per site.
    (d) As long as the 24 traverse points per test run criterion is met, 
the number of traverse points per measurement site may be reduced to 
eight.
    Alternatively, conduct a test run for each measurement site 
individually using the criteria in Section 4.2.1 or 4.2.2 for number of 
traverse points. Each test run shall count toward the total of three 
required for a performance test. If more than three measurement sites 
are sampled, the number of traverse points per measurement site may be 
reduced to eight as long as at least 72 traverse points are sampled for 
all the tests.
    The following examples demonstrate the procedures for sampling 
multiple measurement sites.
    Example 1: A source with nine circular measurement sites of equal 
areas may be tested as follows: For each test run, traverse three 
measurement sites using four points per diameter (eight points per 
measurement site). In this manner, test run number 1 will include 
sampling from sites 1, 2, and 3; run 2

[[Page 769]]

will include samples from sites 4, 5, and 6; and run 3 will include 
sites 7, 8, and 9. Each test area may consist of a separate test of each 
measurement site using eight points. Use the results from all nine tests 
in determining the emission average.
    Example 2: A source with 30 rectangular measurement sites of equal 
areas may be tested as follows: For each of three test runs, traverse 
five measurement sites using a 3 x 3 matrix of traverse points for each 
site. In order to distribute the sampling evenly over all the available 
measurement sites while sampling only 50 percent of the sites, number 
the sites consecutively from 1 to 30 and sample all the even numbered 
(or odd numbered) sites. Alternatively, conduct a separate test of each 
of 15 measurement sites using Section 4.2.1 or 4.2.2 to determine the 
number and location of traverse points, as appropriate.
    Example 3: A source with two measurement sites of equal areas may be 
tested as follows: For each test of three test runs, traverse both 
measurement sites using Section 4.2.3 in determining number of traverse 
points. Alternatively, conduct two full emission test runs of each 
measurement site using the criteria in Section 4.2.1 or 4.2.2 to 
determine the number of traverse points.
    Other test schemes, such as random determination of traverse points 
for a large number of measurement sites, may be used with prior approval 
from the Administrator.
    4.3 Velocity Determination. The velocities of exhaust gases from 
postitive pressure baghouses are often too low to measure accurately 
with the type S pitot specified in Method 2 [i.e., velocity head <1.3 mm 
H2O (0.05 in. H2O)]. For these conditions, measure 
the gas flow rate at the fabric filter inlet following the procedures in 
Method 2. Calculate the average gas velocity at the measurement site as 
follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.134

Where:

v=Average gas velocity at the measurement site(s), m/s (ft/s).
Qi=Inlet gas volume flow rate, m3/s (ft\3\/s).
Ao=Measurement site(s) total cross-sectional area, 
          m2 (ft2).
To=Temperature of gas at measurement site,  deg.K ( deg.R)
Ti=Temperature of gas at inlet,  deg.K ( deg.R).

Use the average velocity calculated for the measurement site in 
determining and maintaining isokinetic sampling rates. Note: All sources 
of gas leakage, into or out of the fabric filter housing between the 
inlet measurement site and the outlet measurement site must be blocked 
and made leak-tight.
    Velocity determinations at measurement sites with gas velocities 
within the range measurable with the type S pitot [i.e., velocity head 
>1.3 mm H2O (0.05 in. H2O)] shall be conducted 
according to the procedures in Method 2.
    4.4  Sampling. Follow the procedures specified in Section 4.1 of 
Method 5 or Method 17 with the exceptions as noted above.
    4.5  Sample Recovery. Follow the procedures specified in Section 4.2 
of Method 5 or Method 17.
    4.6  Sample Analysis. Follow the procedures specified in Section 4.3 
of Method 5 or Method 17.
    4.7  Quality Control Procedures. A QC check of the volume metering 
system at the field site is suggested before collecting the sample. Use 
the procedure defined in Section 4.4 of Method 5.

5. Calibration

    Follow the procedures as specified in Section 5 of Method 5 or 
Method 17.

6. Calculations

    Follow the procedures as specified in Section 6 of Method 5 or 
Method 17 with the exceptions as follows:
    6.1  Total volume flow rate may be determined using inlet velocity 
measurements and stack dimensions.
    6.2  Average Particulate Concentration. For multiple measurement 
sites, calculate the average particulate concentration as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.135

Where:

mi=The mass collected for run i of n, mg(gr).
Voli=The sample volume collected for run i of n, 
          sm3 (scf).
C=Average concentration of particulate for all n runs, mg/sm3 
          (gr/scf).

7. Bibliography

    The bibliography is the same as for Method 5.

[[Page 770]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.113


[[Page 771]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.114

    Method 5E--Determination of Particulate Emissions From the Wool 
              Fiberglass Insulation Manufacturing Industry

1. Applicability and Principle

    1.1  Applicability. This method is applicable for the determination 
of particulate emissions from wool fiberglass insulation manufacturing 
sources.
    1.2  Principle. Particulate matter is withdrawn isokinetically from 
the source and collected on a glass fiber filter maintained at a 
temperature in the range of 120  deg.14  deg.C (248 
deg.25  deg.F) and in solutions of 0.1 N NaOH. The filtered 
particulate mass, which includes any

[[Page 772]]

material that condenses at or above the filtration temperature, is 
determined gravimetrically after removal of uncombined water. The 
condensed particulate material collected in the impinger solutions is 
determined as total organic carbon (TOC) using a nondispersive infrared 
type of analyzer. The sum of the filtered particulate mass and the 
condensed particulate matter is reported as the total particulate mass.

2. Apparatus

    2.1  Sampling Train. The equipment list for the sampling train is 
the same as described in Section 2.1 of Method 5 except as follows:
    2.1.1  Probe Liner. Same as described in Section 2.1.2 of Method 5 
except use only borosilicate or quartz glass liners.
    2.1.2  Filter Holder. Same as described in Section 2.1.5 of Method 5 
with the addition of a leak-tight connection in the rear half of the 
filter holder designed for insertion of a thermocouple or other 
temperature gauge for measuring the sample gas exist temperature.
    2.2  Sample Recovery. The equipment list for sample recovery is the 
same as described in Section 2.2 of Method 5 except three wash bottles 
are needed instead of two and only glass storage bottles and funnels may 
be used.
    2.3  Analysis. The equipment list for analysis is the same as 
Section 2.3 of Method 5 with the additional equipment for TOC analysis 
as described below:
    2.3.1  Sample Blender or Homogenizer. Waring type of ultrasonic.
    2.3.2  Magnetic Stirrer.
    2.3.3  Hypodermic Syringe. 0- to 100-l capacity.
    2.3.4  Total Organic Carbon Analyzer. Beckman Model 915 with 215 B 
infrared analyzer or equivalent and a recorder.
    2.3.5  Beaker. 30 ml.
    2.3.6  Water Bath. Temperature-controlled.
    2.3.7  Volumetric Flasks. 1,000 ml and 500 ml.

3. Reagents

    3.1  Sampling. The reagents used in sampling are the same as used in 
Reference Method 5 with the addition of 0.1 N NaOH (dissolve 40 g of ACS 
reagent grade NaOH in distilled water and dilute to 1 liter).
    3.2  Sample Recovery. The reagents used in sample recovery are the 
same as used in Method 5 with the addition of distilled water and 0.1 N 
NaOH as described in Section 3.1.
    3.3  Analysis. The reagents used in analysis are the same as in 
Method 5 except as follows:
    3.3.1  Carbon Dioxide-Free Water. Distilled or deionized water that 
has been freshly boiled for 15 minutes and cooled to room temperature 
while preventing exposure to ambient air with a cover vented with an 
ascarite tube.
    3.3.2  Hydrochloric Acid. HCl, concentrated, with a dropper.
    3.3.3  Organic Carbon Stock Solution. Dissolve 2.1254 g of dried 
potassium biphthalate in CO2-free water and dilute to 1 liter 
in a volumetric flask. This solution contains 1,000 mg/l organic carbon.
    3.3.4  Inorganic Carbon Stock Solution. Dissolve 4.404 g anhydrous 
sodium carbonate in about 500 ml of CO2-free water in a 1 
liter volumetric flask. Add 3.497 g anhydrous sodium bicarbonate to the 
flask and dilute to 1 liter with CO2-free water. This 
solution contains 1,000 mg/l inorganic carbon.
    3.3.5  Oxygen Gas. CO2-free.

4. Procedure

    4.1  Sampling. The sampling procedures are the same as in Section 
4.1 of Method 5 except as follows:
    4.1.1  Filtration Temperature. The temperature of the filtered gas 
stream, rather than the filter compartment air temperature, is 
maintained at 120  deg.14  deg.C (248  
deg.25 deg.F).
    4.1.2  Impinger Solutions. 0.1 N NaOH is used in place of water in 
the impingers. The volumes of the solutions are the same as in Method 5.
    4.2  Sample Recovery. The sample recovery procedure is as follows:
    Water is used to rinse and clean the probe parts prior to the 
acetone rinse. Save portions of the water, acetone, and 0.1 N NaOH used 
for cleanup as blanks following the procedure as in Section 4.2 of 
Method 5.
    Note: All parts of the sample collection portion of the train (e.g., 
probe and nozzle, filter holder, impinger glassware) must be free of 
organic solvent residue before sample collection. It is necessary that 
all sampling apparatus that have been rinsed with acetone be flushed 
twice with water or dilute NaOH before the sample run. The rinse 
solutions from this cleaning process should be discarded. If other 
solvents that are not readily soluble in water (e.g., TCE) are used, 
place the exposed sampling apparatus in a drying oven at 105  deg.C for 
at least 30 minutes.
    Container No. 1. The filter is removed and stored in the same manner 
as in Section 4.2 of Method 5.
    Container No. 2. Use water to rinse the sample nozzle, probe, and 
front half of the filter holder three times in the manner described in 
Section 4.2 of Method 5 except that no brushing is done. Put all the 
wash water in one container, seal, and label.
    Container No. 3. Rinse and brush the sample nozzle, probe, and front 
half of the filter holder with acetone as described for Container No. 2 
in Section 4.2 of Method 5.
    Container No. 4. Place the contents of the silica gel impinger in 
its original container as described for Container No. 3 in Section 4.2 
of Method 5.
    Container No. 5. Measure the liquid in the first three impingers and 
record the volume

[[Page 773]]

or weight as described for the Impinger Water in Section 4.2 of Method 
5. Do not discard this liquid, but place it in a sample container using 
a glass funnel to aid in the transfer from the impingers or graduated 
cylinder (if used) to the sample container. Rinse each impinger 
thoroughly with 0.1 N NaOH three times, as well as the graduated 
cylinder (if used) and the funnel, and put these rinsings in the same 
sample container. Seal the container and label to identify its contents 
clearly.
    4.3  Analysis. The procedures for analysis are the same as in 
Section 4.3 of Method 5 with exceptions noted as follows:
    Container No. 1. Determination of weight gain on the filter is the 
same as described for Container No. 1 in Section 4.3 of Method 5 except 
that the filters must be dried at 20  deg.6  deg.C (68  
deg.F10  deg.F) and at ambient pressure.
    Containers Nos. 2 and 3. Analyze the contents of Containers Nos. 2 
and 3 as described for Container No. 2 in Section 4.3 of Method 5 except 
that evaporation of the samples must be at 20  deg.6  deg.C 
(68  deg.10  deg.F) and at ambient pressure.
    Container No. 4. Weigh the spent silica gel as described for 
Container No. 3 in Section 4.3 of Method 5.
    ``Water and Acetone Blank'' Containers. Determine the water and 
acetone blank values following the procedures for Acetone Blank 
Container in Section 4.3 of Method 5. Evaporate the samples at ambient 
temperature [20  deg.6  deg.C (68  deg.10  deg. 
F)] and pressure.
    Container No. 5. For the determination of total organic carbon, 
perform two analyses on successive identical samples, i.e., total carbon 
and inorganic carbon. The desired quantity is the difference between the 
two values obtained. Both analyses are based on conversion of sample 
carbon into carbon dioxide for measurement by a nondispersive infrared 
analyzer. Results of analyses register as peaks on a strip chart 
recorder.
    The principal differences between operating parameters for the two 
channels involve the combustion tube packing material and temperature. 
In the total carbon channel, a high temperature [950  deg.C (1740  
deg.F)] furnace heats a Hastelloy combustion tube packed with cobalt 
oxide-impregnated asbestos fiber. The oxygen in the carrier gas, the 
elevated temperature, and catalytic effect of the packing result in 
oxidation of both organic and inorganic carbonaceous material to 
CO2 and steam. In the inorganic carbon channel, a low 
temperature [150  deg.C (300  deg.F)] furnace heats a glass tube 
containing quartz chips wetted with 85 percent phosphoric acid. The acid 
liberates CO2 and steam from inorganic carbonates. The 
operating temperature is below that required to oxidize organic matter. 
Follow the manufacturer's instructions for assembly, testing, 
calibration, and operation of the analyzer.
    As samples collected in 0.1 N NaOH often contain a high measure of 
inorganic carbon that inhibits repeatable determinations of TOC, sample 
pretreatment is necessary. Measure and record the liquid volume of each 
sample. If the sample contains solids or an immiscible liquid, 
homogenize the sample with a blender or ultrasonics until satisfactory 
repeatability is obtained. Transfer a representative portion of 10 to 15 
ml to a 30-ml beaker, acidify with about 2 drops of concentrated HCl to 
a pH of 2 or less. Warm the acidified sample at 50  deg.C (120  deg.F) 
in a water bath for 15 minutes. While stirring the sample with a 
magnetic stirrer, withdraw a 20- to 50-l sample from the beaker 
and inject it into the total carbon port of the analyzer. Measure the 
peak height. Repeat the injections until three consecutive peaks are 
obtained within 10 percent of the average.
    Repeat the analyses for all the samples and the 0.1 N NaOH blank. 
Prepare standard curves for total carbon and for inorganic carbon of 10, 
20, 30, 40, 50, 60, 80, and 100 mg/l by diluting with CO2-
free water 10, 20, 30, 40, and 50 ml of the two stock solutions to 1,000 
ml and 30, 40, and 50 ml of the two stock solutions to 500 ml. Inject 
samples of these solutions into the analyzer and record the peak heights 
as described above. The acidification and warming steps are not 
necessary for preparation of the standard curve.
    Ascertain the sample concentrations for the samples from the 
corrected peak heights for the samples by reference to the appropriate 
standard curve. Calculate the corrected peak height for the standards 
and the samples by deducting the blank correction as follows:
Corrected peak height=A-B
                                                                Eq. 5E-1
Where:

A=Peak height of standard or sample, mm or other appropriate unit.
B=Peak height of blank, mm or other appropriate unit.
    If samples must be diluted for analysis, apply an appropriate 
dilution factor.

5. Calibration
    Calibration of sampling and analysis equipment is the same as in 
Section 5 of Method 5 with the addition of the calibration of the TOC 
analyzer described in Section 4.3 of this method.

6. Calculations

    The calculations and nomenclature for the calculations are the same 
as described in Section 6 of Method 5 with the addition of the 
following:
    6.1  Mass of Condensed Particulate Material Collected.

           mc= 0.001 Ctoc Vs

                                                                Eq. 5E-2

Where:


[[Page 774]]


0.001=Liters per milliliter.
mc=Mass of condensed particulate material collected in the 
          impingers measured as TOC, mg.
Ctoc=Concentration of TOC in the liquid sample from TOC 
          analysis in Section 4.3, mg/l.
Vs=Total volume of liquid sample, ml.
    6.2  Concentration of Condensed Particulate Material.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.136
    
Where:

0.001=Grams per milligram.
Cc=Concentration of condensed particulate matter in stack 
          gas, dry basis, corrected to standard condition, g/dscm.
Vm(std)=Volume of gas sample measured by the dry gas meter, 
          corrected to standard conditions, dscm, from Section 6.3 of 
          Method 5.
    6.3  Total Particulate Concentration.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.137
    
Where:

Ct=Total particulate concentration, dry basis, corrected to 
          standard conditions, g/dscm.
Cs=Concentration of filtered particulate matter in stack gas, 
          dry basis, corrected to standard conditions, g/dscm, from 
          Equation 5-6 of Method 5.

7. Bibliography

    The bibliography is the same as in Method 5 with the addition of the 
following:
    1.  American Public Health Association, American Water Works 
Association, Water Pollution Control Federation. Standard Methods for 
the Examination of Water and Wastewater. Fifteenth Edition. Washington, 
DC 1980.

     Method 5F--Determination of Nonsulfate Particulate Matter From 
                           Stationary Sources

    1. Applicability and Principle.
    1.1  Applicability. This method is to be used for determining 
nonsulfate particulate matter from stationary sources. Use of this 
method must be specified by an applicable subpart of the standards, or 
approved by the Administrator, U.S. Environmental Protection Agency, for 
a particular application.
    1.2  Principle. Particulate matter is withdrawn isokinetically from 
the source using the Method 5 train at 160   deg.C (320   deg.F). The 
collected sample is then extracted with water. A portion of the extract 
is analyzed for sulfate content. The remainder is neutralized with 
ammonium hydroxide before it is dried and weighed.
    2. Apparatus.
    The apparatus is the same as Method 5 with the following additions.
    2.1  Analysis.
    2.1.1  Erlenmeyer Flasks. 125-ml, with ground glass joints.
    2.1.2  Air Condenser. With ground glass joint compatible with the 
Erlenmeyer flasks.
    2.1.3  Beakers. 250-ml.
    2.1.4  Volumetric Flasks. 1-liter, 500-ml (one for each sample), 
200-ml, and 50-ml (one for each sample and standard).
    2.1.5  Pipets. 5-ml (one for each sample and standard).
    2.1.6  Ion Chromatograph. The ion chromatograph should have at least 
the following components.
    2.1.6.1  Columns. An anion separation or other column capable of 
resolving the sulfate ion from other species present and a standard 
anion suppressor column. Suppressor columns are produced as proprietary 
items; however, one can be produced in the laboratory using the resin 
available from BioRad Company, 32nd and Griffin Streets, Richmond, 
California. Other systems which do not use suppressor columns may also 
be used.
    2.1.6.2  Pump. Capable of maintaining a steady flow as required by 
the system.
    2.1.6.3  Flow Gauges. Capable of measuring the specified system flow 
rate.
    2.1.6.4  Conductivity Detector.
    2.1.6.5  Recorder. Compatible with the output voltage range of the 
detector.
    3. Reagents.
    The reagents are the same as for Method 5 with the following 
exceptions:
    3.1  Sample Recovery. Water, deionized distilled to conform to 
American Society for Testing and Materials Specification D1193-74, Type 
3, is needed. At the option of the analyst, the KMnO4 test 
for oxidizable organic matter may be omitted when high concentrations of 
organic matter are not expected to be present.
    3.2  Analysis. The following are required:
    3.2.1  Water. Same as in Section 3.1.
    3.2.2  Stock Standard Solution, 1 mg 
(NH4)2SO4/ml. Dry an adequate amount of 
primary standard grade ammonium sulfate at 105 deg. to 110  deg.C for a 
minimum of 2 hours before preparing the standard solution. Then dissolve 
exactly 1.000 g of dried (NH4)2SO4 in 
water in a 1-liter volumetric flask, and dilute to 1 liter. Mix well.
    3.2.3  Working Standard Solution, 25 g 
(NH4)2SO4/ml. Pipet 5 ml of the stock 
standard solution into a 200-ml volumetric flask. Dilute to 200 ml with 
water.
    3.2.4  Eluent Solution. Weigh 1.018 g of sodium carbonate 
(Na2CO3) and 1.008 g of sodium bicarbonate 
(NaHCO3), and dissolve in 4 liters of water. This solution is 
0.0024 M Na2CO3/0.003 M NaHCO3. Other 
eluents appropriate to the column type and capable of resolving sulfate 
ion from other species present may be used.
    3.2.5  Ammonium Hydroxide. Concentrated, 14.8 M.

[[Page 775]]

    3.2.6  Phenolphthalein Indicator. 3,3-Bis(4-hydroxyphenyl)-1-(3H)-
isobenzofuranone. Dissolve 0.05 g in 50 ml of ethanol and 50 ml of 
water.
    4. Procedure.
    4.1  Sampling. The sampling procedure is the same as Method 5, 
Section 4.1, except that the probe outlet and filter temperatures shall 
be maintained at 160 deg.14  deg.C (320 deg.25 
deg.F).
    4.2  Sample Recovery. The sample recovery procedure is the same as 
Method 5, Section 4.2, except that the recovery solvent shall be water 
instead of acetone.
    4.3  Analysis.
    4.3.1  Sample Extraction. Cut the filter into small pieces, and 
place it in a 125-ml Erlenmeyer flask with a ground glass joint equipped 
with an air condenser. Rinse the shipping container with water, and pour 
the rinse into the flask. Add additional water to the flask until it 
contains about 75 ml, and place the flask on a hot plate. Gently reflux 
the contents for 6 to 8 hours. Cool the solution, and transfer it to a 
500-ml volumetric flask. Rinse the Erlenmeyer flask with water, and 
transfer the rinsings to the volumetric flask including the pieces of 
filter.
    Transfer the probe rinse to the same 500-ml volumetric flask with 
the filter sample. Rinse the sample bottle with water, and add the 
rinsings to the volumetric flask. Dilute the sample to exactly 500 ml 
with water.
    4.3.2  Sulfate (SO4) Analysis. Allow the sample to settle 
until all solid material is at the bottom of the volumetric flask. If 
necessary, centrifuge a portion of the sample. Pipet 5 ml of the sample 
into a 50-ml volumetric flask, and dilute to 50 ml with water. Prepare a 
standard calibration curve according to Section 5.1. Analyze the set of 
standards followed by the set of samples using the same injection volume 
for both standards and samples. Repeat this analysis sequence followed 
by a final analysis of the standard set. Average the results. The two 
sample values must agree within 5 percent of their mean for the analysis 
to be valid. Perform this duplicate analysis sequence on the same day. 
Dilute any sample and the blank with equal volumes of water if the 
concentration exceeds that of the highest standard.
    Document each sample chromatogram by listing the following 
analytical parameters: Injection point, injection volume, sulfate 
retention time, flow rate, detector sensitivity setting, and recorder 
chart speed.
    4.3.3  Sample Residue. Transfer the remaining contents of the 
volumetric flask to a tared 250-ml beaker. Rinse the volumetric flask, 
and add the rinsings to the tared beaker. Make certain that all 
particulate matter is transferred to the beaker. Evaporate the water in 
an oven heated to 105  deg.C until only about 100 ml of water remains. 
Remove the beakers from the oven, and allow them to cool.
    After the beakers have cooled, add five drops of phenolphthalein 
indicator, and then add concentrated ammonium hydroxide until the 
solution turns pink. Return the samples to the oven at 105  deg.C, and 
evaporate the samples to dryness. Cool the samples in a desiccator, and 
weigh the samples to constant weight.
    4.4  Blanks.
    4.4.1  Filter Blank. Choose a clean filter from the same lot as 
those used in the testing. Treat the blank filter as a sample, and 
analyze according to Sections 4.3.1 and 4.3.2.
    4.4.2  Water. Transfer a measured volume of water between 100 and 
200 ml into a tared 250-ml beaker. Treat the blank as a sample, and 
analyze according to Section 4.3.3.
    5. Calibration.
    The calibration procedure is the same as Method 5, Section 5, with 
the following additions:
    5.1  Standard Calibration Curve. Prepare a series of five standards 
by adding 1.0, 2.0, 4.0, 6.0, and 10.0 ml of working standard solution 
(25 g/ml) to a series of five 50-ml volumetric flasks. (The 
standard masses will equal 25, 50, 100, 150, and 250 g.) Dilute 
each flask to volume with water, and mix well. Analyze with the samples 
as described in Section 4.3. Prepare or calculate a linear regression 
plot of the standard masses in g (x-axis) versus their 
responses (y-axis). (Take peak height measurements with symmetrical 
peaks; in all other cases, calculate peak areas.) From this line, or 
equation, determine the slope, and calculate its reciprocal which is the 
calibration factor, S. If any point deviates from the line by more than 
7 percent of the concentration at that point, remake and reanalyze that 
standard. This deviation can be determined by multiplying S times the 
response for each standard. The resultant concentrations must not differ 
by more than 7 percent from each known standard mass (i.e., 25, 50, 100, 
150, and 250 g).
    5.2  Conductivity Detector. Calibrate according to manufacturer's 
specifications prior to initial use.
    6. Calculations.
    Calculations are the same as Method 5, Section 6, with the following 
additions:
    6.1  Nomenclature.

Cw=Water blank residue concentration, mg/ml.

F=Dilution factor (required only if sample dilution was needed to reduce 
          the concentration into the range of calibration).
Hs=Sample response, mm for height or mm\2\ for area.
Hb=Filter blank response, mm for height or mm\2\ for area.
mb=Mass of beaker used to dry sample, mg.
mf=Mass of sample filter, mg.
mn=Mass of nonsulfate particulate matter, mg.

[[Page 776]]

ms=Mass of ammonium sulfate in the sample, mg.
mt=Mass of beaker, filter, and dried sample, mg.
mw=Mass of residue after evaporation of water blank, mg.
S=Calibration factor, g/mm.
Vb=Volume of water blank, ml.
Vs=Volume of sample evaporated, 495 ml.
    6.2  Water Blank Concentration.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.138
    
    6.3  Mass of Ammonium Sulfate.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.139
    
    6.4  Mass of Nonsulfate Particulate Matter.

        
mn=mt-mb-ms-mf-Vs
 Cw
                                                                Eq. 5F-3

                        7. Alternative Procedures

    7.1  The following procedure may be used as an alternative to the 
procedure in Section 4.3.
    7.1.1  Apparatus. Same as for Method 6, Sections 2.3.3 to 2.3.6 with 
the following additions.
    7.1.1.1  Beakers. 250-ml, one for each sample, and 600-ml.
    7.1.1.2  Oven. Capable of maintaining temperatures of 75 
 5  deg.C and 105 5  deg.C.
    7.1.1.3  Buchner Funnel.
    7.1.14  Glass Columns. 25-mm  x  305-mm (1-in.  x  12-in.) with 
Teflon stopcock.
    7.1.1.5  Volumetric Flasks. 50-ml and 500-ml, one set for each 
sample, and 100-ml, 200-ml, and 1000-ml.
    7.1.1.6  Pipettes. Two 20-ml and one 200-ml, one set for each 
sample, and 5-ml.
    7.1.1.7  Filter Flasks. 500-ml.
    7.1.1.8  Polyethylene Bottle. 500-ml, one for each sample.
    7.1.2  Reagents. Same as Method 6, Sections 3.3.2 to 3.3.5 with the 
following additions:
    7.1.2.1  Water, Ammonium Hydroxide, and Phenolphthalein. Same as 
Sections 3.2.1, 3.2.5, and 3.2.6 of this method, respectively.
    7.1.2.2  Filter. Glass fiber to fit Buchner funnel.
    7.1.2.3  Hydrochloric Acid (HCl), 1 M. Add 8.3 ml of concentrated 
HCl (12 M) to 50 ml of water in a 100-ml volumetric flask. Dilute to 100 
ml with water.
    7.1.2.4  Glass Wool.
    7.1.2.5  Ion Exchange Resin. Strong cation exchange resin, hydrogen 
form, analytical grade.
    7.1.2.6  pH Paper. Range of 1 to 7.
    7.1.3  Analysis.
    7.1.3.1  Ion Exchange Column Preparation. Slurry the resin with 1 M 
HCl in a 250-ml beaker, and allow to stand overnight. Place 2.5 cm (1 
in.) of glass wool in the bottom of the glass column. Rinse the slurried 
resin twice with water. Resuspend the resin in water, and pour sufficent 
resin into the column to make a bed 5.1 cm (2 in.) deep. Do not allow 
air bubbles to become entrapped in the resin or glass wool to avoid 
channeling, which may produce erratic results. If necessary, stir the 
resin with a glass rod to remove air bubbles. after the column has been 
prepared, never let the liquid level fall below the top of the upper 
glass wool plug. Place a 2.5-cm (1-in.) plug of glass wool on top of the 
resin. Rinse the column with water until the eluate gives a pH of 5 or 
greater as measured with pH paper.
    7.1.3.2  Sample Extraction. Follow the procedure given in Section 
4.3.1 except do not dilute the sample to 500 ml.
    7.1.3.3  Sample Residue. Place at least one clean glass fiber filter 
for each sample in a Buchner funnel, and rinse the filters with water. 
Remove the filters from the funnel, and dry them in an oven at 105 
 5  deg.C; then cool in a desiccator. Weigh each filter to 
constant weight according to the procedure in Method 5, Section 4.3. 
Record the weight of each filter to the nearest 0.1 mg.
    Assemble the vacuum filter apparatus, and place one of the clean, 
tared glass fiber filters in the Buchner funnel. Decant the liquid 
portion of the extracted sample (Section 7.1.3.2) through the tared 
glass fiber filter into a clean, dry, 500-ml filter flask. Rinse all the 
particulate matter remaining in the volumetric flask onto the glass 
fiber filter with water. Rinse the particulate matter with additional 
water. Transfer the filtrate to a 500-ml volumetric flask, and dilute to 
500 ml with water. Dry the filter overnight at 105  5 
deg.C, cool in a desiccator, and weigh to the nearest 0.1 mg.
    Dry a 250-ml beaker at 75  5  deg.C, and cool in a 
desiccator; then weigh to constant weight to the nearest 0.1 mg. Pipette 
200 ml of the filtrate that was saved into a tared 250-ml beaker; add 
five drops of phenolphtahalein indicator and sufficient concentrated 
ammonium hydroxide to turn the solution pink. Carefully evaporate the 
contents of the beaker to dryness at 75  5  deg.C. Check for 
dryness every 30 minutes. Do not continue to bake the sample once it has 
dried. Cool the sample in a desiccator, and weigh to constant weight to 
the nearest 0.1 mg.
    7.1.3.4  Sulfate Analysis. Adjust the flow rate through the ion 
exchange column to 3 ml/min. Pipette a 20-ml aliquot of the filtrate 
onto the top of the ion exchange column, and collect the eluate in a 50-
ml volumetric flask. Rinse the column with two 15-ml portions of water. 
Stop collection of the eluate when the volume in the flask reaches

[[Page 777]]

50-ml. Pipette a 20-ml aliquot of the eluate into a 250-ml Erlenmeyer 
flask, add 80 ml of 100 percent isopropanol and two to four drops of 
thorin indicator, and titrate to a pink end point using 0.0100 N barium 
perchlorate. Repeat and average the titration volumes. Run a blank with 
each series of samples. Replicate titrations must agree within 1 percent 
or 0.2 ml, whichever is larger. Perform the ion exchange and titration 
procedures on duplicate portions of the filtrate. Results should agree 
within 5 percent. Regenerate or replace the ion exchange resin after 20 
sample aliquotes have been analyzed or if the end point of the titration 
becomes unclear.
    Note: Protect the 0.0100 N barium perchlorate solution from 
evaporation at all times.
    7.1.3.5  Blank Determination. Begin with a sample of water of the 
same volume as the samples being processed and carry it through the 
analysis steps described in Sections 7.1.3.3 and 7.1.3.4. A blank value 
larger than 5 mg should not be subtracted from the final particulate 
matter mass. Causes for large blank values should be investigated and 
any problems resolved before proceeding with further analyses.
    7.1.4  Calibration. Calibrate the barium perchlorate solutions as in 
Method 6, Section 5.5.
    7.1.5  Calculations.
    7.1.5.1  Nomenclature. Same as Section 6.1 with the following 
additions:

ma = Mass of clean analytical filter, mg.
md = Mass of dissolved particulate matter, mg.
me = Mass of beaker and dissolved particulate matter after 
          evaporation of filtrate, mg.
mp = Mass of insoluble particulate matter, mg.
mr = Mass of analytical filter, sample filter, and insoluble 
          particulate matter, mg.
mbk = Mass of nonsulfate particulate matter in blank sample, 
          mg.
N = Normality of Ba(Cl04)2 titrant, meq/ml.
Va = Volume of aliquot taken for titration, 20 ml.
Vc = Volume of titrant used for titration blank, ml.
Vd = Volume of filtrate evaporated, 200 ml.
Ve = Volume of eluate collected, 50 ml.
Vf = Volume of extracted sample, 500 ml.
Vi = Volume of filtrate added to ion exchange column, 20 ml.
Vt = Volume of Ba(Cl04)2 titrant, ml.
W = Equivalent weight of ammonium sulfate, 66.07 mg/meq.
    7.1.5.2  Mass of Insoluble Particulate Matter.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.140
    
    7.1.5.3 Mass of Dissolved Particulate Matter.

      md = (me - (Vf/Vd) 
mb)         Eq. 5F-5

    7.1.5.4 Mass of Ammonium Sulfate.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.141
    
    7.1.5.5 Mass of Nonsulfate Particulate Matter.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.142
    
    8. Bibliography.
    1. Mulik, J.D. and E. Sawicki. Ion Chromatographic Analysis of 
Environmental Pollutants. Ann Arbor, Ann Arbor Science Publishers, Inc. 
Vol. 2. 1979.
    2. Sawicki, E., J.D. Mulik, and E. Wittgenstein. Ion Chromatographic 
Analysis of Environmental Pollutants. Ann Arbor, Ann Arbor Science 
Publishers, Inc. Vol. 1. 1978.
    3. Siemer, D.D. Separation of Chloride and Bromide From Complex 
Matrices Prior to Ion Chromatographic Determination. Analytical 
Chemistry. 52(12):1874-1877. October 1980.
    4. Small, H., T.S. Stevens, and W.C. Bauman. Novel Ion Exchange 
Chromatographic Method Using Conductimetric Determination. Analytical 
Chemistry. 47(11):1801. 1975.

Method 5G--Determination of Particulate Emissions From Wood Heaters From 
                   a Dilution Tunnel Sampling Location

                     1. Applicability and Principle

    1.1  Applicability. This method is applicable for the determination 
of particulate matter emissions from wood heaters.
    1.2  Principle. Particulate matter is withdrawn proportionally at a 
single point from a total collection hood and sampling tunnel that 
combines the wood heater exhaust with ambient dilution air. The 
particulate matter is collected on two glass fiber filters in series. 
The filters are maintained at a temperature of no greater than 32  deg.C 
(90  deg.F). The particulate mass is determined gravimetrically after 
removal of uncombined water.
    There are three sampling train approaches described in this method: 
(1) One dual-filter dry sampling train operated at about 0.015 m\3\/min, 
(2) One dual-filter plus impingers sampling train operated at about 
0.015 m\3\/min, and (3) two dual-filter dry sampling trains operated 
simultaneously at any flow rate. Options (2) and (3) are referenced in 
Section 7 of this method. The dual-filter sampling train equipment and 
operation, option (1), are described in detail in this method.

                              2. Apparatus

    2.1  Sampling Train. The sampling train configuration is shown in 
Figure 5G-1 and consists of the following components:

[[Page 778]]

    2.1.1  Probe. Stainless steel (e.g., 316 or grade more corrosion 
resistant) or glass about 95 mm (\3/8\ in.) I.D., 0.6 m (24 in.) in 
length. If made of stainless steel, the probe shall be constructed from 
seamless tubing.
    2.1.2  Pitot Tube. Type S, as described in Section 2.1 of Method 2. 
The Type S pitot tube assembly shall have a known coefficient, 
determined as outlined in Method 2, Section 4.
    Alternatively, a standard pitot may be used as described in Method 
2, Section 2.1.
    2.1.3  Differential Pressure Gauge. Inclined manometer or equivalent 
device, as described in Method 2, Section 2.2. One manometer shall be 
used for velocity head ( p) readings and another (optional) for 
orifice differential pressure readings ( H).
    2.1.4  Filter Holders. Two each made of borosilicate glass, 
stainless steel, or Teflon, with a glass frit or stainless steel filter 
support and a silicone rubber, Teflon, or Viton gasket. The holder 
design shall provide a positive seal against leakage from the outside or 
around the filters. The filter holders shall be placed in series with 
the backup filter holder located 25 to 100 mm (1 to 4 in.) downstream 
from the primary filter holder. The filter holder shall be capable of 
holding a filter with a 100 mm (4 in.) diameter, except as noted in 
Section 7.
    Note: Mention of trade names or specific product does not constitute 
endorsement by the Environmental Protection Agency.
    2.1.5  Filter Temperature Monitoring System. A temperature gauge 
capable of measuring temperature to within 1.5 percent of absolute 
temperature. The gauge shall be installed at the exit side of the front 
filter holder so that the sensing tip of the temperature gauge is in 
direct contact with the sample gas or in a thermowell as shown in Figure 
5G-1. The temperature gauge shall comply with the calibration 
specifications in Method 2, Section 4. Alternatively, the sensing tip of 
the temperature gauge may be installed at the inlet side of the front 
filter holder.
    2.1.6  Dryer. Any system capable of removing water from the sample 
gas to less than 1.5 percent moisture (volume percent) prior to the 
metering system. System includes monitor for demonstrating that sample 
gas temperature is less than 20  deg.C (68  deg.F).
    2.1.7  Metering System. Same as Method 5, Section 2.1.8.
    2.1.8  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg).
    2.1.9  Dilution Tunnel Gas Temperature Measurement. A temperature 
gauge capable of measuring temperature to within 1.5 percent of absolute 
temperature.
    2.2  Dilution Tunnel. The dilution tunnel apparatus is shown in 
Figure 5G-2 and consists of the following components:
    2.2.1  Hood. Constructed of steel with a minimum diameter of 0.3 m 
(1 ft) on the large end and a standard 0.15 to 0.3 m (0.5 to 1 ft) 
coupling capable of connecting to standard 0.15 to 0.3 m (0.5 to 1 ft) 
stove pipe on the small end.
    2.2.2  90 deg. Elbows. Steel 90 deg. elbows, 0.15 to 0.3 m (0.5 to 1 
ft) in diameter for connecting mixing duct, straight duct and damper 
(optional) assembly. There shall be at least two 90 deg. elbows upstream 
of the sampling section (see Figure 5G-2).
    2.2.3  Straight Duct. Steel, 0.15 to 0.3 m (0.5 to 1 ft) in diameter 
to provide the ducting for the dilution apparatus upstream of the 
sampling section. Steel duct, 0.15 m (0.5 ft) in diameter shall be used 
for the sampling section. In the sampling section, at least 1.2 m (4 ft) 
downstream of the elbow, shall be two holes (velocity traverse ports) at 
90  deg. to each other of sufficient size to allow entry of the pitot 
for traverse measurements. At least 1.2 m (4 ft) downstream of the 
velocity traverse ports, shall be one hole (sampling port) of sufficient 
size to allow entry of the sampling probe. Ducts of larger diameter may 
be used for the sampling section, provided the specifications for 
minimum gas velocity and the dilution rate range shown in Section 4 are 
maintained. The length of duct from the hood inlet to the sampling ports 
shall not exceed 9.1 m (30 ft).
    2.2.4  Mixing Baffles. Steel semicircles (two) attached at 90  deg. 
to the duct axis on opposite sides of the duct midway between the two 
elbows upstream of sampling section. The space between the baffles shall 
be about 0.3 m (12 in.).
    2.2.5  Blower. Squirrel cage or other fan capable of extracting gas 
from the dilution tunnel of sufficient flow to maintain the velocity and 
dilution rate specifications in Section 4 and exhausting the gas to the 
atmosphere.
    2.3  Sample Recovery. Probe brushes, wash bottles, sample storage 
containers, petri dishes, and a funnel as described in Method 5, Section 
2.2.1 through 2.2.4, and 2.2.8, respectively, are needed.
    2.4  Analysis. Glass weighing dishes, desiccator, analytical 
balance, beakers (250 ml or smaller), hygrometer, and temperature gauge 
as described in Method 5, Sections 2.3.1 through 2.3.3 and 2.3.5 through 
2.3.7, respectively, are needed.

                               3. Reagents

    3.1  Sampling. The reagents used in sampling are as follows:
    3.1.1  Filters. Glass fiber filters with a minimum diameter of 100 
mm (4 in.), without organic binder, exhibiting at least 99.95 percent 
efficiency (<0.05 percent penetration) on 0.3-micron dioctyl phthalate 
smoke particles. Gelman A/E 61631 has been found acceptable for this 
purpose.

[[Page 779]]

    3.1.2  Stopcock Grease. Same as Method 5, Section 3.1.5.
    3.2  Sample Recovery. Acetone-reagent grade, same as Method 5, 
Section 3.2.
    3.3  Analysis. Two reagents are required for the analysis:
    3.3.1  Acetone. As in Section 3.2.
    3.3.2  Desiccant. Anhydrous calcium sulfate, calcium chloride, or 
silica gel, indicating type.

                              4. Procedure

    4.1  Dilution Tunnel. A schematic of a dilution tunnel is shown in 
Figure 5G-2. The dilution tunnel dimensions and other features are 
described in Section 2.2. Assemble the dilution tunnel sealing joints 
and seams to prevent air leakage. Clean the dilution tunnel with an 
appropriately sized, wire chimney brush before each certification test.
    4.1.1  Draft Determination. Prepare the wood heater as in Method 28, 
Section 6.2.1. Locate the dilution tunnel hood centrally over the wood 
heater stack exhaust. Operate the dilution tunnel blower at the flow 
rate to be used during the test run. Measure the draft imposed on the 
wood heater by the dilution tunnel (i.e., the difference in draft 
measured with and without the dilution tunnel operating) as described in 
Method 28, Section 6.2.3. Adjust the distance between the top of the 
wood heater stack exhaust and the dilution tunnel hood so that the 
dilution tunnel induced draft is less than 1.25 Pa (0.005 in. 
H2O). Have no fire in the wood heater, close the wood heater 
doors, and open fully the air supply controls during this check and 
adjustment.
    4.1.2  Smoke Capture. During the pretest ignition period described 
in Method 28, Section 6.3, operate the dilution tunnel and visually 
monitor the wood heater stack exhaust. Operate the wood heater with the 
doors closed and determine that 100 percent of the exhaust gas is 
collected by the dilution tunnel hood. If less than 100 percent of the 
wood heater exhaust gas is collected, adjust the distance between the 
wood heater stack and the dilution tunnel hood until no visible exhaust 
gas is escaping. Stop the pretest ignition period, and repeat the draft 
determination procedure described in Section 4.1.1.
    4.2  Velocity Measurements. During the pretest ignition period 
described in Method 28, Section 6.3, conduct a velocity traverse to 
identify the point of average velocity. This single point shall be used 
for measuring velocity during the test run.
    4.2.1  Velocity Traverse. Measure the diameter of the duct at the 
velocity traverse port location through both ports. Calculate the duct 
area using the average of the two diameters. A pretest leak-check of 
pitot lines as in Method 2, Section 3.1, is recommended. Place the 
calibrated pitot tube at the centroid of the stack in either of the 
velocity traverse ports. Adjust the damper or similar device on the 
blower inlet until the velocity indicated by the pitot is approximately 
220 m/min (715 fpm). Continue to read the  p and temperature 
until the velocity has remained constant (less than 5 percent change) 
for 1 minute. Once a constant velocity is obtained at the centroid of 
the duct, perform a velocity traverse as outlined in Method 2, Section 
3.3 using four points per traverse as outlined in Method 1. Measure the 
 p and tunnel temperature at each traverse point and record the 
readings. Calculate the total gas flow rate using calculations contained 
in Method 2, Section 5. Verify that the flow rate is 4 0.45 
sm\3\/min (14014 scfm); if not, readjust the damper, and 
repeat the velocity traverse. The moisture may be assumed to be 4 
percent (100 percent relative humidity at 85  deg.F). Direct moisture 
measurements such as outlined in EPA Method 4 are also permissible.
    Note: If burn rates exceed 3 kg/hr (6.6 lb/hr), dilution tunnel duct 
flow rates greater than 4 sm\3\/min (140 scfm) and sampling section duct 
diameters larger than 150 mm (6 in.) are allowed. If larger ducts or 
flow rates are used, the sampling section velocity shall be at least 220 
m/min (715 fpm). In order to ensure measurable particulate mass catch, 
it is recommended that the ratio of the average mass flow rate in the 
dilution tunnel to the average fuel burn rate be less than 150:1 if 
larger duct sizes or flow rates are used.
    4.2.2  Testing Velocity Measurements. After obtaining velocity 
traverse results that meet the flow rate requirements, choose a point of 
average velocity and place the pitot and thermocouple at that location 
in the duct. Alternatively, locate the pitot and thermocouple at the 
duct centroid and calculate a velocity correction factor for the 
centroidal position. Mount the pitot to ensure no movement during the 
test run and seal the port holes to prevent any air leakage. Align the 
pitot to be parallel with the duct axis, at the measurement point. Check 
that this condition is maintained during the test run (about 30-minute 
interva1s). Monitor the temperature and velocity during the pretest 
ignition period to ensure the proper flow rate is maintained. Make 
adjustments to the dilution tunnel flow rate as necessary.
    4.3  Sampling.
    4.3.1  Pretest Preparation. It is suggested that sampling equipment 
be maintained and calibrated according to the procedure described in 
APTD-0576.
    Check and desiccate filters as described in Method 5, Section 4.1.1.
    4.3.2  Preparation of Collection Train. During preparation and 
assembly of the sampling train, keep all openings where contamination 
can occur covered until just prior to assembly or until sampling is 
about to begin.

[[Page 780]]

    Using a tweezer or clean disposable surgical gloves, place one 
labeled (identified) and weighed filter in each of the filter holders. 
Be sure that each of the filters is properly centered and the gasket 
properly placed so as to prevent the sample gas stream from 
circumventing the filter. Check each of the filters for tears after 
assembly is completed.
    Mark the probe with heat resistant tape or by some other method to 
denote the proper distance into the stack or duct.
    Set up the train as in Figure 5G-1.
    4.3.3  Leak-Check Procedures.
    4.3.3.1  Pretest Leak-Check. A pretest leak-check is recommended, 
but not required. If the tester opts to conduct the pretest leak-check, 
conduct the leak-check as described in Method 5, Section 4.1.4.1. A 
vacuum 130 mm Hg (5 in. Hg) may be used instead of 380 mm Hg (15 in. 
Hg).
    4.3.3.2  Post-Test Leak-Check. A leak-check is mandatory at the 
conclusion of each test run. The leak-check shall be done in accordance 
with the procedures described in Method 5, Section 4.1.4.1. A vacuum of 
130 mm Hg (5 in. Hg) or the greatest vacuum measured during the test 
run, whichever is greater, may be used instead of 380 mm Hg (15 in. Hg).
    4.3.4  Preliminary Determinations. Determine the pressure, 
temperature and the average velocity of the tunnel gases as in Section 
4.2. Moisture content of diluted tunnel gases is assumed to be 4 percent 
for making flow rate calculations; the moisture content may be measured 
directly as in Method 4.
    4.3.5  Sampling Train Operation. Position the probe inlet at the 
stack centroid, and block off the openings around the probe and porthole 
to prevent unrepresentative dilution of the gas stream. Be careful not 
to bump the probe into the stack wall when removing or inserting the 
probe through the porthole; this minimizes the chance of extracting 
deposited material.
    Begin sampling at the start of the test run as defined in Method 28, 
Section 6.4.1. During the test run, maintain a sample flow rate 
proportional to the dilution tunnel flow rate (within 10 percent of the 
initial proportionality ratio) and a filter holder temperature of no 
greater than 32  deg.C (90  deg.F). The initial sample flow rate shall 
be approximately 0.015 m\3\/min (0.5 cfm).
    For each test run, record the data required on a data sheet such as 
the one shown in Figure 5G-3. Be sure to record the initial dry gas 
meter reading. Record the dry gas meter readings at the beginning and 
end of each sampling time increment and when sampling is halted. Take 
other readings as indicated on Figure 5G-3 at least once each 10 minutes 
during the test run. Since the manometer level and zero may drift 
because of vibrations and temperature changes, make periodic checks 
during the test run.
    For the purposes of proportional sampling rate determinations, data 
from calibrated flow rate devices, such as glass rotameters, may be used 
in lieu of incremental dry gas meter readings. Proportional rate 
calculation procedures must be revised, but acceptability limits remain 
the same.
    During the test run, make periodic adjustments to keep the 
temperature between (or upstream of) the filters at the proper level. Do 
not change sampling trains during the test run.
    At the end of the test run (see Method 28, Section 6.4.6), turn off 
the coarse adjust valve, remove the probe from the stack, turn off the 
pump, record the final dry gas meter reading, and conduct a post-test 
leak-check, as outlined in Section 4.3.3. Also, leak-check the pitot 
lines as described in Method 2, Section 3.1; the lines must pass this 
leak-check in order to validate the velocity head data.
    4.3.6  Calculation of Proportional Sampling Rate. Calculate percent 
proportionality (see Calculations, Section 6) to determine whether the 
run was valid or another test run should be made.
    4.4  Sample Recovery. Begin recovery of the probe and filter samples 
as described in Method 5, Section 4.2, except that an acetone blank 
volume of about 50 ml or more may be used.
    Treat the samples as follows:
    Container No. 1. Carefully remove the filter from the primary filter 
holder and place it in its identified (labeled) petri dish container. 
Use a pair of tweezers and/or clean disposable surgical gloves to handle 
the filter. If it is necessary to fold the filter, do so such that the 
particulate cake is inside the fold. Carefully transfer to the petri 
dish any particulate matter and/or filter fibers which adhere to the 
filter holder gasket, by using a dry Nylon bristle brush and/or a sharp-
edged blade. Seal the container.
    Container No. 2. Remove the filter from the second filter holder 
using the same procedures as described above.
    Note: The two filters may be placed in the same container for 
desiccation and weighing. Use the sum of the filter tare weights to 
determine the sample mass collected.
    Container No. 3. Taking care to see that dust on the outside of the 
probe or other exterior surfaces does not get into the sample, 
quantitatively recover particulate matter or any condensate from the 
probe and filter holders by washing and brushing these components with 
acetone and placing the wash in a labeled (No. 3) glass container. At 
least three cycles of brushing and rinsing are necessary.
    Between sampling runs, keep brushes clean and protected from 
contamination.
    After all acetone washings and particulate matter have been 
collected in the sample containers, tighten the lids on the sample 
containers so that the acetone will not leak

[[Page 781]]

out when transferred to the laboratory weighing area. Mark the height of 
the fluid levels to determine whether leakage occurs during transport. 
Label the containers clearly to identify contents. Requirements for 
capping and transport of sample containers are not applicable if sample 
recovery and analysis occur in the same room.
    4.5  Analysis. Record the data required on a sheet such as the one 
shown in Figure 5G-4. Use the same analytical balance for determining 
tare weight and final sample weights. Handle each sample container as 
follows:
    Containers No. 1 and 2. Leave the contents in the sample containers 
or transfer the filters and loose particulate to tared glass weighing 
dishes. Desiccate for no more than 36 hours before the initial weighing, 
weigh to a constant weight, and report the results to the nearest 0.1 
mg. For purposes of this section, the term ``constant weight'' means a 
difference of no more than 0.5 mg or 1 percent of total sample weight 
(less tare weight), whichever is greater, between two consecutive 
weighings, with no less than 2 hours between weighings.
    Container No. 3. Note the level of liquid in the container, and 
confirm on the analysis sheet whether leakage occurred during transport. 
If a noticeable amount of leakage has occurred, either void the sample 
or use methods, subject to the approval of the Administrator, to correct 
the final results. Determination of sample leakage is not applicable if 
sample recovery and analysis occur in the same room. Measure the liquid 
in this container either volumetrically to within 1 ml or 
gravimetrically to within 0.5 g. Transfer the contents to a tared 250 ml 
or smaller beaker and evaporate to dryness at ambient temperature and 
pressure. Desiccate and weigh to a constant weight. Report the results 
to the nearest 0.1 mg.
    ``Acetone Blank'' Container. Measure acetone in this container 
either volumetrically or gravimetrically. Transfer the acetone to a 
tared 250 ml or smaller beaker and evaporate to dryness at ambient 
temperature and pressure. Desiccate and weigh to a constant weight. 
Report the results to the nearest 0.1 mg.

                             5. Calibration

    Maintain a laboratory record of all calibrations.
    5.1  Pitot Tube. The Type S pitot tube assembly shall be calibrated 
according to the procedure outlined in Method 2, Section 4, prior to the 
first certification test and checked semiannually, thereafter. A 
standard pitot need not be calibrated but shall be inspected and 
cleaned, if necessary, prior to each certification test.
    5.2  Volume Metering System.
    5.2.1  Initial and Periodic Calibration. Before its initial use and 
at least semiannually thereafter, calibrate the volume metering system 
as described in Method 5, Section 5.3.1, except that the wet test meter 
with a capacity of 3.0 liters/rev (0.1 ft\3\/rev) may be used. Other 
liquid displacement systems accurate to within 1 percent, may be used as 
calibration standards.
    Procedures and equipment specified in Method 5, Section 7, for 
alternative calibration standards, including calibrated dry gas meters 
and critical orifices, are allowed for calibrating the dry gas meter in 
the sampling train. A dry gas meter used as a calibration standard shall 
be recalibrated at least once annually.
    5.2.2  Calibration After Use. After each certification or audit test 
(four or more test runs conducted on a wood heater at the four burn 
rates specified in Method 28), check calibration of the metering system 
by performing three calibration runs at a single, intermediate flow rate 
as described in Method 5, Section 5.3.2.
    Procedures and equipment specified in Method 5, Section 7, for 
alternative calibration standards are allowed for the post-test dry gas 
meter calibration check.
    5.2.3  Acceptable Variation in Calibration. If the dry gas meter 
coefficient values obtained before and after a certification test differ 
by more than 5 percent, the certification test shall either be voided 
and repeated, or calculations for the certification test shall be 
performed using whichever meter coefficient value (i.e., before or 
after) gives the lower value of total sample volume.
    5.3  Temperature Gauges. Use the procedure in Method 2, Section 4.3, 
to calibrate temperature gauges before the first certification or audit 
test and at least semiannually, thereafter.
    5.4  Leak-Check of Metering System Shown in Figure 5G-1. That 
portion of the sampling train from the pump to the orifice meter shall 
be leak-checked prior to initial use and after each certification or 
audit test. Leakage after the pump will result in less volume being 
recorded than is actually sampled. Use the procedure described in Method 
5, Section 5.6.
    Similar leak-checks shall be conducted for other types of metering 
systems (i.e., without orifice meters).
    5.5  Barometer. Calibrate against a mercury barometer before the 
first certification test and at least semiannually, thereafter. If a 
mercury barometer is used, no calibration is necessary. Follow the 
manufacturer's instructions for operation.
    5.6  Analytical Balance. Perform a multipoint calibration (at least 
five points spanning the operational range) of the analytical balance 
before the first certification test and semiannually, thereafter. Before 
each certification test, audit the balance by weighing at least one 
calibration weight (class F) that corresponds to 50 to 150 percent

[[Page 782]]

of the weight of one filter. If the scale cannot reproduce the value of 
the calibration weight to within 0.1 mg, conduct the multipoint 
calibration before use.

                             6. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after the final 
calculation. Other forms of the equations may be used as long as they 
give equivalent results.
    6.1  Nomenclature.

Bws=Water vapor in the gas stream, proportion by volume 
          (assumed to be 0.04).
cs=Concentration of particulate matter in stack gas, dry 
          basis, corrected to standard conditions, g/dsm\3\ (g/dscf).
E=Particulate emission rate, g/hr.
La=Maximum acceptable leakage rate for either a pretest or 
          post-test leak-check, equal to 0.00057 m\3\/min (0.02 cfm) or 
          4 percent of the average sampling rate, whichever is less.
Lp= Leakage rate observed during the post-test leak-check, 
          m\3\/min (cfm).
ma=Mass of residue of acetone blank after evaporation, mg.
maw=Mass of residue from acetone wash after evaporation, mg.
mn=Total amount of particulate matter collected, mg.
Mw=Molecular weight of water, 18.0 g/g-mole (18.0 lb/lb-
          mole).
Pbar=Barometric pressure at the sampling site, mm Hg (in. 
          Hg).
PR=Percent of proportional sampling rate.
Ps=Absolute gas pressure in dilution tunnel, mm Hg (in. Hg).
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
Qsd=Average gas flow rate in dilution tunnel, calculated as 
          in Method 2, Equation 2-10, dsm\3\/hr (dscf/hr).
Tm=Absolute average dry gas meter temperature (see Figure 5G-
          3), o K (o R).
Tmi=Absolute average dry gas meter temperature during each 
          10-minute interval, i, of the test run, o K 
          (o R).
Ts=Absolute average gas temperature in the dilution tunnel 
          (see Figure 5G 3), o K (o R).
Tsi=Absolute average gas temperature in the dilution tunnel 
          during each 10 minute interval, i, of the test run, 
          o K (o R).
Tstd=Standard absolute temperature, 293 o K (528 
          o R).
Va=Volume of acetone blank, ml.
Vaw=Volume of acetone used in wash, ml.
Vm=Volume of gas sample as measured by dry gas meter, dm\3\ 
          (dcf).
Vmi=Volume of gas sample as measured by dry gas meter during 
          each 10-minute interval, i, of the test run, dm\3\ (dcf).
Vm(std)=Volume of gas sample measured by the dry gas meter, 
          corrected to standard conditions, dsm\3\ (dscf).
Vs=Average gas velocity in dilution tunnel, calculated by 
          Method 2, Equation 2-9, m/sec (ft/sec). The dilution tunnel 
          dry gas molecular weight may be assumed to be 29 g/g mole (lb/
          lb mole).
Vsi=Average gas velocity in dilution tunnel during each 10-
          minute interval, i, of the test run, calculated by Method 2, 
          Equation 2-9, m/sec (ft/sec).
Y=Dry gas meter calibration factor.
 H=Average pressure differential across the orifice meter, if 
          used (see Figure 5G-2), mm H2O (in. 
          H2O).
=Total sampling time, min.
10=10 minutes, length of first sampling period.
13.6=Specific gravity of mercury.
100=Conversion to percent.
    6.2  Dry Gas Volume. Correct the sample volume measured by the dry 
gas meter to standard conditions (20  deg.C, 760 mm Hg or 68  deg.F, 
29.92 in. Hg) by using Equation 5G-1. (If no orifice meter is used in 
sampling train, assume  H=O or measure static pressure at dry 
gas meter outlet.)
[GRAPHIC] [TIFF OMITTED] TC16NO91.143

where;

Kl=0.3858 o K/mm Hg for metric units.
  =17.64 o R/in. Hg for English units.
    Note: If Lp exceeds La, Equation 5G-1 must be 
modified as follows: Replace Vm in Equation 5G-1 with the 
expression:
[Vm-(Lp-La)]

    6.3  Solvent Wash Blank.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.144
    
    6.4  Total Particulate Weight. Determine the total particulate 
catch, mn, from the sum of the weights obtained from 
Containers 1, 2, and 3, less the acetone blank (see Figure 5G-4).

[[Page 783]]

6.5  Particulate Concentration.

cs=(0.001 g/mg) (mn/Vm(std))
                                                                Eq. 5G-3
    6.6 Particulate Emission Rate.

E=cs Qsd
                                                                Eq. 5G-4
    Note: Particulate emission rate results produced using the sampling 
train described in Section 2 and shown in Figure 5G-1 shall be adjusted 
for reporting purposes by the following methods adjustment factor:
Eadj=1.82 (E)0.83
                                                                Eq. 5G-5
    6.7  Proportional Rate Variation. Calculate PR for each 10-minute 
interval, i, of the test run.
[GRAPHIC] [TIFF OMITTED] TC16NO91.145

    Alternate calculation procedures for proportional rate variation may 
be used if other sample flow rate data (e.g., orifice flow meters or 
rotameters) are monitored to maintain proportional sampling rates. The 
proportional rate variations shall be calculated for each 10-minute 
interval by comparing the stack to nozzle velocity ratio for each 10-
minute interval to the average stack to nozzle velocity ratio for the 
test run. Proportional rate variation may be calculated for intervals 
shorter than 10 minutes with appropriate revisions to Equation 5G-6.
    6.8  Acceptable Results. If no more than 10 percent of the PR values 
for all the intervals exceed 90 percent PR 110 
percent, and if no PR value for any interval exceeds 80 percent 
PR 120 percent, the results are acceptable. If the 
PR values for the test run are judged to be unacceptable, report the 
test run emission results, but do not include the results in calculating 
the weighted average emission rate, and repeat the test run.

             7. Alternative Sampling and Analysis Procedure

    7.1  Method 5H Sampling Train. The sampling and analysis train and 
procedures described in Method 5H, Sections 2.1, 3.1, 3.2, 5.1, 5.2.3, 
5.3, and 5.6 may be used in lieu of similar sections in Method 5G. 
Operation of the Method 5H sampling train in the dilution tunnel is as 
described in Section 4.3.5 of this method. Filter temperatures and 
condenser conditions are as described in Method 5H. No methods 
adjustment factor as described in Equation 5G-5, Section 6.6, is to be 
applied to the particulate emission rate data produced by this 
alternative method.
    7.2  Dual Sampling Trains. The tester may operate two sampling 
trains simultaneously at sample flow rates other than that specified in 
Section 4.3.5 provided the following specifications are met.
    7.2.1  Sampling Train. The sampling train configuration shall be the 
same as specified in Section 2.1, except the probe, filter, and filter 
holder need not be the same sizes as specified in the applicable 
sections. Filter holders of plastic materials such as Nalgene or 
polycarbonate materials may be used (the Gelman 1119 filter holder has 
been found suitable for this purpose). With such materials, it is 
recommended not to use solvents in sample recovery. The filter face 
velocity shall not exceed 150 mm/sec (30 ft/min) during the test run. 
The dry gas meter shall be calibrated for the same flow rate range as 
encountered during the test runs. Two separate, complete sampling trains 
are required for each test run.
    7.2.2  Probe Location. Locate the two probes in the dilution tunnel 
at the same level (see Section 2.2.3). Two sample ports are necessary. 
Locate the probe inlets within the 50 mm (2 in.) diameter centroidal 
area of the dilution tunnel no closer than 25 mm (1 in.) apart.
    7.2.3  Sampling Train Operation. Operate the sampling trains as 
specified in Section 4.3.5, maintaining proportional sampling rates and 
starting and stopping the two sampling trains simultaneously. The pitot 
values as described in Section 4.2.2 shall be used to adjust sampling 
rates in both sampling trains.
    7.2.4  Recovery and Analysis of Sample. Recover and analyze the 
samples from the two sampling trains separately, as specified in 
Sections 4.4 and 4.5.
    For this alternative procedure, the probe and filter holder assembly 
may be weighed without sample recovery (use no solvents) described above 
in order to determine the sample weight gains. For this approach, weigh 
the clean, dry probe and filter holder assembly upstream of the front 
filter (without filters) to the nearest 0.1 mg to establish the tare 
weights. The filter holder section between the front and second filter 
need not be weighed. At the end of the test run, carefully clean the 
outside of the probe, cap the ends, and identify the sample (label). 
Remove the filters from the filter holder assemblies as described for 
containers Nos. 1 and 2 above. Reassemble the filter holder assembly, 
cap the ends, identify the sample (label), and transfer all the samples 
to the laboratory weighing area for final weighing. Descriptions of 
capping and transport of samples are not applicable if sample recovery 
and analysis occur in the same room.
    For this alternative procedure, filters may be weighed directly 
without a petri dish. If the probe and filter holder assemb1y are to be 
weighed to determine the sample weight, rinse the probe with acetone to 
remove moisture before desiccating prior to the test run. Following the 
test run, transport the probe and fi1ter ho1der to the dessicator, and

[[Page 784]]

uncap the openings of the probe and the filter holder assembly. 
Desiccate no more than 36 hours and weigh to a constant weight. Report 
the results to the nearest 0.l mg.
    7.2.5  Calculations. Calculate an emission rate (Section 6.6) for 
the sample from each sampling train separately and determine the average 
emission rate for the two values. The two emission rates shall not 
differ by more than 7.5 percent from the average emission rate, or 7.5 
percent of the weighted average emission rate limit in the applicable 
standard, whichever is greater. If this specification is not met, the 
results are unacceptable. Report the results, but do not include the 
results in calculating the weighted average emission rate. Repeat the 
test run until acceptable results are achieved, report the average 
emission rate for the acceptable test run, and use the average in 
calculating the weighted average emission rate.

                             8. Bibliography

    1. Same as for Method 5, citations 1 through 11, with the addition 
of the following:
    2. Oregon Department of Environmental Quality Standard Method for 
Measuring the Emissions and Efficiencies of Woodstoves, June 8, 1984. 
Pursuant to Oregon Administrative Rules Chapter 340, Division 21.
    3. American Society for Testing Materials. Proposed Test Methods for 
Heating Performance and Emissions of Residential Wood-fired Closed 
Combustion-Chamber Heating Appliances. E-6 Proposal P 180. August 1986.
[GRAPHIC] [TIFF OMITTED] TC01JN92.115


[[Page 785]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.116


[[Page 786]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.117

 Stove__________________________________________________________________
 Date___________________________________________________________________
 Run No.________________________________________________________________
 Filter Nos.____________________________________________________________
Liquid lost during
 transport, ml__________________________________________________________
 Acetone blank volume, ml_______________________________________________
 Acetone wash volume, ml________________________________________________

[[Page 787]]

Acetone blank
 concentration, mg/mg___________________________________________________
 Acetone wash blank, mg_________________________________________________

------------------------------------------------------------------------
                                                Weight of particulate
                                                    collected, mg
               Container No.               -----------------------------
                                              Final     Tare     Weight
                                             weight    weight     gain
------------------------------------------------------------------------
1.........................................  ........  ........  ........
2.........................................  ........  ........  ........
3.........................................  ........  ........  ........
                                           -----------------------------
  Total...................................  ........  ........  ........
Less acetone blank........................  ........  ........  ........
Weight of particulate matter..............  ........  ........  ........
------------------------------------------------------------------------


               Stack Moisture Measurement Data (Optional)
------------------------------------------------------------------------
                                                 Volume of liquid water
                                                        collected
                                               -------------------------
                                                  Impinger    Silica gel
                                                 volume, ml   weight, g
------------------------------------------------------------------------
Final.........................................  ...........  ...........
Initial.......................................  ...........  ...........
Liquid collected..............................  ...........  ...........
Total volume collected........................  ...........      g\1\ ml
------------------------------------------------------------------------
\1\ Convert weight of water to volume by dividing total weight increase
  by density of water (1 g/ml).

  [GRAPHIC] [TIFF OMITTED] TC16NO91.146
  
Figure 5G-4. Analysis data sheet.

Method 5H--Determination of Particulate Emissions From Wood Heaters From 
                            a Stack Location

                       Applicability and Principle

    1.1  Applicability. This method is applicable for the determination 
of particulate matter and condensible emissions from wood heaters.
    1.2  Principle. Particulate matter is withdrawn proportionally from 
the wood heater exhaust and is collected on two glass fiber filters 
separated by impingers immersed in an ice bath. The first filter is 
maintained at a temperature of no greater than 120  deg.C (248  deg.F). 
The second filter and the impinger system are cooled such that the 
exiting temperature of the gas is no greater than 20  deg.C (68  deg.F). 
The particulate mass collected in the probe, on the filters, and in the 
impingers is determined gravimetrically after removal of uncombined 
water.

                              2. Apparatus

    2.1  Sampling Train. The sampling train configuration is shown in 
Figure 5H-1. APTD-0576 is suggested for operating and maintenance 
procedures. The train consists of the following components:
    2.1.1  Probe Nozzle. (Optional) Same as Method 5, Section 2.1.1. A 
straight sampling probe without a nozzle is an acceptable alternative.
    2.1.2  Probe Liner. Same as Method 5, Section 2.1.2, except that the 
maximum length of the sample probe shall be 0.6 m (2 ft) and probe 
heating is optional.
    2.1.3  Differential Pressure Gauge. Same as Method 5, Section 2.1.4.
    2.1.4  Filter Holders. Two each of borosilicate glass, with a glass 
frit or stainless steel filter support and a silicone rubber, Teflon, or 
Viton gasket. The holder design shall provide a positive seal against 
leakage from the outside or around the filter. The front filter holder 
shall be attached immediately at the outlet of the probe and prior to 
the first impinger. The second filter holder shall be attached on the 
outlet of the third impinger and prior to the inlet of the fourth 
(silica gel) impinger.
    Note: Mention of trade names or specific product does not constitute 
endorsement by the Environmental Protection Agency.
    2.1.5  Filter Heating System. Same as Method 5, Section 2.1.6.
    2.1.6  Condenser. Same as Method 5, Section 2.1.7, used to collect 
condensible materials and determine the stack gas moisture content.
    2.1.7  Metering System. Same as Method 5, Section 2.1.8.
    2.1.8  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg).
    2.2  Stack Flow Rate Measurement System. A schematic of an example 
test system is shown in Figure 5H-2. The flow rate measurement system 
consists of the following components:
    2.2.1  Sample Probe. A glass or stainless steel sampling probe.
    2.2.2  Gas Conditioning System. A high density filter to remove 
particulate matter and a condenser capable of lowering the dew point of 
the gas to less than 5  deg.C (40  deg.F). Desiccant, such as Drierite, 
may be used to dry the sample gas. Do not use silica gel.
    2.2.3  Pump. An inert (i.e., Teflon or stainless steel heads) 
sampling pump capable of delivering more than the total amount of sample 
required in the manufacturer's instructions for the individual 
instruments. A means of controlling the analyzer flow rate and a device 
for determining proper sample flow rate (e.g., precision rotameter, 
pressure gauge downstream of all flow controls) shall be provided at the 
analyzer. The requirements for measuring and controlling the analyzer 
flow rate are not applicable if data are presented that demonstrate the 
analyzer is insensitive to flow variations over the range encountered 
during the test.
    2.2.4  CO Analyzer. Any analyzer capable of providing a measure of 
CO in the range of

[[Page 788]]

0 to 10 percent by volume at least once every 10 minutes.
    2.2.5  CO2 Analyzer. Any analyzer capable of providing a 
measure of CO2 in the range of 0 to 25 percent by volume at 
least once every 10 minutes.
    Note: Analyzers with ranges less than those specified above may be 
used provided actual concentrations do not exceed the range of the 
analyzer.
    2.2.6  Manifold. A sampling tube capable of delivering the sample 
gas to two analyzers and handling an excess of the total amount used by 
the analyzers. The excess gas is exhausted through a separate port.
    2.2.7  Recorders (optional). To provide a permanent record of the 
analyzer outputs.
    2.3  Proportional Gas Flow Rate System. To monitor stack flow rate 
changes and provide a measurement that can be used to adjust and 
maintain particulate sampling flow rates proportional to the stack flow 
rate. A schematic of the proportional flow rate system is shown in 
Figure 5H-2 and consists of the following components:
    2.3.1  Tracer Gas Injection System. To inject a known concentration 
of SO2 into the flue. The tracer gas injection system 
consists of a cylinder of SO2, a gas cylinder regulator, a 
stainless steel needle valve or flow controller, a nonreactive 
(stainless steel and glass) rotameter, and an injection loop to disperse 
the SO2 evenly in the flue.
    2.3.2  Sample Probe. A glass or stainless steel sampling probe.
    2.3.3  Gas Conditioning System. A combustor as described in Method 
16A, Sections 2.1.5 and 2.1.6, followed by a high density filter to 
remove particulate matter, and a condenser capable of lowering the dew 
point of the gas to less than 5  deg.C (40  deg.F). Desiccant, such as 
Drierite, may be used to dry the sample gas. Do not use silica gel.
    2.3.4  Pump. As described in Section 2.2.3.
    2.3.5  SO2 Analyzer. Any analyzer capable of providing a 
measure of the SO2 concentration in the range of 0 to 1,000 
ppm by volume (or other range necessary to measure the SO2 
concentration) at least once every 10 minutes.
    2.3.6  Recorder (optional). To provide a permanent record of the 
analyzer outputs.
    Note: Other tracer gas systems, including helium gas systems, are 
allowed for determining instantaneous proportional sampling rates.
    2.4  Sample Recovery. Probe liner and probe nozzle brushes, wash 
bottles, sample storage containers, petri dishes, graduated cylinder or 
balance, plastic storage containers, funnel and rubber policeman, as 
described in Method 5, Sections 2.2.1 through 2.2.8, respectively, are 
needed.
    2.5  Analysis. Weighing dishes, desiccator, analytical balance, 
beakers (250 ml or less), hygrometer or psychrometer, and temperature 
gauge as described in Method 5, Sections 2.3.1 through 2.3.7, 
respectively, are needed. In addition, a separatory funnel, glass or 
Teflon, 500 ml or greater, is needed.

                               3. Reagents

    3.1  Sampling. The reagents used in sampling are as follows:
    3.1.1  Filters. Glass fiber filters, without organic binder, 
exhibiting at least 99.95 percent efficiency (<0.05 percent penetration) 
on 0.3-micron dioctyl phthalate smoke particles. Gelman A/E 61631 
filters have been found acceptable for this purpose.
    3.1.2  Silica Gel. Same as Method 5, Section 3.1.2.
    3.1.3  Water. Deionized distilled to conform to ASTM Specification 
D1193-77, Type 3 (incorporated by reference--see Sec. 60.17). Run blanks 
prior to field use to eliminate a high blank on test samples.
    3.1.4  Crushed Ice.
    3.1.5  Stopcock Grease. Same as Method 5, Section 3.1.5.
    3.2  Sample Recovery. Same as Method 5, Section 3.2.
    3.3  Cylinder Gases. For the purposes of this procedure, span value 
is defined as the upper limit of the range specified for each analyzer 
as described in Section 2.2 or 2.3. If an analyzer with a range 
different from that specified in this method is used, the span value 
shall be equal to the upper limit of the range for the analyzer used 
(see Note in Section 2.2.5).
    3.3.1  Calibration Gases. The calibration gases for the 
CO2, CO and SO2 analyzers shall be CO2, 
CO, or SO2, as appropriate, in N2. CO2 
and CO calibration gases may be combined in a single cylinder.
    There are two alternatives for checking the concentrations of the 
calibration gases. (a) The first is to use calibration gases that are 
documented traceable to National Bureau of Standards Reference 
Materials. Use Tracebility Protocol for Establishing True Concentrations 
of Gases Used for Calibrations and Audits of Continuous Source Emission 
Monitors (Protocol Number 1) that is available from the Environmental 
Monitoring and Support Laboratory, Quality Assurance Branch, Mail Drop 
77, Environmental Protection Agency, Research Triangle Park, North 
Carolina 27711. Obtain a certification from the gas manufacturer that 
the protocol was followed. These calibration gases are not to be 
analyzed with the test methods. (b) The second alternative is to use 
calibration gases not prepared according to the protocol. If this 
alternative is chosen, within 6 months prior to the certification test, 
analyze each of the CO2 and CO calibration gas mixtures in 
triplicate using Method 3, and within 1 month prior to the certification 
test, analyze SO2 calibration gas mixtures using Method 6. 
For the low-level, mid-level, or high-level gas mixtures, each of the 
individual SO2 analytical results must be within 10 percent 
(or

[[Page 789]]

10 ppm, whichever is greater) of the triplicate set average; 
CO2 and CO test results must be within 0.5 percent 
CO2 and CO; otherwise, discard the entire set and repeat the 
triplicate analyses. If the average of the triplicate test method 
results is within 5 percent for SO2 gas (or 0.5 percent 
CO2 and CO for the CO2 and CO gases) of the 
calibration gas manufacturer's tag values, use the tag value; otherwise, 
conduct at least three additional test method analyses until the results 
of six individual SO2 runs (the three original plus three 
additional) agree within 10 percent (or 10 ppm, whichever is greater) of 
the average (CO2 and CO test results must be within 0.5 
percent). Then use this average for the cylinder value. Four calibration 
gas levels are required as specified below:
    3.3.1.1  High-level Gas. A gas concentration that is equivalent to 
80 to 90 percent of the span value.
    3.3.1.2  Mid-level Gas. A gas concentration that is equivalent to 45 
to 55 percent of the span value.
    3.3.1.3  Low-level Gas. A gas concentration that is equivalent to 20 
to 30 percent of the span value.
    3.3.1.4  Zero Gas. A gas concentration of less than 0.25 percent of 
the span value. Purified air may be used as zero gas for the 
CO2, CO, and SO2 analyzers.
    3.3.2  SO2 Injection Gas. A known concentration of 
SO2 in N2. The concentration must be at least 2 
percent SO2 with a maximum of 100 percent SO2. The 
cylinder concentration shall be certified by the manufacturer to be 
within 2 percent of the specified concentration.
    3.4  Analysis. Three reagents are required for the analysis:
    3.4.1  Acetone. Same as 3.2.
    3.4.2  Dichloromethane (Methylene Chloride). Reagent grade, <0.001 
percent residue in glass bottles.
    3.4.3  Desiccant. Anhydrous calcium sulfate, calcium chloride, or 
silica gel, indicating type.

          4. Gas Measurement System Performance Specifications.

    4.1  Response Time. The amount of time required for the measurement 
system to display 95 percent of a step change in gas concentration. The 
response time for each analyzer and gas conditioning system shall be no 
more than 2 minutes.
    4.2  Zero Drift. The zero drift value for each analyzer shall be 
less than 2.5 percent of the span value over the period of the test run.
    4.3  Calibration Drift. The calibration drift value measured with 
the mid-level calibration gas for each analyzer shall be less than 2.5 
percent of the span value over the period of the test run.
    4.4  Resolution. The resolution of the output for each analyzer 
shall be 0.5 percent of span value or less.
    4.5  Calibration Error. The linear calibration curve produced using 
the zero and mid-level calibration gases shall predict the actual 
response to the low-level and high-level calibration gases within 2 
percent of the span value.

                              5. Procedure

    5.1  Pretest Preparation.
    5.1.1  Filter and Desiccant. Same as Method 5, Section 4.1.1.
    5.1.2  Sampling Probe and Nozzle. The sampling location for the 
particulate sampling probe shall be 2.450.15 m 
(80.5 ft) above the platform upon which the wood heater is 
placed (i.e., the top of the scale).
    Select a nozzle, if used, sized for the range of velocity heads, 
such that it is not necessary to change the nozzle size in order to 
maintain proportional sampling rates. During the run, do not change the 
nozzle size.
    Select a suitable probe liner and probe length to effect minimum 
blockage.
    5.1.3  Preparation of Particulate Sampling Train. During preparation 
and assembly of the particulate sampling train, keep all openings where 
contamination can occur covered until just prior to assembly or until 
sampling is about to begin.
    Place 100 ml of water in each of the first two impingers, leave the 
third impinger empty, and transfer approximately 200 to 300 g of 
preweighed silica gel from its container to the fourth impinger. More 
silica gel may be used, but care should be taken to ensure that it is 
not entrained and carried out from the impinger during sampling. Place 
the container in a clean place for later use in the sample recovery. 
Alternatively, the weight of the silica gel plus impinger may be 
determined to the nearest 0.5 g and recorded.
    Using a tweezer or clean surgical gloves, place one labeled 
(identified) and weighed filter in each of the filter holders. Be sure 
that each of the filters is properly centered and the gasket properly 
placed so as to prevent the sample gas stream from circumventing the 
filter. Check the filters for tears after assembly is completed.
    When glass liners are used, install the selected nozzle using a 
Viton A O-ring. Other connecting systems using either 316 stainless 
steel or Teflon ferrules may be used. Mark the probe with heat resistant 
tape or by some other method to denote the proper distance into the 
stack or duct.
    Set up the train as in Figure 5H 1, using (if necessary) a very 
light coat of silicone grease on all ground glass joints, greasing only 
the outer portion (see APTD-0576) to avoid possibility of contamination 
by the silicone grease.
    Place crushed ice around the impingers.
    5.1.4  Leak-Check Procedures.

[[Page 790]]

    5.1.4.1  Pretest Leak-Check. A pretest leak-check is recommended, 
but not required. If the tester opts to conduct the pretest leak-check, 
conduct the leak-check as described in Method 5, Section 4.1.4.1, except 
that a vacuum of 130 mm Hg (5 in. Hg) may be used instead of 380 mm Hg 
(15 in. Hg).
    5.1.4.2  Leak-Checks During Sample Run. If, during the sampling run, 
a component (e.g., filter assembly or impinger) change becomes 
necessary, conduct a leak-check as described in Method 5, Section 
4.1.4.2.
    5.1.4.3  Post-Test Leak-Check. A leak-check is mandatory at the 
conclusion of each sampling run. The leak-check shall be done in 
accordance with the procedures described in Method 5, Section 4.1.4.3, 
except that a vacuum of 130 mm Hg (5 in. Hg) or the greatest vacuum 
measured during the test run, whichever is greater, may be used instead 
of 380 mm Hg (15 in. Hg).
    5.1.5  Tracer Gas Procedure. A schematic of the tracer gas injection 
and sampling systems is shown in Figure 5H-2.
    5.1.5.1  SO2 Injection Probe. Install the SO2 
injection probe and dispersion loop in the stack at a location 
2.80.15 m (9.50.5 ft) above the sampling 
platform.
    5.1.5.2  SO2 Sampling Probe. Install the SO2 
sampling probe at the centroid of the stack at a location 
40.15 m (13.50.5 ft) above the sampling 
platform.
    5.1.6  Flow Rate Measurement System. A schematic of the flow rate 
measurement system is shown in Figure 5H-2. Locate the flow rate 
measurement sampling probe at the centroid of the stack at a location 
2.30.3 m (7.51 ft) above the sampling platform.
    5.2  Test Run Procedures. The start of the test run is defined as in 
Method 28, Section 6.4.1.
    5.2.1  Tracer Gas Procedure. Within 1 minute after closing the wood 
heater door at the start of the test run, meter a known concentration of 
SO2 tracer gas at a constant flow rate into the wood heater 
stack. Monitor the SO2 concentration in the stack, and record 
the SO2 concentrations at 10-minute intervals or more often 
at the option of the tester. Adjust the particulate sampling flow rate 
proportionally to the SO2 concentration changes using 
Equation 5H-6 (e.g., the SO2 concentration at the first 10-
minute reading is measured to be 100 ppm; the next 10 minute 
SO2 concentration is measured to be 75 ppm: the particulate 
sample flow rate is adjusted from the initial 0.15 cfm to 0.20 cfm). A 
check for proportional rate variation shall be made at the completion of 
the test run using Equation 5H-10.
    5.2.2  Volumetric Flow Rate Procedure. Apply stoichiometric 
relationships to the wood combustion process in determining the exhaust 
gas flow rate as follows:
    5.2.2.1  Test Fuel Charge Weight. Record the test fuel charge weight 
in kilograms (wet) as specified in Method 28, Section 6.4.2. The wood is 
assumed to have the following weight percent composition: 51 percent 
carbon, 7.3 percent hydrogen, 41 percent oxygen. Record the wood 
moisture for each wood charge as described in Method 28, Section 6.2.5. 
The ash is assumed to have negligible effect on associated C, H, O 
concentrations after the test burn.
    5.2.2.2  Measured Values. Record the CO and CO2 
concentrations in the stack on a dry basis every 10 minutes during the 
test run or more often at the option of the tester. Average these values 
for the test run. Use as a mole fraction (e.g., 10 percent 
CO2 is recorded as 0.10) in the calculations to express total 
flow Equation 5H-7.
    5.2.3  Particulate Train Operation. For each run, record the data 
required on a data sheet such as the one shown in Figure 5H-3. Be sure 
to record the initial dry gas meter reading. Record the dry gas meter 
readings at the beginning and end of each sampling time increment, when 
changes in flow rates are made, before and after each leak-check, and 
when sampling is halted. Take other readings as indicated on Figure 5H-3 
at least once each 10 minutes during the test run.
    Remove the nozzle cap, verify that the filter and probe heating 
systems are up to temperature, and that the probe is properly 
positioned. Position the nozzle, if used, facing into gas stream, or the 
probe tip in the 50 mm (2 in.) centroidal area of the stack.
    Be careful not to bump the probe tip into the stack wall when 
removing or inserting the probe through the porthole; this minimizes the 
chance of extracting deposited material.
    When the probe is in position, block off the openings around the 
probe and porthole to prevent unrepresentative dilution of the gas 
stream.
    Begin sampling at the start of the test run as defined in Method 28, 
Section 6.4.1, start the sample pump, and adjust the sample flow rate to 
between 0.003 and 0.015 m\3\/min (0.1 and 0.5 cfm). Adjust the sample 
flow rate proportionally to the stack flow during the test run (Section 
5.2.1), and maintain a proportional sampling rate (within 10 percent of 
the desired value) and a filter holder temperature no greater than 120 
deg.C (248  deg.F).
    During the test run, make periodic adjustments to keep the 
temperature around the filter holder at the proper level. Add more ice 
to the impinger box and, if necessary, salt to maintain a temperature of 
less than 20  deg.C (68  deg.F) at the condenser/silica gel outlet.
    If the pressure drop across the filter becomes too high, making 
sampling difficult to maintain, either filter may be replaced during a 
sample run. It is recommended that another complete filter assembly be 
used rather than attempting to change the filter itself. Before a new 
filter assembly is installed, conduct a leak-check (see Section

[[Page 791]]

5.1.4.2). The total particulate weight shall include the summation of 
all filter assembly catches. The total time for changing sample train 
components shall not exceed 10 minutes. No more than one component 
change is allowed for any test run.
    At the end of the test run, turn off the coarse adjust valve, remove 
the probe and nozzle from the stack, turn off the pump, record the final 
dry gas meter reading, and conduct a post-test leak-check, as outlined 
in Section 5.1.4.3.
    5.3  Sample Recovery. Begin recovery of the probe and filter sample 
as described in Method 5, Section 4.2, except that an acetone blank 
volume of about 50 ml may be used. Treat the samples as follows:
    Container No. 1. Carefully remove the filter from the front filter 
holder and place it in its identified petri dish container. Use a pair 
of tweezers and/or clean disposable surgical gloves to handle the 
filter. If it is necessary to fold the filter, do so such that the 
particulate cake is inside the fold. Carefully transfer to the petri 
dish any particulate matter and/or filter fibers which adhere to the 
filter holder gasket, by using a dry Nylon bristle brush and/or a sharp-
edged blade. Seal and label the container.
    Container No. 2. Remove the filter from the back filter holder using 
the same procedures as described above.
    Container No. 3. Same as Method 5, Section 4.2 for Container No. 2. 
except that descriptions of capping and sample transport are not 
applicable if sample recovery and analysis occur in the same room.
    Container No. 4. Treat the impingers as follows: Measure the liquid 
which is in the first three impingers to within 1 ml by using a 
graduated cylinder or by weighing it to within 0.5 g by using a balance 
(if one is available). Record the volume or weight of liquid present. 
This information is required to calculate the moisture content of the 
effluent gas.
    Transfer the water from the first, second and third impingers to a 
glass container. Tighten the lid on the sample container so that water 
will not leak out. Rinse impingers and graduated cylinder, if used, with 
acetone three times or more. Avoid direct contact between the acetone 
and any stopcock grease or collection of any stopcock grease in the 
rinse solutions. Add these rinse solutions to sample Container No. 3.
    Whenever possible, containers should be transferred in such a way 
that they remain upright at all times. Descriptions of capping and 
transport of samples are not applicable if sample recovery and analysis 
occur in the same room.
    Container No. 5. Transfer the silica gel from the fourth impinger to 
its original container and seal. A funnel may make it easier to pour the 
silica gel without spilling. A rubber policeman may be used as an aid in 
removing the silica gel from the impinger. It is not necessary to remove 
the small amount of dust particles that may adhere to the impinger wall 
and are difficult to remove. Since the gain in weight is to be used for 
moisture calculations, do not use any water or other liquids to transfer 
the silica gel. If a balance is available, follow the procedure for 
Container No. 5 in Section 5.4.
    5.4  Analysis. Record the data required on a sheet such as the one 
shown in Figure 5H-4. Handle each sample container as follows:
    Containers No. 1 and 2. Leave the contents in the shipping container 
or transfer both of the filters and any loose particulate from the 
sample container to a tared glass weighing dish. Desiccate for no more 
than 36 hours. Weigh to a constant weight and report the results to the 
nearest 0.1 mg. For purposes of this Section, 5.6, the term ``constant 
weight'' means a difference of no more than 0.5 mg or 1 percent of total 
weight less tare weight, whichever is greater, between two consecutive 
weighings, with no less than 2 hours between weighings.
    Container No. 3. Note the level of liquid in the container and 
confirm on the analysis sheet whether leakage occurred during transport. 
If a noticeable amount of leakage has occurred, either void the sample 
or use methods, subject to the approval of the Administrator, to correct 
the final results. Determination of sample leakage is not applicable if 
sample recovery and analysis occur in the same room. Measure the liquid 
in this container either volumetrically to within 1 ml or 
gravimetrically to within 0.5 g. Transfer the contents to a tared 250-ml 
or smaller beaker, and evaporate to dryness at ambient temperature and 
pressure. Desiccate and weigh to a constant weight. Report the results 
to the nearest 0.1 mg.
    Container No. 4. Note the level of liquid in the container and 
confirm on the analysis sheet whether leakage occurred during transport. 
If a noticeable amount of leakage has occurred, either void the sample 
or use methods, subject to the approval of the Administrator, to correct 
the final results. Determination of sample leakage is not applicable if 
sample recovery and analysis occur in the same room. Measure the liquid 
in this container either volumetrically to within 1 ml or 
gravimetrically to within 0.5 g. Transfer the contents to a 500 ml or 
larger separatory funnel. Rinse the container with water, and add to the 
separatory funnel. Add 25 ml of dichloromethane to the separatory 
funnel, stopper and vigorously shake 1 minute, let separate and transfer 
the dichloromethane (lower layer) into a tared beaker or evaporating 
dish. Repeat twice more. It is necessary to rinse the Container No. 4 
with dichloromethane. This rinse is added to the impinger extract 
container. Transfer the remaining water from the separatory funnel to a 
tared beaker or

[[Page 792]]

evaporating dish and evaporate to dryness at 220  deg.F (105  deg.C). 
Desiccate and weigh to a constant weight. Evaporate the combined 
impinger water extracts at ambient temperature and pressure. Desiccate 
and weigh to a constant weight. Report both results to the nearest 0.1 
mg.
    Container No. 5. Weigh the spent silica gel (or silica gel plus 
impinger) to the nearest 0.5 g using a balance.
    ``Acetone Blank'' Container. Measure acetone in this container 
either volumetrically or gravimetrically. Transfer the acetone to a 
tared 250-ml or smaller beaker, and evaporate to dryness at ambient 
temperature and pressure. Desiccate and weigh to a constant weight. 
Report the results to the nearest 0.1 mg.
    ``Dichloromethane'' Container. Measure 75 ml of dichloromethane in 
this container and treat it the same as the ``acetone blank.''
    ``Water Blank'' Container. Measure 200 ml water into this container 
either volumetrically or gravemetrically. Transfer the water to a tared 
250-ml beaker and evaporate to dryness at 105  deg.C (221  deg.F). 
Desiccate and weigh to a constant weight.

                             6. Calibration

    Maintain a laboratory record of all calibrations.
    6.1  Volume Metering System.
    6.1.1  Initial and Periodic Calibration. Before the first 
certification or audit test and at least semiannually, thereafter, 
calibrate the volume metering system as described in Method 5G, Section 
5.2.1.
    6.1.2  Calibration After Use. Same as Method 5G, Section 5.2.2.
    6.1.3  Acceptable Variation in Calibration. Same as Method 5G, 
Section 5.2.3.
    6.2  Probe Heater Calibration. (Optional) The probe heating system 
shall be calibrated before the first certification or audit test. Use 
the procedure described in Method 5, Section 5.4.
    6.3  Temperature Gauges. Use the procedure in Method 2, Section 4.3, 
to calibrate in-stack temperature gauges before the first certification 
or audit test and semiannually, thereafter.
    6.4  Leak-Check of Metering System Shown in Figure 5H-1. That 
portion of the sampling train from the pump to the orifice meter shall 
be leak-checked after each certification or audit test. Use the 
procedure described in Method 5, Section 5.6.
    6.5  Barometer. Calibrate against a mercury barometer before the 
first certification test and semiannually, thereafter. If a mercury 
barometer is used, no calibration is necessary. Follow the 
manufacturer's instructions for operation.
    6.6   SO2 Injection Rotameter. Calibrate the 
SO2 injection rotameter system with a soap film flowmeter or 
similar direct volume measuring device with an accuracy of  
2 percent. Operate the rotameter at a single reading for at least three 
calibration runs for 10 minutes each. When three consecutive calibration 
flow rates agree within 5 percent, average the three flow rates, mark 
the rotameter at the calibrated setting, and use the calibration flow 
rate as the SO2 injection flow rate during the test run. 
Repeat the rotameter calibration before the first certification test and 
semiannually, thereafter.
    6.7  Analyzer Calibration Error Check. Conduct the analyzer 
calibration error check prior to each certification test.
    6.7.1  Calibration Gas Injection. After the flow rate measurement 
system and the tracer gas measurement system have been prepared for use 
(Sections 5.1.5.2 and 5.1.6), introduce zero gases and then the mid-
level calibration gases for each analyzer. Set the analyzers' output 
responses to the appropriate levels. Then introduce the low-level and 
high-level calibration gases, one at a time, for each analyzer. Record 
the analyzer responses.
    6.7.2  Acceptability Values. If the linear curve for any analyzer 
determined from the zero and mid-level calibration gases' responses does 
not predict the actual responses of the low-level and high-level gases 
within 2 percent of the span value, the calibration of that analyzer 
shall be considered invalid. Take corrective measures on the measurement 
system before repeating the calibration error check and proceeding with 
the test runs.
    6.8  Measurement System Response Time. Introduce zero gas at the 
calibration gas valve into the flow rate measurement system and the 
tracer gas measurement system until all readings are stable. Then, 
quickly switch to introduce the mid-level calibration gas at the 
calibration value until a stable value is obtained. A stable value is 
equivalent to a change of less than 1 percent of span value for 30 
seconds. Record the response time. Repeat the procedure three times. 
Conduct the response time check for each analyzer separately before its 
initial use and at least semiannually thereafter.
    6.9  Measurement System Drift Checks. Immediately prior to the start 
of each test run (within 1 hour of the test run start), introduce zero 
and mid-level calibration gases, one at a time, to each analyzer through 
the calibration valve. Adjust the analyzers to respond appropriately. 
Immediately following each test run (within 1 hour of the end of the 
test run), or if adjustments to the analyzers or measurement systems are 
required during the test run, reintroduce the zero- and mid-level 
calibration gases and record the responses, as described above. Make no 
adjustments to the analyzers or the measurement system until after the 
drift checks are made.
    If the difference between the analyzer responses and the known 
calibration gas values exceed the specified limits (Sections 4.2

[[Page 793]]

and 4.3), the test run will be considered invalid and shall be repeated 
following corrections to the measurement system. Alternatively, 
recalibrate the measurement system and recalculate the measurement data. 
Report the test run results using both the initial and final calibration 
data.
    6.10  Analytical Balance. Perform a multipoint calibration (at least 
five points spanning the operational range) of the analytical balance 
before the first certification test and semiannually, thereafter. Before 
each certification test, audit the balance by weighing at least one 
calibration weight (class F) that corresponds to 50 to 150 percent of 
the weight of one filter. If the scale cannot reproduce the value of the 
calibration weight to within 0.1 mg, conduct the multipoint calibration 
before use.

                             7. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after the final 
calculation. Other forms of the equations may be used as long as they 
give equivalent results.
    7.1  Nomenclature.

a=Sample flow rate adjustment factor.
BR=dry wood burn rate, kg/hr (lb/hr), from Method 28, Section 8.3.
Bws=Water vapor in the gas stream, proportion by volume.
cs=Concentration of particulate matter in stack gas, dry 
          basis, corrected to standard conditions, g/dsm \3\ (g/dscf).
E=Particulate emission rate, g/hr.
 H=Average pressure differential across the orifice meter (see 
          Figure 5H-1), mm H2O (in. H2O).
La=Maximum acceptable leakage rate for either a post-test 
          leak check or for a leak-check following a component change; 
          equal to 0.00057 m \3\/min (0.02 cfm) or 4 percent of the 
          average sampling rate, whichever is less.
L1=Individual leakage rate observed during the leak-check 
          conducted before a component change, m \3\/min (cfm).
Lp=Leakage rate observed during the post-test leak-check, m 
          \3\/min (cfm).
mn=Total amount of particulate matter collected, mg.
ma=Mass of residue of solvent after evaporation, mg.
NC=Gram atoms of carbon/gram of dry fuel (lb/lb), equal to 
          0.0425.
NT=Total dry moles of exhaust gas/Kg of dry wood burned, g-
          moles/kg (lb-moles/lb).
PR=Percent of proportional sampling rate.
Pbar=Barometric pressure at the sampling site, mm Hg (in. 
          Hg).
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
Qsd=Total gas flow rate, dsm \3\/hr (dscf/hr).
QT=Flow of tracer gas, liters/min.
Si=Concentration measured at the SO2 analyzer for 
          the ``ith'' 10 minute interval, ppm.
S1=Concentration measured at the SO2 analyzer for 
          the first 10-minute interval, ppm.
T1=Absolute average stack gas temperature for the first 10-
          minute interval,  deg. K ( deg. R).
Ti=Absolute average stack gas temperature at the 
          ``ith'' 10-minute interval,  deg. K ( deg. R).
Tm=Absolute average dry gas meter temperature (see Figure 5H-
          3),  deg. K ( deg. R).
Tstd=Standard absolute temperature, 293  deg. K (528  deg. 
          R).
Va=volume of solvent blank, ml.
Vaw=Volume of solvent used in wash, ml.
Vlc=Total volume of liquid collected in impingers and silica 
          gel (see Figure 5H-4), ml.
Vm=Volume of gas sample as measured by dry gas meter, dm \3\ 
          (dcf).
Vm(std)=Volume of gas sample measured by the dry gas meter, 
          corrected to standard conditions, dsm \3\ (dscf).
Vml(std)=Volume of gas sample measured by the dry gas meter 
          during the first 10-minute interval, corrected to standard 
          conditions, dsm \3\ (dscf).
Vmi(std)=Volume of gas sample measured by the dry gas meter 
          during the ``ith'' 10-minute interval, dsm \3\ 
          (dscf).
Vw(std)=Volume of water vapor in the gas sample, corrected to 
          standard conditions, sm \3\ (scf).
Wa=Weight of residue in solvent wash, mg.
Y=Dry gas meter calibration factor.
YCO=Measured mole fraction of CO (dry), average from Section 
          5.2.2.2, g/g-mole (lb/lb-mole).
YCO2=Measured mole fraction of CO2 (dry), average 
          from Section 5.2.2.2, g/g-mole (lb/lb-mole).
YHC=Assumed mole fraction of HC (dry), g/g-mole (lb/lb-mole);
    =0.0088 for catalytic wood heaters;
    =0.0132 for non-catalytic wood heaters;
    =0.0080 for pellet-fired wood heaters.
10=Length of first sampling period, minutes.
13.6=Specific gravity of mercury.
100=Conversion to percent.
=Total sampling time, min.
1=Sampling time interval, from the beginning of a 
          run until the first component change, min.

    7.2  Average dry gas meter temperature and average orifice pressure 
drop. See data sheet (Figure 5H-3).
    7.3  Dry Gas Volume. Correct the sample volume measured by the dry 
gas meter to standard conditions (20  deg.C, 760 mm Hg or 68  deg.F, 
29.92 in. Hg) by using Equation 5H-1.

[[Page 794]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.118

where;
K1=0.3858 0 K/m. Hg for metric units.
  =17.64 0 R/in. Hg for English units.
    Note: Equation 5H-1 can be used as written unless the leakage rate 
observed during any of the mandatory leak-checks (i.e., the post-test 
leak-check or leak-check conducted before a component change) exceeds 
La.

    If Lp exceeds La, Equation 5H-1 must be 
modified as follows:
    (a) Case I. No component changes made during sampling run. In this 
case, replace Vm in Equation 5H-1 with the expression:
[Vm-(Lp-La)]

    (b) Case II. One component change made during the sampling run. In 
this case, replace Vm in Equation 5H-1 by the expression:

Vm-(L1-La)1

and substitute only for those leakage rates (L1 or 
Lp) which exceed La.
    7.4  Volume of Water Vapor.

Vw(std)=K2Vlc      Eq. 5H-2

where:
K2=0.001333 m\3\/ml for metric units
  =0.04707 ft\3\/ml for English units.

    7.5  Moisture Content.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.119
    
    7.6  Solvent Wash Blank.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.120
    
    7.7  Total Particulate Weight. Determine the total particulate catch 
from the sum of the weights obtained from containers 1, 2, 3, and 4 less 
the appropriate solvent blanks (see Figure 5H-4).
    Note: Refer to Method 5, Section 4.1.5 to assist in calculation of 
results involving two filter assemblies.
    7.8  Particulate Concentration.

cs=(0.001 g/mg) (mn/Vm(std))
      Eq. 5H-5

    7.9  Sample Flow Rate Adjustment.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.147
    
    7.10  Carbon Balance for Total Moles of Exhaust Gas (dry)/Kg of Wood 
Burned in the Exhaust Gas.
[GRAPHIC] [TIFF OMITTED] TC01JN92.121

where:

K3=1000 g/kg for metric units.
K3=1.0 lb/lb for English units.
    Note: The NOx/SOx portion of the gas is 
assumed to be negligible.
    7.11  Total Stack Gas Flow Rate.

Qsd=K4 NTBR
                                                                Eq. 5H-8

where:

K4=0.02406 for metric units, dsm\3\/g-mole.
  =384.8 for English units, dscf/lb-mole.
    7.12  Particulate Emission Rate.

E=cs Qsd
                                                                Eq. 5H-9
    7.13  Proportional Rate Variation. Calculate PR for each 10-minute 
interval, i, of the test run.
[GRAPHIC] [TIFF OMITTED] TC01JN92.122

    7.14  Acceptable Results. If no more than 15 percent of the PR 
values for all the intervals exceed 90 percent  PR 
 110 percent, and if no PR value for any interval exceeds 75 


[[Page 795]]

PR  125 percent, the results are acceptable. If the PR values 
for the test runs are judged to be unacceptable, report the test run 
emission results, but do not include the test run results in calculating 
the weighted average emission rate, and repeat the test.

                             8. Bibliography

    1. Same as for Method 5, citations 1 through 11, with the addition 
of the following:
    2. Oregon Department of Environmental Quality Standard Method for 
Measuring the emissions and efficiencies of Woodstoves, July 8, 1984. 
Pursuant to Oregon Administrative Rules Chapter 340, Division 21.
    3. American Society for Testing Materials. Proposed Test Methods for 
Heating Performance and Emissions of Residential Wood-fired Closed 
Combustion-Chamber Heating Appliances. E-6 Proposal P 180. August 1986.

[[Page 796]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.123


[[Page 797]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.124


[[Page 798]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.125


[[Page 799]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.126

  Method 6--Determination of Sulfur Dioxide Emissions From Stationary 
                                 Sources

1. Principle and Applicability

    1.1  Principle. A gas sample is extracted from the sampling point in 
the stack. The sulfuric acid mist (including sulfur trioxide)

[[Page 800]]

and the sulfur dioxide are separated. The sulfur dioxide fraction is 
measured by the barium-thorin titration method.
    1.2  Applicability. This method is applicable for the determination 
of sulfur dioxide emissions from stationary sources. The minimum 
detectable limit of the method has been determined to be 3.4 milligrams 
(mg) of SO2/m3 (2.12 x 10-7 lb/
ft3). Although no upper limit has been established, tests 
have shown that concentrations as high as 80,000 mg/m3 of 
SO2 can be collected efficiently in two midget impingers, 
each containing 15 milliliters of 3 percent hydrogen peroxide, at a rate 
of 1.0 lpm for 20 minutes. Based on theoretical calculations, the upper 
concentration limit in a 20-liter sample is about 93,300 mg/m3.
    Possible interferents are free ammonia, water-soluble cations, 
and fluorides. The cations and fluorides are removed by glass wool 
filters and an isopropanol bubbler, and hence do not affect the SO2 
analysis. When samples are being taken from a gas stream with high 
concentrations of very fine metallic fumes (such as in inlets to control 
devices), a high-efficiency glass fiber filter must be used in place of 
the glass wool plug (i.e., the one in the probe) to remove the cation 
interferents.
    Free ammonia interferes by reacting with SO2 to form 
particulate sulfite and by reacting with the indicator. If free ammonia 
is present (this can be determined by knowledge of the process and the 
presence of white particulate matter in the probe and isopropanol 
bubbler), the alternative procedures in Section 7.2 shall be used.

[[Page 801]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.127

2. Apparatus

    2.1  Sampling. The sampling train is shown in Figure 6-1, and 
component parts are discussed below. The tester has the option of 
substituting sampling equipment described in Method 8 in place of the 
midget impinger equipment of Method 6. However,

[[Page 802]]

the Method 8 train must be modified to include a heated filter between 
the probe and isopropanol impinger, and the operation of the sampling 
train and sample analysis must be at the flow rates and solution volumes 
defined in Method 8.
    The tester also has the option of determining SO2 
simultaneously with particulate matter and moisture determinations by 
(1) replacing the water in a Method 5 impinger system with 3 percent 
peroxide solution, or (2) by replacing the Method 5 water impinger 
system with a Method 8 isopropanol-filter-peroxide system. The analysis 
for SO2 must be consistent with the procedure in Method 8.
    2.1.1  Probe. Borosilicate glass, or stainless steel (other 
materials of construction may be used, subject to the approval of the 
Administrator), approximately 6-mm inside diameter, with a heating 
system to prevent water condensation and a filter (either in-stack or 
heated out-stack) to remove particulate matter, including sulfuric acid 
mist. A plug of glass wool is a satisfactory filter.
    2.1.2  Bubbler and Impingers. One midget bubbler, with medium-coarse 
glass frit and borosilicate or quartz glass wool packed in top (see 
Figure 6-1) to prevent sulfuric acid mist carryover, and three 30-ml 
midget impingers. The bubbler and midget impingers must be connected in 
series with leak-free glass connectors. silicone grease may be used, if 
necessary, to prevent leakage.
    At the option of the tester, a midget impinger may be used in place 
of the midget bubbler.
    Other collection absorbers and flow rates may be used, but are 
subject to the approval of the Administrator. Also, collection 
efficiency must be shown to be at least 99 percent for each test run and 
must be documented in the report. If the efficiency is found to be 
acceptable after a series of three tests, further documentation is not 
required. To conduct the efficiency test, an extra absorber must be 
added and analyzed separately. This extra absorber must not contain more 
than 1 percent of the total SO2.
    2.1.3  Glass Wool. Borosilicate or quartz.
    2.1.4  Stopcock Grease. Acetone-insoluble, heatstable silicone 
grease may be used, if necessary.
    2.1.5  Temperature Gauge. Dial thermometer, or equivalent, to 
measure temperature of gas leaving impinger train to within 1  deg.C (2 
deg.F.)
    2.1.6  Drying Tube. Tube packed with 6- to 16-mesh indicating type 
silica gel, or equivalent, to dry the gas sample and to protect the 
meter and pump. If the silica gel has been used previously, dry at 175 
deg.C (350  deg.F) for 2 hours. New silica gel may be used as received. 
Alternatively, other types of desiccants (equivalent or better) may be 
used, subject to approval of the Administrator.
    2.1.7  Valve. Needle valve, to regulate sample gas flow rate.
    2.1.8  Pump. Leak-free diaphragm pump, or equivalent, to pull gas 
through the train. Install a small surge tank between the pump and rate 
meter to eliminate the pulsation effect of the diaphragm pump on the 
rotameter.
    2.1.9  Rate Meter. Rotameter, or equivalent, capable of measuring 
flow rate to within 2 percent of the selected flow rate of about 1000 
cc/min.
    2.1.10  Volume Meter. Dry gas meter, sufficiently accurate to 
measure the sample volume within 2 percent, calibrated at the selected 
flow rate and conditions actually encountered during sampling, and 
equipped with a temperature gauge (dial thermometer, or equivalent) 
capable of measuring temperature to within 3  deg.C (5.4  deg.F).
    2.1.11  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg). In many 
cases, the barometric reading may be obtained from a nearby National 
Weather Service station, in which case the station value (which is the 
absolute barometric pressure) shall be requested and an adjustment for 
elevation differences between the weather station and sampling point 
shall be applied at a rate of minus 2.5 mm Hg (0.1 in. Hg) per 30 m (100 
ft) elevation increase or vice versa for elevation decrease.
    2.1.12  Vacuum Gauge and Rotameter. At least 760 mm Hg (30 in. Hg) 
gauge and 0-40 cc/min rotameter, to be used for leak check of the 
sampling train.
    2.2  Sample Recovery.
    2.2.1  Wash Bottles. Polyethylene or glass, 500 ml, two.
    2.2.2  Storage Bottles. Polyethylene, 100 ml, to store impinger 
samples (one per sample).
    2.3  Analysis.
    2.3.1  Pipettes. Volumetric type, 5-ml, 20-ml (one per sample), and 
25-ml sizes.
    2.3.2  Volumetric Flasks. 100-ml size (one per sample) and 1000 ml 
size.
    2.3.3  Burettes. 5- and 50-ml sizes.
    2.3.4  Erlenmeyer Flasks. 250 ml-size (one for each sample, blank, 
and standard).
    2.3.5  Dropping Bottle. 125-ml size, to add indicator.
    2.3.6  Graduated Cylinder. 100-ml size.
    2.3.7  Spectrophotometer. To measure absorbance at 352 nanometers.

3. Reagents

    Unless otherwise indicated, all reagents must conform to the 
specifications established by the Committee on Analytical Reagents of 
the American Chemical Society. Where such specifications are not 
available, use the best available grade.
    3.1  Sampling.

[[Page 803]]

    3.1.1  Water. Deionized distilled to conform to ASTM Specification 
D1193-77, Type 3 (incorporated by reference--see Sec. 60.17). At the 
option of the analyst, the KMnO4 test for oxidizable organic 
matter may be omitted when high concentrations of organic matter are not 
expected to be present. Unless otherwise specified, this water shall be 
used throughout this method.
    3.1.2  Isopropanol, 80 percent. Mix 80 ml of isopropanol with 20 ml 
of water. Check each lot of isopropanol for peroxide impurities as 
follows: shake 10 ml of isopropanol with 10 ml of freshly prepared 10 
percent potassium iodide solution. Prepare a blank by similarly treating 
10 ml of water. After 1 minute, read the absorbance at 352 nanometers on 
a spectrophotometer. If absorbance exceeds 0.1, reject alcohol for use.
    Peroxides may be removed from isopropanol by redistilling or by 
passage through a column of activated alumina; however, reagent grade 
isopropanol with suitably low peroxide levels may be obtained from 
commercial sources. Rejection of contaminated lots may, therefore, be a 
more efficient procedure.
    3.1.3  Hydrogen Peroxide, 3 Percent. Dilute 30 percent hydrogen 
peroxide 1:9 (v/v) with water (30 ml is needed per sample). Prepare 
fresh daily.
    3.1.4  Potassium Iodide Solution, 10 Percent. Dissolve 10.0 grams KI 
in water and dilute to 100 ml. Prepare when needed.
    3.2  Sample Recovery.
    3.2.1  Water. Same as in Section 3.1.1.
    3.2.2  Isopropanol, 80 Percent. Mix 80 ml of isopropanol with 20 ml 
of water.
    3.3  Analysis.
    3.3.1  Water. Same as in Section 3.1.1.
    3.3.2  Isopropanol, 100 Percent.
    3.3.3  Thorin Indicator. 1-(o-arsonophenylazo)-2-naphthol-3,6-
disulfonic acid, disodium salt, or equivalent. Dissolve 0.20 g in 100 ml 
of water.
    3.3.4  Barium Perchlorate Solution, 0.0100 N. Dissolve 1.95 g of 
barium perchlorate trihydrate 
[Ba(ClO4)23H2O] in 200 ml water 
and dilute to 1 liter with isopropanol. Alternatively, 1.22 g of 
[BaCl22H2O] may be used instead of the 
perchlorate. Standardize as in Section 5.5.
    3.3.5  Sulfuric Acid Standard, 0.0100 N. Purchase or standardize to 
plus-minus0.0002 N against 0.0100 N NaOH which has previously 
been standardized against potassium acid phthalate (primary standard 
grade).
    3.3.6  Quality Assurance Audit Samples. Sulfate samples in glass 
vials prepared by EPA's Environmental Monitoring Systems Laboratory, 
Quality Assurance Division, Source Branch, Mail Drop 77A, Research 
Triangle Park, North Carolina 27711. Each set will consist of two vials 
having solutions of unknown concentrations. Only when making compliance 
determinations, obtain an audit sample set from the Quality Assurance 
Management office at each EPA regional Office or the responsible 
enforcement agency. (Note: The tester should notify the quality 
assurance office or the responsible enforcement agency at least 30 days 
prior to the test date to allow sufficient time for sample delivery.)
    3.3.7  Hydrochloric Acid (HCl) Solution, 0.1 N (for use in Section 
7.2). Carefully pipette 8.6 ml of concentrated HCl into a 1-liter 
volumetric flask containing water. Dilute to volume with mixing.

4. Procedure

    4.1  Sampling.
    4.1.1  Preparation of Collection Train. Measure 15 ml of 80 percent 
isopropanol into the midget bubbler and 15 ml of 3 percent hydrogen 
peroxide into each of the first two midget impingers. Leave the final 
midget impinger dry. Assemble the train as shown in Figure 6-1. Adjust 
probe heater to a temperature sufficient to prevent water condensation. 
Place crushed ice and water around the impingers.
    4.1.2  Leak-Check Procedure. A leak check prior to the sampling run 
is optional; however, a leak check after the sampling run is mandatory. 
The leak-check procedure is as follows:
    Temporarily attach a suitable (e.g., 0-40 cc/min) rotameter to the 
outlet of the dry gas meter and place a vacuum gauge at or near the 
probe inlet. Plug the probe inlet, pull a vaccum of at least 250 mm Hg 
(10 in. Hg), and note the flow rate as indicated by the rotameter. A 
leakage rate not in excess of 2 percent of the average sampling rate is 
acceptable.
    Note: Carefully release the probe inlet plug before turning off the 
pump.
    It is suggested (not mandatory) that the pump be leak-checked 
separately, either prior to or after the sampling run. If done prior to 
the sampling run, the pump leak-check shall precede the leak check of 
the sampling train described immediately above; if done after the 
sampling run, the pump leak-check shall follow the train leak-check. To 
leak check the pump, proceed as follows: Disconnect the drying tube from 
the probe-impinger assembly. Place a vacuum gauge at the inlet to either 
the drying tube or the pump, pull a vacuum of 250 mm (10 in.) Hg, plug 
or pinch off the outlet of the flow meter and then turn off the pump. 
The vacuum should remain stable for at least 30 seconds.
    Other leak-check procedures may be used, subject to the approval of 
the Adminstrator, U.S. Environmental Protection Agency.
    4.1.3  Sample Collection. Record the initial dry gas meter reading 
and barometric pressure. To begin sampling, position the tip of the 
probe at the sampling point, connect the probe to the bubbler, and start 
the pump. Adjust the sample flow to a constant rate of approximately 1.0 
liter/min as indicated by the

[[Page 804]]

rotameter. Maintain this constant rate (plus-minus10 percent) 
during the entire sampling run. Take readings (dry gas meter, 
temperatures at dry gas meter and at impinger outlet, and rate meter) at 
least every 5 minutes. Add more ice during the run to keep the 
temperature of the gases leaving the last impinger at 20  deg.C (68 
deg.F) or less. At the conclusion of each run, turn off the pump, remove 
probe from the stack, and record the final readings. Conduct a leak 
check as in Section 4.1.2 (This leak check is mandatory.) If a leak is 
found, void the test run, or use procedures acceptable to the 
Administrator to adjust the sample volume for the leakage. Drain the ice 
bath, and purge the remaining part of the train by drawing clean ambient 
air through the system for 15 minutes at the sampling rate.
    Clean ambient air can be provided by passing air through a charcoal 
filter or through an extra midget impinger with 15 ml of 3 percent 
H2O2. The tester may opt to simply use ambient 
air, without purification.
    4.2  Sample Recovery. Disconnect the impingers after purging. 
Discard the contents of the midget bubbler. Pour the contents of the 
midget impingers into a leak-free polyethylene bottle for shipment. 
Rinse the three midget impingers and the connecting tubes with water, 
and add the washings to the same storage container. Mark the fluid 
level. Seal and identify the sample container.
    4.3  Sample Analysis. Note level of liquid in container, and confirm 
whether any sample was lost during shipment; note this on analytical 
data sheet. If a noticeable amount of leakage has occurred, either void 
the sample or use methods, subject to the approval of the Administrator, 
to correct the final results.
    Transfer the contents of the storage container to a 100-ml 
volumetric flask and dilute to exactly 100 ml with water. Pipette a 20-
ml aliquot of this solution into a 250-ml Erlenmeyer flask, add 80 ml of 
100 percent isopropanol and two to four drops of thorin indicator, and 
titrate to a pink endpoint using 0.0100 N barium perchlorate. Repeat and 
average the titration volumes. Run a blank with each series of samples. 
Replicate titrations must agree within 1 percent or 0.2 ml, whichever is 
larger.
    Note: Protect the 0.0100 N barium perchlorate solution from 
evaporation at all times.
    4.4  Audit Sample Analysis. Concurrently analyze the two audit 
samples and a set of compliance samples (Section 4.3) in the same manner 
to evaluate the technique of the analyst and the standards preparation. 
(Note: It is recommended that known quality control samples be analyzed 
prior to the compliance and audit sample analysis to optimize the system 
accuracy and precision. One source of these samples is the Source Branch 
listed in Section 3.3.6.) The same analysts, analytical reagents, and 
analytical system shall be used both for compliance samples and the EPA 
audit samples; if this condition is met, auditing of subsequent 
compliance analyses for the same enforcement agency within 30 days is 
not required. An audit sample set may not be used to validate different 
sets of compliance samples under the jurisdiction of different 
enforcement agencies, unless prior arrangements are made with both 
enforcement agencies.
    Calculate the concentrations in mg/dscm using the specified sample 
volume in the audit instructions. (Note: Indication of acceptable 
results may be obtained immediately by reporting the audit results in 
mg/dscm and compliance results in total mg SO2/sample by 
telephone to the responsible enforcement agency.) Include the results of 
both audit samples, their identification numbers, and the analyst's name 
with the results of the compliance determination samples in appropriate 
reports to the EPA regional office or the appropriate enforcement 
agency. Include this information with subsequent compliance analyses for 
the same enforcement agency during the 30-day period.
    The concentrations of the audit samples obtained by the analyst 
shall agree within 5 percent of the actual concentrations. If the 5-
percent specification is not met, reanalyze the compliance samples and 
audit samples, and include initial and reanalysis values in the test 
report (see Note in first paragraph of this section).
    Failure to meet the 5-percent specification may require retests 
until the audit problems are resolved. However, if the audit results do 
not affect the compliance or noncompliance status of the affected 
facility, the Administrator may waive the reanalysis requirement, 
further audits, or retests and accept the results of the compliance 
test. While steps are being taken to resolve audit analysis problems, 
the Administrator may also choose to use the data to determine the 
compliance or noncompliance status of the affected facility.

5. Calibration

    5.1  Metering System.
    5.1.1  Initial Calibration. Before its initial use in the field, 
first leak check the metering system (drying tube, needle valve, pump, 
rotameter, and dry gas meter) as follows: place a vacuum gauge at the 
inlet to the drying tube and pull a vaccum of 250 mm (10 in.) Hg; plug 
or pinch off the outlet of the flow meter, and then turn off the pump. 
The vaccum shall remain stable for at least 30 seconds. Carefully 
release the vaccum gauge before releasing the flow meter end.
    Next, remove the drying tube and calibrate the metering system (at 
the sampling flow

[[Page 805]]

rate specified by the method) as follows: connect an appropriately sized 
wet test meter (e.g., 1 liter per revolution) to the inlet of the drying 
tube. Make three independent calibration runs, using at least five 
revolutions of the dry gas meter per run. Calculate the calibration 
factor, Y (wet test meter calibration volume divided by the dry gas 
meter volume, both volumes adjusted to the same reference temperature 
and pressure), for each run, and average the results. If any Y value 
deviates by more than 2 percent from the average, the metering system is 
unacceptable for use. Otherwise, use the average as the calibration 
factor for subsequent test runs.
    5.1.2  Post-Test Calibration Check. After each field test series, 
conduct a calibration check as in Section 5.1.1 above, except for the 
following variations: (a) the leak check is not to be conducted, (b) 
three, or more revolutions of the dry gas meter may be used, and (c) 
only two independent runs need be made. If the calibration factor does 
not deviate by more than 5 percent from the initial calibration factor 
(determined in Section 5.1.1), then the dry gas meter volumes obtained 
during the test series are acceptable. If the calibration factor 
deviates by more than 5 percent, recalibrate the metering system as in 
Section 5.1.1, and for the calculations, use the calibration factor 
(initial or recalibration) that yields the lower gas volume for each 
test run.
    5.2  Thermometers. Calibrate against mercury-in-glass thermometers.
    5.3  Rotameter. The rotameter need not be calibrated but should be 
cleaned and maintained according to the manufactuturer's instruction.
    5.4  Barometer. Calibrate against a mercury barometer.
    5.5  Barium Perchlorate Solution. Standardize the barium perchlorate 
solution against 25 ml of standard sulfuric acid to which 100 ml of 100 
percent isopropanol has been added.

    Run duplicate analyses. Calculate the normality using the average of 
a pair of duplicate analyses where the titrations agree within 1 percent 
or 0.2 ml, whichever is larger.

6. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after final 
calculation.
    6.1  Nomenclature.

Cso2=Concentration of sulfur dioxide, dry basis corrected to 
          standard conditions, mg/dscm (lb/dscf).
N=Normality of barium perchlorate titrant, milliequivalents/ml.
Pbar=Barometric pressure at the exit orifice of the dry gas 
          meter, mm Hg (in. Hg).
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
Tm=Average dry gas meter absolute temperature,  deg.K 
          ( deg.R).
Tstd=Standard absolute temperature, 293 deg.K (528 deg.R).
Va=Volume of sample aliquot titrated, ml.
Vm=Dry gas volume as measured by the dry gas meter, dcm 
          (dcf).
Vm(std)=Dry gas volume measured by the dry gas meter, 
          corrected to standard conditions, dscm (dscf).
Vsoln=Total volume of solution in which the sulfur dioxide 
          sample is contained, 100 ml.
Vt=Volume of barium perchlorate titrant used for the sample, 
          ml (average or replicate titrations).
Vtb=Volume of barium perchlorate titrant used for the blank, 
          ml.
Y=Dry gas meter calibration factor.
32.03=Equivalent weight of sulfur dioxide.
    6.2  Dry Sample Gas Volume, Corrected to Standard Conditions.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.128
    
Where:
K1=0.3858 deg.K/mm Hg for metric units.
   =17.64 deg.R/in. Hg for English units.

    6.3 Sulfur Dioxide Concentration.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.304
    
Where:

K3=32.03 mg/meq. for metric units.
   =7.061 x 10-5 lb/meq. for English units.
    6.4  Relative Error (RE) for QA Audit Samples, Percent.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.148
    
Where:

Cd=Determined audit sample concentration, mg/dscm.
Ca=Actual audit sample concentration, mg/dscm.

7. Alternative Procedures

    7.1  Dry Gas Meter as a Calibration Standard. A dry gas meter may be 
used as a calibration standard for volume measurements in place of the 
wet test meter specified in Section 5.1, provided that it is calibrated 
initially and recalibrated periodically according to the same procedures 
outlined in Method 5, Section 7.1, with the following exception: (1) the 
dry gas meter is calibrated against a wet test meter having a capacity 
of

[[Page 806]]

1 liter/rev or 3 liters/rev and having the capability of measuring 
volume to within 1 percent; (2) the dry gas meter is 
calibrated at 1 liter/min (2 cfh); and (3) the meter box of the Method 6 
sampling train is calibrated at the same flow rate.
    7.2  Critical Orifices for Volume and Rate Measurements. A critical 
orifice may be used in place of the dry gas meter specified in Section 
2.1.10, provided that it is selected, calibrated, and used as follows:
    7.2.1  Preparation of Collection Train. Prepare the sampling train 
as shown in Figure 6-2. The rotameter and surge tank are optional but 
are recommended in order to detect changes in the flow rate.
    Note: The critical orifices can be adapted to a Method 6 type 
sampling train as follows: Insert sleeve type, serum bottle stoppers 
into two reducing unions. Insert the needle into the stoppers as shown 
in Figure 6-3.

[[Page 807]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.129


[[Page 808]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.130

    7.2.2  Selection of Critical Orifices. The procedure that follows 
describes the use of hypodermic needles and stainless steel needle 
tubings, which have been found suitable for use as critical orifices. 
Other materials and critical orifice designs may be used provided the 
orifices act as true critical orifices, i.e., a critical vacuum can be 
obtained, as described in this section. Select a critical orifice that 
is sized to operate at the desired flow rate. The needle sizes and 
tubing lengths shown below give the following approximate flow rates.

------------------------------------------------------------------------
                     Flow rate, cc/                       Flow rate, cc/
     Gauge/cm              min             Gauge/cm            min
------------------------------------------------------------------------
       21/7.6              1100             23/3.8              500
       22/2.9              1000             23/5.1              450
       22/3.8               900             24/3.2              400
------------------------------------------------------------------------

    Determine the suitability and the appropriate operating vaccum of 
the critical orifice as follows: If applicable, temporarily attach a 
rotameter and surge tank to the outlet of the sampling train. Turn on 
the pump, and adjust the valve to give an outlet vacuum reading 
corresponding to about half of the atmospheric pressure. Observe the 
rotameter reading. Slowly increase the vacuum until a stable reading is 
obtained on the rotameter. Record the critical vacuum, which is the 
outlet vacuum when the rotameter first reaches a stable value. Orifices 
that do not reach a critical value shall not be used.
    7.2.3  Field Procedure.
    7.2.3.1  Leak-Check Procedure. A leak-check before the sampling run 
is recommended, but is optional. The leak-check procedure is as follows:
    Temporarily attach a suitable (e.g., 0-40 cc/min) rotameter and 
surge tank, or a soap bubble meter and surge tank to the outlet of the 
pump. Plug the probe inlet, pull an outlet vacuum of at least 254 mm Hg 
(10 in. Hg), and note the flow rate as indicated by the rotameter or 
bubble meter. A leakage rate not in excess of 2 percent of the average 
sampling rate (Qstd) is acceptable. Carefully release the 
probe inlet plug before turning off the pump.
    7.2.3.2  Moisture Determination. At the sampling location, prior to 
testing, determine the percent moisture of the ambient air using the wet 
and dry bulb temperatures or, if appropriate, a relative-humidity meter.
    7.2.3.3  Critical Orifice Calibration. Prior to testing, at the 
sampling location, calibrate the entire sampling train using a 500-cc 
soap bubble meter which is attached to the inlet of the probe and an 
outlet vacuum of 25 to 50 mm Hg (1 to 2 in. Hg) above the critical 
vacuum. Record the information listed in Figure 6-4.
    Calculate the standard volume of air measured by the soap bubble 
meter and the volumetric flow rate, using the equations below:

[[Page 809]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.131

where:
Pbar=Barometric pressure, mm Hg (in. Hg).
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
Qstd=Volumetric flow rate through critical orifice, scm/min 
          (scf/min).
Tamb=Ambient absolute temperature of air,  deg.K ( deg.R).
Tstd=Standard absolute temperature, 273 deg.K (528 deg.R).
Vsb=Volume of gas as measured by the soap bubble meter, 
          m3 (ft3).
Vsb(std)=Volume of gas as measured by the soap bubble meter, 
          corrected to standard conditions, scm (scf).
=Time, min.
[GRAPHIC] [TIFF OMITTED] TC01JN92.132


[[Page 810]]


    7.2.3.4  Sampling. Operate the sampling train for sample collection 
at the same vacuum used during the calibration run. Start the watch and 
pump simultaneously. Take readings (temperature, rate meter, inlet 
vacuum, and outlet vacuum) at least every 5 minutes. At the end of the 
sampling run, stop the watch and pump simultaneously.
    Conduct a post-test calibration run using the calibration procedure 
outlined in Section 7.2.3.3. If the Qstd obtained before and 
after the test differ by more than 5 pecent, void the test run; if not, 
calculate the volume of the gas measured with the critical orifice, 
Vm(std), using Equation 6-6 and the average of 
Qstd of both runs, as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.133

where:
Vm(std)=Dry gas volume measured with the critical orifice, 
          corrected to standard conditions, dscm (dscf).
Qstd=Average flow rate of pretest and post-test calibration 
          runs, scm/min (scf/min).
Bwa=Water vapor in ambient air, proportion by volume.
s=Sampling time, min.
Pc=Inlet vacuum reading obtained during the calibration run, 
          mm Hg (in. Hg).
Psr=Inlet vacuum reading obtained during the sampling run, mm 
          Hg (in. Hg).
    If the percent difference between the molecular weight of the 
ambient air at saturated conditions and the sample gas is more than 
#3 percent, then the molecular weight of the gas sample must 
be considered in the calculations using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.134

where:
Ma=Molecular weight of the ambient air saturated at impinger 
          temperature, g/g-mole (lb/lb-mole).
Ms=Molecular weight of the sample gas saturated at impinger 
          temperature, g/g-mole (lb/lb-mole).
    Note: A post-test leak-check is not necessary because the post-test 
calibration run results will indicate whether there is any leakage.
    Drain the ice bath, and purge the sampling train using the procedure 
described in Section 4.1.3.
    7.3  Elimination of Ammonia Interference. The following alternative 
procedures shall be used in addition to those specified in the method 
when sampling at sources having ammonia emissions.
    7.3.1  Sampling. The probe shall be maintained at 275  deg.C and 
equipped with a high-efficiency in-stack filter (glass fiber) to remove 
particulate matter. The filter material shall be unreactive to 
SO2. Whatman 934AH (formerly Reeve Angel 934AH) filters 
treated as described in Citation 10 of the Method 5 bibliography is an 
example of a filter that has been shown to work. Where alkaline 
particulate matter and condensed moisture are present in the gas stream, 
the filter shall be heated above the moisture dew point but below 225 
deg.C.
    7.3.2  Sample Recovery. Recover the sample according to Section 4.2 
except for discarding the contents of the midget bubbler. Add the 
bubbler contents, including the rinsings of the bubbler with water, to 
the polyethylene bottle containing the rest of the sample. Under normal 
testing conditions where sulfur trioxide will not be present 
significantly, the tester may opt to delete the midget bubbler from the 
sampling train. If an approximation of the sulfur trioxide concentration 
is desired, transfer the contents of the midget bubbler to a separate 
polyethylene bottle.
    7.3.3  Sample Analysis. Follow the procedures in Section 4.3, except 
add 0.5 ml of 0.1 N HC1 to the Erlenmeyer flask and mix before adding 
the indicator. The following analysis procedure may be used for an 
approximation of the sulfur trioxide concentration. The accuracy of the 
calculated concentration will depend upon the ammonia to

[[Page 811]]

SO2 ratio and the level of oxygen present in the gas stream. 
A fraction of the SO2 will be counted as sulfur trioxide as 
the ammonia to SO2 ratio and the sample oxygen content 
increases. Generally, when this ratio is 1 or less and the oxygen 
content is in the range of 5 percent, less than 10 percent of the 
SO2 will be counted as sulfur trioxide. Analyze the peroxide 
and isopropanol sample portions separately. Analyze the peroxide portion 
as described above. Sulfur trioxide is determined by difference using 
sequential titration of the isopropanol portion of the sample. Transfer 
the contents of the isopropanol storage container to a 100-ml volumetric 
flask, and dilute to exactly 100 ml with water. Pipette a 20-ml aliquot 
of this solution into a 250-ml Erlenmeyer flask, add 0.5 ml of 0.1 N 
HC1, 80 ml of 100 percent isopropanol, and two to four drops of thorin 
indicator. Titrate to a pink endpoint using 0.0100 N barium perchlorate. 
Repeat and average the titration volumes that agree within 1 percent or 
0.2 ml, whichever is larger. Use this volume in Equation 6-2 to 
determine the sulfur trioxide concentration. From the flask containing 
the remainder of the isopropanol sample, determine the fraction of 
SO2 collected in the bubbler by pipetting 20-ml aliquots into 
250-ml Erlenmeyer flasks. Add 5 ml of 3 percent hydrogen peroxide, 100 
ml of 100 percent isopropanol, and two to four drops of thorin 
indicator, and titrate as before. From this titration volume, subtract 
the titrant volume determined for sulfur trioxide, and add the titrant 
volume determined for the peroxide portion. This final volume 
constitutes Vt, the volume of barium perchlorate used for the 
SO2 sample.

8. Bibliography

    1. Atmospheric Emissions from Sulfuric Acid Manufacturing Processes. 
U.S. DHEW, PHS, Division of Air Pollution. Public Health Service 
Publication No. 999-AP-13. Cincinnati, OH. 1965.
    2. Corbett, P. F. The Determination of SO2 and SO3 
in Flue Gases. Journal of the Institute of Fuel. 24: 237-243, 1961.
    3. Matty, R. E. and E. K. Diehl. Measuring Flue-Gas SO2 
and SO3. Power. 101: 94-97. November 1957.
    4. Patton, W. F. and J. A. Brink, Jr. New Equipment and Techniques 
for Sampling Chemical Process Gases. J. Air Pollution Control 
Association. 13: 162. 1963.
    5. Rom, J. J. Maintenance, Calibration, and Operation of Isokinetic 
Source-sampling Equipment. Office of Air Programs, Environmental 
Protection Agency. Research Triangle Park, NC. APTD-0576. March 1972.
    6. Hamil, H. F. and D. E. Camann. Collaborative Study of Method for 
the Determination of Sulfur Dioxide Emissions from Stationary Sources 
(Fossil-Fuel Fired Steam Generators). Environmental Protection Agency, 
Research Triangle Park, NC. EPA-650/4-74-024. December 1973.
    7. Annual Book of ASTM Standards. Part 31; Water, Atmospheric 
Analysis. American Society for Testing and Materials. Philadelphia, PA. 
1974. pp. 40-42.
    8. Knoll, J. E. and M. R. Midgett. The Application of EPA Method 6 
to High Sulfur Dioxide Concentrations. Environmental Protection Agency. 
Research Triangle Park, NC. EPA-600/4-76-038. July 1976.
    9. Westlin, P. R. and R. T. Shigehara. Procedure for Calibrating and 
Using Dry Gas Meter Volume Meters as Calibration Standards. Source 
Evaluation Society Newsletter. 3(1):17-30. February 1978.
    10. Yu, K. K. Evaluation of Moisture Effect on Dry Gas Meter 
Calibration. Source Evaluation Society Newsletter. 5(1):24-28. February 
1980.
    11. Lodge, J.P., Jr., J.B. Pate, B.E. Ammons, and G.A. Swanson. The 
Use of Hypodermic Needles as Critical Orifices in Air Sampling. J. Air 
Pollution Control Association. 16:197-200. 1966.
    12. Shigehara, R.T., and Candace B. Sorrell. Using Critical Orifices 
as Method 5 Calibration Standards. Source Evaluation Society Newsletter. 
10(3):4-15. August 1985.

Method 6A--Determination of Sulfur Dioxide, Moisture, and Carbon Dioxide 
              Emissions From Fossil Fuel Combustion Sources

1. Principle and Applicability

    1.1  Applicability. This method applies to the determination of 
sulfur dioxide (SO2) emissions from fossil fuel combustion 
sources in terms of concentration (mg/m\3\) and in terms of emission 
rate (ng/J) and to the determination of carbon dioxide (CO2) 
concentration (percent). Moisture, if desired, may also be determined by 
this method.
    The minimum detectable limit, the upper limit, and the interferences 
of the method for the measurement of SO2 are the same as for 
Method 6. For a 20-liter sample, the method has a precision of 0.5 
percent CO2 for concentrations between 2.5 and 25 percent 
CO2 and 1.0 percent moisture for moisture concentrations 
greater than 5 percent.
    1.2  Principle. The principle of sample collection is the same as 
for Method 6 except that moisture and CO2 are collected in 
addition to SO2 in the same sampling train. Moisture and 
CO2 fractions are determined gravimetrically.

2. Apparatus

    2.1  Sampling. The sampling train is shown in Figure 6A-1; the 
equipment required is the same as for Method 6, Section 2.1, except as 
specified below:
    2.1.1  SO2 Absorbers. Two 30-ml midget impingers with a 
1-mm restricted tip and two 30-ml midget bubblers with an unrestricted 
tip. Other types of impingers and

[[Page 812]]

bubblers, such as Mae West for SO2 collection and rigid 
cylinders for moisture absorbers containing Drierite, may be used with 
proper attention to reagent volumes and levels, subject to the 
Administrator's approval.
    2.1.2  CO2 Absorber. A sealable rigid cylinder or bottle 
with an inside diameter between 30 and 90 mm and a length between 125 
and 250 mm and with appropriate connections at both ends.
    Note: For applications downstream of wet scrubbers, a heated out-of-
stack filter (either borosilicate glass wool or glass fiber mat) is 
necessary. The filter may be a separate heated unit or may be within the 
heated portion of the probe. If the filter is within the sampling probe, 
the filter should not be within 15 cm of the probe inlet or any unheated 
section of the probe, such as the connection to the first SO2 
absorber. The probe and filter should be heated to at least 20  deg.C 
above the source temperature, but not greater than 120  deg.C. The 
filter temperature (i.e., the sample gas temperature) should be 
monitored to assure the desired temperature is maintained. A heated 
Teflon connector may be used to connect the filter holder or probe to 
the first impinger.

    Note: Mention of a brand name does not constitute endorsement by the 
Environmental Protection Agency.
    2.2  Sample Recovery and Analysis. The equipment needed for sample 
recovery and analysis is the same as required for Method 6. In addition, 
a balance to measure within 0.05 g is needed for analysis.

3. Reagents

    Unless otherwise indicated, all reagents must conform to the 
specifications established by the committee on analytical reagents of 
the American Chemical Society. Where such specifications are not 
available, use the best available grade.
    3.1  Sampling. The reagents required for sampling are the same as 
specified in Method 6. In addition, the following reagents are required:
[GRAPHIC] [TIFF OMITTED] TC01JN92.135

    3.1.1  Drierite. Anhydrous calcium sulfate (CaSO4) 
desiccant, 8 mesh, indicating type is recommended. (Do not use silica 
gel or similar desiccant in the application.)
    3.1.2  CO2 Absorbing Material. Ascarite II. Sodium 
hydroxide coated silica, 8 to 20 mesh.
    3.2  Sample Recovery and Analysis. The reagents needed for sample 
recovery and analysis are the same as for Method 6, Sections 3.2 and 
3.3, respectively.

4. Procedure

    4.1  Sampling.
    4.1.1  Preparation of Collection Train. Measure 15 ml of 80 percent 
isopropanol into the first midget bubbler and 15 ml of 3 percent 
hydrogen peroxide into each of the first two midget impingers as 
described in Method

[[Page 813]]

6. Insert the glass wool into the top of the isopropanol bubbler as 
shown in Figure 6A-1. Into the fourth vessel in the train, the second 
midget bubbler, place about 25 g of Drierite. Clean the outsides of the 
bubblers and impingers, and weigh at room temperature (20 
deg.C) to the nearest 0.1 g. Weigh the four vessels simultaneously, and 
record this initial mass.
    With one end of the CO2 absorber sealed, place glass wool 
in the cylinder to a depth of about 1 cm. Place about 150 g of CO2 
absorbing material in the cylinder on top of the glass wool, and fill 
the remaining space in the cylinder with glass wool. Assemble the 
cylinder as shown in Figure 6A-2. With the cylinder in a horizontal 
position, rotate it around the horizontal axis. The CO2 
absorbing material should remain in position during the rotation, and no 
open spaces or channels should be formed. If necessary, pack more glass 
wool into the cylinder to make the CO2 absorbing material 
stable. Clean the outside of the cylinder of loose dirt and moisture and 
weigh at room temperature to the nearest 0.1 g. Record this initial 
mass.
    Assemble the train as shown in Figure 6A-1. Adjust the probe heater 
to a temperature sufficient to prevent condensation (see Note in section 
2.1.1). Place crushed ice and water around the impingers and bubblers. 
Mount the CO2 absorber outside the water bath in a vertical 
flow position with the sample gas inlet at the bottom. Flexible tubing, 
e.g., Tygon, may be used to connect the last SO2 absorbing 
bubbler to the Drierite absorber and to connect the Drierite absorber to 
the CO2 absorber. A second, smaller CO2 absorber 
containing Ascarite II may be added in line downstream of the primary 
CO2 absorber as a breakthrough indicator. Ascarite II turns 
white when CO2 is absorbed.
[GRAPHIC] [TIFF OMITTED] TC01JN92.136

    4.1.2  Leak-Check Procedure and Sample Collection. The leak-check 
procedure and sample collection procedure are the same as specified in 
Method 6, Sections 4.1.2 and 4.1.3, respectively.
    4.2  Sample Recovery.
    4.2.1  Moisture Measurement. Disconnect the isopropanol bubbler, the 
SO2 impingers, and the moisture absorber from the sample 
train. Allow about 10 minutes for them to reach room temperature, clean 
the outsides of loose dirt and moisture, and weigh them simultaneously 
in the same manner as in Section 4.1.1. Record this final mass.
    4.2.2  Peroxide Solution. Discard the contents of the isopropanol 
bubbler and pour the contents of the midget impingers into a leak-free 
polyethylene bottle for shipping. Rinse the two midget impingers and 
connecting tubes with deionized distilled water, and add the washings to 
the same storage container.
    4.2.3  CO2 Absorber. Allow the CO2 absorber to 
warm to room temperature (about 10 minutes), clean the outside of loose 
dirt and moisture, and weigh to the nearest 0.1 g in the same manner as 
in Section 4.1.1. Record this final mass. Discard used Ascarite II 
material.
    4.3  Sample Analysis. The sample analysis procedure for 
SO2 is the same as specified in Method 6, Section 4.3.

[[Page 814]]

    4.4  Quality Assurance (QA) Audit Samples. Only when this method is 
used for compliance determinations, obtain an audit sample set as 
directed in Section 3.3.6 of Method 6. Analyze the audit samples, and 
report the results as directed in Section 4.4 of Method 6. Acceptance 
criteria for the audit results are the same as in Method 6.

5. Calibration

    The calibrations and checks are the same as required in Method 6, 
Section 5.

6. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after final 
calculations. The calculations, nomenclature, and procedures are the 
same as specified in Method 6 with the addition of the following:

    6.1  Nomenclature.

Cw= Concentration of moisture, percent.
CCO2=Concentration of CO2, dry basis, 
          percent.
mwi=Initial mass of impingers, bubblers, and moisture 
          absorber, g.
mwf=Final mass of impingers, bubblers, and moisture absorber, 
          g.
mai=Initial mass of CO2 absorber, g.
maf=Final mass of CO2 absorber, g.
VCO2(std)=Equivalent volume of CO2 collected at 
          standard conditions, dsm3.
Vw(std)=Equivalent volume of moisture collected at standard 
          conditions, sm3.
5.467 x 10-4=Equivalent volume of gaseous CO2 at 
          standard conditions per gram, sm3/g.
1.336 x 10-3=Equivalent volume of water vapor at standard 
          conditions per gram, sm3/g.
    6.2  CO2 Volume Collected, Corrected to Standard 
Conditions.

VCO2(std)=5.467 x 10-4 (maf- 
mai)    Eq. 6A-1

    6.3  Moisture Volume Collected, Corrected to Standard Conditions.
Vw(std)=1.336 x 10-3(mwf- 
mwi)
                                                                Eq. 6A-2
    6.4  SO2 Concentration.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.137
    
    6.5  CO2 Concentration.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.138
    
    6.6  Moisture Concentration.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.149
    
7. Emission Rate Procedure

    If the only emission measurement desired is in terms of emission 
rate of SOpara. (ng/J), an abbreviated procedure may be used. The 
differences between Method 6A and the abbreviated procedure are 
described below.
    7.1  Sample Train. The sample train is the same as shown in Figure 
6A-1 and as described in Section 4, except that the dry gas meter is not 
needed.
    7.2  Preparation of the Collection Train. Follow the same procedure 
as in Section 4.1.1, except do not weigh the isopropanol bubbler, the 
SO2 absorbing impingers or the moisture absorber.
    7.3  Sampling. Operate the train as described in Section 4.1.3, 
except that dry gas meter readings, barometric pressure, and dry gas 
meter temperatures need not be recorded.
    7.4  Sample Recovery. Follow the procedure in Section 4.2, except do 
not weigh the isopropanol bubbler, the SO2 absorbing 
impingers, or the moisture absorber.
    7.5  Sample Analysis. Analysis of the peroxide solution is the same 
as described in Section 4.3. Only when making compliance determinations, 
conduct an audit of the SO2 analysis procedure as described 
in Section 4.4.
    7.6  Calculations.
    7.6.1  SO2 Mass Collected.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.139
    
Where:

mSO2=Mass of SO2 collected, mg.
    7.6.2  Sulfur Dioxide Emission Rate.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.140
    
Where:

ESO2=Emission rate of SO2 (ng/J).
Fc=Carbon F Factor for the fuel burned, m3/J, from 
          Method 19.

8. Bibliography

    1.  Same as for Method 6, Citations 1 through 8, with the addition 
of the following:
    2.  Stanley, Jon and P.R. Westlin. An Alternate Method for Stack Gas 
Moisture Determination. Source Evaluation Society Newsletter. Vol. 3, 
No. 4. November 1978.
    3.  Whittle, Richard N. and P.R. Westlin. Air Pollution Test Report: 
Development and Evaluation of an Intermittent Integrated SO2/
CO2 Emission Sampling Procedure. Environmental Protection 
Agency, Emission Standard and Engineering Division, Emission Measurement 
Branch. Research Triangle Park, NC. December 1979. 14 pages.

[[Page 815]]

  Method 6B--Determination of Sulfur Dioxide and Carbon Dioxide Daily 
          Average Emissions From Fossil Fuel Combustion Sources

1. Principle and Applicability

    1.1  Applicability. This method applies to the determination of 
sulfur dioxide (SO2) emissions from combustion sources in 
terms of concentration (ng/m3) and emission rate (ng/J), and 
for the determination of carbon dioxide (CO2) concentration 
(percent) on a daily (24 hours) basis.
    The minimum detectable limits, upper limit, and the interferences 
for SO2 measurements are the same as for Method 6. EPA-
sponsored collaborative studies were undertaken to determine the 
magnitude of repeatability and reproducibility achievable by qualified 
testers following the procedures in this method. The results of the 
studies evolve from 145 field tests including comparisons with Methods 3 
and 6. For measurements of emission rates from wet, flue gas 
desulfurization units in (ng/J), the repeatability (within laboratory 
precision) is 8.0 percent and the reproducibility (between laboratory 
precision) is 11.1 percent.
    1.2  Principle. A gas sample is extracted from the sampling point in 
the stack intermittently over a 24-hour or other specified time period. 
Sampling may also be conducted continuously if the apparatus and 
procedures are appropriately modified (see Note in Section 4.1.1). The 
SO2 and CO2 are separated and collected in the 
sampling train. The SO2 fraction is measured by the barium-
thorin titration method, and CO2 is determined 
gravimetrically.

2. Apparatus

    The equipment required for this method is the same as specified for 
Method 6A, Section 2, except the isopropanol bubbler is not used. An 
empty bubbler for the collection of liquid droplets and does not allow 
direct contact between the collected liquid and the gas sample may be 
included in the train. For intermittent operation, include an industrial 
timer-switch designed to operate in the ``on'' position at least 2 
minutes continuously and ``off'' the remaining period over a repeating 
cycle. The cycle of operation in designated in the applicable 
regulation. At a minimum, the sampling operation should include at least 
12, equal, evenly-spaced periods per 24 hours.
    For applications downstream of wet scrubbers, a heated out-of-stack 
filter (either borosilicate glass wool or glass fiber mat) is necessary. 
The probe and filter should be heated continuously to at least 
20+C above the source temperature, but not greater than 
120+C. The filter (i.e., sample gas) temperature should be 
monitored to assure the desired temperature is maintained.
    Stainless steel sampling probes, type 316, are not recommended for 
use with Method 6B because of potential corrosion and contamination of 
sample. Glass probes or other types of stainless steel, e.g., Hasteloy 
or Carpenter 20, are recommended for long-term use.
    Other sampling equipment, such as Mae West bubblers and rigid 
cylinders for moisture absorption, which requires sample or reagent 
volumes other than those specified in this procedure for full 
effectiveness may be used, subject to the approval of the Administrator.

3. Reagents

    All reagents for sampling and analysis are the same as described in 
Method 6A, Section 3, except isopropanol is not used for sampling. The 
hydrogen peroxide absorbing solution shall be diluted to no less than 6 
percent by volume, instead of 3 percent as specified in Method 6. If 
Method 6B is to be operated in a low sample flow condition (less than 
100 ml/min), molecular sieve material may be substituted for Ascarite II 
as the CO2 absorbing material. The recommended molecular 
sieve material is Union Carbide \1/16\ inch pellets, 5A+, or 
equivalent. Molecular sieve material need not be discarded following the 
sampling run provided it is regenerated as per the manufacturer's 
instruction. Use of molecular sieve material at flow rates higher than 
100 ml/min may cause erroneous CO2 results.

4. Procedure

    4.1  Sampling.
    4.1.1  Preparation of Collection Train. Preparation of the sample 
train is the same as described in Method 6A, Section 4.1.4, with the 
addition of the following:
    The sampling train is assembled as shown in Figure 6A-1, except the 
isopropanol bubbler is not included. The probe must be heated to a 
temperature sufficient to prevent water condensation and must include a 
filter (either in-stack, out-of-stack, or both) to prevent particulate 
entrainment in the peroxide impingers. The electric supply for the probe 
heat should be continuous and separate from the timed operation of the 
sample pump.
    Adjust the timer-switch to operate in the ``on'' position from 2 to 
4 minutes on a 2-hour repeating cycle or other cycle specified in the 
applicable regulation. Other timer sequences may be used with the 
restriction that the total sample volume collected is between 25 and 60 
liters for the amounts of sampling reagents prescribed in this method.
    Add cold water to the tank until the impingers and bubblers are 
covered at least two-thirds of their length. The impingers and bubbler 
tank must be covered and protected from intense heat and direct 
sunlight. If freezing conditions exist, the impinger solution and the 
water bath must be protected.
    Note: Sampling may be conducted continuously if a low flow-rate 
sample pump (20

[[Page 816]]

to 40 ml/min for the reagent volumes described in this method) is used. 
Then the timer-switch is not necessary. In addition, if the sample pump 
is designed for constant rate sampling, the rate meter may be deleted. 
The total gas volume collected should be between 25 and 60 liters for 
the amounts of sampling reagents prescribed in this method.
    4.1.2  Leak-Check Procedure. The leak-check procedure is the same as 
described in Method 6, Section 4.1.2.
    4.1.3  Sample Collection. Record the initial dry gas meter reading. 
To begin sampling, position the tip of the probe at the sampling point, 
connect the probe to the first impinger (or filter), and start the timer 
and the sample pump. Adjust the sample flow to a constant rate of 
approximately 1.0 liter/min as indicated by the rotameter. Assure that 
the timer is operating as intended, i.e., in the ``on'' position for the 
desired period and the cycle repeats as required.
    During the 24-hour sampling period, record the dry gas meter 
temperature one time between 9:00 a.m. and 11:00 a.m., and the 
barometric pressure.
    At the conclusion of the run, turn off the timer and the sample 
pump, remove the probe from the stack, and record the final gas meter 
volume reading. Conduct a leak check as described in Section 4.1.2. If a 
leak is found, void the test run or use procedures acceptable to the 
Administrator to adjust the sample volume for leakage. Repeat the steps 
in this section (4.1.3) for successive runs.
    4.2  Sample Recovery. The procedures for sample recovery (moisture 
measurement, peroxide solution, and CO2 absorber) are the 
same as in Method 6A, Section 4.2.
    4.3  Sample Analysis. Analysis of the peroxide impinger solutions is 
the same as in Method 6, Section 4.3.
    4.4  Quality Assurance (QA) Audit Samples. Only when this method is 
used for compliance determinations, obtain an audit sample set as 
directed in Section 3.3.6 of Method 6. Analyze the audit samples at 
least once for every 30 days of sample collection, and report the 
results as directed in Section 4.4 of Method 6. The analyst performing 
the sample analyses shall perform the audit analyses. If more than one 
analyst performed the sample analyses during the 30-day sampling period, 
each analyst shall perform the audit analyses and all audit results 
shall be reported. Acceptance criteria for the audit results are the 
same as in Method 6.

5. Calibration

    5.1  Metering System.
    5.1.1  Initial Calibration. The initial calibration for the volume 
metering system is the same as for Method 6, Section 5.1.1.
    5.1.2  Periodic Calibration Check. After 30 days of operation of the 
test train, conduct a calibration check as in Section 5.1.1 above, 
except for the following variations: (1) The leak check is not to be 
conducted, (2) three or more revolutions of the dry gas meter must be 
used, and (3) only two independent runs need be made. If the calibration 
factor does not deviate by more than 5 percent from the initial 
calibration factor determined in Section 5.1.1, then the dry gas meter 
volumes obtained during the test series are acceptable and use of the 
train can continue. If the calibration factor deviates by more than 5 
percent, recalibrate the metering system as in Section 5.1.1; and for 
the calculations for the preceding 30 days of data, use the calibration 
factor (initial or recalibration) that yields the lower gas volume for 
each test run. Use the latest calibration factor for succeeding tests.
    5.2  Thermometers. Calibrate against mercury-in-glass thermometers 
initially and at 30-day intervals.
    5.3  Rotameter. The rotameter need not be calibrated, but should be 
cleaned and maintained according to the manufacturer's instructions.
    5.4  Barometer. Calibrate against a mercury barometer initially and 
at 30-day intervals.
    5.5  Barium Perchlorate Solution. Standardize the barium perchlorate 
solution against 25 ml of standard sulfuric acid to which 100 ml of 100 
percent isopropanol has been added.

6. Calculations

    The nomenclature and calculation procedures are the same as in 
Method 6A with the following exceptions:

Pbar= Initial barometric pressure for the test period, mm Hg.
Tm= Absolute meter temperature for the test period,  deg.K.

7. Emission Rate Procedure

    The emission rate procedure is the same as described in Method 6A, 
Section 7, except that the timer is needed and is operated as described 
in this method. Only when this method is used for compliance 
determinations, perform the QA audit analyses as described in Section 
4.4.

8. Bibliography

    The bibliography is the same as described in Method 6A, with the 
addition of the following:
    1.  Butler, Frank E; J.E. Knoll, J.C. Suggs, M.R. Midgett, and W. 
Mason. The Collaborative Test of Method 6B: Twenty-Four-Hour Analysis of 
SO2 and CO2. JAPCA. Vol. 33, No. 10. October 1983.

  Method 6C--Determination of Sulfur Dioxide Emissions From Stationary 
                Sources (Instrumental Analyzer Procedure)

1. Applicability and Principle

    1.1  Applicability. This method is applicable to the determination 
of sulfur dioxide (SO2)

[[Page 817]]

concentrations in controlled and uncontrolled emissions from stationary 
sources only when specified within the regulations.
    1.2  Principle. A gas sample is continuously extracted from a stack, 
and a portion of the sample is conveyed to an instrumental analyzer for 
determination of SO2 gas concentration using an ultraviolet 
(UV), nondispersive infrared (NDIR), or fluorescence analyzer. 
Performance specifications and test procedures are provided to ensure 
reliable data.

2. Range and Sensitivity

    2.1  Analytical Range. The analytical range is determined by the 
instrumental design. For this method, a portion of the analytical range 
is selected by choosing the span of the monitoring system. The span of 
the monitoring system shall be selected such that the pollutant gas 
concentration equivalent to the emission standard is not less than 30 
percent of the span. If at any time during a run the measured gas 
concentration exceeds the span, the run shall be considered invalid.
    2.2  Sensitivity. The minimum detectable limit depends on the 
analytical range, span, and signal-to-noise ratio of the measurement 
system. For a well designed system, the minimum detectable limit should 
be less than 2 percent of the span.

3. Definitions

    3.1  Measurement System. The total equipment required for the 
determination of gas concentration. The measurement system consists of 
the following major subsystems:
    3.1.1  Sample Interface. That portion of a system used for one or 
more of the following: sample acquisition, sample transport, sample 
conditioning, or protection of the analyzers from the effects of the 
stack effluent.
    3.1.2  Gas Analyzer. That portion of the system that senses the gas 
to be measured and generates an output proportional to its 
concentration.
    3.1.3  Data Recorder. A strip chart recorder, analog computer, or 
digital recorder for recording measurement data from the analyzer 
output.
    3.2  Span. The upper limit of the gas concentration measurement 
range displayed on the data recorder.
    3.3  Calibration Gas. A known concentration of a gas in an 
appropriate diluent gas.
    3.4  Analyzer Calibration Error. The difference between the gas 
concentration exhibited by the gas analyzer and the known concentration 
of the calibration gas when the calibration gas is introduced directly 
to the analyzer.
    3.5  Sampling System Bias. The difference between the gas 
concentrations exhibited by the measurement system when a known 
concentration gas is introduced at the outlet of the sampling probe and 
when the same gas is introduced directly to the analyzer.
    3.6  Zero Drift. The difference in the measurement system output 
reading from the initial calibration response at the zero concentration 
level after a stated period of operation during which no unscheduled 
maintenance, repair, or adjustment took place.
    3.7  Calibration Drift. The difference in the measurement system 
output reading from the initial calibration response at a mid-range 
calibration value after a stated period of operation during which no 
unscheduled maintenance, repair, or adjustment took place.
    3.8  Response Time. The amount of time required for the measurement 
system to display 95 percent of a step change in gas concentration on 
the data recorder.
    3.9  Interference Check. A method for detecting analytical 
interferences and excessive biases through direct comparison of gas 
concentrations provided by the measurement system and by a modified 
Method 6 procedure. For this check, the modified Method 6 samples are 
acquired at the sample by-pass discharge vent.
    3.10  Calibration Curve. A graph or other systematic method of 
establishing the relationship between the analyzer response and the 
actual gas concentration introduced to the analyzer.

4. Measurement System Performance Specifications

    4.1  Analyzer Calibration Error. Less than 2 percent of 
the span for the zero, mid-range, and high-range calibration gases.
    4.2  Sampling System Bias. Less than 5 percent of the 
span for the zero, and mid- or high-range calibration gases.
    4.3  Zero Drift. Less than 3 percent of the span over 
the period of each run.
    4.4  Calibration Drift. Less than 3 percent of the span 
over the period of each run.
    4.5  Interference Check. Less than 7 percent of the 
modified Method 6 result for each run.

5. Apparatus and Reagents

    5.1  Measurement System. Any measurement system for SO2 
that meets the specifications of this method. A schematic of an 
acceptable measurement system is shown in Figure 6C-1. The essential 
components of the measurement system are described below:
    5.1.1  Sample Probe. Glass, stainless steel, or equivalent, of 
sufficient length to traverse the sample points. The sampling probe 
shall be heated to prevent condensation.
    5.1.2  Sample Line. Heated (sufficient to prevent condensation) 
stainless steel or Teflon tubing, to transport the sample gas to the 
moisture removal system.
    5.1.3  Sample Transport Lines. Stainless steel or Teflon tubing, to 
transport the sample from the moisture removal system to the sample 
pump, sample flow rate control, and sample gas manifold.

[[Page 818]]

    5.1.4  Calibration Valve Assembly. A three-way valve assembly, or 
equivalent, for blocking the sample gas flow and introducing calibration 
gases to the measurement system at the outlet of the sampling probe when 
in the calibration mode.
    5.1.5  Moisture Removal System. A refrigerator-type condenser or 
similar device (e.g., permeation dryer), to remove condensate 
continuously from the sample gas while maintaining minimal contact 
between the condensate and the sample gas. The moisture removal system 
is not necessary for analyzers that can measure gas concentrations on a 
wet basis; for these analyzers, (1) heat the sample line and all 
interface components up to the inlet of the analyzer sufficiently to 
prevent condensation, and (2) determine the moisture content and correct 
the measured gas concentrations to a dry basis using appropriate 
methods, subject to the approval of the Administrator. The determination 
of sample moisture content is not necessary for pollutant analyzers that 
measure concentrations on a wet basis when (1) a wet basis 
CO2 analyzer operated according to Method 3A is used to 
obtain simultaneous measurements, and (2) the pollutant/CO2 
measurements are used to determine emissions in units of the standard.
    5.1.6  Particulate Filter. An in-stack or heated (sufficient to 
prevent water condensation) out-of-stack filter. The filter shall be 
borosilicate or quartz glass wool, or glass fiber mat. Additional 
filters at the inlet or outlet of the moisture removal system and inlet 
of the analyzer may be used to prevent accumulation of particulate 
material in the measurement system and extend the useful life of the 
components. All filters shall be fabricated of materials that are 
nonreactive to the gas being sampled.
    5.1.7  Sample Pump. A leak-free pump, to pull the sample gas through 
the system at a flow rate sufficient to minimize the response time of 
the measurement system. The pump may be constructed of any material that 
is nonreactive to the gas being sampled.
    5.1.8  Sample Flow Rate Control. A sample flow rate control valve 
and rotameter, or equivalent, to maintain a constant sampling rate 
within 10 percent.
    (Note: The tester may elect to install a back-pressure regulator to 
maintain the sample gas manifold at a constant pressure in order to 
protect the analyzer(s) from overpressurization, and to minimize the 
need for flow rate adjustments.)
    5.1.9  Sample Gas Manifold. A sample gas manifold, to divert a 
portion of the sample gas stream to the analyzer, and the remainder to 
the by-pass discharge vent. The sample gas manifold should also include 
provisions for introducing calibration gases directly to the analyzer. 
The manifold may be constructed of any material that is nonreactive to 
the gas being sampled.
    5.1.10  Gas Analyzer. A UV or NDIR absorption or fluorescence 
analyzer, to determine continuously the SO2 concentration in 
the sample gas stream. The analyzer shall meet the applicable 
performance specifications of Section 4. A means of controlling the 
analyzer flow rate and a device for determining proper sample flow rate 
(e.g., precision rotameter, pressure gauge downstream of all flow 
controls, etc.) shall be provided at the analyzer.
    (Note: Housing the analyzer(s) in a clean, thermally-stable, 
vibration-free environment will minimize drift in the analyzer 
calibration.)
    5.1.11  Data Recorder. A strip chart recorder, analog computer, or 
digital recorder, for recording measurement data. The data recorder 
resolution (i.e., readability) shall be 0.5 percent of span. 
Alternatively, a digital or analog meter having a resolution of 0.5 
percent of span may be used to obtain the analyzer responses and the 
readings may be recorded manually. If this alternative is used, the 
readings shall be obtained at equally spaced intervals over the duration 
of the sampling run. For sampling run durations of less than 1 hour, 
measurements at 1-minute intervals or a minimum of 30 measurements, 
whichever is less restrictive, shall be obtained. For sampling run 
durations greater than 1 hour, measurements at 2-minute intervals or a 
minimum of 96 measurements, whichever is less restrictive, shall be 
obtained.
    5.2  Method 6 Apparatus and Reagents. The apparatus and reagents 
described in Method 6, and shown by the schematic of the sampling train 
in Figure 6C-2, to conduct the interference check.
    5.3  SO2 Calibration Gases. The calibration gases for the 
gas analyzer shall be SO2 in N2 or SO2 
in air. Alternatively, SO2/CO2, SO2/
O2, or SO2/CO2/O2 gas 
mixtures in N2 may be used. For fluorescence-based analyzers, 
the O2 and CO2 concentrations of the calibration 
gases as introduced to the analyzer shall be within 1 percent (absolute) 
O2 and 1 percent (absolute) CO2 of the 
O2 and Co2 concentrations of the effluent samples 
as introduced to the analyzer. Alternatively, for fluorescence-based 
analyzers, use calibration blends of SO2 in air and the 
nomographs provided by the vendor to determine the quenching correction 
factor (the effluent O2 and CO2 concentrations 
must be known). Use three calibration gases as specified below:
    5.3.1  High-Range Gas. Concentration equivalent to 80 to 100 percent 
of the span.
    5.3.2  Mid-Range Gas. Concentration equivalent to 40 to 60 percent 
of the span.
    5.3.3  Zero Gas. Concentration of less than 0.25 percent of the 
span. Purified ambient air may be used for the zero gas by passing air 
through a charcoal filter, or through one or more impingers containing a 
solution of 3 percent H2O2.


[[Page 819]]


6. Measurement System Performance Test Procedures

    Perform the following procedures before measurement of emissions 
(Section 7).
    6.1  Calibration Gas Concentration Verification. There are two 
alternatives for establishing the concentrations of calibration gases. 
Alternative Number 1 is preferred.
    6.1.1  Alternative Number 1--Use of calibration gases that are 
analyzed following the Environmental Protection Agency Traceability 
Protocol Number 1 (see Citation 1 in the Bibliography). Obtain a 
certification from the gas manufacturer that Protocol Number 1 was 
followed.
    6.1.2  Alternative Number 2--Use of calibration gases not prepared 
according to Protocol Number 1. If this alternative is chosen, obtain 
gas mixtures with a manufacturer's tolerance not to exceed 2 
percent of the tag value. Within 6 months before the emission test, 
analyze each of the calibration gases in triplicate using Method 6. 
Citation 2 in the Bibliography describes procedures and techniques that 
may be used for this analysis. Record the results on a data sheet 
(example is shown in Figure 6C-3). Each of the individual SO2 
analytical results for each calibration gas shall be within 5 percent 
(or 5 ppm, whichever is greater) of the triplicate set average; 
otherwise, discard the entire set, and repeat the triplicate analyses. 
If the average of the triplicate analyses is within 5 percent of the 
calibration gas manufacturer's cylinder tag value, use the tag value; 
otherwise, conduct at least three additional analyses until the results 
of six consecutive runs agree with 5 percent (or 5 ppm, whichever is 
greater) of their average. Then use this average for the cylinder value.
    6.2  Measurement System Preparation. Assemble the measurement system 
by following the manufacturer's written instructions for preparing and 
preconditioning the gas analyzer and, as applicable, the other system 
components. Introduce the calibration gases in any sequence, and make 
all necessary adjustments to calibrate the analyzer and the data 
recorder. Adjust system components to achieve correct sampling rates.
    6.3  Analyzer Calibration Error. Conduct the analyzer calibration 
error check by introducing calibration gases to the measurement system 
at any point upstream of the gas analyzer as follows:
    6.3.1  After the measurement system has been prepared for use, 
introduce the zero, mid-range, and high-range gases to the analyzer. 
During this check, make no adjustments to the system except those 
necessary to achieve the correct calibration gas flow rate at the 
analyzer. Record the analyzer responses to each calibration gas on a 
form similar to Figure 6C-4.
    Note: A calibration curve established prior to the analyzer 
calibration error check may be used to convert the analyzer response to 
the equivalent gas concentration introduced to the analyzer. However, 
the same correction procedure shall be used for all effluent and 
calibration measurements obtained during the test.
    6.3.2  The analyzer calibration error check shall be considered 
invalid if the gas concentration displayed by the analyzer exceeds 
2 percent of the span for any of the calibration gases. If 
an invalid calibration is exhibited, take corrective action, and repeat 
the analyzer calibration error check until acceptable performance is 
achieved.
    6.4  Sampling System Bias Check. Perform the sampling system bias 
check by introducing calibration gases at the calibration valve 
installed at the outlet of the sampling probe. A zero gas and either the 
mid-range or high-range gas, whichever most closely approximates the 
effluent concentrations, shall be used for this check as follows:
    6.4.1  Introduce the upscale calibration gas, and record the gas 
concentration displayed by the analyzer on a form similar to Figure 6C-
5. Then introduce zero gas, and record the gas concentration displayed 
by the analyzer. During the sampling system bias check, operate the 
system at the normal sampling rate, and make no adjustments to the 
measurement system other than those necessary to achieve proper 
calibration gas flow rates at the analyzer. Alternately introduce the 
zero and upscale gases until a stable response is achieved. The tester 
shall determine the measurement system response time by observing the 
times required to achieve a stable response for both the zero and 
upscale gases. Note the longer of the two times as the response time.
    6.4.2  The sampling system bias check shall be considered invalid if 
the difference between the gas concentrations displayed by the 
measurement system for the analyzer calibration error check and for the 
sampling system bias check exceeds 5 percent of the span for 
either the zero or upscale calibration gas. If an invalid calibration is 
exhibited, take corrective action, and repeat the sampling system bias 
check until acceptable performance is achieved. If adjustment to the 
analyzer is required, first repeat the analyzer calibration error check, 
then repeat the sampling system bias check.

7. Emission Test Procedure

    7.1  Selection of Sampling Site and Sampling Points. Select a 
measurement site and sampling points using the same criteria that are 
applicable to Method 6.
    7.2 Interference Check Preparation. For each individual analyzer, 
conduct an interference check for at least three runs during the initial 
field test on a particular source category. Retain the results, and 
report

[[Page 820]]

them with each test performed on that source category.
    If an interference check is being performed, assemble the modified 
Method 6 train (flow control valve, two midget impingers containing 3 
percent H2O2, and dry gas meter) as shown in 
Figure 6C-2. Install the sampling train to obtain a sample at the 
measurement system sample by-pass discharge vent. Record the initial dry 
gas meter reading.
    7.3  Sample Collection. Position the sampling probe at the first 
measurement point, and begin sampling at the same rate as used during 
the sampling system bias check. Maintain constant rate sampling (i.e., 
10 percent) during the entire run. The sampling time per run 
shall be the same as for Method 6 plus twice the system response time. 
For each run, use only those measurements obtained after twice response 
time of the measurement system has elapsed, to determine the average 
effluent concentration. If an interference check is being performed, 
open the flow control valve on the modified Method 6 train concurrent 
with the initiation of the sampling period, and adjust the flow to 1 
liter per minute (10 percent).
    (Note: If a pump is not used in the modified Method 6 train, caution 
should be exercised in adjusting the flow rate since overpressurization 
of the impingers may cause leakage in the impinger train, resulting in 
positively biased results).
    7.4  Zero and Calibration Drift Tests. Immediately preceding and 
following each run, or if adjustments are necessary for the measurement 
system during the run, repeat the sampling system bias check procedure 
described in Section 6.4 (Make no adjustments to the measurement system 
until after the drift checks are completed.) Record and analyzer's 
responses on a form similar to Figure 6C-5.
    7.4.1  If either the zero or upscale calibration value exceeds the 
sampling system bias specification, then the run is considered invalid. 
Repeat both the analyzer calibration error check procedure (Section 6.3) 
and the sampling system bias check procedure (Section 6.4) before 
repeating the run.
    7.4.2  If both the zero and upscale calibration values are within 
the sampling system bias specification, then use the average of the 
initial and final bias check values to calculate the gas concentration 
for the run. If the zero or upscale calibration drift value exceeds the 
drift limits, based on the difference between the sampling system bias 
check responses immediately before and after the run, repeat both the 
analyzer calibration error check procedure (Section 6.3) and the 
sampling system bias check procedure (Section 6.4) before conducting 
additional runs.
    7.5  Interference Check (if performed). After completing the run, 
record the final dry gas meter reading, meter temperature, and 
barometric pressure. Recover and analyze the contents of the midget 
impingers, and determine the SO2 gas concentration using the 
procedures of Method 6. (It is not necessary to analyze EPA performance 
audit samples for Method 6.) Determine the average gas concentration 
exhibited by the analyzer for the run. If the gas concentrations 
provided by the analyzer and the modified Method 6 differ by more than 7 
percent of the modified Method 6 result, the run is invalidated.

8. Emission Calculation

    The average gas effluent concentration is determined from the 
average gas concentration displayed by the gas analyzer, and is adjusted 
for the zero and upscale sampling system bias checks, as determined in 
accordance with Section 7.4. The average gas concentration displayed by 
the analyzer may be determined by integration of the area under the 
curve for chart recorders, or by averaging all of the effluent 
measurements. Alternatively, the average may be calculated from 
measurements recorded at equally spaced intervals over the entire 
duration of the run. For sampling run durations of less than 1 hour, 
measurements at 1-minute intervals or a minimum of 30 measurements, 
whichever is less restrictive, shall be used. For sampling run durations 
greater than 1 hour, measurements at 2-minute intervals or a minimum of 
96 measurements, whichever is less restrictive, shall be used. Calculate 
the effluent gas concentration using Equation 6C-1.
[GRAPHIC] [TIFF OMITTED] TC16NO91.150

Where:

Cgas = Effluent gas concentration, dry basis, ppm.
C = Average gas concentration indicated by gas analyzer, dry basis, ppm.
Co = Average of initial and final system calibration bias 
          check responses for the zero gas, ppm.
Cm = Average of initial and final system calibration bias 
          check responses for the upscale calibration gas, ppm.
Cma = Actual concentration of the upscale calibration gas, 
          ppm.

9. Bibliography

    1. Traceability Protocol for Establishing True Concentrations of 
Gases Used for Calibrations and Audits of Continuous Source Emission 
Monitors: Protocol Number 1. U.S. Environmental Protection Agency, 
Quality Assurance Division. Research Triangle Park, NC. June 1978.
    2. Westlin, Peter R. and J. W. Brown. Methods for Collecting and 
Analyzing Gas Cylinder Samples. Source Evaluation Society Newsletter. 
3(3):5-15. September 1978.

[[Page 821]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.141

               Figure 6C-3--Analysis of Calibration Gases

 Date___________________________________________________________________
 Analytic method used___________________________________________________

------------------------------------------------------------------------
                                     Gas concentration (indicate units)
                                  --------------------------------------
                                                              High-range
                                      Zero a    Mid-range b       c
------------------------------------------------------------------------
Sample run:
  1..............................  ...........  ...........  ...........
  2..............................  ...........  ...........  ...........
  3..............................  ...........  ...........  ...........
    Average......................  ...........  ...........  ...........
Maximum percent deviation........  ...........  ...........  ...........
------------------------------------------------------------------------
a Average must be less than 0.25 percent of span.

[[Page 822]]

 
b Average must be 50 to 60 percent of span.
c Average must be 80 to 90 percent of span.

                 Figure 6C-4--Analyzer calibration data

 Source identification:_________________________________________________
 Test personnel:________________________________________________________
 Date:__________________________________________________________________
Analyzer calibration data for sampling
   runs:________________________________________________________________
 Span:__________________________________________________________________

----------------------------------------------------------------------------------------------------------------
                                                                             Analyzer
                                                                Cylinder   calibration    Absolute    Difference
                                                                 value       response    difference  (percent of
                                                               (indicate    (indicate    (indicate      span)
                                                                 units)       units)       units)
----------------------------------------------------------------------------------------------------------------
Zero gas....................................................  ...........  ...........  ...........  ...........
Mid-range gas...............................................  ...........  ...........  ...........  ...........
High-range gas..............................................  ...........  ...........  ...........  ...........
----------------------------------------------------------------------------------------------------------------

           Figure 6C-5--System calibration bias and drift data

 Source identification:_________________________________________________
 Test personnel:________________________________________________________
 Date:__________________________________________________________________
 Run number:____________________________________________________________
 Span:__________________________________________________________________

----------------------------------------------------------------------------------------------------------------
                                                      Initial values             Final values
                                                ----------------------------------------------------
                                      Analyzer                System cal.               System cal.     Drift
                                    calibration     System        bias        System        bias     (percent of
                                      response   calibration  (percent of  calibration  (percent of     span)
                                                   response      span)       response      span)
----------------------------------------------------------------------------------------------------------------
Zero gas..........................  ...........  ...........  ...........  ...........  ...........  ...........
Upscale gas.......................  ...........  ...........  ...........  ...........  ...........  ...........
----------------------------------------------------------------------------------------------------------------

      
    [GRAPHIC] [TIFF OMITTED] TC16NO91.151
    
  Method 7--Determination of Nitrogen Oxide Emissions From Stationary 
                                 Sources

1. Principle and Applicability

    1.1  Principle. A grab sample is collected in an evacuated flask 
containing a dilute sulfuric acid-hydrogen peroxide absorbing solution, 
and the nitrogen oxides, except nitrous oxide, are measured 
colorimetrically using the phenoldisulfonic acid (PDS) procedure.
    1.2  Applicability. This method is applicable to the measurement of 
nitrogen oxides emitted from stationary sources. The range of the method 
has been determined to be 2 to 400 milligrams NOx (as 
NO2) per dry standard cubic meter, without having to dilute 
the sample.

2. Apparatus

    2.1  Sampling (see Figure 7-1). Other grab sampling systems or 
equipment, capable of measuring sample volume to within 
plus-minus2.0 percent and collecting a sufficient sample 
volume to allow analytical reproducibility to within 
plus-minus5 percent, will be considered acceptable 
alternatives, subject to approval of the Administrator, U.S. 
Environmental Protection Agency. The following equipment is used in 
sampling: 
---------------------------------------------------------------------------

    3  Mention of trade names or specific products does not 
constitute endorsement by the Environmental Protection Agency.
---------------------------------------------------------------------------

    2.1.1  Probe. Borosilicate glass tubing, sufficiently heated to 
prevent water condensation and equipped with an in-stack or out-stack 
filter to remove particulate matter (a

[[Page 823]]

plug of glass wool is satisfactory for this purpose). Stainless steel or 
Teflon 3 tubing may also be used for the probe. Heating is 
not necessary if the probe remains dry during the purging period.
[GRAPHIC] [TIFF OMITTED] TC01JN92.142


[[Page 824]]


    2.1.2  Collection Flask. Two-liter borosilicate, round bottom flask, 
with short neck and 24/40 standard taper opening, protected against 
implosion or breakage.
    2.1.3  Flask Valve. T-bore stopcock connected to a 24/40 standard 
taper joint.
    2.1.4  Temperature Gauge. Dial-type thermometer, or other 
temperature gauge, capable of measuring 1  deg.C (2  deg.F) intervals 
from -5 to 50  deg.C (25 to 125  deg.F).
    2.1.5  Vacuum Line. Tubing capable of withstanding a vacuum of 75 mm 
Hg (3 in. Hg) absolute pressure, with ``T'' connection and T-bore 
stopcock.
    2.1.6  Vacuum Gauge. U-tube manometer, 1 meter (36 in.), with 1-mm 
(0.1-in.) divisions, or other gauge capable of measuring pressure to 
within plus-minus2.5 mm Hg (0.10 in. Hg).
    2.1.7  Pump. Capable of evacuating the collection flask to a 
pressure equal to or less than 75 mm Hg (3 in. Hg) absolute.
    2.1.8  Squeeze Bulb. One-way.
    2.1.9  Volumetric Pipette. 25 ml.
    2.1.10  Stopcock and Ground Joint Grease. A high-vacuum, high-
temperature chlorofluorocarbon grease is required. Halocarbon 25-5S has 
been found to be effective.
    2.1.11  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg). In many 
cases, the barometric reading may be obtained from a nearby National 
Weather Service station, in which case the station value (which is the 
absolute barometric pressure) shall be requested and an adjustment for 
elevation differences between the weather station and sampling point 
shall be applied at a rate of minus 2.5 mm Hg (0.1 in. Hg) per 30 m (100 
ft) elevation increase, or vice versa for elevation decrease.
    2.2  Sample Recovery. The following equipment is required for sample 
recovery:
    2.2.1  Graduated Cylinder. 50 ml with 1-ml divisions.
    2.2.2  Storage Containers. Leak-free polyethylene bottles.
    2.2.3  Wash Bottle. Polyethylene or glass.
    2.2.4  Glass Stirring Rod.
    2.2.5  Test Paper for Indicating pH. To cover the pH range of 7 to 
14.
    2.3  Analysis. For the analysis, the following equipment is needed:
    2.3.1  Volumetric Pipettes. Two 1 ml, two 2 ml, one 3 ml, one 4 ml, 
two 10 ml, and one 25 ml for each sample and standard.
    2.3.2  Porcelain Evaporating Dishes. 175- to 250-ml capacity with 
lip for pouring, one for each sample and each standard. The Coors No. 
45006 (shallow-form, 195 ml) has been found to be satisfactory. 
Alternatively, polymethyl pentene beakers (Nalge No. 1203, 150 ml), or 
glass beakers (150 ml) may be used. When glass beakers are used, etching 
of the beakers may cause solid matter to be present in the analytical 
step; the solids should be removed by filtration (see Section 4.3).
    2.3.3  Steam Bath. Low-temperature ovens or thermostatically 
controlled hot plates kept below 70  deg.C (160  deg.F) are acceptable 
alternatives.
    2.3.4  Dropping Pipette or Dropper. Three required.
    2.3.5  Polyethylene Policeman. One for each sample and each 
standard.
    2.3.6  Graduated Cylinder. 100 ml with 1-ml divisions.
    2.3.7  Volumetric Flasks. 50 ml (one for each sample and each 
standard), 100 ml (one for each sample and each standard, and one for 
the working standard KNO3 solution), and 1000 ml (one).
    2.3.8  Spectrophotometer. To measure absorbance at 410 nm.
    2.3.9  Graduated Pipette. 10 ml with 0.1-ml divisions.
    2.3.10  Test Paper for Indicating pH. To cover the pH range of 7 to 
14.
    2.3.11  Analytical Balance. To measure to within 0.1 mg.

3. Reagents

    Unless otherwise indicated, it is intended that all reagents conform 
to the specifications established by the Committee on Analytical 
Reagents of the American Chemical Society, where such specifications are 
available; otherwise, use the best available grade.
    3.1  Sampling. To prepare the absorbing solution, cautiously add 2.8 
ml concentrated H2SO4 to 1 liter of deionized, 
distilled water. Mix well and add 6 ml of 3 percent hydrogen peroxide, 
freshly prepared from 30 percent hydrogen peroxide solution. The 
absorbing solution should be used within 1 week of its preparation. Do 
not expose to extreme heat or direct sunlight.
    3.2  Sample Recovery. Two reagents are required for sample recovery:
    3.2.1  Sodium Hydroxide (1N). Dissolve 40 g NaOH in deionized, 
distilled water and dilute to 1 liter.
    3.2.2  Water. Deionized, distilled to conform to ASTM Specification 
D1193-77, Type 3 (incorporated by reference--see Sec. 60.17). At the 
option of the analyst, the KMnO4 test for oxidizable organic 
matter may be omitted when high concentrations of organic matter are not 
expected to be present.
    3.3  Analysis. For the analysis, the following reagents are 
required:
    3.3.1  Fuming Sulfuric Acid. 15 to 18 percent by weight free sulfur 
trioxide. HANDLE WITH CAUTION.
    3.3.2  Phenol. White solid.
    3.3.3  Sulfuric Acid. Concentrated, 95 percent minimum assay. HANDLE 
WITH CAUTION.
    3.3.4  Potassium Nitrate. Dried at 105 to 110  deg.C (220 to 230 
deg.F) for a minimum of 2 hours just prior to preparation of standard 
solution.

[[Page 825]]

    3.3.5  Standard KNO3 Solution. Dissolve exactly 2.198 g 
of dried potassium nitrate (KNO3) in deionized, distilled 
water and dilute to 1 liter with deionized, distilled water in a 1,000-
ml volumetric flask.
    3.3.6  Working Standard KNO3 Solution. Dilute 10 ml of 
the standard solution to 100 ml with deionized distilled water. One 
milliter of the working standard solution is equivalent to 100 
g nitrogen dioxide (NO2).
    3.3.7  Water. Deionized, distilled as in Section 3.2.2.
    3.3.8  Phenoldisulfonic Acid Solution. Dissolve 25 g of pure white 
phenol in 150 ml concentrated sulfuric acid on a steam bath. Cool, add 
75 ml fuming sulfuric acid, and heat at 100  deg.C (212  deg.F) for 2 
hours. Store in a dark, stoppered bottle.
    3.3.9  Quality Assurance Audit Samples. Nitrate samples in glass 
vials prepared by EPA's Environmental Monitoring Systems Laboratory, 
Quality Assurance Division, Source Branch, Mail Drop 77A, Research 
Triangle Park, North Carolina 27711. Each set will consist of two vials 
having solutions of unknown concentrations. Only when making compliance 
determinations, obtain an audit sample set from the quality assurance 
management office at each EPA regional office or the responsible 
enforcement agency. (Note: The tester should notify the quality 
assurance office or the responsible enforcement agency at least 30 days 
prior to the test date to allow sufficient time for sample delivery.)

4. Procedures

    4.1  Sampling.
    4.1.1  Pipette 25 ml of absorbing solution into a sample flask, 
retaining a sufficient quantity for use in preparing the calibration 
standards. Insert the flask valve stopper into the flask with the valve 
in the ``purge'' position. Assemble the sampling train as shown in 
Figure 7-1 and place the probe at the sampling point. Make sure that all 
fitings are tight and leak-free, and that all ground glass joints have 
been properly greased with a high-vacuum, high-temperature 
chlorofluorocarbon-based stopcock grease. Turn the flask valve and the 
pump valve to their ``evacuate'' positions. Evacuate the flask to 75 mm 
Hg (3 in. Hg) absolute pressure, or less. Evacuation to a pressure 
approaching the vapor pressure of water at the existing temperature is 
desirable. Turn the pump valve to its ``vent'' position and turn the off 
the pump. Check for leakage by observing the manometer for any pressure 
fluctuation. (Any variation greater than 10 mm Hg (0.4 in. Hg) over a 
period of 1 minute is not acceptable, and the flask is not to be used 
until the leakage problem is corrected. Pressure in the flask is not to 
exceed 75 mm Hg (3 in. Hg) absolute at the time sampling is commenced.) 
Record the volume of the flask and valve (Vf), the flask 
temperature (Ti), and the barometric pressure. Turn the flask 
valve counterclockwise to its ``purge'' position and do the same with 
the pump valve. Purge the probe and the vacuum tube using the squeeze 
bulb. If condensation occurs in the probe and the flask valve area, heat 
the probe and purge until the condensation disappears. Next, turn the 
pump valve to its ``vent'' position. Turn the flask valve clockwise to 
its ``evacuate'' position and record the difference in the mercury 
levels in the manometer. The absolute internal pressure in the flask 
(Pi) is equal to the barometric pressure less the manometer 
reading. Immediately turn the flask valve to the ``sample'' position and 
permit the gas to enter the flask until pressures in the flask and 
sample line (i.e., duct, stack) are equal. This will usually require 
about 15 seconds; a longer period indicates a ``plug'' in the probe, 
which must be corrected before sampling is continued. After collecting 
the sample, turn the flask valve to its ``purge'' position and 
disconnect the flask from the sampling train. Shake the flask for at 
least 5 minutes.
    4.1.2  If the gas being sampled contains insufficient oxygen for the 
conversion of NO to NO2 (e.g., an applicable subpart of the 
standard may require taking a sample of a calibration gas mixture of NO 
in N2), then oxygen shall be introduced into the flask to 
permit this conversion. Oxygen may be introduced into the flask by one 
of three methods; (1) Before evacuating the sampling flask, flush with 
pure cylinder oxygen, then evacuate flask to 75 mm Hg (3 in. Hg) 
absolute pressure or less; or (2) inject oxygen into the flask after 
sampling; or (3) terminate sampling with a minimum of 50 mm Hg (2 in. 
Hg) vacuum remaining in the flask, record this final pressure, and then 
vent the flask to the atmosphere until the flask pressure is almost 
equal to atmospheric pressure.
    4.2  Sample Recovery. Let the flask set for a minimum of 16 hours 
and then shake the contents for 2 minutes. Connect the flask to a 
mercury filled U-tube manometer. Open the valve from the flask to the 
manometer and record the flask temperature (Tf), the 
barometric pressure, and the difference between the mercury levels in 
the manometer. The absolute internal pressure in the flask 
(Pf) is the barometric pressure less the manometer reading. 
Transfer the contents of the flask to a leak-free polyethylene bottle. 
Rinse the flask twice with 5-ml portions of deionized, distilled water 
and add the rinse water to the bottle. Adjust the pH to between 9 and 12 
by adding sodium hydroxide (1 N), dropwise (about 25 to 35 drops). Check 
the pH by dipping a stirring rod into the solution and then touching the 
rod to the pH test paper. Remove as little material as possible during 
this step. Mark the height of the liquid level so that the container can 
be checked for leakage after transport. Label

[[Page 826]]

the container to clearly identify its contents. Seal the container for 
shipping.
    4.3  Analysis. Note the level of the liquid in container and confirm 
whether or not any sample was lost during shipment; note this on the 
analytical data sheet. If a noticeable amount of leakage has occurred, 
either void the sample or use methods, subject to the approval of the 
Administrator, to correct the final results. Immediately prior to 
analysis, transfer the contents of the shipping container to a 50-ml 
volumetric flask, and rinse the container twice with 5-ml portions of 
deionized, distilled water. Add the rinse water to the flask and dilute 
to the mark with deionized, distilled water; mix thoroughly. Pipette a 
25-ml aliquot into the procelain evaporating dish. Return any unused 
portion of the sample to the polyethylene storage bottle. Evaporate the 
25-ml aliquot to dryness on a steam bath and allow to cool. Add 2 ml 
phenoldisulfonic acid solution to the dried residue and triturate 
thoroughly with a polyethylene policeman. Make sure the solution 
contacts all the residue. Add 1 ml deionized, distilled water and four 
drops of concentrated sulfuric acid. Heat the solution on a steam bath 
for 3 minutes with occasional stirring. Allow the solution to cool, add 
20 ml deionized, distilled water, mix well by stirring, and add 
concentrated ammonium hydroxide, dropwise, with constant stirring, until 
the pH is 10 (as determined by pH paper). If the sample contains solids, 
these must be removed by filtration (centrifugation is an acceptable 
alternative, subject to the approval of the Administrator), as follows: 
filter through Whatman No. 41 filter paper into a 100-ml volumetric 
flask; rinse the evaporating dish with three 5-ml portions of deionized, 
distilled water; filter these three rinses. Wash the filter with at 
least three 15-ml portions of deionized, distilled water. Add the filter 
washings to the contents of the volumetric flask and dilute to the mark 
with deionized, distilled water. If solids are absent, the solution can 
be transferred directly to the 100-ml volumetric flask and diluted to 
the mark with deionized, distilled water. Mix the contents of the flask 
thoroughly, and measure the absorbance at the optimum wavelength used 
for the standards (Section 5.2.1), using the blank solution as a zero 
reference. Dilute the sample and the blank with equal volumes of 
deionized, distilled water if the absorbance exceeds A4, the 
absorbance of the 400 g NO2 standard (see Section 
5.2.2).
    4.4  Audit Sample Analysis. Concurrently analyze the two audit 
samples and a set of compliance samples (Section 4.3) in the same manner 
to evaluate the technique of the analyst and the standards preparation. 
(Note: It is recommended that known quality control samples be analyzed 
prior to the compliance and audit sample analysis to optimize the system 
accuracy and precision. One source of these samples is the Source Branch 
listed in Section 3.3.9.) The same analysts, analytical reagents, and 
analytical system shall be used both for the compliance samples and the 
EPA audit samples; if this condition is met, auditing of subsequent 
compliance analyses for the same enforcement agency within 30 days is 
not required. An audit sample set may not be used to validate different 
sets of compliance samples under the jurisdiction of different 
enforcement agencies, unless prior arrangements are made with both 
enforcement agencies.
    Calculate the concentrations in mg/dscm using the specified sample 
volume in the audit instructions. (Note: Indication of acceptable 
results may be obtained immediately by reporting the audit results in 
mg/dscm and compliance results in total g NO2/sample 
by telephone to the responsible enforcement agency.) Include the results 
of both audit samples, their identification numbers, and the analyst's 
name with the results of the compliance determination samples in 
appropriate reports to the EPA regional office or the appropriate 
enforcement agency. Include this information with subsequent compliance 
analyses for the same enforcement agency during the 30-day period.
    The concentrations of the audit samples obtained by the analyst 
shall agree within 10 percent of the actual audit concentrations. If the 
10-percent specification is not met, reanalyze the compliance samples 
and audit samples and include initial and reanalysis values in the test 
report (see Note in the first paragraph of this section).
    Failure to meet the 10-percent specification may require retests 
until the audit problems are resolved. However, it the audit results do 
not affect the compliance or noncompliance status of the affected 
facility, the Administrator may waive the reanalysis requirement, 
further audits, or retests and accept the results of the compliance 
test. While steps are being taken to resolve audit analysis problems, 
the Administrator may also choose to use the data to determine the 
compliance or noncompliance status of the affected facility.

5. Calibration

    5.1  Flask Volume. The volume of the collection flask-flask valve 
combination must be known prior to sampling. Assemble the flask and 
flask valve and fill with water, to the stopcock. Measure the volume of 
water to plus-minus10 ml. Record this volume on the flask.
    5.2  Spectrophotometer Calibration.
    5.2.1  Optimum Wavelength Determination. Calibrate the wavelength 
scale of the spectrophotometer every 6 months. The calibration may be 
accomplished by using an energy source with an intense line emission 
such as a mercury lamp, or by using a series of glass filters spanning 
the measuring range

[[Page 827]]

of the spectrophotometer. Calibration materials are available 
commercially and from the National Bureau of Standards. Specific details 
on the use of such materials should be supplied by the vendor; general 
information about calibration techniques can be obtained from general 
reference books on analytical chemistry. The wavelength scale of the 
spectrophotometer must read correctly within plus-minus5 nm 
at all calibration points; otherwise, the spectrophotometer shall be 
repaired and recalibrated. Once the wavelength scale of the 
spectrophotometer is in proper calibration, use 410 nm as the optimum 
wavelength for the measurement of the absorbance of the standards and 
samples.
    Alternatively, a scanning procedure may be employed to determine the 
proper measuring wavelength. If the instrument is a double-beam 
spectrophotometer, scan the spectrum between 400 and 415 nm using a 200 
g NO2 standard solution in the sample cell and a 
blank solution in the reference cell. If a peak does not occur, the 
spectrophotometer is probably malfunctioning and should be repaired. 
When a peak is obtained within the 400 to 415 nm range, the wavelength 
at which this peak occurs shall be the optimum wavelength for the 
measurement of absorbance of both the standards and the samples. For a 
single-beam spectrophotometer, follow the scanning procedure described 
above, except that the blank and standard solutions shall be scanned 
separately. The optimum wavelength shall be the wavelength at which the 
maximum difference in absorbance between the standard and the blank 
occurs.
    5.2.2  Determination of Spectrophotometer Calibration Factor 
Kc. Add 0.0 ml, 2 ml, 4 ml, 6 ml., and 8 ml of the KNO3 
working standard solution (1 ml=100 g NO2) to a 
series of five 50-ml volumetric flasks. To each flask, add 25 ml of 
absorbing solution, 10 ml deionized, distilled water, and sodium 
hydroxide (1 N) dropwise until the pH is between 9 and 12 (about 25 to 
35 drops each). Dilute to the mark with deionized, distilled water. Mix 
thoroughly and pipette a 25-ml aliquot of each solution into a separate 
porcelain evaporating dish. Beginning with the evaporation step, follow 
the analysis procedure of Section 4.3 until the solution has been 
transferred to the 100 ml volumetric flask and diluted to the mark. 
Measure the absorbance of each solution, at the optimum wavelength, as 
determined in Section 5.2.1. This calibration procedure must be repeated 
on each day that samples are analyzed. Calculate the spectrophotometer 
calibration factor as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.152


Where:

Kc=Calibration factor, g.
A1=Absorbance of the 100-g NO2 standard.
A2=Absorbance of the 200-g NO2 standard.
A3=Absorbance of the 300-g NO2 standard.
A4=Absorbance of the 400-g NO2 standard.
    5.2.3  Spectrophotometer Calibration Quality Control. Multiply the 
absorbance value obtained for each standard by the Kc factor 
(least squares slope) to determine the distance each calibration point 
lies from the theoretical calibration line. These calculated 
concentration values should not differ from the actual concentrations 
(i.e., 100, 200, 300, and 400 g NO2) by more than 7 
percent for three of the four standards.
    5.3  Barometer. Calibrate against a mercury barometer.
    5.4  Temperature Gauge. Calibrate dial thermometers against mercury-
in-glass thermometers.
    5.5  Vacuum Gauge. Calibrate mechanical gauges, if used, against a 
mercury manometer such as that specified in 2.1.6.
    5.6  Analytical Balance. Calibrate against standard weights.

6. Calculations

    Carry out the calculations, retaining at least one extra decimal 
figure beyond that of the acquired data. Round off figures after final 
calculations.
    6.1  Nomenclature.
A=Absorbance of sample.
C=Concentration of NOx as NO2, dry basis, 
          corrected to standard conditions, mg/dscm (lb/dscf).
F=Dilution factor (i.e., 25/5, 25/10, etc., required only if sample 
          dilution was needed to reduce the absorbance into the range of 
          calibration).
Kc=Spectrophotometer calibration factor.
m=Mass of NOx as NO2 in gas sample, g.
Pf=Final absolute pressure of flask, mm Hg (in. Hg).
Pi=Initial absolute pressure of flask, mm Hg (in. Hg).
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
Tf=Final absolute temperature of flask,  deg.K ( deg.R).
Ti=Initial absolute temperature of flask,  deg.K ( deg.R).
Tstd=Standard absolute temperature 293 deg.K (528 deg.R).
Vsc=Sample volume at standard conditions (dry basis), ml.
Vf=Volume of flask and valve, ml.
Va=Volume of absorbing solution, 25 ml.
2=50/25, the aliquot factor. (If other than a 25-ml aliquot was used for 
          analysis, the corresponding factor must be substituted).
6.2 Sample Volume, Dry Basis, Corrected to Standard Conditions.
Vsc= (Tstd/Pstd)(Vf 
          -Va)(Pf/Tf-Pi/
          Ti)
    =K1 (Vf -25 ml)(Pf/Tf- 
Pi/Ti)        Eq. 7-2

Where:
K1=0.3858 deg.K/mm Hg for metric units
    =17.64  deg.R/in. Hg for English units.


[[Page 828]]


6.3 Total g NO2 Per Sample.

m= 2Kc A F                Eq. 7-3
    Note: If other than a 25-ml aliquot is used for analysis, the factor 
2 must be replaced by a corresponding factor.
    6.4  Sample Concentration, Dry Basis, Corrected to Standard 
Conditions.
[GRAPHIC] [TIFF OMITTED] TC01JN92.143

Where:
K2=10\3\ (mg/scm)/(g/ml) for metric units.
   =6.242 x 10-5 (lb/scf)/(g/ml) for English units.

To convert from mg/dscm to g/dscm, divide C by 1,000.
    6.5 Relative Error (RE) for QA Audit Samples, Percent.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.153
    
Where:

Cd=Determined audit sample concentration, mg/dscm.
Ca=Actual audit sample concentration, mg/dscm.

7. Bibliography

    1. Standard Methods of Chemical Analysis 6th ed. New York, D. Van 
Nostrand Co., Inc. 1962. Vol. 1, p. 329-330.
    2. Standard Method of Test for Oxides of Nitrogen in Gaseous 
Combustion Products (Phenoldisulfonic Acid Procedure). In: 1968 Book of 
ASTM Standards, Part 26. Philadelphia, PA. 1968. ASTM Designation D-
1608-60, p. 725-729.
    3. Jacob, M. B. The Chemical Analysis of Air Pollutants. New York. 
Interscience Publisher, Inc. 1960. Vol. 10, p. 351-356.
    4. Beatty, R. L., L. B. Berger, and H. H. Schrenk. Determination of 
Oxides of Nitrogen by the Phenoldisulfonic Acid Method. Bureau of Mines, 
U.S. Dept. of Interior. RI. 3687. February 1943.
    5. Hamil, H. F. and D. E. Camann. Collaborative Study of Method for 
the Determination of Nitrogen Oxide Emissions from Stationary Sources 
(Fossil Fuel-Fired Steam Generators). Southwest Research Institute 
report for Environmental Protection Agency. Research Triangle Park, NC. 
October 5, 1973.
    6. Hamil, H. F. and R. E. Thomas. Collaborative Study of Method for 
the Determination of Nitrogen Oxide Emissions from Stationary Sources 
(Nitric Acid Plants). Southwest Research Institute report for 
Environmental Protection Agency. Research Triangle Park, NC. May 8, 
1974.

  Method 7A--Determination of Nitrogen Oxide Emissions From Stationary 
                   Sources--Ion Chromatographic Method

1. Applicability and Principle

    1.1  Applicability. This method applies to the measurement of 
nitrogen oxides emitted from stationary sources; it may be used as an 
alternative to Method 7 (as defined in 40 CFR Part 60.8(b)) to determine 
compliance if the stack concentration is within the analytical range. 
The analytical range of the method is from 125 to 1,250 mg 
NOx/m3 as NO2 (65 to 655 ppm), and 
higher concentrations may be analyzed by diluting the sample. The lower 
detection limit is approximately 19 mg/m3 (10 ppm), but may 
vary among instruments.
    1.2  Principle. A grab sample is collected in an evacuated flask 
containing a diluted sulfuric acid-hydrogen peroxide absorbing solution. 
The nitrogen oxides, except nitrous oxide, are oxidized to nitrate and 
measured by ion chromatography.

2. Apparatus

    2.1  Sampling. Same as in Method 7, Section 2.1.
    2.2  Sampling Recovery. Same as in Method 7, Section 2.2, except the 
stirring rod and pH paper are not needed.
    2.3  Analysis. For the analysis, the following equipment is needed. 
Alternative instrumentation and procedures will be allowed provided the 
calibration precision in Section 5.2 and acceptable audit accuracy can 
be met.
    2.3.1  Volumetric Pipets. Class A; 1-, 2-, 4-, 5-ml (two for the set 
of standards and one per sample), 6-, 10-, and graduated 5-ml sizes.
    2.3.2  Volumetric Flasks. 50-ml (two per sample and one per 
standard), 200-ml, and 1-liter sizes.
    2.3.3  Analytical Balance. To measure to within 0.1 mg.
    2.3.4  Ion Chromatograph. The ion chromatograph should have at least 
the following components:
    2.3.4.1  Columns. An anion separation or other column capable of 
resolving the nitrate ion from sulfate and other species present and a 
standard anion suppressor column (optional). Suppressor columns are 
produced as proprietary items; however, one can be produced in the 
laboratory using the resin available from BioRad Company, 32nd and 
Griffin Streets, Richmond, CA. Peak resolution can be optimized by 
varying the efluent strength or column flow rate, or by experimenting 
with alternative columns that may offer more efficient separation. When 
using guard columns with the stronger reagent to protect the separation 
column, the analyst should allow rest periods between injection 
intervals to purge possible sulfate buildup in the guard column.
    2.3.4.2  Pump. Capable of maintaining a steady flow as required by 
the system.

[[Page 829]]

    2.3.4.3  Flow Gauges. Capable of measuring the specified system flow 
rate.
    2.3.4.4  Conductivity Detector.
    2.3.4.5  Recorder. Compatible with the output voltage range of the 
detector.

3. Reagents

    Unless otherwise indicated, it is intended that all reagents conform 
to the specifications established by the Committee on Analytical 
Reagents of the American Chemical Society, where such specifications are 
available; otherwise, use the best available grade.
    3.1  Sampling. An absorbing solution consisting of sulfuric acid 
(H2SO4) and hydrogen peroxide 
(H2O2) is required for sampling. To prepare the 
absorbing solution, cautiously add 2.8 ml concentrated 
H2SO4 to a 1-liter flask containing water (same as 
Section 3.2). Add 6 ml of 3 percent H2O2 that has 
been freshly prepared from 30 percent solution. Dilute to volume with 
water, and mix well. This absorbing solution should be used within 1 
week of its preparation. Do not expose to extreme heat or direct 
sunlight.
    Note: Biased testing results have been observed when sampling under 
conditions of high sulfur dioxide concentrations (above 2000 ppm).
    3.2  Sample Recovery. Deionized distilled water that conforms to 
American Society for Testing and Materials Specification D 1193-74, Type 
3, is required for sample recovery. At the option of the analyst, the 
KMnO4 test for oxidizable organic matter may be omitted when 
high concentrations of organic matter are not expected to be present.
    3.3  Analysis. For the analysis, the following reagents are 
required:
    3.3.1  Water. Same as in Section 3.2.
    3.3.2  Stock Standard Solution, 1 mg NO2/ml. Dry an 
adequate amount of sodium nitrate (NaNO3) at 105 to 110\1/2\ 
C for a minimum of 2 hours just before preparing the standard solution. 
Then dissolve exactly 1.847 g of dried NaNO3 in water, and 
dilute to 1 liter in a volumetric flask. Mix well. This solution is 
stable for 1 month and should not be used beyond this time.
    3.3.3  Working Standard Solution, 25g/ml. Dilute 5 ml of 
the standard solution to 200 ml with water in a volumetric flask, and 
mix well.
    3.3.4  Eluent Solution. Weight 1.018 g of sodium carbonate 
(Na2CO3) and 1.008 g of sodium bicarbonate 
(NaHCO3), and dissolve in 4 liters of water. This solution is 
0.0024 M Na2CO3/0.003 M NaHCO3. Other 
eluents appropriate to the column type and capable of resolving nitrate 
ion from sulfate and other species present may be used.
    3.3.5  Quality Assurance Audit Samples. Same as required in Method 
7.

4. Procedure

    4.1  Sampling. Same as in Method 7, Section 4.1.
    4.2  Sample Recovery. Same as in Method 7, Section 4.2, except 
delete the steps on adjusting and checking the pH of the sample. Do not 
store the samples more than 4 days between collection and recovery.
    4.3  Sample. Preparation. the level of the liquid in the container 
and confirm whether any sample was lost during shipment; note this on 
the analytical data sheet. If a noticeable amount of leakage has 
occurred, either void the sample or use methods, subject to the approval 
of the Administrator, to correct the final results. Immediately before 
analysis, transfer the contents of the shipping container to a 50-ml 
volumetric flask, and rinse the container twice with 5-ml portions of 
water. Add the rinse water to the flask, and dilute to the mark with 
water. Mix thoroughly.
    Pipet a 5-ml aliquot of the sample into a 50-ml volumetric flask, 
and dilute to the mark with water. Mix thoroughly. For each set of 
determinations, prepare a reagent blank by diluting 5 ml of absorbing 
solution to 50 ml with water. (Alternatively, eluent solution may be 
used in all sample, standard, and blank dilutions.)
    4.4  Analysis. Prepare a standard calibration curve according to 
Section 5.2. Analyze the set of standards followed by the set of samples 
using the same injection volume for both standards and samples. Repeat 
this analysis sequence followed by a final analysis of the standard set. 
Average the results. The two sample values must agree within 5 percent 
of their mean for the analysis to be valid. Perform this duplicate 
analysis sequence on the same day. Dilute any sample and the blank with 
equal volumes of water if the concentration exceeds that of the highest 
standard.
    Document each sample chromatogram by listing the following 
analytical parameters: injection point, injection volume, nitrate and 
sulfate retention times, flow rate, detector sensitivity setting, and 
recorder chart speed.
    4.5  Audit Sample Analysis. Same as required in Method 7.

5. Calibration

    5.1  Flask Volume. Same as in Method 7, Section 5.1.
    5.2  Standard Calibration Curve. Prepare a series of five standards 
by adding 1.0, 2.0, 4.0, 6.0, and 10.0 ml of working standard solution 
(25g/ml) to a series of five 50-ml volumetric flasks. (The 
standard masses will equal 25, 50, 100, 150, and 250g.) Dilute 
each flask to volume with water, and mix well. Analyze with the samples 
as described in Section 4.4 and subtract the blank from each value. 
Prepare or calculate a linear regression plot to the standard masses in 
g (x-axis) versus their peak height responses in millimeters 
(y-axis). (Take peak height measurements with symmetrical peaks; in all 
other cases,

[[Page 830]]

calculate peak areas.) From this curve, or equation, determine the 
slope, and calculate its reciprocal to denote as the calibration factor, 
S. If any point deviates from the line by more than 7 percent of the 
concentration at that point, remake and reanalyze that standard. This 
deviation can be determined by multiplying S times the peak height 
response for each standard. The resultant concentrations must not differ 
by more than 7 percent from each known standard mass (i.e., 25, 50, 100, 
150, and 250g).
    5.3  Conductivity Detector. Calibrate according to manufacturer's 
specifications prior to initial use.
    5.4  Barometer. Calibrate against a mercury barometer.
    5.5  Temperature Gauge. Calibrate dial thermometers against mercury-
in-glass thermometers.
    5.6  Vacuum Gauge. Calibrate mechanical gauges, if used, against a 
mercury manometer such as that specified in Section 2.1.6 of Method 7.
    5.7  Analytical Balance. Calibrate against standard weights.

6. Calculations

    Carry out the calculations, retaining at least one extra decimal 
figure beyond that of the acquired data. Round off figures after final 
calculations.
    6.1  Sample Volume. Calculate the sample volume Vsc (in 
ml) on a dry basis, corrected to standard conditions, using Equation 7-2 
of Method 7.
    6.2  Sample Concentration of NOx as NO2. 
Calculate the sample concentration C (in mg/dscm) as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.154

Where:

H =Sample peak height, mm.
S =Calibration factor, g/mm.
F =Dilution factor (required only if sample dilution was needed to 
          reduce the concentration into the range of calibration)
104 = 1:10 dilution times conversion factor of
[GRAPHIC] [TIFF OMITTED] TC16NO91.155

To convert from mg/dscm to g/dscm, divide C by 1000.
    If desired, the concentration of NO2 may be calculated as 
ppm NO2 at standard conditions as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.156

Where:

0.5228 = ml/mg NO2.

7. Bibliography

    1. Mulik, J. D. and E. Sawicki. Ion Chromatographic Analysis of 
Environmental Pollutants. Ann Arbor, Ann Arbor Science Publishers, Inc. 
Vol. 2, 1979.
    2. Sawicki, E., J. D. Mulik, and E. Wittgenstein. Ion 
Chromatographic Analysis of Environmental Pollutants. Ann Arbor, Ann 
Arbor Science Publishers, Inc. Vol. 1. 1978.
    3. Siemer, D. D. Separation of Chloride and Bromide from Complex 
Matrices Prior to Ion Chromatographic Determination. Analytical 
Chemistry 52(12:1874-1877). October 1980.
    4. Small, H., T. S. Stevens, and W. C. Bauman. Novel Ion Exchange 
Chromatographic Method Using Conductimetric Determination. Analytical 
Chemistry. 47(11:1801). 1975.
    5. Yu, King K. and Peter R. Westlin. Evaluation of Reference Method 
7 Flask Reaction Time. Source Evaluation Society Newsletter. 4(4). 
November 1979. 10 p.

  Method 7B--Determination of Nitrogen Oxide Emissions From Stationary 
                 Sources (Ultraviolet Spectrophotometry)

1. Applicability and Principle

    1.1  Applicability. This method is applicable to the measurement of 
nitrogen oxides emitted from nitric acid plants. The range of the method 
as outlined has been determined to be 57 to 1,500 milligrams NOx 
(as NO2) per dry standard cubic meter, or 30 to 786 ppm 
NOx (as NO2), assuming corresponding standards are 
prepared.
    1.2  Principle. A grab sample is collected in an evacuated flask 
containing a dilute sulfuric acid-hydrogen peroxide absorbing solution; 
and the nitrogen oxides, except nitrous oxide, are measured by 
ultraviolet absorption.

2. Apparatus

    2.1  Sampling. Same as Method 7, Section 2.1.1 through Section 
2.1.11.
    2.2  Sample Recovery. The following equipment is required for sample 
recovery:
    2.2.1  Wash Bottle. Polyethylene or glass.
    2.2.2  Volumetric Flasks. 100-ml (one for each sample).
    2.3  Analysis. The following equipment is needed for analysis:
    2.3.1  Volumetric Pipettes. 5-, 10-, 15-, and 20-ml to make 
standards and sample dilutions.
    2.3.2  Volumetric Flasks. 1000- and 100-ml for preparing standards 
and dilution of samples.
    2.3.3  Spectrophotometer. To measure ultraviolet absorbance at 210 
nm.
    2.3.4  Analytical Balance. To measure to within 0.1 mg.

3. Reagents


[[Page 831]]


    Unless otherwise indicated, all reagents are to conform to the 
specifications established by the committee on analytical reagents of 
the American Chemical Society, where such specifications are available. 
Otherwise, use the best available grade.
    3.1  Sampling. Same as Method 7, Section 3.1. It is important that 
the amount of hydrogen peroxide in the absorbing solution not be 
increased. Higher concentrations of peroxide may interfere with sample 
analysis.
    3.2  Sample Recovery. Same as for Method 7, Section 3.2.2.
    3.3  Analysis. Same as for Method 7, Sections 3.3.4, 3.3.5, and 
3.3.7 with the addition of the following:
    3.3.1  Working Standard KNO3 Solution. Dilute 10 ml of 
the standard solution to 1000 ml with water. One milliliter of the 
working standard is equivalent to 10 g nitrogen dioxide 
(NO2).
    3.3.2  Absorbing Solution. Same as in Section 3.1.
    3.3.3  Quality Assurance Audit Samples. Nitrate samples are prepared 
in glass vials by the Environmental Protection Agency (EPA), 
Environmental Monitoring Systems Laboratory, Research Triangle Park, 
North Carolina. Each set will consist of two vials with two unknown 
concentrations. When making compliance determinations, obtain the audit 
samples from the quality assurance management office at each EPA 
regional office.

4. Procedures

    4.1  Sampling. Same as Method 7, Sections 4.1.1 and 4.1.2.
    4.2  Sample Recovery. Let the flask sit for a minimum of 16 hours, 
and then shake the contents for 2 minutes. Connect the flask to a 
mercury filled U-tube manometer. Open the valve from the flask to the 
manometer, and record the flask temperature (Tf), the 
barometric pressure, and the difference between the mercury levels in 
the manometer. The absolute internal pressure in the flask 
(Pf) is the barometric pressure less the manometer reading.
    Transfer the contents of the flask to a 100-ml volumetric flask. 
Rinse the flask three times with 10-ml portions of water, and add to the 
volumetric flask. Dilute to 100 ml with water. Mix thoroughly. The 
sample is now ready for analysis.
    4.3  Analysis. Pipette a 20-ml aliquot of sample into a 100-ml 
volumetric flask. Dilute to 100 ml with water. The sample is now ready 
to be read by ultraviolet spectrophotometry. Using the blank as zero 
reference, read the absorbance of the sample at 210 nm.
    4.4  Audit Analysis. With each set of compliance samples or once per 
analysis day, or once per week when averaging continuous samples, 
analyze each performance audit in the same manner as the sample to 
evaluate the analyst's technique and standard preparation. The same 
person, the same reagents, and the same analytical system must be used 
both for compliance determination samples and the EPA audit samples. 
Report the results of all audit samples with the results of the 
compliance determination samples. The relative error will be determined 
by the regional office or the appropriate enforcement agency.

5. Calibration

    Same as Method 7, Section 5.1 and Sections 5.3 through 5.6 with the 
addition of the following:
    5.1  Determination of Spectrophotometer Standard Curve. Add 0.0 ml, 
5 ml, 10 ml, 15 ml, and 20 ml of the KNO3 working standard 
solution (1 ml= 10 g NO2) to a series to five 100-ml 
volumetric flasks. To each flask, add 5 ml of absorbing solution. Dilute 
to the mark with water. The resulting solutions contain 0.0, 50, 100, 
150, and 200 g NO2, respectively. Measure the 
absorbance by ultraviolet spectrophotometry at 210 nm, using the blank 
as a zero reference. Prepare a standard curve plotting absorbance vs. 
g NO2.
    Note: If other than a 20-ml aliquot of sample is used for analysis, 
then the amount of absorbing solution in the blank and standards must be 
adjusted such that the same amount of absorbing solution is in the blank 
and standards as is in the aliquot of sample used. Calculate the 
spectrophotometer calibration factor Kc as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.144

Where:

mi=Mass of NO2 in standard i, g.
Ai=Absorbance of NO2 standard i.
N=Total number of calibration standards.
    For the set of calibration standards specified here, Equation 7-1 
simplifies to the following:
[GRAPHIC] [TIFF OMITTED] TC16NO91.157

6. Calculations

    Same as Method 7, Sections 6.1, 6.2, and 6.4 with the addition of 
the following:
    6.1  Total g NO2 Per Sample:

                m=5Kc AF          Eq. 7B-3

Where:

5=100/20, the aliquot factor.
    Note: If other than a 20-ml aliquot is used for analysis, the factor 
5 must be replaced by a corresponding factor.

[[Page 832]]

    6.2  Relative Error (RE) for Quality Assurance Audits.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.158
    
Where:

Cd=Determined audit concentration.
Ca=Actual audit concentration.

7. Bibliography

    1. National Institute for Occupational Safety and Health 
Recommendations for Occupational Exposure to Nitric Acid. In: 
Occupational Safety and Health Reporter. Washington, DC. Bureau of 
National Affairs, Inc. 1976. p. 149.
    2. Rennie, P.J., A.M. Sumner, and F.B. Basketter. ``Determination of 
Nitrate in Raw, Potable, and Waste Waters by Ultraviolet 
Spectrophotometry.'' ``Analyst.'' Vol. 104. September 1979. p. 837.

  Method 7C--Determination of Nitrogen Oxide Emissions From Stationary 
           Sources--Alkaline-Permanganate/Colorimetric Method

1. Applicability, Principle, Interferences, Precision, Bias, and 
Stability

    1.1  Applicability. The method is applicable to the determination of 
NOx emissions from fossil-fuel fired steam generators, 
electric utility plants, nitric acid plants, or other sources as 
specified in the regulations. The lower detectable limit is 13 mg 
NOx/m3, as NO2 (7 ppm NOx) 
when sampling at 500 cc/min for 1 hour. No upper limit has been 
established; however, when using the recommended sampling conditions, 
the method has been found to collect NOx emissions 
quantitatively up to 1,782 mg NOx/m3, as 
NO2 (932 ppm NOx).
    1.2  Principle. An integrated gas sample is extracted from the stack 
and collected in alkaline-potassium permanganate solution; 
NOx (NO+NO2) emissions are oxidized to 
NO2- and NO3-. The NO3- is reduced to 
NO2- with cadmium, and the NO2- is analyzed 
colorimetrically.
    1.3  Interferences. Possible interferences are SO2 and 
NH3. High concentrations of SO2 could interfere 
because SO2 consumes MnO4- (as does 
NOx) and, therefore, could reduce the NOx 
collection efficiency. However, when sampling emissions from a coal-
fired electric utility plant burning 2.1-percent sulfur coal with no 
control of SO2 emissions, collection efficiency was not 
reduced. In fact, calculations show that sampling 3000 ppm 
SO2 will reduce the MnO4- concentration by only 5 
percent if all the SO2 is consumed in the first impinger.
    NH3 is slowly oxidized to NO3- by the 
absorbing solution. At 100 ppm NH3 in the gas stream, an 
interference of 6 ppm NOx (11 mg NO2/
m3) was observed when the sample was analyzed 10 days after 
collection. Therefore, the method may not be applicable to plants using 
NH3 injection to control NOx emissions unless 
means are taken to correct the results. An equation has been developed 
to allow quantitation of the interference and is discussed in Citation 5 
of the Bibliography.
    1.4  Precision and Bias. The method does not exhibit any bias 
relative to Method 7. The within-laboratory relative standard deviation 
for a single measurement is 2.8 and 2.9 percent at 201 and 268 ppm 
NOx, respectively.
    1.5  Stability. Collected samples are stable for at least 4 weeks.

2. Apparatus

    2.1  Sampling and Sample Recovery. The sampling train is shown in 
Figure 7C-1, and component parts are discussed below. Alternative 
apparatus and procedures are allowed provided acceptable accuracy and 
precision can be demonstrated.

[[Page 833]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.145

    2.1.1  Probe. Borosilicate glass tubing, sufficiently heated to 
prevent water condensation and equipped with an in-stack or out-stack 
filter to remove particulate matter (a plug of glass wool is 
satisfactory for this purpose). Stainless steel or Teflon tubing may 
also be used for the probe. (Note: Mention of trade names or specific 
products does not constitute endorsement by the U.S. Environmental 
Protection Agency.)
    2.1.2  Impingers. Three restricted-orifice glass impingers, having 
the specifications given in Figure 7C-2, are required for each sampling 
train. The impingers must be connected in series with leak-free glass 
connectors. Stopcock grease may be used, if necessary, to prevent 
leakage. (The impingers can be fabricated by a glass blower until they 
become available commercially.)

[[Page 834]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.146

    2.1.3  Glass Wool, Stopcock Grease, Drying Tube, Valve, Pump, 
Barometer, and Vacuum Gauge and Rotameter. Same as in Method 6, Sections 
2.1.3, 2.1.4, 2.1.6, 2.1.7, 2.1.8, 2.1.11, and 2.1.12, respectively.
    2.1.4  Rate Meter. Rotameter, or equivalent, accurate to within 2 
percent at the selected flow rate between 400 and 500 cc/min. For 
rotameters, a range of 0 to 1 liter/min is recommended.
    2.1.5  Volume Meter. Dry gas meter capable of measuring the sample 
volume, under the sampling conditions of 400 to 500 cc/min for 60 
minutes within an accuracy of 2 percent.
    2.1.6  Filter. To remove NOx from ambient air, prepared 
by adding 20 g of a 5-angstrom molecular sieve to a cylindrical tube, 
e.g., a polyethylene drying tube.
    2.1.7  Polyethylene Bottles. 1-liter, for sample recovery.
    2.1.8  Funnel and Stirring Rods. For sample recovery.
    2.2  Sample Preparation and Analysis.

[[Page 835]]

    2.2.1  Hot Plate. Stirring type with 50- by 10-mm Teflon-coated 
stirring bars.
    2.2.2  Beakers. 400-, 600-, and 1000-ml capacities.
    2.2.3  Filtering Flask. 500-ml capacity with side arm.
    2.2.4  Buchner Funnel. 75-mm ID, with spout equipped with a 13-mm ID 
by 90-mm long piece of Teflon tubing to minimize possibility of 
aspirating sample solution during filtration.
    2.2.5  Filter Paper. Whatman GF/C, 7.0-cm diameter.
    2.2.6  Stirring Rods.
    2.2.7  Volumetric Flasks. 100-, 200- or 250-, 500-, and 1000-ml 
capacity.
    2.2.8  Watch Glasses. To cover 600- and 1,000-ml beakers.
    2.2.9  Graduated Cylinders. 50- and 250-ml capacities.
    2.2.10  Pipettes. Class A
    2.2.11  pH Meter. To measure pH from 0.5 to 12.0
    2.2.12  Burette. 50-ml with a micrometer type stopcock. (The 
stopcock is Catalogue No. 8225-t-05, Ace Glass, Inc., Post Office Box 
996, Louisville, Kentucky 50201.) Place a glass wool plug in bottom of 
burette. Cut off burette at a height of 43 cm from the top of plug, and 
have a glass blower attach a glass funnel to top of burette such that 
the diameter of the burette remains essentially unchanged. Other means 
of attaching the funnel are acceptable.
    2.2.13  Glass Funnel. 75-mm ID at the top.
    2.2.14  Spectrophotometer. Capable of measuring absorbance at 540 
nm. One-cm cells are adequate.
    2.2.15  Metal Thermometers. Bimetallic thermometers, range 0 to 
150\1/2\ C.
    2.2.16  Culture Tubes. 20- by 150-mm, Kimax No. 45048.
    2.2.17  Parafilm ``M.'' Obtained from American Can Company, 
Greenwich, Connecticut 06830.
    2.2.18  CO2 Measurement Equipment. Same as in Method 3.

3. Reagents

    Unless otherwise indicated, all reagents should conform to the 
specifications established by the Committee on Analytical Reagents of 
the American Chemical Society, where such specifications are available; 
otherwise, use the best available grade.
    3.1  Sampling.
    3.1.1  Water. Deionized distilled to conform to ASTM Specification D 
1193-74, Type 3 (incorporated by reference--see Sec. 60.17).
    3.1.2  Potassium Permanganate, 4.0 percent (w/w), Sodium Hydroxide, 
2.0 percent (w/w). Dissolve 40.0 g of KMnO4 and 20.0 g of 
NaOH in 940 ml of water.
    3.2  Sample Preparation and Analysis.
    3.2.1  Water. Same as in Section 3.1.1.
    3.2.2  Sulfuric Acid. Concentrated H2SO4.
    3.2.3  Oxalic Acid Solution. Dissolve 48 g of oxalic acid 
[(COOH)22H2O] in water, and dilute to 500 ml. Do 
not heat the solution.
    3.2.4  Sodium Hydroxide, 0.5 N. Dissolve 20 g of NaOH in water, and 
dilute to 1 liter.
    3.2.5  Sodium Hydroxide, 10 N. Dissolve
40 g of NaOH in water and dilute to 100 ml.
    3.2.6  Ethylenediamine Tetraacetic Acid (EDTA) Solution, 6.5 
Percent. Dissolve 6.5 g of EDTA (disodium salt) in water, and dilute to 
100 ml. Solution is best accomplished by using a magnetic stirrer.
    3.2.7  Column Rinse Solution. Add 20 ml of 6.5 percent EDTA solution 
to 960 ml of water, and adjust the pH to 11.7 to 12.0 with 0.5 N NaOH.
    3.2.8  Hydrochloric Acid (HCl), 2 N. Add 86 ml of concentrated HCl 
to a 500-ml volumetric flask containing water, dilute to volume, and mix 
well. Store in a glass-stoppered bottle.
    3.2.9  Sulfanilamide Solution. Add 20 g of sulfanilamide (melting 
point 165 to 167  deg.C) to 700 ml of water. Add, with mixing, 50 ml 
concentrated phosphoric acid (85 percent), and dilute to 1000 ml. This 
solution is stable for at least 1 month, if refrigerated.
    3.2.10  N-(1-Naphthyl)-Ethylenediamine Dihydrochloride (NEDA) 
Solution. Dissolve 0.5 g of NEDA in 500 ml of water. An aqueous solution 
should have one absorption peak at 320 nm over the range of 260 to 400 
nm. NEDA, showing more than one absorption peak over this range, is 
impure and should not be used. This solution is stable for at least 1 
month if protected from light and refrigerated.
    3.2.11  Cadmium. Obtained from Matheson Coleman and Bell, 2909 
Highland Avenue, Norwood, Ohio 45212, as EM Laboratories Catalogue No. 
2001. Prepare by rinsing in 2 N HCl for 5 minutes until the color is 
silver-grey. Then rinse the cadmium with water until the rinsings are 
neutral when tested with pH paper. CAUTION: H2 is liberated 
during preparation. Prepare in an exhaust hood away from any flame.
    3.2.12  NaNO2 Standard Solution, Nominal Concentration, 
1000 g NO2-/ml. Desiccate NaNO2 
overnight. Accurately weigh 1.4 to 1.6 g of NaNO2 (assay of 
97 percent NaNO2 or greater), dissolve in water, and dilute 
to 1 liter. Calculate the exact NO2- concentration from the 
following relationship:
[GRAPHIC] [TIFF OMITTED] TC16NO91.159


[[Page 836]]


This solution is stable for at least 6 months under laboratory 
conditions.
    3.2.13  KNO3 Standard Solution. Dry KNO3 at 
110  deg.C for 2 hours, and cool in a desiccator. Accurately weigh 9 to 
10 g of KNO3 to within 0.1 mg, dissolve in water, and dilute 
to 1 liter. Calculate the exact NO3- concentration from the 
following relationship:
[GRAPHIC] [TIFF OMITTED] TC16NO91.160

This solution is stable for 2 months without preservative under 
laboratory conditions.
    3.2.14  Spiking Solution. Pipette 7 ml of the KNO3 
standard into a 100-ml volumetric flask, and dilute to volume.
    3.2.15  Blank Solution. Dissolve 2.4 g of KMnO4 and 1.2 g 
of NaOH in 96 ml of water. Alternatively, dilute 60 ml of 
KMnO4/NaOH solution to 100 ml.
    3.2.16  Quality Assurance Audit Samples. Same as in Method 7, 
Section 3.3.9. When requesting audit samples, specify that they be in 
the appropriate concentration range for Method 7C.

4. Procedure

    4.1  Sampling.
    4.1.1  Preparation of Collection Train. Add 200 ml of 
KMnO4/NaOH solution (3.1.2) to each of three impingers, and 
assemble the train as shown in Figure 7C-1. Adjust probe heater to a 
temperature sufficient to prevent water condensation.
    4.1.2  Leak-Check Procedure. A leak-check prior to the sampling run 
should be carried out; a leak-check after the sampling run is mandatory. 
Carry out the leak-check(s) according to Method 6, Section 4.1.2.
    4.1.3  Check of Rotameter Calibration Accuracy (Optional). 
Disconnect the probe from the first impinger, and connect the filter 
(2.1.6). Start the pump, and adjust the rotameter to read between 400 
and 500 cc/min. After the flow rate has stabilized, start measuring the 
volume sampled, as recorded by the dry gas meter (DGM), and the sampling 
time. Collect enough volume to measure accurately the flow rate, and 
calculate the flow rate. This average flow rate must be less than 500 
cc/min for the sample to be valid; therefore, it is recommended that the 
flow rate be checked as above prior to each test.
    4.1.4  Sample Collection. Record the initial DGM reading and 
barometric pressure. Determine the sampling point or points according to 
the appropriate regulations, e.g., Sec. 60.46(c) of 40 CFR Part 60. 
Position the tip of the probe at the sampling point, connect the probe 
to the first impinger, and start the pump. Adjust the sample flow to a 
value between 400 and 500 cc/min. CAUTION: HIGHER FLOW RATES WILL 
PRODUCE LOW RESULTS. Once adjusted, maintain a constant flow rate during 
the entire sampling run. Sample for 60 minutes. For relative accuracy 
(RA) testing of continuous emission monitors, the minimum sampling time 
is 1 hour, sampling 20 minutes at each traverse point. [Note.-- When the 
SO2 concentration is greater than 1200 ppm, the sampling time 
may have to be reduced to 30 minutes to eliminate plugging of the 
impinger orifice with MnO2. For RA tests with SO2 
greater than 1200 ppm, sample for 30 minutes (10 minutes at each 
point)]. Record the DGM temperature, and check the flow rate at least 
every 5 minutes. At the conclusion of each run, turn off the pump, 
remove probe from the stack, and record the final readings. Divide the 
sample volume by the sampling time to determine the average flow rate. 
Conduct a leak-check as in Section 4.1.2. If a leak is found, void the 
test run, or use procedures acceptable to the Administrator to adjust 
the sample volume for the leakage.
    4.1.5  CO2 Measurement. During sampling, measure the 
CO2 content of the stack gas near the sampling point using 
Method 3. The single-point grab sampling procedure is adequate, provided 
the measurements are made at least three times--near the start, midway, 
and before the end of a run and the average CO2 concentration 
is computed. The Orsat or Fyrite analyzer may be used for this analysis.
    4.2  Sample Recovery. Disconnect the impingers. Pour the contents of 
the impingers into a 1-liter polyethylene bottle using a funnel and a 
stirring rod (or other means) to prevent spillage. Complete the 
quantitative transfer by rinsing the impingers and connecting tubes with 
water until the rinsings are clear to light pink, and add the rinsings 
to the bottle. Mix the sample, and mark the solution level. Seal and 
identify the sample container.
    4.3  Sample Preparation for Analysis. Prepare a cadmium reduction 
column as follows: Fill the burette (2.2.12) with water. Add freshly 
prepared cadmium slowly with tapping until no further settling occurs. 
The height of the cadmium column should be 39 cm. When not in use, store 
the column under rinse solution (3.2.7). (Note.-- The column should not 
contain any bands of cadmium fines. This may occur if regenerated column 
is used and will greatly reduce the column lifetime.)
    Note the level of liquid in the sample container, and determine 
whether any sample was lost during shipment. If a noticeable amount of 
leakage has occurred, the volume lost can be determined from the 
difference between initial and final solution levels, and this value can 
then be used to correct the analytical result. Quantitatively transfer 
the contents to a 1-liter volumetric flask, and dilute to volume.
    Take a 100-ml aliquot of the sample and blank (unexposed 
KMnO4/NaOH) solutions, and transfer to 400-ml beakers 
containing magnetic stirring bars. Using a pH meter,

[[Page 837]]

add concentrated H2SO4 with stirring until a pH of 
0.7 is obtained. Allow the solutions to stand for 15 minutes. Cover the 
beakers with watch glasses, and bring the temperature of the solutions 
to 50  deg.C. Keep the temperature below 60  deg.C. Dissolve 4.8 g of 
oxalic acid in a minimum volume of water, approximately 50 ml, at room 
temperature. Do not heat the solution. Add this solution slowly, in 
increments, until the KMnO4 solution becomes colorless. If 
the color is not completely removed, prepare some more of the above 
oxalic acid solution, and add until a colorless solution is obtained. 
Add an excess of oxalic acid by dissolving 1.6 g of oxalic acid in 50 ml 
of water, and add 6 ml of this solution to the colorless solution. If 
suspended matter is present, add concentrated H2SO4 
until a clear solution is obtained.
    Allow the samples to cool to near room temperature, being sure that 
the samples are still clear. Adjust the pH to 11.7 to 12.0 with 10 N 
NaOH. Quantitatively transfer the mixture to a Buchner funnel containing 
GF/C filter paper, and filter the precipitate. Filter the mixture into a 
500-ml filtering flask. Wash the solid material four times with water. 
When filtration is complete, wash the Teflon tubing, quantitatively 
transfer the filtrate to a 500-ml volumetric flask, and dilute to 
volume. The samples are now ready for cadmium reduction. Pipette a 50-ml 
aliquot of the sample into a 150-ml beaker, and add a magnetic stirring 
bar. Pipette in 1.0 ml of 6.5 percent EDTA solution, and mix.
    Determine the correct stopcock setting to establish a flow rate of 7 
to 9 ml/min of column rinse solution through the cadmium reduction 
column. Use a 50-ml graduated cylinder to collect and measure the 
solution volume. After the last of the rinse solution has passed from 
the funnel into the burette, but before air entrapment can occur, start 
adding the sample, and collect it in a 250-ml graduated cylinder. 
Complete the quantitative transfer of the sample to the column as the 
sample passes through the column. After the last of the sample has 
passed from the funnel into the burette, start adding 60 ml of column 
rinse solution, and collect the rinse solution until the solution just 
disappears from the funnel. Quantitatively transfer the sample to a 200-
ml volumetric flask (250-ml may be required), and dilute to volume. The 
samples are now ready for NO2- analysis. [Note.-- Both the 
sample and blank should go through this procedure. Additionally, two 
spiked samples should be run with every group of samples passed through 
the column. To do this, prepare two additional 50-ml aliquots of the 
sample suspected to have the highest NO3- concentration, and 
add 1 ml of the spiking solution to these aliquots. If the spike 
recovery or column efficiency (see 6.2.1) is below 95 percent, prepare a 
new column, and repeat the cadmium reduction].
    4.4  Sample Analysis. Pipette 10 ml of sample into a culture tube. 
(Note.-- Some test tubes give a high blank NO2- value but 
culture tubes do not.) Pipette in 10 ml of sulfanilamide solution and 
1.4 ml of NEDA solution. Cover the culture tube with parafilm, and mix 
the solution. Prepare a blank in the same manner using the sample from 
treatment of the unexposed KMnO4/NaOH solution (3.1.2). Also, 
prepare a calibration standard to check the slope of the calibration 
curve. After a 10-minute color development interval, measure the 
absorbance at 540 nm against water. Read g NO2-/ml 
from the calibration curve. If the absorbance is greater than that of 
the highest calibration standard, pipette less than 10 ml of sample and 
enough water to make the total sample volume 10 ml, and repeat the 
analysis. Determine the NO2 concentration using the 
calibration curve obtained in Section 5.3.
    4.5 Audit Analysis. This is the same as in Method 7, Section 4.4.

5. Calibration

    5.1 Dry Gas Metering System (DGM).
    5.1.1 Initial Calibration. Same as in Method 6, Section 5.1.1. For 
detailed instructions on carrying out this calibration, it is suggested 
that Section 3.5.2 of Citation 4 in the Bibiography be consulted.
    5.1.2  Post-Test Calibration Check. Same as in Method 6, Section 
5.1.2.
    5.2  Thermometers for DGM and Barometer. Same as in Method 6, 
Sections 5.2 and 5.4, respectively.
    5.3  Calibration Curve for Spectrophotometer. Dilute 5.0 ml of the 
NaNO2 standard solution to 200 ml with water. This solution 
nominally contains 25 g NO2-/ml. Use this solution 
to prepare calibration standards to cover the range of 0.25 to 3.00 
g NO2-/ml. Prepare a minimum of three standards each 
for the linear and slightly nonlinear (described below) range of the 
curve. Use pipettes for all additions.
    Run standards and a water blank as instructed in Section 4.4. Plot 
the net absorbance vs gNO2-/ml. Draw a smooth curve 
through the points. The curve should be linear up to an absorbance of 
approximately 1.2 with a slope of approximately 0.53 absorbance units/
g NO2-/ml. The curve should pass through the origin. 
The curve is slightly nonlinear from an absorbance of 1.2 to 1.6.

6. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after final 
calculation.
    6.1 Sample volume, dry basis, corrected to standard conditions.

[[Page 838]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.161

Where:

Vm(std)=Dry gas volume measured by the dry gas meter, 
          corrected to standard conditions, dscm.
Vm=Dry gas volume as measured by the dry gas meter, dcm.
Y=Dry gas meter calibration factor.
X=Correction factor for CO2 collection.
[GRAPHIC] [TIFF OMITTED] TC16NO91.162

Pbar=Barometric pressure, mm Hg.
Pstd=Standard absolute pressure, 760 mm Hg.
Tm=Average dry gas meter absolute temperature,  deg.K.
Tstd=Standard absolute temperature, 293  deg.K.
K1=0.3858  deg.K/mm Hg.
    6.2  Total g NO2 Per Sample.
    6.2.1  Efficiency of Cadmium Reduction Column. Calculate this value 
as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.147

Where:

E=Column efficiency, unitless.
x=Analysis of spiked sample, g NO2-/ml.
y=Analysis of unspiked sample, g NO2-/ml.
200=Final volume of sample and blank after passing through the column, 
          ml.
s=Concentration of spiking solution, g NO3-/ml.
1.0=Volume of spiking solution added, ml.
46.01=g NO2-/ mole.
62.01=g NO3-/ mole.
    6.2.2  Total g NO2.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.163
    
Where:
m=Mass of NOx, as NO2, in sample, g.
S=Analysis of sample, g NO2-/ml.
B=Analysis of blank, g NO2-/ml.
500=Total volume of prepared sample, ml.
50=Aliquot of prepared sample processed through cadmium column, ml.
100=Aliquot of KMnO4/NaOH solution, ml.
1000=Total volume of KMnO4/NaOH solution ml.
    6.3  Sample Concentration.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.164
    
Where:
C=Concentration of NOx as NO2, dry basis, mg/dscm.
K2=10-3 mg/g.

    6.4  Conversion Factors.
1.0 ppm NO=1.247 mg NO/m3 at STP.
1.0 ppm NO2=1.912 mg NO2/m3 at STP.
1 ft3=2.832 x 10-2 m3.
1000 mg = 1 g.

7. Quality Control

    Quality control procedures are specified in Sections 4.1.3 (flow 
rate accuracy); 4.3 (cadmium column efficiency); 4.4 (calibration

[[Page 839]]

curve accuracy); and 4.5 (audit analysis accuracy).

8. Bibliography

    1. Margeson, J.H., W.J. Mitchell, J.C. Suggs, and M.R. Midgett. 
Integrated Sampling and Analysis Methods for Determining NOx 
Emissions at Electric Utility Plants. U.S. Environmental Protection 
Agency, Research Triangle Park, NC. Journal of the Air Pollution Control 
Association. 32:1210-1215. 1982.
    2. Memorandum and attachment from J.H. Margeson, Source Branch, 
Quality Assurance Division, Environmental Monitoring Systems Laboratory, 
to The Record, EPA. March 30, 1983. NH3 Interference in 
Methods 7C and 7D.
    3. Margeson, J.H., J.C. Suggs, and M.R. Midgett. Reduction of 
Nitrate to Nitrite with Cadmium. Anal. Chem. 52:1955-57. 1980.
    4. Quality Assurance Handbook for Air Pollution Measurement Systems. 
Volume III--Stationary Source Specific Methods. August 1977. U.S. 
Environmental Protection Agency. Research Triangle Park, NC. Publication 
No. EPA-600/4-77-027b. August 1977.
    5. Margeson, J.H., et al. An Integrated Method for Determining 
NOx Emissions at Nitric Acid Plants. Manuscript submitted to 
Analytical Chemistry. April 1984.

  Method 7D--Determination of Nitrogen Oxide Emissions From Stationary 
        Sources--Alkaline-Permanganate/Ion Chromatographic Method

1. Applicability, Principle, Interferences, Precision, Bias, and 
Stability

    1.1  Applicability. The method is applicable to the determination of 
NOx emissions from fossil-fuel fired steam generators, 
electric utility plants, nitric acid plants, or other sources as 
specified in the regulations. The lower detectable limit is similar to 
that for Method 7C. No upper limit has been established; however, when 
using the recommended sampling conditions, the method has been found to 
collect NOx emissions quantitatively up to 1782 mg 
NOx/m3, as NO2 (932 pm NOx).
    1.2  Principle. An integrated gas sample is extracted from the stack 
and collected in alkaline-potassium permanganate solution; 
NOx (NO+NO2) emissions are oxidized to 
NO3-. Then NO3- is analyzed by ion chromatography.
    1.3  Interferences. Possible interferences are SO2 and 
NH3. High concentrations of SO2 could interfere 
because SO2 consumes MnO4- (as does 
NOx) and, therefore, could reduce the NOx 
collection efficiency. However, when sampling emissions from a coal-
fired electric utility plant burning 2.1-percent sulfur coal with no 
control of SO2 emissions, collection efficiency was not 
reduced. In fact, calculations show that sampling 3000 ppm 
SO2 will reduce the MnO4- concentration by only 5 
percent if all the SO2 is consumed in the first impinger.
    NH3 is slowly oxidized to NO3- by the 
absorbing solution. At 100 ppm NH3 in the gas stream, an 
interference of 6 ppm NOx (11 mg NO2/
m3) was observed when the sample was analyzed 10 days after 
collection. Therefore, the method may not be applicable to plants using 
NH3 injection to control NOx emissions unless 
means are taken to correct the results. An equation has been developed 
to allow quantitation of the interference and is discussed in Citation 4 
of the Bibliography.
    1.4  Precision and Bias. The method does not exhibit any bias 
relative to Method 7. The within-laboratory relative standard deviation 
for a single measurement was approximately 6 percent at 200 to 270 ppm 
NOx.
    1.5  Stability. Collected samples are stable for at least 4 weeks.

2. Apparatus

    2.1  Sampling and Sample Recovery. The sampling train is the same as 
in Figure 7C-1 of Method 7C. Component parts are the same as in Method 
7C, Section 2.1.
    2.2  Sample Preparation and Analysis.
    2.2.1  Magnetic Stirrer. With 25- by 10-mm Teflon-coated stirring 
bars.
    2.2.2  Filtering Flask. 500-ml capacity with sidearm.
    2.2.3  Buchner Funnel. 75-mm ID. The spout equipped with a 13-mm ID 
by 90-mm long piece of Teflon tubing to minimize possibility of 
aspirating sample solution during filtration.
    2.2.4  Filter Paper. Whatman GF/C, 7.0-cm diameter.
    2.2.5  Stirring Rods.
    2.2.6  Volumetric Flask. 250-ml.
    2.2.7  Pipettes. Class A.
    2.2.8  Erlenmeyer Flasks. 250-ml.
    2.2.9  Ion Chromatograph. Equipped with an anion separator column to 
separate NO3-, a H= suppressor, and necessary 
auxiliary equipment. Nonsuppressed and other forms of ion chromatography 
may also be used provided that adequate resolution of NO3- is 
obtained. The system must also be able to resolve and detect 
NO2-.

3. Reagents

    Unless otherwise indicated, all reagents should conform to the 
specifications established by the Committee on Analytical Reagents of 
the American Chemical Society, where such specifications are available; 
otherwise, use the best available grade.
    3.1  Sampling.
    3.1.1  Water. Deionized distilled to conform to ASTM Specification D 
1193-74, Type 3 (incorporated by reference--see Sec. 60.17).
    3.1.2  Potassium Permanganate, 4.0 Percent (w/w), Sodium Hydroxide, 
2.0 Percent (w/w). Dissolve 40.0 g of KMnO4 and 20.0 g of 
NaOH in 940 ml of water.
    3.2  Sample Preparation and Analysis.
    3.2.1  Water. Same as in Section 3.1.1.

[[Page 840]]

    3.2.2  Hydrogen Peroxide, 5 Percent. Dilute 30 percent 
H2O2 1:5 (v/v) with water.
    3.2.3  Blank Solution. Dissolve 2.4 g of KMnO4 and 1.2 g 
of NaOH in 96 ml of water. Alternatively, dilute 60 ml of 
KMnO4/NaOH solution to 100 ml.
    3.2.4  KNO3 Standard Solution. Dry KNO3 at 110 
 deg. C for 2 hours, and cool in a desiccator. Accurately weigh 9 to 10 
g of KNO3 to within 0.1 mg, dissolve in water, and dilute to 
1 liter. Calculate the exact NO3- concentration from the 
following relationship:
[GRAPHIC] [TIFF OMITTED] TC16NO91.165

This solution is stable for 2 months without preservative under 
laboratory conditions.
    3.2.5  Eluent, 0.003 M NaHCO3/0.0024 M 
Na2CO3. Dissolve 1.008 g NaHCO3 and 
1.018 g Na2CO3 in water, and dilute to 4 liters. 
Other eluents capable of resolving nitrate ion from sulfate and other 
species present may be used.
    3.2.6  Quality Assurance Audit Samples. This is the same as in 
Method 7, Section 3.3.9. When requesting audit samples, specify that 
they be in the appropriate concentration range for Method 7D.

4. Procedure

    4.1  Sampling. This is the same as in Method 7C, Section 4.1.
    4.2  Sample Recovery. This is the same as in Method 7C, Section 4.2.
    4.3  Sample Preparation for Analysis. Note the level of liquid in 
the sample container, and determine whether any sample was lost during 
shipment. If a noticeable amount of leakage has occurred, the volume 
lost can be determined from the difference between initial and final 
solution levels, and this value can then be used to correct the 
analytical result. Quantitatively transfer the contents to a 1-liter 
volumetric flask, and dilute to volume.
    Sample preparation can be started 36 hours after collection. This 
time is necessary to ensure that all NO2- is converted to 
NO3- Take a 50-ml aliquot of the sample and blank, and 
transfer to 250-ml Erlenmeyer flasks. Add a magnetic stirring bar. 
Adjust the stirring rate to as fast a rate as possible without loss of 
solution. Add 5 percent H2O2 in increments of 
approximately 5 ml using a 5-ml pipette. When the KMnO4 color 
appears to have been removed, allow the precipitate to settle, and 
examine the supernatant liquid. If the liquid is clear, the 
H2O2 addition is complete. If the KMnO4 
color persists, add more H2O2 , with stirring, 
until the supernatant liquid is clear. (Note: The faster the stirring 
rate, the less volume of H2O2 that will be 
required to remove the KMnO4.) Quantitatively transfer the 
mixture to a Buchner funnel containing GF/C filter paper, and filter the 
precipitate. The spout of the Buchner funnel should be equipped with a 
13-mm ID by 90-mm long piece of Teflon tubing. This modification 
minimizes the possibility of aspirating sample solution during 
filtration. Filter the mixture into a 500-ml filtering flask. Wash the 
solid material four times with water. When filtration is complete, wash 
the Teflon tubing, quantitatively transfer the filtrate to a 250-ml 
volumetric flask, and dilute to volume. The sample and blank are now 
ready for NO3- analysis.
    4.4  Sample Analysis. The following chromatographic conditions are 
recommended: 0.003 M NaHCO3/0.0024 M 
Na2CO3 eluent solution. (3.2.5), full scale range 
3 MHO; sample loop, 0.5 ml; flow rate, 2.5 ml/min. These 
conditions should give a NO3- retention time of approximately 
15 minutes (Figure 7D-1).

[[Page 841]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.148

    Establish a stable baseline. Inject a sample of water, and determine 
if any NO3- appears in the chromatogram. If NO3- 
is present, repeat the water load/injection procedure approximately five 
times; then re-inject a water sample, and observe the chromatogram. When 
no NO3- is present, the instrument is ready for use. Inject 
calibration standards. Then inject samples and a blank. Repeat the 
injection of the calibration standards (to compensate for any drift in 
response of the instrument). Measure the NO3- peak height or 
peak area, and determine the sample concentration from the calibration 
curve.
    4.5  Audit analysis. This is the same as in Method 7, Section 4.4.

5. Calibration

    5.1  Dry Gas Metering System (DGM).
    5.1.1  Initial Calibration. Same as in Method 6, Section 5.1.1. For 
detailed instructions on carrying out this calibration, it is suggested 
that Section 3.5.2 of Citation 3 in the Bibliography be consulted.
    5.1.2  Post-Test Calibration Check. Same as in Method 6, Section 
5.1.2.
    5.2  Thermometers for DGM and Barometer. Same as in Method 6, 
Section 5.2 and 5.4, respectively.
    5.3  Calibration Curve for Ion Chromatograph. Dilute a given volume 
(1.0 ml or greater) of the KNO3 standard solution to a 
convenient volume with water, and use this solution to prepare 
calibration standards. Prepare at least four standards to cover the 
range of the samples being analyzed. Use pipettes for all additions. Run 
standards as instructed in Section 4.4. Determine peak height or area, 
and plot the individual values versus concentration in 
gNO3-/ml. Do not

[[Page 842]]

force the curve through zero. Draw a smooth curve through the points. 
The curve should be linear. With the linear curve, use linear regression 
to determine the calibration equation.

6. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after final 
calculation.
    6.1  Sample Volume, Dry Basis, Corrected to Standard Conditions. 
Same as in Method 7C, Section 6.1.
    6.2  Total g NO2 Per Sample.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.166
    
Where:

m=Mass of NOx, as NO2, in sample, g.
S=Analysis of sample, g NO3-/ml.
B=Analysis of blank, g NO3-/ml.
250=Volume of prepared sample, ml.
46.01=Molecular weight of NO2-.
62.01=Molecular weight of NO3-.
1000=Total volume of KMnO4 solution, ml.
50=Aliquot KMnO4/NaOH solution, ml.
    6.3  Sample Concentration.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.167
    
Where:
C=Concentration of NOx as NO2, dry basis, mg/dscm.
K2=10-3 mg/g.
Vm(std)=Dry gas volume measured by the dry gas meter, 
          corrected to standard conditions, dscm.
    6.4  Conversion Factors.
1.0 ppm NO=1.247 mg NO/m3 at STP.
1.0 ppm NO2=1.912 mg NO2/m3 at STP.
1 ft3=2.832 x 10-2 m3.
1000 mg = 1 g.

7. Quality Control

    Quality control procedures are specified in Sections 4.1.3 (flow 
rate accuracy) and 4.5 (audit analysis accuracy) of Method 7C.

8. Bibliography

    1. Margeson, J.H., W.J. Mitchell, J.C. Suggs, and M.R. Midgett. 
Integrated Sampling and Analysis Methods for Determining NOx 
Emissions at Electric Utility Plants. U.S. Environmental Protection 
Agency, Research Triangle Park, NC. Journal of the Air Pollution Control 
Association. 32:1210-1215. 1982.
    2. Memorandum and attachment from J.H. Margeson, Source Branch, 
Quality Assurance Division, Environmental Monitoring Systems Laboratory, 
to The Record, EPA. March 30, 1983. NH3 Interference in 
Methods 7C and 7D.
    3. Quality Assurance Handbook for Air Pollution Measurement Systems. 
Volume III--Stationary Source Specific Methods. U.S. Environmental 
Protection Agency, Research Triangle Park, NC. Publication No. EPA-600/
4-77-027b. August 1977.
    4. Margeson, J.H., et al. An Integrated Method for determining 
NOx Emissions at Nitric Acid Plants. Manuscript submitted to 
Analytical Chemistry. April 1984.

 Method 7E--Determination of Nitrogen Oxides Emissions From Stationary 
                Sources (Instrumental Analyzer Procedure)

1. Applicability and Principle

    1.1  Applicability. This method is applicable to the determination 
of nitrogen oxides (NOx) concentrations in emissions from 
stationary sources only when specified within the regulations.
    1.2  Principle. A gas simple is continuously extracted from a stack, 
and a portion of the sample is conveyed to an instrumental 
chemiluminescent analyzer for determination of NOx 
concentration. Performance specifications and test procedures are 
provided to ensure reliable data.

2. Range and Sensitivity

    Same as Method 6C, Sections 2.1 and 2.2.

3. Definitions

    3.1  Measurement System. The total equipment required for the 
determination of NOx concentration. The measurement system 
consists of the following major subsystems:
    3.1.1  Sample Interface, Gas Analyzer, and Data Recorder. Same as 
Method 6C, Sections 3.1.1, 3.1.2, and 3.1.3.
    3.1.2  NO2 to NO Converter. A device that converts the 
nitrogen dioxide (NO2) in the sample gas to nitrogen oxide 
(NO).
    3.2  Span, Calibration Gas, Analyzer Calibration Error, Sampling 
System Bias, Zero Drift, Calibration Drift, and Response Time. Same as 
Method 6C, Sections 3.2 through 3.8.
    3.3  Interference Response. The output response of the measurement 
system to a component in the sample gas, other than the gas component 
being measured.

4. Measurement System Performance Specifications


[[Page 843]]


    Same as Method 6C, Sections 4.1 through 4.4.

5. Apparatus and Reagents

    5.1  Measurement System. Any measurement system for NOx 
that meets the specifications of this method. A schematic of an 
acceptable measurement system is shown in Figure 6C-1 of Method 6C. The 
essential components of the measurement system are described below:
    5.1.1  Sample Probe, Sample Line, Calibration Valve Assembly, 
Moisture Removal System, Particulate Filter, Sample Pump, Sample Flow 
Rate Control, Sample Gas Manifold, and Data Recorder. Same as Method 6C, 
Sections 5.1.1 through 5.1.9, and 5.1.11.
    5.1.2  NO2 to NO Converter. That portion of the system 
that converts the nitrogen dioxide (NO2) in the sample gas to 
nitrogen oxide (NO). An NO2 to NO converter is not necessary 
if data are presented to demonstrate that the NO2 portion of 
the exhaust gas is less than 5 percent of the total NOx 
concentration.
    5.1.3  NOx Analyzer. An analyzer based on the principles 
of chemiluminescence, to determine continuously the NOx 
concentration in the sample gas stream. The analyzer shall meet the 
applicable performance specifications of Section 4. A means of 
controlling the analyzer flow rate and a device for determining proper 
sample flow rate (e.g., precision rotameter, pressure gauge downstream 
of all flow controls, etc.) shall be provided at the analyzer.
    5.2 NOx Calibration Gases. The calibration gases for the 
NOx analyzer shall be NO in N2. Three calibration 
gases, as specified in Sections 5.3.1 through 5.3.3. of Method 6C, shall 
be used. Ambient air may be used for the zero gas.

6. Measurement System Performance Test Procedures

    Perform the following procedures before measurement of emissions 
(Section 7).
    6.1 Calibration Gas Concentration Verification. Follow Section 6.1 
of Method 6C, except if calibration gas analysis is required, use Method 
7, and change all 5 percent performance values to 10 percent (or 10 ppm, 
whichever is greater).
    6.2 Interference Response. Conduct an interference response test of 
the analyzer prior to its initial use in the field. Thereafter, recheck 
the measurement system if changes are made in the instrumentation that 
could alter the interference response (e.g., changes in the gas 
detector). Conduct the interference response in accordance with Section 
5.4 of Method 20.
    6.3 Measurement System Preparation, Analyzer Calibration Error, and 
Sample System Bias Check. Follow Sections 6.2 through 6.4 of Method 6C.
    6.4 NO2 to NO Conversion Efficiency. Unless data are 
presented to demonstrate that the NO2 concentration within 
the sample stream is not greater than 5 percent of the NOx 
concentration, conduct an NO2 to NO conversion efficiency 
test in accordance with Section 5.6 of Method 20.

7. Emission Test Procedure

    7.1 Selection of Sampling Site and Sampling Points. Select a 
measurement site and sampling points using the same criteria that are 
applicable to tests performed using Method 7.
    7.2 Sample Collection. Position the sampling probe at the first 
measurement point, and begin sampling at the same rate as used during 
the system calibration drift test. Maintain constant rate sampling 
(i.e., 10 percent) during the entire run. The sampling time 
per run shall be the same as the total time required to perform a run 
using Method 7, plus twice the system response time. For each run, use 
only those measurements obtained after twice the response time of the 
measurement system has elapsed, to determine the average effluent 
concentration.
    7.3 Zero and Calibration Drift Test. Follow Section 7.4 of Method 
6C.

8. Emission Calculation

    Follow Section 8 of Method 6C.

9. Bibliography

    Same as bibliography of Method 6C.

    Method 8--Determination of Sulfuric Acid Mist and Sulfur Dioxide 
                    Emissions From Stationary Sources

1. Principle and Applicability

    1.1  Principle. A gas sample is extracted isokinetically from the 
stack. The sulfuric acid mist (including sulfur trioxide) and the sulfur 
dioxide are separated, and both fractions are measured separately by the 
barium-thorin titration method.
    1.2  Applicability. This method is applicable for the determination 
of sulfuric acid mist (including sulfur trioxide, and in the absence of 
other particulate matter) and sulfur dioxide emissions from stationary 
sources. Collaborative tests have shown that the minimum detectable 
limits of the method are 0.05 milligrams/cubic meter (0.03>10-7 
pounds/cubic foot) for sulfur trioxide and 1.2 mg/m3 (0.74 
10-7 lb/ft3) for sulfur dioxide. No upper limits 
have been established. Based on theoretical calculations for 200 
milliters of 3 percent hydrogen peroxide solution, the upper 
concentration limit for sulfur dioxide in a 1.0 m3 (35.3 
ft3) gas sample is about 12,500 mg/m3 
(7.7 x 10-4 lb/ft3). The upper limit can be 
extended by increasing the quantity of peroxide solution in the 
impingers.
    Possible interfering agents of this method are fluorides, free 
ammonia, and dimethyl aniline. If any of these interfering agents are 
present (this can be determined by knowledge of the process), 
alternative methods,

[[Page 844]]

subject to the approval of the Administrator, U. S. E. P.A., are 
required.
    Filterable particulate matter may be determined along with SO3 
and SO2 (subject to the approval of the Administrator) by 
inserting a heated glass fiber filter between the probe and isopropanol 
impinger (see Section 2.1 of Method 6.) If this option is chosen, 
particulate analysis is gravimetric only; H2SO4 
acid mist is not determined separately.

2. Apparatus

    2.1  Sampling. A schematic of the sampling train used in this method 
is shown in Figure 8-1; it is similiar to the Method 5 train except that 
the filter position is different and the filter holder does not have to 
be heated. Commercial models of this train are available. For those who 
desire to build their own, however, complete construction details are 
described in APTD-0581. Changes from the APTD-0581 document and 
allowable modifications to Figure 8-1 are discussed in the following 
subsections.
    The operating and maintenance procedures for the sampling train are 
described in APTD-0576. Since correct usage is important in obtaining 
valid results, all users should read the APTD-0576 document and adopt 
the operating and maintenance procedures outlined in it, unless 
otherwise specified herein. Further details and guidelines on operation 
and maintenance are given in Method 5 and should be read and followed 
whenever they are applicable.
    2.1.1  Probe Nozzle. Same as Method 5, Section 2.1.1.
    2.1.2  Probe Liner. Borosilicate or quartz glass, with a heating 
system to prevent visible condensation during sampling. Do not use metal 
probe liners.
    2.1.3  Pitot Tube. Same as Method 5, Section 2.1.3.

[[Page 845]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.149

    2.1.4  Differential Pressure Gauge. Same as Method 5, Section 2.1.4.
    2.1.5  Filter Holder. Borosilicate glass, with a glass frit filter 
support and a silicone rubber gasket. Other gasket materials, e.g., 
Teflon or Viton, may be used subject to the approval of the 
Administrator. The holder design shall provide a positive seal against 
leakage from the outside or around the filter. The filter holder shall 
be placed between the first and second impingers. Note: Do not heat the 
filter holder.
    2.1.6  Impingers. Four, as shown in Figure 8-1. The first and third 
shall be of the Greenburg-Smith design with standard tips. The second 
and fourth shall be of the Greenburg-Smith design, modified by replacing 
the insert with an approximately 13 millimeter (0.5 in.) ID glass tube, 
having an unconstricted tip located 13 mm (0.5 in.) from the bottom of 
the flask. Similar collection systems, which have been approved by the 
Administrator, may be used.
    2.1.7  Metering System. Same as Method 5, Section 2.1.8.
    2.1.8  Barometer. Same as Method 5, Section 2.1.9.

[[Page 846]]

    2.1.9  Gas Density Determination Equipment. Same as Method 5, 
Section 2.1.10.
    2.1.10  Temperature Gauge. Thermometer, or equivalent, to measure 
the temperature of the gas leaving the impinger train to within 1  deg.C 
(2  deg.F).
    2.2  Sample Recovery.
    2.2.1  Wash Bottles. Polyethylene or glass, 500 ml. (two).
    2.2.2  Graduated Cylinders. 250 ml, 1 liter. (Volumetric flasks may 
also be used.
    2.2.3  Storage Bottles. Leak-free polyethlene bottles, 1000 ml size 
(two for each sampling run).
    2.2.4  Trip Balance. 500-gram capacity, to measure to 
plus-minus0.5 g (necessary only if a moisture content 
analysis is to be done).
    2.3  Analysis.
    2.3.1  Pipettes. Volumetric 25 ml, 100 ml.
    2.3.2  Burette, 50 ml.
    2.3.3  Erlenmeyer Flask. 250 ml. (one for each sample, blank, and 
standard).
    2.3.4  Graduated Cylinder. 100 ml.
    2.3.5  Trip Balance. 500 g capacity, to measure to 
plus-minus0.5 g.
    2.3.6  Dropping Bottle. To add indicator solution, 125-ml size.

3. Reagents

    Unless otherwise indicated, all reagents are to conform to the 
specifications established by the Committee on Analytical Reagents of 
the American Chemical Society, where such specifications are available. 
Otherwise, use the best available grade.
    3.1  Sampling.
    3.1.1  Filters. Same as Method 5, Section 3.1.1.
    3.1.2  Silica Gel. Same as Method 5, Section 3.1.2.
    3.1.3  Water. Deionized, distilled to conform to ASTM Specification 
D1193-77, Type 3 (incorporated by reference--see Sec. 60.17). At the 
option of the analyst, the KMnO4 test for oxidizable organic 
matter may be omitted when high concentrations of organic matter are not 
expected to be present.
    3.1.4  Isopropanol. 80 Percent. Mix 800 ml of isopropanol with 200 
ml of deionized, distilled water.
    Note: Experience has shown that only A.C.S. grade isopropanol is 
satisfactory. Tests have shown that isopropanol obtained from commercial 
sources occasionally has peroxide impurities that will cause erroneously 
high sulfuric acid mist measurement. Use the following test for 
detecting peroxides in each lot of isopropanol: Shake 10 ml of the 
isopropanol with 10 ml of freshly prepared 10 percent potassium iodide 
solution. Prepare a blank by similarly treating 10 ml of distilled 
water. After 1 minute, read the absorbance on a spectrophotometer at 352 
nanometers. If the absorbance exceeds 0.1, the isopropanol shall not be 
used. Peroxides may be removed from isopropanol by redistilling, or by 
passage through a column of activated alumina. However, reagent grade 
isopropanol with suitably low peroxide levels is readily available from 
commercial sources; therefore, rejection of contaminated lots may be 
more efficient than following the peroxide removal procedure.
    3.1.5  Hydrogen Peroxide, 3 Percent. Dilute 100 ml of 30 percent 
hydrogen peroxide to 1 liter with deionized, distilled water. Prepare 
fresh daily.
    3.1.6  Crushed Ice.
    3.2  Sample Recovery.
    3.2.1  Water. Same as 3.1.3.
    3.2.2  Isopropanol, 80 Percent. Same as 3.1.4.
    3.3  Analysis.
    3.3.1  Water. Same as 3.1.3.
    3.3.2  Isopropanol, 100 Percent.
    3.3.3  Thorin Indicator. 1-(o-arsonophenylazo) 2-naphthol-3, 6-
disulfonic acid, disodium salt, or equivalent. Dissolve 0.20 g in 100 ml 
of deionized, distilled water.
    3.3.4  Barium Perchlorate (0.0100 Normal). Dissolve 1.95 g of barium 
perchlorate trihydrate (Ba(C104)2  
3H2O) in 200 ml deionized, distilled water, and dilute to 1 
liter with isopropanol; 1.22 g of barium chloride dihydrate (BaC12 
 2H2O) may be used instead of the barium 
perchlorate. Standardize with sulfuric acid as in Section 5.2. This 
solution must be protected against evaporation at all times.
    3.3.5  Sulfuric Acid Standard (0.0100 N). Purchase or standardize to 
plus-minus0.0002 N against 0.0100 N NaOH that has previously 
been standardized against primary standard potassium acid phthalate.
    3.3.6  Quality Assurance Audit Samples. Same as in Method 6, Section 
3.3.6.

4. Procedure

    4.1  Sampling.
    4.1.1  Pretest Preparation. Follow the procedure outlined in Method 
5, Section 4.1.1; filters should be inspected, but need not be 
desiccated, weighed, or identified. If the effluent gas can be 
considered dry, i.e., moisture free, the silica gel need not be weighed.
    4.1.2  Preliminary Determinations. Follow the procedure outlined in 
Method 5, Section 4.1.2.
    4.1.3  Preparation of Collection Train. Follow the procedure 
outlined in Method 5, Section 4.1.3 (except for the second paragraph and 
other obviously inapplicable parts) and use Figure 8-1 instead of Figure 
5-1. Replace the second paragraph with: Place 100 ml of 80 percent 
isopropanol in the first impinger, 100 ml of 3 percent hydrogen peroxide 
in both the second and third impingers; retain a portion of each reagent 
for use as a blank solution. Place about 200 g of silica gel in the 
fourth impinger.
    Note: If moisture content is to be determined by impinger analysis, 
weigh each of the first three impingers (plus absorbing solution) to the 
nearest 0.5 g and record these

[[Page 847]]

weights. The weight of the silica gel (or silica gel plus container) 
must also be determined to the nearest 0.5 g and recorded.
    4.1.4  Pretest Leak-Check Procedure. Follow the basic procedure 
outlined in Method 5, Section 4.1.4.1, noting that the probe heater 
shall be adjusted to the minimum temperature required to prevent 
condensation, and also that verbage such as, ``. . . plugging the inlet 
to the filter holder . . .,'' shall be replaced by, ``. . . plugging the 
inlet to the first impinger . . .'' The pretest leak-check is optional.
    4.1.5  Train Operation. Follow the basic procedures outlined in 
Method 5, Section 4.1.5, in conjunction with the following special 
instructions. Data shall be recorded on a sheet similar to the one in 
Figure 8-2. The sampling rate shall not exceed 0.030 m3/min 
(1.0 cfm) during the run. Periodically during the test, observe the 
connecting line between the probe and first impinger for signs of 
condensation. If it does occur, adjust the probe heater setting upward 
to the minimum temperature required to prevent condensation. If 
component changes become necessary during a run, a leak-check shall be 
done immediately before each change, according to the procedure outlined 
in Section 4.1.4.2 of Method 5 (with appropriate modifications, as 
mentioned in Section 4.1.4 of this method); record all leak rates. If 
the leakage rate(s) exceed the specified rate, the tester shall either 
void the run or shall plan to correct the sample volume as outlined in 
Section 6.3 of Method 5. Immediately after component changes, leak-
checks are optional. If these leak-checks are done, the procedure 
outlined in Section 4.1.4.1 of Method 5 (with appropriate modifications) 
shall be used.

[[Page 848]]



                                             Figure 8-2--Field Data
 
                                  --------------------------------------
Plant............................                                        Static pressure, mm Hg (in. Hg)..  ....
Location.........................                                        Ambient temperature..............  ....
Operator.........................                                        Barometer pressure...............  ....
Date.............................                                        Assumed moisture, %..............  ....
Run No...........................                                        Probe length, m (ft).............  ....
Sample box No....................                                        Nozzle identification No.........  ....
Meter box No.....................                                        Average calibrated nozzle          ....
                                                                          diameter, cm (in.).
Meter  H@...............                                        Probed heater setting............  ....
C factor.........................                                        Leak rate, m\3\/min, (cfm).......  ....
Pitot tube coefficient, Cp.......                                        Probe liner material.............  ....
                                                                         Filter No........................  ....
                                  --------------------------------------
                                        Schematic of Stack Cross Section


------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                                            Pressure                         Gas sample temperature at dry gas   Temperature of
                                                                          Stack         Velocity head     differential-      Gas sample                    meter                   gas leaving
     Traverse point number        Sampling time        Vacuum       temperature (TS)    ( P)    across orifice        volume      ------------------------------------   condenser or
                                                                                                              meter                               Inlet            Outlet         last impinger
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                (),     mm Hg (in. Hg)..    deg.C (         mm H20 (in H20).  mm H20 (in H20).  m\3\ (ft\3\)....    deg.C (           deg.C (           deg.C (
                                 min..                               deg.F).                                                                 deg.F).           deg.F).           deg.F)
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Total                                                                                                                                       Avg               Avg
Average                                                                                                                                     Avg


[[Page 849]]

    After turning off the pump and recording the final readings at the 
conclusion of each run, remove the probe from the stack. Conduct a post-
test (mandatory) leak-check as in Section 4.1.4.3 of Method 5 (with 
appropriate modification) and record the leak rate. If the post-test 
leakage rate exceeds the specified acceptable rate, the tester shall 
either correct the sample volume, as outlined in Section 6.3 of Method 
5, or shall void the run.
    Drain the ice bath and, with the probe disconnected, purge the 
remaining part of the train, by drawing clean ambient air through the 
system for 15 minutes at the average flow rate used for sampling.
    Note: Clean ambient air can be provided by passing air through a 
charcoal filter. At the option of the tester, ambient air (without 
cleaning) may be used.
    4.1.6  Calculation of Percent Isokinetic. Follow the procedure 
outlined in Method 5, Section 4.1.6.
    4.2  Sample Recovery.
    4.2.1  Container No. 1. If a moisture content analysis is to be 
done, weigh the first impinger plus contents to the nearest 0.5 g and 
record this weight.
    Transfer the contents of the first impinger to a 250-ml graduated 
cylinder. Rinse the probe, first impinger, all connecting glassware 
before the filter, and the front half of the filter holder with 80 
percent isopropanol. Add the rinse solution to the cylinder. Dilute to 
250 ml with 80 percent isopropanol. Add the filter to the solution, mix, 
and transfer to the storage container. Protect the solution against 
evaporation. Mark the level of liquid on the container and identify the 
sample container.
    4.2.2  Container No. 2. If a moisture content analysis is to be 
done, weigh the second and third impingers (plus contents) to the 
nearest 0.5 g and record these weights. Also, weigh the spent silica gel 
(or silica gel plus impinger) to the nearest 0.5 g.
    Transfer the solutions from the second and third impingers to a 
1000-ml graduated cylinder. Rinse all connecting glassware (including 
back half of filter holder) between the filter and silica gel impinger 
with deionized, distilled water, and add this rinse water to the 
cylinder. Dilute to a volume of 1000 ml with deionized, distilled water. 
Transfer the solution to a storage container. Mark the level of liquid 
on the container. Seal and identify the sample container.
    4.3  Analysis.
    Note the level of liquid in Containers 1 and 2, and confirm whether 
or not any sample was lost during shipment; note this on the analytical 
data sheet. If a noticeable amount of leakage has occured, either void 
the sample or use methods, subject to the approval of the Administrator, 
to correct the final results.
    4.3.1  Container No. 1. Shake the container holding the isopropanol 
solution and the filter. If the filter breaks up, allow the fragments to 
settle for a few minutes before removing a sample. Pipette a 100-ml 
aliquot of this solution into a 250-ml Erlenmeyer flask, add 2 to 4 
drops of thorin indicator, and titrate to a pink endpoint using 0.0100 N 
barium perchlorate. Repeat the titration with a second aliquot of sample 
and average the titration values. Replicate titrations must agree within 
1 percent or 0.2 ml, whichever is greater.
    4.3.2  Container No. 2. Thoroughly mix the solution in the container 
holding the contents of the second and third impingers. Pipette a 10-ml 
aliquot of sample into a 250-ml Erlenmeyer flask. Add 40 ml of 
isopropanol, 2 to 4 drops of thorin indicator, and titrate to a pink 
endpoint using 0.0100 N barium perchlorate. Repeat the titration with a 
second aliquot of sample and average the titration values. Replicate 
titrations must agree within 1 percent or 0.2 ml, whichever is greater.
    4.3.3  Blanks. Prepare blanks by adding 2 to 4 drops of thorin 
indicator to 100 ml of 80 percent isopropanol. Titrate the blanks in the 
same manner as the samples.
    4.4  Quality Control Procedures. Same as in Method 5, Section 4.4.
    4.5  Audit Sample Analysis. Same as in Method 6, Section 4.4.

5. Calibration

    5.1  Calibrate equipment using the procedures specified in the 
following sections of Method 5: Section 5.3 (metering system); Section 
5.5 (temperature gauges); Section 5.7 (barometer). Note that the 
recommended leak-check of the metering system, described in Section 5.6 
of Method 5, also applies to this method.
    5.2  Standardize the barium perchlorate solution with 25 ml of 
standard sulfuric acid, to which 100 ml of 100 percent isopropanol has 
been added.

6. Calculations
    Note: Carry out calculations retaining at least one extra decimal 
figure beyond that of the acquired data. Round off figures after final 
calculation.
    6.1  Nomenclature.
An=Cross-sectional area of nozzle, 
          m2(ft2).
Bws=Water vapor in the gas stream, proportion by volume.
CH2SO4=Sulfuric acid (including SO3) 
          concentration, g/dscm (lb/dscf).
CSO2=Sulfur dioxide concentration, g/dscm (lb/dscf).
I=Percent of isokinetic sampling.
N=Normality of barium perchlorate titrant, meq/ml.
Pbar=Barometric pressure at the sampling site, mm Hg (in. 
          Hg).
Ps=Absolute stack gas pressure, mm Hg (in. Hg).

[[Page 850]]

Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
Tm=Average absolute dry gas meter temperature (see Figure 8-
          2),  deg. K ( deg. R).
Ts=Average absolute stack gas temperature (see Figure 8-2), 
          deg. K ( deg. R).
Tstd=Standard absolute temperature, 293 deg.K (528 deg.R).
Va=Volume of sample aliquot titrated, 100 ml for 
          H2SO4 and 10 ml for SO2.
Vlc=Total volume of liquid collected in impingers and 
          silica gel, ml.
Vm=Volume of gas sample as measured by dry gas meter, dcm 
          (dcf).
Vm(std)=Volume of gas sample measured by the dry gas meter 
          corrected to standard conditions, dscm (dscf).
vs=Average stack gas velocity, calculated by Method 2, 
          Equation 2-9, using data obtained from Method 8, m/sec (ft/
          sec).
Vsoln=Total volume of solution in which the sulfuric acid or 
          sulfur dioxide sample is contained, 250 ml or 1,000 ml, 
          respectively.
Vt=Volume of barium perchlorate titrant used for the sample, 
          ml.
Vtb=Volume of barium perchlorate titrant used for the blank, 
          ml.
Y=Dry gas meter calibration factor.
H=Average pressure drop across orifice meter, mm (in.) 
          H2O.
1=0.3858  deg.K/mm Hg for metric units.
  =17.64  deg.R/in., Hg for English units.
    Note: If the leak rate observed during any mandatory leak-checks 
exceeds the specified acceptable rate, the tester shall either correct 
the value of Vm in Equation 8-1 (as described in Section 6.3 
of Method 5), or shall invalidate the test run.
    6.4  Volume of Water Vapor and Moisture Content. Calculate the 
volume of water vapor using Equation 5-2 of Method 5; the weight of 
water collected in the impingers and silica gel can be directly 
converted to milliliters (the specific gravity of water is 1 g/ml). 
Calculate the moisture content of the stack gas, using Equation 5-3 of 
Method 5. The ``Note'' in Section 6.5 of Method 5 also applies to this 
method. Note that if the effluent gas stream can be considered dry, the 
volume of water vapor and moisture content need not be calculated.
    6.5  Sulfuric Acid Mist (including SO3) Concentration.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.151
    
Where:
K2=0.04904 g/milliequivalent for metric units.
  =1.081 x 10-4lb/meq for English units.
6.6  Sulfur Dioxide Concentration.
[GRAPHIC] [TIFF OMITTED] TC01JN92.152

Where:
K3=0.03203 g/meq for metric units.
  =7.061 x 10-5 lb/meq for English units.
6.7  Isokinetic Variation.
6.7.1  Calculation from Raw Data.

[[Page 851]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.248

Where:
K4=0.003464 mm Hg-m3/ml- deg.K for metric units.
  =0.002676 in. Hg-ft3/ml- deg.R for English units.
6.7.2  Calculation from Intermediate Values.
[GRAPHIC] [TIFF OMITTED] TC01JN92.153

where:

K5=4.320 for metric units.
  =0.09450 for English units
    6.8  Acceptable Results. If 90 percent < I <110 percent, the results 
are acceptable. If the results are low in comparison to the standards 
and I is beyond the acceptable range, the Administrator may opt to 
accept the results. Use Citation 4 in the Bibliography of Method 5 to 
make judgments. Otherwise, reject the results and repeat the test.
    6.9  Stack Gas Velocity and Volumetric Flow Rate. Calculate the 
average stack gas velocity and volumetric flow rate, if needed, using 
data obtained in this method and equations in Sections 5.2 and 5.3 of 
Method 2.
    6.10  Relative Error (RE) for QA Audit Samples. Same as in Method 6, 
Section 6.4.

7. Bibliography

    1. Atmospheric Emissions from Sulfuric Acid Manufacturing Processes. 
U.S. DHEW, PHS, Division of Air Pollution. Public Health Service 
Publication No. 999-AP-13. Cincinnati, OH. 1965.
    2. Corbett, P. F. The Determination of SO2 and SO3 
in Flue Gases. Journal of the Institute of Fuel. 24:237-243. 1961.
    3. Martin, Robert M. Construction Details of Isokinetic Source 
Sampling Equipment. Environmental Protection Agency. Research Triangle 
Park, NC. Air Pollution Control Office Publication No. APTD-0581. April, 
1971.
    4. Patton, W. F. and J. A. Brink, Jr. New Equipment and Techniques 
for Sampling Chemical Process Gases. Journal of Air Pollution Control 
Association. 13:162. 1963.
    5. Rom, J. J. Maintenance, Calibration, and Operation of Isokinetic 
Source-Sampling Equipment. Office of Air Programs, Environmental 
Protection Agency. Research Triangle Park, NC. APTD-0576. March, 1972.
    6. Hamil, H. F. and D. E. Camann. Collaborative Study of Method for 
Determination of Sulfur Dioxide Emissions from Stationary Sources 
(Fossil Fuel-Fired Steam Generators). Environmental Protection Agency. 
Research Triangle Park, NC. EPA-650/4-74-024. December, 1973.
    7. Annual Book of ASTM Standards. Part 31; Water, Atmospheric 
Analysis. pp. 40-42. American Society for Testing and Materials. 
Philadelphia, Pa. 1974.

    Method 9--Visual Determination of the Opacity of Emissions From 
                           Stationary Sources

    Many stationary sources discharge visible emissions into the 
atmosphere; these emissions are usually in the shape of a plume. This 
method involves the determination of plume opacity by qualified 
observers. The method includes procedures for the training and 
certification of observers, and procedures to be used in the field for 
determination of plume opacity. The appearance of a plume as viewed by 
an observer depends upon a number of variables, some of which may be 
controllable and some of which may not be controllable in the field. 
Variables which can be controlled to an extent to which they no longer 
exert a significant influence upon plume appearance include: Angle of 
the observer with respect to the plume; angle of the observer with 
respect to the sun; point of observation of attached and detached steam 
plume; and angle of the observer with respect to a plume emitted from a 
rectangular stack with a large length to width ratio. The method 
includes specific criteria applicable to these variables.
    Other variables which may not be controllable in the field are 
luminescence and color contrast between the plume and the background 
against which the plume is viewed. These variables exert an influence 
upon the appearance of a plume as viewed by an observer, and can affect 
the ability of the observer to accurately assign opacity values to the 
observed plume. Studies of the theory of plume opacity and field studies 
have demonstrated that a plume is most visible and presents the greatest 
apparent opacity when viewed against a contrasting background. It 
follows from this, and is confirmed by field trials, that the opacity of 
a plume, viewed under conditions where a contrasting background is 
present can be assigned with the greatest degree of accuracy. However, 
the potential for a positive error is also the greatest when a plume is 
viewed under such contrasting conditions. Under conditions presenting a 
less contrasting background, the apparent opacity of a plume is less and

[[Page 852]]

approaches zero as the color and luminescence contrast decrease toward 
zero. As a result, significant negative bias and negative errors can be 
made when a plume is viewed under less contrasting conditions. A 
negative bias decreases rather than increases the possibility that a 
plant operator will be cited for a violation of opacity standards due to 
observer error.
    Studies have been undertaken to determine the magnitude of positive 
errors which can be made by qualified observers while reading plumes 
under contrasting conditions and using the procedures set forth in this 
method. The results of these studies (field trials) which involve a 
total of 769 sets of 25 readings each are as follows:
    (1) For black plumes (133 sets at a smoke generator), 100 percent of 
the sets were read with a positive error \1\ of less than 7.5 
percent opacity; 99 percent were read with a positive error of less than 
5 percent opacity.
---------------------------------------------------------------------------

    \1\  For a set, positive error = average opacity 
determined by observers' 25 observations--average opacity determined 
from transmissometer's 25 recordings.
---------------------------------------------------------------------------

    (2) For white plumes (170 sets at a smoke generator, 168 sets at a 
coal-fired power plant, 298 sets at a sulfuric acid plant), 99 percent 
of the sets were read with a positive error of less than 7.5 percent 
opacity; 95 percent were read with a positive error of less than 5 
percent opacity.
    The positive observational error associated with an average of 
twenty-five readings is therefore established. The accuracy of the 
method must be taken into account when determining possible violations 
of applicable opacity standards.

1. Principle and Applicability

    1.1 Principle. The opacity of emissions from stationary sources is 
determined visually by a qualified observer.
    1.2 Applicability. This method is applicable for the determination 
of the opacity of emissions from stationary sources pursuant to 
Sec. 60.11(b) and for qualifying observers for visually determining 
opacity of emissions.

2. Procedures

    The observer qualified in accordance with section 3 of this method 
shall use the following procedures for visually determining the opacity 
of emissions:
    2.1 Position. The qualified observer shall stand at a distance 
sufficient to provide a clear view of the emissions with the sun 
oriented in the 140 deg. sector to his back. Consistent with maintaining 
the above requirement, the observer shall, as much as possible, make his 
observations from a position such that his line of vision is 
approximately perpendicular to the plume direction, and when observing 
opacity of emissions from rectangular outlets (e.g., roof monitors, open 
baghouses, noncircular stacks), approximately perpendicular to the 
longer axis of the outlet. The observer's line of sight should not 
include more than one plume at a time when multiple stacks are involved, 
and in any case the observer should make his observations with his line 
of sight perpendicular to the longer axis of such a set of multiple 
stacks (e.g., stub stacks on baghouses).
    2.2 Field Records. The observer shall record the name of the plant, 
emission location, type facility, observer's name and affiliation, a 
sketch of the observer's position relative to the source, and the date 
on a field data sheet (Figure 9-1). The time, estimated distance to the 
emission location, approximate wind direction, estimated wind speed, 
description of the sky condition (presence and color of clouds), and 
plume background are recorded on a field data sheet at the time opacity 
readings are initiated and completed.
    2.3 Observations. Opacity observations shall be made at the point of 
greatest opacity in that portion of the plume where condensed water 
vapor is not present. The observer shall not look continuously at the 
plume, but instead shall observe the plume momentarily at 15-second 
intervals.
    2.3.1 Attached Steam Plumes. When condensed water vapor is present 
within the plume as it emerges from the emission outlet, opacity 
observations shall be made beyond the point in the plume at which 
condensed water vapor is no longer visible. The observer shall record 
the approximate distance from the emission outlet to the point in the 
plume at which the observations are made.
    2.3.2 Detached Steam Plume. When water vapor in the plume condenses 
and becomes visible at a distinct distance from the emission outlet, the 
opacity of emissions should be evaluated at the emission outlet prior to 
the condensation of water vapor and the formation of the steam plume.
    2.4 Recording Observations. Opacity observations shall be recorded 
to the nearest 5 percent at 15-second intervals on an observational 
record sheet. (See Figure 9-2 for an example.) A minimum of 24 
observations shall be recorded. Each momentary observation recorded 
shall be deemed to represent the average opacity of emissions for a 15-
second period.
    2.5 Data Reduction. Opacity shall be determined as an average of 24 
consecutive observations recorded at 15-second intervals. Divide the 
observations recorded on the record sheet into sets of 24 consecutive 
observations. A set is composed of any 24 consecutive observations. Sets 
need not be consecutive in time and in no case shall two sets overlap. 
For each set of 24 observations, calculate the average by summing the 
opacity of the 24 observations and dividing this sum

[[Page 853]]

by 24. If an applicable standard specifies an averaging time requiring 
more than 24 observations, calculate the average for all observations 
made during the specified time period. Record the average opacity on a 
record sheet. (See Figure 9-1 for an example.)

3. Qualifications and Testing

    3.1 Certification Requirements. To receive certification as a 
qualified observer, a candidate must be tested and demonstrate the 
ability to assign opacity readings in 5 percent increments to 25 
different black plumes and 25 different white plumes, with an error not 
to exceed 15 percent opacity on any one reading and an average error not 
to exceed 7.5 percent opacity in each category. Candidates shall be 
tested according to the procedures described in section 3.2. Smoke 
generators used pursuant to section 3.2 shall be equipped with a smoke 
meter which meets the requirements of section 3.3.
    The certification shall be valid for a period of 6 months, at which 
time the qualification procedure must be repeated by any observer in 
order to retain certification.
    3.2 Certification Procedure. The certification test consists of 
showing the candidate a complete run of 50 plumes--25 black plumes and 
25 white plumes--generated by a smoke generator. Plumes within each set 
of 25 black and 25 white runs shall be presented in random order. The 
candidate assigns an opacity value to each plume and records his 
observation on a suitable form. At the completion of each run of 50 
readings, the score of the candidate is determined. If a candidate fails 
to qualify, the complete run of 50 readings must be repeated in any 
retest. The smoke test may be administered as part of a smoke school or 
training program, and may be preceded by training or familiarization 
runs of the smoke generator during which candidates are shown black and 
white plumes of known opacity.
    3.3 Smoke Generator Specifications. Any smoke generator used for the 
purposes of section 3.2 shall be equipped with a smoke meter installed 
to measure opacity across the diameter of the smoke generator stack. The 
smoke meter output shall display instack opacity based upon a pathlength 
equal to the stack exit diameter, on a full 0 to 100 percent chart 
recorder scale. The smoke meter optical design and performance shall 
meet the specifications shown in Table 9-1. The smoke meter shall be 
calibrated as prescribed in section 3.3.1 prior to the conduct of each 
smoke reading test. At the completion of each test, the zero and span 
drift shall be checked and if the drift exceeds plus-minus1 
percent opacity, the condition shall be corrected prior to conducting 
any subsequent test runs. The smoke meter shall be demonstrated, at the 
time of installation, to meet the specifications listed in Table 9-1. 
This demonstration shall be repeated following any subsequent repair or 
replacement of the photocell or associated electronic circuitry 
including the chart recorder or output meter, or every 6 months, 
whichever occurs first.

      Table 9-1--Smoke Meter Design and Performance Specifications
------------------------------------------------------------------------
                Parameter                          Specification
------------------------------------------------------------------------
a. Light source..........................  Incandescent lamp operated at
                                            nominal rated voltage.
b. Spectral response of photocell........  Photopic (daylight spectral
                                            response of the human eye--
                                            Citation 3).
c. Angle of view.........................  15 deg. maximum total angle.
d. Angle of projection...................  15 deg. maximum total angle.
e. Calibration error.....................  plus-minus3% opacity,
                                            maximum.
f. Zero and span drift...................  plus-minus1% opacity, 30
                                            minutes
g. Response time.........................  5 seconds.
------------------------------------------------------------------------

    3.3.1 Calibration. The smoke meter is calibrated after allowing a 
minimum of 30 minutes warmup by alternately producing simulated opacity 
of 0 percent and 100 percent. When stable response at 0 percent or 100 
percent is noted, the smoke meter is adjusted to produce an output of 0 
percent or 100 percent, as appropriate. This calibration shall be 
repeated until stable 0 percent and 100 percent readings are produced 
without adjustment. Simulated 0 percent and 100 percent opacity values 
may be produced by alternately switching the power to the light source 
on and off while the smoke generator is not producing smoke.
    3.3.2 Smoke Meter Evaluation. The smoke meter design and performance 
are to be evaluated as follows:
    3.3.2.1 Light Source. Verify from manufacturer's data and from 
voltage measurements made at the lamp, as installed, that the lamp is 
operated within plus-minus5 percent of the nominal rated 
voltage.
    3.3.2.2 Spectral Response of Photocell. Verify from manufacturer's 
data that the photocell has a photopic response; i.e., the spectral 
sensitivity of the cell shall closely approximate the standard spectral-
luminosity curve for photopic vision which is referenced in (b) of Table 
9-1.

[[Page 854]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.154


                     Figure 9-2--Observation Record
                                                Page ____ of ____
Company...........................      Observer..............  ........
Location..........................      Type facility.........  ........
Test Number.......................      Point of emissions....  ........
Date..............................
 


[[Page 855]]


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               Figure 9-2--Observation Record--(Continued)
                                                Page ____ of ____
Company...........................      Observer..............  ........
Location..........................      Type facility.........  ........
Test Number.......................      Point of emissions....  ........
Date..............................
 


----------------------------------------------------------------------------------------------------------------
                        Seconds                  Steam plume (check if applicable)
 Hr.    Min. -----------------------------------------------------------------------------        Comments
                0      15     30     45           Attached                Detached
----------------------------------------------------------------------------------------------------------------
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[[Page 856]]

 
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    3.3.2.3 Angle of View. Check construction geometry to ensure that 
the total angle of view of the smoke plume, as seen by the photocell, 
does not exceed 15 deg.. The total angle of view may be calculated from: 
- 1d/2L, where - 1d/2L, where plus-minus2 percent shall be used. Care should be taken when 
inserting the filters to prevent stray light from affecting the meter. 
Make a total of five nonconsecutive readings for each filter. The 
maximum error on any one reading shall be 3 percent opacity.
    3.3.2.6 Zero and Span Drift. Determine the zero and span drift by 
calibrating and operating the smoke generator in a normal manner over a 
1-hour period. The drift is measured by checking the zero and span at 
the end of this period.
    3.3.2.7 Response Time. Determine the response time by producing the 
series of five simulated 0 percent and 100 percent opacity values and 
observing the time required to reach stable response. Opacity values of 
0 percent and 100 percent may be simulated by alternately switching the 
power to the light source off and on while the smoke generator is not 
operating.

4. Bibliography.

    1. Air Pollution Control District Rules and Regulations, Los Angeles 
County Air Pollution Control District, Regulation IV, Prohibitions, Rule 
50.
    2. Weisburd, Melvin I., Field Operations and Enforcement Manual for 
Air, U.S. Environmental Protection Agency, Research Triangle Park, NC. 
APTD-1100, August 1972, pp. 4.1-4.36.
    3. Condon, E.U., and Odishaw, H., Handbook of Physics, McGraw-Hill 
Co., New York, NY, 1958, Table 3.1, p. 6-52.

   Alternate Method 1--Determination of the Opacity of Emissions From 
                  Stationary Sources Remotely by Lidar

    This alternate method provides the quantitative determination of the 
opacity of an emissions plume remotely by a mobile lidar system (laser 
radar; Light Detection and Ranging). The method includes procedures for 
the calibration of the lidar and procedures to be used in the field for 
the lidar determination of plume opacity. The lidar is used to measure 
plume opacity during either day or nighttime hours because it contains 
its own pulsed light source or transmitter. The operation of the lidar 
is not dependent upon ambient lighting conditions (light, dark, sunny or 
cloudy).
    The lidar mechanism or technique is applicable to measuring plume 
opacity at numerous wavelengths of laser radiation. However, the 
performance evaluation and calibration test results given in support of 
this method apply only to a lidar that employs a ruby (red light) laser 
[Reference 5.1].

1. Principle and Applicability

    1.1  Principle. The opacity of visible emissions from stationary 
sources (stacks, roof vents, etc.) is measured remotely by a mobile 
lidar (laser radar).
    1.2  Applicability. This method is applicable for the remote 
measurement of the opacity of visible emissions from stationary sources 
during both nighttime and daylight conditions, pursuant to 40 CFR 
Sec. 60.11(b). It is also applicable for the calibration and performance 
verification of the mobile lidar for the measurement of the opacity of 
emissions. A performance/design specification for a basic lidar system 
is also incorporated into this method.
    1.3  Definitions.
    Azimuth angle: The angle in the horizontal plane that designates 
where the laser beam is pointed. It is measured from an arbitrary fixed 
reference line in that plane.
    Backscatter: The scattering of laser light in a direction opposite 
to that of the incident laser beam due to reflection from particulates 
along the beam's atmospheric path which may include a smoke plume.
    Backscatter signal: The general term for the lidar return signal 
which results from laser light being backscattered by atmospheric and 
smoke plume particulates.
    Convergence distance: The distance from the lidar to the point of 
overlap of the lidar receiver's field-of-view and the laser beam.
    Elevation angle: The angle of inclination of the laser beam 
referenced to the horizontal plane.
    Far region: The region of the atmosphere's path along the lidar 
line-of-sight beyond or behind the plume being measured.
    Lidar: Acronym for Light Detection and Ranging.
    Lidar range: The range or distance from the lidar to a point of 
interest along the lidar line-of-sight.
    Near region: The region of the atmospheric path along the lidar 
line-of-sight between the lidar's convergence distance and the plume 
being measured.
    Opacity: One minus the optical transmittance of a smoke plume, 
screen target, etc.
    Pick interval: The time or range intervals in the lidar backscatter 
signal whose minimum average amplitude is used to calculate opacity. Two 
pick intervals are required, one in the near region and one in the far 
region.
    Plume: The plume being measured by lidar.
    Plume signal: The backscatter signal resulting from the laser light 
pulse passing through a plume.

[[Page 858]]

    1/R2correction: The correction made for the systematic 
decrease in lidar backscatter signal amplitude with range.
    Reference signal: The backscatter signal resulting from the laser 
light pulse passing through ambient air.
    Sample interval: The time period between successive samples for a 
digital signal or between successive measurements for an analog signal.
    Signal spike: An abrupt, momentary increase and decrease in signal 
amplitude.
    Source: The source being tested by lidar.
    Time reference: The time (to) when the laser pulse 
emerges from the laser, used as the reference in all lidar time or range 
measurements.

2. Procedures

    The mobile lidar calibrated in accordance with Paragraph 3 of this 
method shall use the following procedures for remotely measuring the 
opacity of stationary source emissions:
    2.1  Lidar Position. The lidar shall be positioned at a distance 
from the plume sufficient to provide an unobstructed view of the source 
emissions. The plume must be at a range of at least 50 meters or three 
consecutive pick intervals (whichever is greater) from the lidar's 
transmitter/receiver convergence distance along the line-of-sight. The 
maximum effective opacity measurement distance of the lidar is a 
function of local atmospheric conditions, laser beam diameter, and plume 
diameter. The test position of the lidar shall be selected so that the 
diameter of the laser beam at the measurement point within the plume 
shall be no larger than three-fourths the plume diameter. The beam 
diameter is calculated by Equation (AM1-1):

D(lidar)=A+R0.75 D(Plume) (AM1-1)
Where:

D(Plume)=diameter of the plume (cm),
=laser beam divergence measured in radians
R=range from the lidar to the source (cm)
D(Lidar)=diameter of the laser beam at range R (cm),
A=diameter of the laser beam or pulse where it leaves the laser.

The lidar range, R, is obtained by aiming and firing the laser at the 
emissions source structure immediately below the outlet. The range value 
is then determined from the backscatter signal which consists of a 
signal spike (return from source structure) and the atmospheric 
backscatter signal [Reference 5.1]. This backscatter signal should be 
recorded.
    When there is more than one source of emissions in the immediate 
vicinity of the plume, the lidar shall be positioned so that the laser 
beam passes through only a single plume, free from any interference of 
the other plumes for a minimum of 50 meters or three consecutive pick 
intervals (whichever is greater) in each region before and beyond the 
plume along the line-of-sight (determined from the backscatter signals). 
The lidar shall initially be positioned so that its line-of-sight is 
approximately perpendicular to the plume.
    When measuring the opacity of emissions from rectangular outlets 
(e.g., roof monitors, open baghouses, noncircular stacks, etc.), the 
lidar shall be placed in a position so that its line-of-sight is 
approximately perpendicular to the longer (major) axis of the outlet.
    2.2  Lidar Operational Restrictions. The lidar receiver shall not be 
aimed within an angle of plus-minus 15 deg. (cone angle) of 
the sun.
    This method shall not be used to make opacity measurements if 
thunderstorms, snowstorms, hail storms, high wind, high-ambient dust 
levels, fog or other atmospheric conditions cause the reference signals 
to consistently exceed the limits specified in Section 2.3.
    2.3  Reference Signal Requirements. Once placed in its proper 
position for opacity measurement, the laser is aimed and fired with the 
line-of-sight near the outlet height and rotated horizontally to a 
position clear of the source structure and the associated plume. The 
backscatter signal obtained from this position is called the ambient-air 
or reference signal. The lidar operator shall inspect this signal 
[Section V of Reference 5.1] to: (1) determine if the lidar line-of-
sight is free from interference from other plumes and from physical 
obstructions such as cables, power lines, etc., for a minimum of 50 
meters or three consecutive pick intervals (whichever is greater) in 
each region before and beyond the plume, and (2) obtain a qualitative 
measure of the homogeneity of the ambient air by noting any signal 
spikes.
    Should there be any signal spikes on the reference signal within a 
minimum of 50 meters or three consecutive pick intervals (whichever is 
greater) in each region before and beyond the plume, the laser shall be 
fired three more times and the operator shall inspect the reference 
signals on the display. If the spike(s) remains, the azimuth angle shall 
be changed and the above procedures conducted again. If the spike(s) 
disappears in all three reference signals, the lidar line-of-sight is 
acceptable if there is shot-to-shot consistency and there is no 
interference from other plumes.
    Shot-to-shot consistency of a series of reference signals over a 
period of twenty seconds is verified in either of two ways. (1) The 
lidar operator shall observe the reference signal amplitudes. For shot-
to-shot consistency the ratio of Rf to Rn 
[amplitudes of the near and far region pick intervals (Section 2.6.1)] 
shall vary by not more than plus-minus 6% between shots; or 
(2) the lidar operator shall accept any one of the reference signals and 
treat the other two as plume signals; then

[[Page 859]]

the opacity for each of the subsequent reference signals is calculated 
(Equation AM1-2). For shot-to-shot consistency, the opacity values shall 
be within plus-minus 3% of 0% opacity and the associated 
So values less than or equal to 8% (full scale) [Section 
2.6].
    If a set of reference signals fails to meet the requirements of this 
section, then all plume signals [Section 2.4] from the last set of 
acceptable reference signals to the failed set shall be discarded.
    2.3.1  Initial and Final Reference Signals. Three reference signals 
shall be obtained within a 90-second time period prior to any data run. 
A final set of three reference signals shall be obtained within three 
(3) minutes after the completion of the same data run.
    2.3.2  Temporal Criterion for Additional Reference Signals. An 
additional set of reference signals shall be obtained during a data run 
if there is a change in wind direction or plume drift of 30 deg. or more 
from the direction that was prevalent when the last set of reference 
signals was obtained. An additional set of reference signals shall also 
be obtained if there is an increase in value of SIn (near 
region standard deviation, Equation AM1-5) or SIf (far region 
standard deviation, Equation AM1-6) that is greater than 6% (full scale) 
over the respective values calculated from the immediately previous 
plume signal, and this increase in value remains for 30 seconds or 
longer. An additional set of reference signals shall also be obtained if 
there is a change in amplitude in either the near or the far region of 
the plume signal, that is greater than 6% of the near signal amplitude 
and this change in amplitude remains for 30 seconds or more.
    2.4  Plume Signal Requirements. Once properly aimed, the lidar is 
placed in operation with the nominal pulse or firing rate of six pulses/
minute (1 pulse/10 seconds). The lidar operator shall observe the plume 
backscatter signals to determine the need for additional reference 
signals as required by Section 2.3.2. The plume signals are recorded 
from lidar start to stop and are called a data run. The length of a data 
run is determined by operator discretion. Short-term stops of the lidar 
to record additional reference signals do not constitute the end of a 
data run if plume signals are resumed within 90 seconds after the 
reference signals have been recorded, and the total stop or interrupt 
time does not exceed 3 minutes.
    2.4.1  Non-hydrated Plumes. The laser shall be aimed at the region 
of the plume which displays the greatest opacity. The lidar operator 
must visually verify that the laser is aimed clearly above the source 
exit structure.
    2.4.2  Hydrated Plumes. The lidar will be used to measure the 
opacity of hydrated or so-called steam plumes. As listed in the 
reference method, there are two types, i.e., attached and detached steam 
plumes.
    2.4.2.1  Attached Steam Plumes. When condensed water vapor is 
present within a plume, lidar opacity measurements shall be made at a 
point within the residual plume where the condensed water vapor is no 
longer visible. The laser shall be aimed into the most dense region 
(region of highest opacity) of the residual plume.
    During daylight hours the lidar operator locates the most dense 
portion of the residual plume visually. During nighttime hours a high-
intensity spotlight, night vision scope, or low light level TV, etc., 
can be used as an aid to locate the residual plume. If visual 
determination is ineffective, the lidar may be used to locate the most 
dense region of the residual plume by repeatedly measuring opacity, 
along the longitudinal axis or center of the plume from the emissions 
outlet to a point just beyond the steam plume. The lidar operator should 
also observe color differences and plume reflectivity to ensure that the 
lidar is aimed completely within the residual plume. If the operator 
does not obtain a clear indication of the location of the residual 
plume, this method shall not be used.
    Once the region of highest opacity of the residual plume has been 
located, aiming adjustments shall be made to the laser line-of-sight to 
correct for the following: movement to the region of highest opacity out 
of the lidar line-of-sight (away from the laser beam) for more than 15 
seconds, expansion of the steam plume (air temperature lowers and/or 
relative humidity increases) so that it just begins to encroach on the 
field-of-view of the lidar's optical telescope receiver, or a decrease 
in the size of the steam plume (air temperature higher and/or relative 
humidity decreases) so that regions within the residual plume whose 
opacity is higher than the one being monitored, are present.
    2.4.2.2  Detached Steam Plumes. When the water vapor in a hydrated 
plume condenses and becomes visible at a finite distance from the stack 
or source emissions outlet, the opacity of the emissions shall be 
measured in the region of the plume clearly above the emissions outlet 
and below condensation of the water vapor.
    During daylight hours the lidar operators can visually determine if 
the steam plume is detached from the stack outlet. During nighttime 
hours a high-intensity spotlight, night vision scope, low light level 
TV, etc., can be used as an aid in determining if the steam plume is 
detached. If visual determination is ineffective, the lidar may be used 
to determine if the steam plume is detached by repeatedly measuring 
plume opacity from the outlet to the steam plume along the plume's 
longitudinal axis or center line. The lidar operator should also observe 
color differences and plume reflectivity to detect a

[[Page 860]]

detached plume. If the operator does not obtain a clear indication of 
the location of the detached plume, this method shall not be used to 
make opacity measurements between the outlet and the detached plume.
    Once the determination of a detached steam plume has been confirmed, 
the laser shall be aimed into the region of highest opacity in the plume 
between the outlet and the formation of the steam plume. Aiming 
adjustments shall be made to the lidar's line-of-sight within the plume 
to correct for changes in the location of the most dense region of the 
plume due to changes in wind direction and speed or if the detached 
steam plume moves closer to the source outlet encroaching on the most 
dense region of the plume. If the detached steam plume should move too 
close to the source outlet for the lidar to make interference-free 
opacity measurements, this method shall not be used.
    2.5  Field Records. In addition to the recording recommendations 
listed in other sections of this method the following records should be 
maintained. Each plume measured should be uniquely identified. The name 
of the facility, type of facility, emission source type, geographic 
location of the lidar with respect to the plume, and plume 
characteristics should be recorded. The date of the test, the time 
period that a source was monitored, the time (to the nearest second) of 
each opacity measurement, and the sample interval should also be 
recorded. The wind speed, wind direction, air temperature, relative 
humidity, visibility (measured at the lidar's position), and cloud cover 
should be recorded at the beginning and end of each time period for a 
given source. A small sketch depicting the location of the laser beam 
within the plume should be recorded.
    If a detached or attached steam plume is present at the emissions 
source, this fact should be recorded. Figures AM1-I and AM1-II are 
examples of logbook forms that may be used to record this type of data. 
Magnetic tape or paper tape may also be used to record data.

[[Page 861]]

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[[Page 862]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.156


[[Page 863]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.157

    2.6  Opacity Calculation and Data Analysis. Referring to the 
reference signal and plume signal in Figure AM1-III, the measured 
opacity (Op) in percent for each lidar measurement is 
calculated using Equation AM1-2. (Op=1-Tp; Tp 
is the plume transmittance.)

[[Page 864]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.158

Where:

In=near-region pick interval signal amplitude, plume signal, 
          1/R2corrected,
If=far-region pick interval signal amplitude, plume signal, 
          1/R2corrected,
Rn=near-region pick interval signal amplitude, reference 
          signal, 1/R2corrected, and
Rf=far-region pick interval signal amplitude, reference 
          signal, 1/R2corrected.
    The 1/R2 correction to the plume and reference signal 
amplitudes is made by multiplying the amplitude for each successive 
sample interval from the time reference, by the square of the lidar time 
(or range) associated with that sample interval [Reference 5.1].
    The first step in selecting the pick intervals for Equation AM1-2 is 
to divide the plume signal amplitude by the reference signal amplitude 
at the same respective ranges to obtain a ``normalized'' signal. The 
pick intervals selected using this normalized signal, are a minimum of 
15 m (100 nanoseconds) in length and consist of at least 5 contiguous 
sample intervals. In addition, the following criteria, listed in order 
of importance, govern pick interval selection. (1) The intervals shall 
be in a region of the normalized signal where the reference signal meets 
the requirements of Section 2.3 and is everywhere greater than zero. (2) 
The intervals (near and far) with the minimum average amplitude are 
chosen. (3) If more than one interval with the same minimum average 
amplitude is found, the interval closest to the plume is chosen. (4) The 
standard deviation, So, for the calculated opacity shall be 
8% or less. (So is calculated by Equation AM1-7).
    If So is greater than 8%, then the far pick interval 
shall be changed to the next interval of minimal average amplitude. If 
So is still greater than 8%, then this procedure is repeated 
for the far pick interval. This procedure may be repeated once again for 
the near pick interval, but if So remains greater than 8%, 
the plume signal shall be discarded.
    The reference signal pick intervals, Rn and 
Rf, must be chosen over the same time interval as the plume 
signal pick intervals, In and If, respectively 
[Figure AM1-III]. Other methods of selecting pick intervals may be used 
if they give equivalent results. Field-oriented examples of pick 
interval selection are available in Reference 5.1.
    The average amplitudes for each of the pick intervals, 
In, If, Rn, Rf, shall be 
calculated by averaging the respective individual amplitudes of the 
sample intervals from the plume signal and the associated reference 
signal each corrected for 1/R2. The amplitude of In 
shall be calculated according to Equation (AM-3).
[GRAPHIC] [TIFF OMITTED] TC01JN92.159

Where:

Ini=the amplitude of the ith sample interval (near-region),
=sum of the individual amplitudes for the sample intervals,
m=number of sample intervals in the pick interval, and
In=average amplitude of the near-region pick interval.
    Similarly, the amplitudes for If, Rn, and 
Rf are calculated with the three expressions in Equation 
(AM1-4).
[GRAPHIC] [TIFF OMITTED] TC01JN92.160

    The standard deviation, SIn, of the set of amplitudes for 
the near-region pick interval, In, shall be calculated using 
Equation (AM1-5).
    Similarly, the standard deviations SIf, SRn, 
and SRf are calculated with the three expressions in Equation 
(AM1-6).

[[Page 865]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.161

[GRAPHIC] [TIFF OMITTED] TC01JN92.162

The standard deviation, So, for each associated opacity 
value, Op, shall be calculated using Equation (AM1-7).
[GRAPHIC] [TIFF OMITTED] TC01JN92.163

    The calculated values of In, If, 
Rn, Rf, SIn, SIf, 
SRn, SRf, Op, and So should 
be recorded. Any plume signal with an So greater than 8% 
shall be discarded.
    2.6.1  Azimuth Angle Correction. If the azimuth angle correction to 
opacity specified in this section is performed, then the elevation angle 
correction specified in Section 2.6.2 shall not be performed. When 
opacity is measured in the residual region of an attached steam plume, 
and the lidar line-of-sight is not perpendicular to the plume, it may be 
necessary to correct the opacity measured by the lidar to obtain the 
opacity that would be measured on a path perpendicular to the plume. The 
following method, or any other method which produces equivalent results, 
shall be used to determine the need for a correction, to calculate the 
correction, and to document the point within the plume at which the 
opacity was measured.
    Figure AM1-IV(b) shows the geometry of the opacity correction. L' is 
the path through the plume along which the opacity measurement is made. 
P' is the path perpendicular to the plume at the same point. The angle 
/2-p, measured along the path L' shall be corrected to 
obtain the corrected opacity, Opc, for the path P', using 
Equation (AM1-8).
[GRAPHIC] [TIFF OMITTED] TC01JN92.164


[[Page 866]]


The correction in Equation (AM1-8) shall be performed if the inequality 
in Equation (AM1-9) is true.
      
    [GRAPHIC] [TIFF OMITTED] TC01JN92.165
    
    Figure AM1-IV(a) shows the geometry used to calculate s=range from lidar to source*...............................
s=elevation angle of Rs*.................
Rp=range from lidar to plume at the opacity measurement 
point*..................................................................
p=elevation angle of Rp*.................
Ra=range from lidar to plume at some arbitrary point, 
Pa, so the drift angle of the plume can be determined*.......
a=elevation angle of Ra*.................
=angle between Rp and Ra.......................
R's=projection of Rs in the horizontal plane
R'p=projection of Rp in the horizontal plane......

[[Page 868]]

R'a=projection of Ra in the horizontal plane
'=angle between R's and R'p*............
'=angle between R'p and R'a*.............
R=distance from the source to the opacity measurement point 
projected in the horizontal plane.......................................
Rp to the 
point in the plume Pa..............................................
[GRAPHIC] [TIFF OMITTED] TC01JN92.167

The correction angle =Cos-1 (Cosp Cosa 
          Cos'+Sinp 
          Sina),

and
Rp2+Ra2-2 Rp Ra 
          Cos)1/2

    R, the distance from the source to the opacity 
measurement point projected in the horizontal plane, shall be determined 
using Equation AM1-11.
[GRAPHIC] [TIFF OMITTED] TC01JN92.168

Where:
R's=Rs Cos s, and
R'p=Rp Cos p.

In the special case where the plume centerline at the opacity 
measurement point is horizontal, parallel to the ground, Equation AM1-12 
may be used to determine s=(R'2s+Rp2Sin2
          p)1/2.

If the angle  30 deg. or 
 150 deg., the azimuth angle correction shall not be 
performed and the associated opacity value shall be discarded.
    2.6.2  Elevation Angle Correction. An individual lidar-measured 
opacity, Op, shall be corrected for elevation angle if the 
laser elevation or inclination angle, p [Figure AM1-
V], is greater than or equal to the value calculated in Equation AM1-13.
[GRAPHIC] [TIFF OMITTED] TC01JN92.170

The measured opacity, Op, along the lidar path L, is adjusted 
to obtain the corrected opacity, Opc, for the actual plume 
(horizontal) path, P, by using Equation (AM1-14).
      

[[Page 869]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.171

Where:

p=lidar elevation or inclination angle,
Op=measured opacity along path L, and
Opc=corrected opacity for the actual plume thickness P.
    The values for p, Op and Opc 
should be recorded.

[[Page 870]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.172

    2.6.3  Determination of Actual Plume Opacity. Actual opacity of the 
plume shall be determined by Equation AM1-15.
[GRAPHIC] [TIFF OMITTED] TC01JN92.173

    2.6.4  Calculation of Average Actual Plume Opacity. The average of 
the actual plume opacity, Opa, shall be calculated as the 
average of the consecutive individual actual opacity values, 
Opa, by Equation AM1-16.

[[Page 871]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.174

Where:

(Opa)k=the kth actual opacity value in an 
          averaging interval containing n opacity values; k is a summing 
          index.
=the sum of the individual actual opacity values.
n=the number of individual actual opacity values contained in the 
          averaging interval.
Opa=average actual opacity calculated over the averaging 
          interval.

3.  Lidar Performance Verification

    The lidar shall be subjected to two types of performance 
verifications that shall be performed in the field. The annual 
calibration, conducted at least once a year, shall be used to directly 
verify operation and performance of the entire lidar system. The routine 
verification, conducted for each emission source measured, shall be used 
to insure proper performance of the optical receiver and associated 
electronics.
    3.1  Annual Calibration Procedures. Either a plume from a smoke 
generator or screen targets shall be used to conduct this calibration.
    If the screen target method is selected, five screens shall be 
fabricated by placing an opaque mesh material over a narrow frame (wood, 
metal extrusion, etc.). The screen shall have a surface area of at least 
one square meter. The screen material should be chosen for precise 
optical opacities of about 10, 20, 40, 60, and 80%. Opacity of each 
target shall be optically determined and should be recorded. If a smoke 
generator plume is selected, it shall meet the requirements of Section 
3.3 of Reference Method 9. This calibration shall be performed in the 
field during calm (as practical) atmospheric conditions. The lidar shall 
be positioned in accordance with Section 2.1.
    The screen targets must be placed perpendicular to and coincident 
with the lidar line-of-sight at sufficient height above the ground 
(suggest about 30 ft) to avoid ground-level dust contamination. 
Reference signals shall be obtained just prior to conducting the 
calibration test.
    The lidar shall be aimed through the center of the plume within 1 
stack diameter of the exit, or through the geometric center of the 
screen target selected. The lidar shall be set in operation for a 6-
minute data run at a nominal pulse rate of 1 pulse every 10 seconds. 
Each backscatter return signal and each respective opacity value 
obtained from the smoke generator transmissometer, shall be obtained in 
temporal coincidence. The data shall be analyzed and reduced in 
accordance with Section 2.6 of this method. This calibration shall be 
performed for 0% (clean air), and at least five other opacities 
(nominally 10, 20, 40, 60, and 80%).
    The average of the lidar opacity values obtained during a 6-minute 
calibration run shall be calculated and should be recorded. Also the 
average of the opacity values obtained from the smoke generator 
transmissometer for the same 6-minute run shall be calculated and should 
be recorded.
    Alternate calibration procedures that do not meet the above 
requirements but produce equivalent results may be used.
    3.2  Routine Verification Procedures. Either one of two techniques 
shall be used to conduct this verification. It shall be performed at 
least once every 4 hours for each emission source measured. The 
following parameters shall be directly verified.
    1) The opacity value of 0% plus a minimum of 5 (nominally 10, 20, 
40, 60, and 80%) opacity values shall be verified through the PMT 
detector and data processing electronics.
    2) The zero-signal level (receiver signal with no optical signal 
from the source present) shall be inspected to insure that no spurious 
noise is present in the signal. With the entire lidar receiver and 
analog/digital electronics turned on and adjusted for normal operating 
performance, the following procedures shall be used for Techniques 1 and 
2, respectively.
    3.2.1  Procedure for Technique 1. This test shall be performed with 
no ambient or stray light reaching the PMT detector. The narrow band 
filter (694.3 nanometers peak) shall be removed from its position in 
front of the PMT detector. Neutral density filters of nominal opacities 
of 10, 20, 40, 60, and 80% shall be used. The recommended test 
configuration is depicted in Figure AM1-VI.

[[Page 872]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.175

    The zero-signal level shall be measured and should be recorded, as 
indicated in Figure AM1-VI(a). This simulated clear-air or 0% opacity 
value shall be tested in using the selected light source depicted in 
Figure AM1-VI(b).
    The light source either shall be a continuous wave (CW) laser with 
the beam mechanically chopped or a light emitting diode controlled with 
a pulse generator (rectangular pulse). (A laser beam may have to be 
attenuated so as not to saturate the PMT detector). This signal level 
shall be measured

[[Page 873]]

and should be recorded. The opacity value is calculated by taking two 
pick intervals [Section 2.6] about 1 microsecond apart in time and using 
Equation (AM1-2) setting the ratio Rn/Rf=1. This 
calculated value should be recorded.
    The simulated clear-air signal level is also employed in the optical 
test using the neutral density filters. Using the test configuration in 
Figure AM1-VI(c), each neutral density filter shall be separately placed 
into the light path from the light source to the PMT detector. The 
signal level shall be measured and should be recorded. The opacity value 
for each filter is calculated by taking the signal level for that 
respective filter (If), dividing it by the 0% opacity signal 
level (In) and performing the remainder of the calculation by 
Equation (AM1-2) with Rn/Rf=1. The calculated 
opacity value for each filter should be recorded.
    The neutral density filters used for Technique 1 shall be calibrated 
for actual opacity with accuracy of plus-minus2% or better. 
This calibration shall be done monthly while the filters are in use and 
the calibrated values should be recorded.
    3.2.2  Procedure for Technique 2. An optical generator (built-in 
calibration mechanism) that contains a light-emitting diode (red light 
for a lidar containing a ruby laser) is used. By injecting an optical 
signal into the lidar receiver immediately ahead of the PMT detector, a 
backscatter signal is simulated. With the entire lidar receiver 
electronics turned on and adjusted for normal operating performance, the 
optical generator is turned on and the simulation signal (corrected for 
1/R\2\) is selected with no plume spike signal and with the opacity 
value equal to 0%. This simulated clear-air atmospheric return signal is 
displayed on the system's video display. The lidar operator then makes 
any fine adjustments that may be necessary to maintain the system's 
normal operating range.
    The opacity values of 0% and the other five values are selected one 
at a time in any order. The simulated return signal data should be 
recorded. The opacity value shall be calculated. This measurement/
calculation shall be performed at least three times for each selected 
opacity value. While the order is not important, each of the opacity 
values from the optical generator shall be verified. The calibrated 
optical generator opacity value for each selection should be recorded.
    The optical generator used for Technique 2 shall be calibrated for 
actual opacity with an accuracy of plus-minus1% or better. 
This calibration shall be done monthly while the generator is in use and 
calibrated value should be recorded.
    Alternate verification procedures that do not meet the above 
requirements but produce equivalent results may be used.
    3.3  Deviation. The permissible error for the annual calibration and 
routine verification are:
    3.3.1  Annual Calibration Deviation.
    3.3.1.1  Smoke Generator. If the lidar-measured average opacity for 
each data run is not within plus-minus5% (full scale) of the 
respective smoke generator's average opacity over the range of 0% 
through 80%, then the lidar shall be considered out of calibration.
    3.3.1.2  Screens. If the lidar-measured average opacity for each 
data run is not within plus-minus3% (full scale) of the 
laboratory-determined opacity for each respective simulation screen 
target over the range of 0% through 80%, then the lidar shall be 
considered out of calibration.
    3.3.2  Routine Verification Error. If the lidar-measured average 
opacity for each neutral density filter (Technique 1) or optical 
generator selection (Technique 2) is not within plus-minus3% 
(full scale) of the respective laboratory calibration value then the 
lidar shall be considered non-operational.

4.  Performance/Design Specification for Basic Lidar System

    4.1  Lidar Design Specification. The essential components of the 
basic lidar system are a pulsed laser (transmitter), optical receiver, 
detector, signal processor, recorder, and an aiming device that is used 
in aiming the lidar transmitter and receiver. Figure AM1-VII shows a 
functional block diagram of a basic lidar system.

[[Page 874]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.176

    4.2  Performance Evaluation Tests. The owner of a lidar system shall 
subject such a lidar system to the performance verification tests 
described in Section 3, prior to first use of this method. The annual 
calibration shall be performed for three separate, complete

[[Page 875]]

runs and the results of each should be recorded. The requirements of 
Section 3.3.1 must be fulfilled for each of the three runs.
    Once the conditions of the annual calibration are fulfilled the 
lidar shall be subjected to the routine verification for three separate 
complete runs. The requirements of Section 3.3.2 must be fulfilled for 
each of the three runs and the results should be recorded. The 
Administrator may request that the results of the performance evaluation 
be submitted for review.

5.  References

    5.1  The Use of Lidar for Emissions Source Opacity Determination, 
U.S. Environmental Protection Agency, National Enforcement 
Investigations Center, Denver, CO. EPA-330/1-79-003-R, Arthur W. 
Dybdahl, current edition [NTIS No. PB81-246662].
    5.2  Field Evaluation of Mobile Lidar for the Measurement of Smoke 
Plume Opacity, U.S. Environmental Protection Agency, National 
Enforcement Investigations Center, Denver, CO. EPA/NEIC-TS-128, February 
1976.
    5.3  Remote Measurement of Smoke Plume Transmittance Using Lidar, C. 
S. Cook, G. W. Bethke, W. D. Conner (EPA/RTP). Applied Optics 11, pg 
1742. August 1972.
    5.4  Lidar Studies of Stack Plumes in Rural and Urban Environments, 
EPA-650/4-73-002, October 1973.
    5.5  American National Standard for the Safe Use of Lasers ANSI Z 
136.1-176, March 8, 1976.
    5.6  U.S. Army Technical Manual TB MED 279, Control of Hazards to 
Health from Laser Radiation, February 1969.
    5.7  Laser Institute of America Laser Safety Manual, 4th Edition.
    5.8  U.S. Department of Health, Education and Welfare, Regulations 
for the Administration and Enforcement of the Radiation Control for 
Health and Safety Act of 1968, January 1976.
    5.9  Laser Safety Handbook, Alex Mallow, Leon Chabot, Van Nostrand 
Reinhold Co., 1978.

 Method 10--Determination of Carbon Monoxide Emissions From Stationary 
                                 Sources

1. Principle and Applicability

    1.1 Principle. An integrated or continuous gas sample is extracted 
from a sampling point and analyzed for carbon monoxide (CO) content 
using a Luft-type nondispersive infrared analyzer (NDIR) or equivalent.
    1.2 Applicability. This method is applicable for the determination 
of carbon monoxide emissions from stationary sources only when specified 
by the test procedures for determining compliance with new source 
performance standards. The test procedure will indicate whether a 
continuous or an integrated sample is to be used.

2. Range and Sensitivity

    2.1 Range. 0 to 1,000 ppm.
    2.2 Sensitivity. Minimum detectable concentration is 20 ppm for a 0 
to 1,000 ppm span.

3. Interferences

    Any substance having a strong absorption of infrared energy will 
interfere to some extent. For example, discrimination ratios for water 
(H2O) and carbon dioxide (CO2) are 3.5 percent 
H2O per 7 ppm CO and 10 percent CO2 per 10 ppm CO, 
respectively, for devices measuring in the 1,500 to 3,000 ppm range. For 
devices measuring in the 0 to 100 ppm range, interference ratios can be 
as high as 3.5 percent H2O per 25 ppm CO and 10 percent 
CO2 per 50 ppm CO. The use of silica gel and ascarite traps 
will alleviate the major interference problems. The measured gas volume 
must be corrected if these traps are used.

4. Precision and Accuracy

    4.1 Precision. The precision of most NDIR analyzers is approximately 
plus-minus2 percent of span.
    4.2 Accuracy. The accuracy of most NDIR analyzers is approximately 
plus-minus5 percent of span after calibration.

5. Apparatus

    5.1 Continuous Sample (Figure 10-1).
    5.1.1 Probe. Stainless steel or sheathed Pyrex\1\  glass, equipped 
with a filter to remove particulate matter.
---------------------------------------------------------------------------

    \1\ Mention of trade names or specific products does not constitute 
endorsement by the Environmental Protection Agency.
---------------------------------------------------------------------------

    5.1.2 Air-Cooled Condenser or Equivalent. To remove any excess 
moisture.
    5.2 Integrated Sample (Figure 10-2).
    5.2.1 Probe. Stainless steel or sheathed Pyrex glass, equipped with 
a filter to remove particulate matter.
    5.2.2 Air-Cooled Condenser or Equivalent. To remove any excess 
moisture.
    5.2.3 Valve. Needle valve, or equivalent, to adjust flow rate.
    5.2.4 Pump. Leak-free diaphragm type, or equivalent, to transport 
gas.
    5.2.5 Rate Meter. Rotameter, or equivalent, to measure a flow range 
from 0 to 1.0 liter per min (0.035 cfm).
    5.2.6 Flexible Bag. Tedlar, or equivalent, with a capacity of 60 to 
90 liters (2 to 3 ft\3\). Leak-test the bag in the laboratory before 
using by evacuating bag with a pump followed by a dry gas meter. When 
evacuation is complete, there should be no flow through the meter.
    5.2.7 Pitot Tube. Type S, or equivalent, attached to the probe so 
that the sampling rate can be regulated proportional to the stack gas 
velocity when velocity is varying with the time or a sample traverse is 
conducted.
    5.3 Analysis (Figure 10-3).

[[Page 876]]

    5.3.1 Carbon Monoxide Analyzer. Nondispersive infrared spectrometer, 
or equivalent. This instrument should be demonstrated, preferably by the 
manufacturer, to meet or exceed manufacturer's specifications and those 
described in this method.
    5.3.2 Drying Tube. To contain approximately 200 g of silica gel.
    5.3.3 Calibration Gas. Refer to section 6.1.
    5.3.4 Filter. As recommended by NDIR manufacturer.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.177
    
    [GRAPHIC] [TIFF OMITTED] TC01JN92.178
    
    5.3.5 CO2 Removal Tube. To contain approximately 500 g of 
ascarite.
    5.3.6 Ice Water Bath. For ascarite and silica gel tubes.
    5.3.7 Valve. Needle valve, or equivalent, to adjust flow rate
    5.3.8 Rate Meter. Rotameter or equivalent to measure gas flow rate 
of 0 to 1.0 liter per min (0.035 cfm) through NDIR.
    5.3.9 Recorder (optional). To provide permanent record of NDIR 
readings.

6. Reagents

    6.1 Calibration Gases. Known concentration of CO in nitrogen 
(N2) for instrument span, prepurified grade of N2 
for zero, and two additional concentrations corresponding approximately 
to 60 percent and 30 percent span. The span concentration shall not 
exceed 1.5 times the applicable source performance standard. The 
calibration gases shall be certified by the manufacturer to be within 
plus-minus2 percent of the specified concentration.
[GRAPHIC] [TIFF OMITTED] TC01JN92.179

    6.2 Silica Gel. Indicating type, 6 to 16 mesh, dried at 175  deg.C 
(347  deg.F) for 2 hours.
    6.3 Ascarite. Commercially available.

7. Procedure

    7.1 Sampling.
    7.1.1 Continuous Sampling. Set up the equipment as shown in Figure 
10-1 making sure all connections are leak free. Place the probe in the 
stack at a sampling point and purge the sampling line. Connect the 
analyzer and begin drawing sample into the analyzer. Allow 5 minutes for 
the system to stabilize, then record the analyzer reading as required by 
the test procedure. (See section 7.2 and 8). CO2 content of 
the gas may be determined by using the Method 3 integrated sample 
procedure, or by weighing the ascarite CO2 removal tube and 
computing CO2 concentration from the gas volume sampled and 
the weight gain of the tube.
    7.1.2 Integrated Sampling. Evacuate the flexible bag. Set up the 
equipment as shown in Figure 10-2 with the bag disconnected. Place the 
probe in the stack and purge the sampling line. Connect the bag, making 
sure that all connections are leak free. Sample at a rate proportional 
to the stack velocity. CO2 content of the gas may be 
determined by using the Method 3 integrated sample procedures, or by 
weighing the ascarite CO2 removal tube and computing CO2 
concentration from the gas volume sampled and the weight gain of the 
tube.
    7.2 CO Analysis. Assemble the apparatus as shown in Figure 10-3, 
calibrate the instrument, and perform other required operations as 
described in section 8. Purge analyzer with N2 prior to 
introduction of each sample. Direct the sample stream through the 
instrument for the test period, recording the readings. Check the zero 
and span again after the test to assure that any drift or malfunction is 
detected. Record the sample data on Table 10-1.

8. Calibration

    Assemble the apparatus according to Figure 10-3. Generally an 
instrument requires a warm-up period before stability is obtained. 
Follow the manufacturer's instructions for specific procedure. Allow a 
minimum time of 1 hour for warm-up. During this time check

[[Page 877]]

the sample conditioning apparatus, i.e., filter, condenser, drying tube, 
and CO2 removal tube, to ensure that each component is in 
good operating condition. Zero and calibrate the instrument according to 
the manufacturer's procedures using, respectively, nitrogen and the 
calibration gases.

                         Table 10-1--Field data
------------------------------------------------------------------------
                                                      Comments
------------------------------------------------------------------------
Location..................................  ............................
Test......................................  ............................
Date......................................  ............................
Operator..................................  ............................
------------------------------------------------------------------------


 
                                         Rotameter setting, liters per
             Clock time                 minute (cubic feet per minute)
------------------------------------------------------------------------
 
 
------------------------------------------------------------------------

9. Calculation

    Calculate the concentration of carbon monoxide in the stack using 
Equation 10-1.
CCO!stack=CCO!NDIR(1-Fco2)
                                                                Eq. 10-1
Where:

CCO!stack=Concentration of CO in stack, ppm by volume (dry 
          basis).
CCO!NDIR=Concentration of CO measured by NDIR analyzer, ppm 
          by volume (dry basis).
FCO!2=Volume fraction of CO2 in sample, i.e., 
          percent CO2 from Orsat analysis divided by 100.

                       10. Alternative Procedures

    10.1  Interference Trap. The sample conditioning system described in 
Method 10A, sections 2.1.2 and 4.2, may be used as an alternative to the 
silica gel and ascarite traps.

11. Bibliography

1.  McElroy, Frank, The Intertech NDIR-CO Analyzer, Presented at 11th 
          Methods Conference on Air Pollution, University of California, 
          Berkeley, CA. April 1, 1970.
2.  Jacobs, M. B., et al., Continuous Determination of Carbon Monoxide 
          and Hydrocarbons in Air by a Modified Infrared Analyzer, J. 
          Air Pollution Control Association, 9(2): 110-114. August 1959.
3.  MSA LIRA Infrared Gas and Liquid Analyzer Instruction Book, Mine 
          Safety Appliances Co., Technical Products Division, 
          Pittsburgh, PA.
4.  Models 215A, 315A, and 415A Infrared Analyzers, Beckman Instruments, 
          Inc., Beckman Instructions 1635-B, Fullerton, CA. October 
          1967.
5.  Continuous CO Monitoring System, Model A5611, Intertech Corp., 
          Princeton, NJ.
6.  UNOR Infrared Gas Analyzers, Bendix Corp., Ronceverte, WV

                                 Addenda

    A. Performance Specifications for NDIR Carbon Monoxide Analyzers
Range (minimum)...........................  0-1000 ppm.
Output (minimum)..........................  0-10mV.
Minimum detectable sensitivity............  20 ppm.
Rise time, 90 percent (maximum)...........  30 seconds.
Fall time, 90 percent (maximum)...........  30 seconds.
Zero drift (maximum)......................  10% in 8 hours.
Span drift (maximum)......................  10% in 8 hours.
Precision (minimum).......................  plus-minus2% of full scale.
Noise (maximum)...........................  plus-minus1% of full scale.
Linearity (maximum deviation).............  2% of full scale.
Interference rejection ratio..............  CO2--1000 to 1, H2O--500 to
                                             1.
------------------------------------------------------------------------

    B. Definitions of Performance Specifications.
    Range-- The minimum and maximum measurement limits.
    Output-- Electrical signal which is proportional to the measurement; 
intended for connection to readout or data processing devices. Usually 
expressed as millivolts or milliamps full scale at a given impedance.
    Full scale-- The maximum measuring limit for a given range.
    Minimum detectable sensitivity-- The smallest amount of input 
concentration that can be detected as the concentration approaches zero.
    Accuracy-- The degree of agreement between a measured value and the 
true value; usually expressed as plus-minus percent of full 
scale.
    Time to 90 percent response-- The time interval from a step change 
in the input concentration at the instrument inlet to a reading of 90 
percent of the ultimate recorded concentration.
    Rise Time (90 percent)--The interval between initial response time 
and time to 90 percent response after a step increase in the inlet 
concentration.
    Fall Time (90 percent)--The interval between initial response time 
and time to 90 percent response after a step decrease in the inlet 
concentration.
    Zero Drift-- The change in instrument output over a stated time 
period, usually 24 hours, of unadjusted continuous operation when the 
input concentration is zero; usually expressed as percent full scale.
    Span Drift-- The change in instrument output over a stated time 
period, usually 24 hours, of unadjusted continuous operation when the 
input concentration is a stated upscale value; usually expressed as 
percent full scale.
    Precision-- The degree of agreement between repeated measurements of 
the same concentration, expressed as the average deviation of the single 
results from the mean.
    Noise--Spontaneous deviations from a mean output not caused by input 
concentration changes.

[[Page 878]]

    Linearity--The maximum deviation between an actual instrument 
reading and the reading predicted by a straight line drawn between upper 
and lower calibration points.

  Method 10A--Determination of Carbon Monoxide Emissions in Certifying 
     Continuous Emission Monitoring Systems at Petroleum Refineries

                     1. Applicability and Principle

    1.1 Applicability. This method applies to the measurement of carbon 
monoxide (CO) at petroleum refineries. This method serves as the 
reference method in the relative accuracy test for nondispersive 
infrared (NDIR) CO continuous emission monitoring systems (CEMS's) that 
are required to be installed in petroleum refineries on fluid catalytic 
cracking unit catalyst regenerators [40 CFR Part 60.105(a)(2)].
    1.2 Principle. An integrated gas sample is extracted from the stack, 
passed through an alkaline permanganate solution to remove sulfur and 
nitrogen oxides, and collected in a Tedlar bag. The CO concentration in 
the sample is measured spectrophotometrically using the reaction of CO 
with p-sulfaminobenzoic acid.
    1.3 Range and Sensitivity.
    1.3.1 Range. Approximately 3 to 1800 ppm CO. Samples having 
concentrations below 400 ppm are analyzed at 425 nm, and samples having 
concentrations above 400 ppm are analyzed at 600 nm.
    1.3.2 Sensitivity. The detection limit is 3 ppm based on three times 
the standard deviation of the mean reagent blank values.
    1.4 Interferences. Sulfur oxides, nitric oxide, and other acid gases 
interfere with the colorimetric reaction. They are removed by passing 
the sampled gas through an alkaline potassium permanganate scrubbing 
solution. Carbon dioxide (CO2) does not interfere, but, 
because it is removed by the scrubbing solution, its concentration must 
be measured independently and an appropriate volume correction made to 
the sampled gas.
    1.5 Precision, Accuracy, and Stability.
    1.5.1 Precision. The estimated intralaboratory standard deviation of 
the method is 3 percent of the mean for gas samples analyzed in 
duplicate in the concentration range of 39 to 412 ppm. The 
interlaboratory precision has not been established.
    1.5.2 Accuracy. The method contains no significant biases when 
compared to an NDIR analyzer calibrated with National Bureau of 
Standards (NBS) standards.
    1.5.3 Stability. The individual components of the colorimetric 
reagent are stable for at least 1 month. The colorimetric reagent must 
be used within 2 days after preparation to avoid excessive blank 
correction. The samples in the Tedlar \1\ bag should be stable for at 
least 1 week if the bags are leak-free.
---------------------------------------------------------------------------

    \1\ Mention of trade names or commercial products in this 
publication does not constitute the endorsement or recommendation for 
use by the Environmental Protection Agency.
---------------------------------------------------------------------------

                              2. Apparatus

    2.1 Sampling. The sampling train is shown in Figure 10A-1, and 
component parts are discussed below:

[[Page 879]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.180

    2.1.1 Probe. Stainless steel, sheathed Pyrex glass, or equivalent, 
equipped with a glass wool plug to remove particulate matter.
    2.1.2 Sample Conditioning System. Three Greenburg-Smith impingers 
connected in series with leak-free connections.
    2.1.3 Pump. Leak-free pump with stainless steel and Teflon parts to 
transport sample at a flow rate of 300 ml/min to the flexible bag.
    2.1.4 Surge Tank. Installed between the pump and the rate meter to 
eliminate the pulsation effect of the pump on the rate meter.
    2.1.5 Rate Meter. Rotameter, or equivalent, to measure flow rate at 
300 ml/min. Calibrate according to Section 5.2.
    2.1.6 Flexible Bag. Tedlar, or equivalent, with a capacity of 10 
liters and equipped with a sealing quick-connect plug. The bag must be 
leak-free according to Section 4.1. For protection, it is recommened 
that the bag be enclosed with a rigid container.
    2.1.7 Valves. Stainless-steel needle valve to adjust flow rate, and 
stainless-steel three-way valve, or equivalent.
    2.1.8 CO2 Analyzer. Method 3 or its approved alternative 
to measure CO2 concentration to within 0.5 percent.
    2.1.9 Volume Meter. Dry gas meter, calibrated and capable of 
measuring the sample volume under rotameter calibration conditions of 
300 ml/min for 10 minutes.
    2.1.10 Pressure Gauge. A water filled U-tube manometer, or 
equivalent, of about 28 cm (12 in.) to leak-check the flexible bag.
    2.2 Analysis.
    2.2.1 Spectrophotometer. Single- or double-beam to measure 
absorbance at 425 and 600 nm. Slit width should not exceed 20 nm.
    2.2.2 Spectrophotometer Cells. 1-cm pathlength.
    2.2.3  Vacuum Gauge. U-tube mercury manometer, 1 meter (39 in.), 
with 1-mm divisions, or other gauge capable of measuring pressure to 
within 1 mm Hg.
    2.2.4  Pump. Capable of evacuating the gas reaction bulb to a 
pressure equal to or less than 40 mm Hg absolute, equipped with coarse 
and fine flow control valves.

[[Page 880]]

    2.2.5  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 1 mm Hg.
    2.2.6  Reaction Bulbs. Pyrex glass, 100.ml with Teflon stopcock 
(Figure 10A-2), leak-free at 40 mm Hg, designed so that 10 ml of the 
colorimetric reagent can be added and removed easily and accurately. 
Commercially available gas sample bulbs such as Supelco Catalog No. 2-
2161 may also be used.

[[Page 881]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.181

    2.2.7  Manifold. Stainless steel, with connections for three 
reaction bulbs and the appropriate connections for the manometer and 
sampling bag as shown in Figure 10A-3.
    2.2.8  Pipets. Class A, 10-ml size.
    2.2.9  Shaker Table. Reciprocating-stroke type such as Eberbach 
Corporation, Model 6015. A rocking arm or rotary-motion type

[[Page 882]]

shaker may also be used. The shaker must be large enough to accommodate 
at least six gas sample bulbs simultaneously. It may be necessary to 
construct a table top extension for most commercial shakers to provide 
sufficient space for the needed bulbs (Figure 10A-4).
    2.2.10  Valve. Stainless steel shut-off valve.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.182
    
    2.2.11  Analytical Balance. Capable of accurately weighing to 0.1 
mg.

                               3. Reagents

    Unless otherwise indicated, all reagents shall conform to the 
specifications established by the Committee on Analytical Reagents of 
the American Chemical Society, where such specifications are available, 
otherwise, the best available grade shall be used.
    3.1  Sampling.
    3.1.1  Water. Deionized distilled, as described in Method 6, Section 
3.1.1.
    3.1.2  Alkaline Permanganate Solution, 0.25 M KMn04/1.5 M 
NaOH. Dissolve 40 g KMn04 and 60 g NaOH in water, and dilute 
to 1 liter.
    3.2  Analysis.
    3.2.1  Water. Same as in Section 3.1.1.
    3.2.2  1 M Sodium Hydroxide (NaOH) Solution. Dissolve 40 g NaOH in 
approximately 900 ml of water, cool, and dilute to 1 liter.
    3.2.3  0.1 M Silver Nitrate (AgNO3) Solution. Dissolve 
8.5 g AgNO3 in water, and dilute to 500 ml.
    3.2.4  0.1 M Para-Sulfaminobenzoic Acid (p-SABA) Solution. Dissolve 
10.0 g p-SABA in 0.1 M NaOH (prepared by diluting 50 ml of 1 M NaOH to 
500 ml), and dilute to 500 ml with 0.1 M NaOH.

[[Page 883]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.183

    3.2.5  Colorimetric Solution. To a flask, add 100 ml of p-SABA 
solution and 100 ml of AgNO3 solution. Mix, and add 50 ml of 
1 M NaOH with shaking. The resultant solution should be clear and 
colorless. This solution is acceptable for use for a period of 2 days.
    3.2.6  Standard Gas Mixtures. Traceable to NBS standards and 
containing between 50 and 1000 ppm CO in nitrogen. At least two 
concentrations are needed to span each calibration range used (Section 
5.3).
    The calibration gases shall be certified by the manufacturer to be 
within 2 percent of the specified concentrations.

                              4. Procedure

    4.1  Sample Bag Leak-checks. While a bag leak-check is required 
after bag use, it should also be done before the bag is used for sample 
collection. The bag should be leak-checked in the inflated and deflated 
condition according to the following procedures.
    Connect the bag to a water manometer, and pressurize the bag to 5 to 
10 cm H20 (2 to 4 in. H20). Allow the bag to stand 
for 60 minutes. Any displacement in the water manometer indicates a 
leak. Now, evacuate the bag with a leakless pump that is connected on 
the downstream side of a flow-indicating device such as a 0-to 100-ml/
min rotameter or an impinger containing water. When the bag is 
completely evacuated, no flow should be evident if the bag is leak-free.
    4.2  Sampling. Evacuate the Tedlar bag completely using a vacuum 
pump. Assemble the apparatus as shown in Figure 10A-1. Loosely pack 
glass wool in the tip of the probe. Place 400 ml of alkaline 
permanganate

[[Page 884]]

solution in the first two impingers and 250 ml in the third. Connect the 
pump to the third impinger, and follow this with the surge tank, rate 
meter, and three-way valve. Do not connect the Tedlar bag to the system 
at this time.
    Leak-check the sampling system by placing a vacuum gauge at or near 
the probe inlet, plugging the probe inlet, opening the three-way valve, 
and pulling a vacuum of approximately 250 mm Hg on the system while 
observing the rate meter for flow. If flow is indicated on the rate 
meter, do not proceed further until the leak is found and corrected.
    Purge the system with sample gas by inserting the probe into the 
stack and drawing sample through the system at 300 ml/min #10 
percent for 5 minutes. Connect the evacuated Tedlar bag to the system, 
record the starting time, and sample at a rate of 300 ml/min for 30 
minutes, or until the Tedlar bag is nearly full. Record the sampling 
time, the barometric pressure, and the ambient temperature. Purge the 
system as described above immediately before each sample.
    The scrubbing solution is adequate for removing sulfur and nitrogen 
oxides from 50 liters of stack gas when the concentration of each is 
less than 1,000 ppm and the CO2 concentration is less than 15 
percent. Replace the scrubber solution after every fifth sample.
    4.3  Carbon Dioxide Measurement. Measure the CO2 content 
in the stack to the nearest 0.5 percent each time a CO sample is 
collected. A simultaneous grab sample analyzed by the Fyrite analyzer is 
acceptable.
    4.4  Analysis. Assemble the system shown in Figure 10A-3, and record 
the information required in Table 10A-1 as it is obtained. Pipet 10.0 ml 
of the colorimetric reagent into each gas reaction bulb, and attach the 
bulbs to the system. Open the stopcocks to the reaction bulbs, but leave 
the valve to the Tedlar bag closed. Turn on the pump, fully open the 
coarse-adjust flow valve, and slowly open the fine-adjust valve until 
the pressure is reduced to at least 40 mm Hg. Now close the coarse 
adjust valve, and observe the manometer to be certain that the system is 
leak-free. Wait a minimum of 2 minutes. If the pressure has increased 
less than 1 mm, proceed as described below. If a leak is present, find 
and correct it before proceeding further.
[GRAPHIC] [TIFF OMITTED] TC01JN92.184

    Record the vacuum pressure (Pv) to the nearest 1 mm Hg, 
and close the reaction bulb stopcocks. Open the Tedlar bag valve, and 
allow the system to come to atmospheric pressure. Close the bag valve, 
open the pump coarse adjust valve, and evacuate the system again. Repeat 
this fill/evacuation procedure at least twice to flush the manifold 
completely. Close the pump coarse adjust valve, open the Tedlar bag 
valve, and let the system fill to atmospheric pressure. Open the 
stopcocks to the reaction bulbs, and let the entire system come to 
atmospheric pressure. Close the bulb stopcocks, remove the bulbs, record 
the room temperature and barametric pressure (Pbar, to 
nearest mm Hg), and place the bulbs on the shaker table with their main 
axis either parallel to or perpendicular to the plane of the table top. 
Purge the bulb-filling system with ambient air for several minutes 
between samples. Shake the samples for exactly 2 hours.
    Immediately after shaking, measure the absorbance (A) of each bulb 
sample at 425 nm if the concentration is less than or equal to 400 ppm 
CO or at 600 nm if the concentration

[[Page 885]]

is above 400 ppm. This may be accomplished with multiple bulb sets by 
sequentially collecting sets and adding to the shaker at staggered 
intervals, followed by sequentially removing sets from the shaker for 
absorbance measurement after the two-hour designated intervals have 
elapsed.
    Use a small portion of the sample to rinse a spectrophotometer cell 
several times before taking an aliquot for analysis. If one cell is used 
to analyze multiple samples, rinse the cell several times between 
samples with water.
    Prepare and analyze standards and a reagent blank as described in 
Section 5.3. Use water as the reference. Reject the analysis if the 
blank absorbance is greater than 0.1. All conditions should be the same 
for analysis of samples and standards. Measure the absorbances as soon 
as possible after shaking is completed. Determine the CO concentration 
of each bag sample using the calibration curve for the appropriate 
concentration range as discussed in Section 5.3.

                             5. Calibration

    5.1 Bulb Calibration. Weigh the empty bulb to the nearest 0.1 g. 
Fill the bulb to the stopcock with water, and again weigh to the nearest 
0.1 g. Subtract the tare weight, and calculate the volume in liters to 
three significant figures using the density of water (at the measurement 
temperature). Record the volume on the bulb; alternatively, mark an 
identification number on the bulb, and record the volume in a notebook.
    5.2  Rate Meter Calibration. Assemble the system as shown in Figure 
10A-1 (the impingers may be removed), and attach a volume meter to the 
probe inlet. Set the rotameter at 300 ml/min, record the volume meter 
reading, start the pump, and pull gas through the system for 10 minutes. 
Record the final volume meter reading. Repeat the procedure and average 
the results to determine the volume of gas that passed through the 
system.
    5.3  Spectrophotometer Calibration Curve. The calibration curve is 
established by taking at least two sets of three bulbs of known CO 
collected from Tedlar bags through the analysis procedure. Reject the 
standard set where any of the individual bulb absorbances differ from 
the set mean by more than 10 percent. Collect the standards as described 
in Section 4.2. Prepare standards to span the 0- to 400- or 400- to 
1000-ppm range. If any samples span both concentration ranges, prepare a 
calibration curve for each range. A set of three bulbs containing 
colorimetric reagent but no CO should serve as a reagent blank and be 
taken through the analysis procedure.
    Calculate the average absorbance for each set (3 bulbs) of standards 
using Equation 10A-1 and Table 10A-1. Construct a graph of average 
absorbance for each standard against its corresponding concentration in 
ppm. Draw a smooth curve through the points. The curve should be linear 
over the two concentration ranges discussed in Section 1.3.1.

                             6. Calculations

    Carry out calculations retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after final 
calculation.

                            6.1 Nomenclature.

A=Sample absorbance, uncorrected for the reagent blank.
Ar=Absorbance of the reagent blank.
As=Average sample absorbance per liter, units/liter.
Bw=Moisture content in the bag sample.
C=CO concentration in the stack gas, dry basis, ppm.
Cb=CO concentration of the bag sample, dry basis, ppm.
Cg=CO concentration from the calibration curve, ppm.
F=Volume fraction of CO2 in the stack.
n=Number of reaction bulbs used per bag sample.
Pbar=Barometric pressure, mm Hg.
Pv=Residual pressure in the sample bulb after evacuation, mm 
          Hg.
Pw=Vapor pressure of H20 in the bag (from Table 
          10A-2), mm Hg.
Vb=Volume of the sample bulb, liters.
Vr=Volume of reagent added to the sample bulb, 0.0100 liter.

                6.2 Average Sample Absorbance per Liter.

    Average the three absorbance values for each bulb set. Then 
calculate As for each set of gas bulbs using Equation 10A-1. 
Use As to determine the CO concentration from the calibration 
curve (Cg).
[GRAPHIC] [TIFF OMITTED] TC16NO91.168

    Note: A and Ar must be at the same wavelength.

                    6.3 CO Concentration in the Bag.

    Calculate Cb using Equations 10A-2 and 10A-3. If 
condensate is visible in the Tedlar bag, calculate Bw using 
Table 10A-2 and the temperature and barometric pressure in the analysis 
room. If condensate is not visible, calculate Bw using the 
temperature and barometric pressure recorded at the sampling site.
[GRAPHIC] [TIFF OMITTED] TC16NO91.169


[[Page 886]]


[GRAPHIC] [TIFF OMITTED] TC16NO91.170

    6.4 CO Concentration in the Stack.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.171
    
    [GRAPHIC] [TIFF OMITTED] TC01JN92.185
    
                             7. Bibliography

    1. Butler, F.E., J.E. Knoll, and M.R. Midgett. Development and 
Evaluation of Methods for Determining Carbon Monoxide Emissions. Quality 
Assurance Division, Environmental Monitoring Systems Laboratory, U.S. 
Environmental Protection Agency, Research Triangle Park, NC 27711. June 
1985. 33 p.
    2. Ferguson, B.B., R.E. Lester, and W.J. Mitchell. Field Evaluation 
of Carbon Monoxide and Hydrogen Sulfide Continuous Emission Monitors at 
an Oil Refinery. U.S. Environmental Protection Agency. Research Triangle 
Park, NC. Publication No. EPA-600/4-82-054. August 1982. 100 p.
    3. Lambert, J.L., and R.E. Weins. Induced Colorimetric Method for 
Carbon Monoxide. Analytical Chemistry. 46(7):929-930. June 1974.
    4. Levaggi, D.A., and M. Feldstein. The Colorimetric Determination 
of Low Concentrations of Carbon Monoxide. Industrial Hygiene Journal. 
25:64-66. January-February 1964.
    5. Repp, M. Evaluation of Continuous Monitors for Carbon Monoxide in 
Stationary Sources. U.S. Environmental Protection Agency. Research 
Triangle Park, NC. Publication No. EPA-600/2-77-063. March 1977. 155 p.
    6. Smith, F., D.E. Wagoner, and R.P. Donovan. Guidelines for 
Development of a Quality Assurance Program: Volume VIII--Determination 
of CO Emissions from Stationary Sources by NDIR Spectrometry. U.S. 
Environmental Protection Agency. Research Triangle Park, NC. Publication 
No. EPA-650/4-74-005-h. February 1975. 96 p.

 Method 10B--Determination of Carbon Monoxide Emissions From Stationary 
                                 Sources

                     1. Applicability and Principle

    1.1  Applicability. This method applies to the measurement of carbon 
monoxide (CO) emissions at petroleum refineries and from other sources 
when specified in an applicable subpart of the regulations.

[[Page 887]]

    1.2  Principle. An integrated gas sample is extracted from the 
sampling point and analyzed for CO. The sample is passed through a 
conditioning system to remove interferences and collected in a Tedlar 
bag. The CO is separated from the sample by gas chromatography (GC) and 
catalytically reduced to methane (CH4) prior to analysis by 
flame ionization detection FID. The analytical portion of this method is 
identical to applicable sections in Method 25 detailing CO measurement. 
The oxidation catalyst required in Method 25 is not needed for sample 
analysis. Complete Method 25 analytical systems are acceptable 
alternatives when calibrated for CO and operated by the Method 25 
analytical procedures.
    Note: Mention of trade names or commercial products in this method 
does not constitute the endorsement or recommendation for use by the 
Environmental Protection Agency.
    1.3  Interferences. Carbon dioxide (CO2) and organics 
potentially can interfere with the analysis. Carbon dioxide is primarily 
removed from the sample by the alkaline permanganate conditioning 
system; any residual CO2 and organics are separated from the 
CO by GC.

                              2. Apparatus

    2.1  Sampling. Same as in Method 10A, section 2.1.
    2.2  Analysis.
    2.2.1  Gas Chromatographic (GC) Analyzer. A semicontinuous GC/FID 
analyzer capable of quantifying CO in the sample and containing at least 
the following major components.
    2.2.1.1  Separation Column. A column that separates CO from 
CO2 and organic compounds that may be present. A \1/8\-in. OD 
stainless-steel column packed with 5.5 ft of 60/80 mesh Carbosieve S-II 
(available from Supelco) has been used successfully for this purpose. 
The column listed in Addendum 1 of Method 25 is also acceptable.
    2.2.1.2  Reduction Catalyst. Same as in Method 25, section 2.3.2.
    2.2.1.3  Sample Injection System. Same as in Method 25, section 
2.3.4, equipped to accept a sample line from the Tedlar bag.
    2.2.1.4  Flame Ionization Detector. Linearity meeting the 
specifications in section 2.3.5.1 of Method 25 where the linearity check 
is carried out using standard gases containing 20-, 200-, and 1,000-ppm 
CO. The minimal instrument range shall span 10 to 1,000 ppm CO.
    2.2.1.5  Data Recording System. Same as in Method 25, section 2.3.6.
    3. Reagents
    3.1  Sampling. Same as in Method 10A, section 3.1.
    3.2  Analysis.
    3.2.1  Carrier, Fuel, and Combustion Gases. Same as in Method 25, 
sections 3.2.1, 3.2.2, and 3.2.3.
    3.2.2  Linearity and Calibration Gases. Three standard gases with 
nominal CO concentrations of 20-, 200-, and 1,000-ppm CO in nitrogen.
    3.2.3  Reduction Catalyst Efficiency Check Calibration Gas. Standard 
CH4 gas with a concentration of 1,000 ppm in air.

                              4. Procedure

    4.1  Sample Bag Leak-checks, Sampling, and CO2 
Measurement. Same as in Method 10A, sections 4.1, 4.2, and 4.3.
    4.2  Preparation for Analysis. Before putting the GC analyzer into 
routine operation, conduct the calibration procedures listed in section 
5. Establish an appropriate carrier flow rate and detector temperature 
for the specific instrument used.
    4.3  Sample Analysis. Purge the sample loop with sample, and then 
inject the sample. Analyze each sample in triplicate, and calculate the 
average sample area (A). Determine the bag CO concentration according to 
section 6.2.

                             5. Calibration

    5.1  Carrier Gas Blank Check. Analyze each new tank of carrier gas 
with the GC analyzer according to section 4.3 to check for 
contamination. The corresponding concentration must be less than 5 ppm 
for the tank to be acceptable for use.
    5.2  Reduction Catalyst Efficiency Check. Prior to initial use, the 
reduction catalyst shall be tested for reduction efficiency. With the 
heated reduction catalyst bypassed, make triplicate injections of the 
1,000-ppm CH4 gas (section 3.2.3) to calibrate the analyzer. 
Repeat the procedure using 1,000-ppm CO (section 3.2.2) with the 
catalyst in operation. The reduction catalyst operation is acceptable if 
the CO response is within 5 percent of the certified gas value.
    5.3  Analyzer Linearity Check and Calibration. Perform this test 
before the system is first placed into operation. With the reduction 
catalyst in operation, conduct a linearity check of the analyzer using 
the standards specified in section 3.2.2. Make triplicate injections of 
each calibration gas, and then calculate the average response factor 
(area/ppm) for each gas, as well as the overall mean of the response 
factor values. The instrument linearity is acceptable if the average 
response factor of each calibration gas is within 2.5 percent of the 
overall mean value and if the relative standard deviation (calculated in 
section 6.9 of Method 25) for each set of triplicate injections is less 
than 2 percent. Record the overall mean of the response factor values as 
the calibration response factor (R).

[[Page 888]]

                             6. Calculations

    Carry out calculations retaining at least one extra decimal figure 
beyond that of the acquired data. Round off results only after the final 
calculation.
    6.1  Nomenclature.
    A=Average sample area.
    Bw=Moisture content in the bag sample, fraction.
    C=CO concentration in the stack gas, dry basis, ppm.
    Cb=CO concentration in the bag sample, dry basis, ppm.
    F=Volume fraction of CO2 in the stack, fraction.
    Pbar=Barometric pressure, mm Hg.
    Pw=Vapor pressure H2O in the bag (from Table 
10-2, Method 10A), mm Hg.
    R=Mean calibration response factor, area/ppm.
    6.2  CO Concentration in the Bag. Calculate Cb using 
Equations 10B-1 and 10B-2. If condensate is visible in the Tedlar bag, 
calculate Bw using Table 10A-1 of Method 10A and the 
temperature and barometric pressure in the analysis room. If condensate 
is not visible, calculate Bw using the temperature and 
barometric pressure at the sampling site.
[GRAPHIC] [TIFF OMITTED] TC16NO91.172


[GRAPHIC] [TIFF OMITTED] TC16NO91.173


    6.3  CO Concentration in the Stack.

C=Cb(1-F)

Eq. 10B-3

                             7. Bibliography

    1. Butler, F.E, J.E. Knoll, and M.R. Midgett. Development and 
Evaluation of Methods for Determining Carbon Monoxide Emissions. Quality 
Assurance Division, Environmental Monitoring Systems Laboratory, U.S. 
Environmental Protection Agency, Research Triangle Park, NC 27711. June 
1985. 33p.
    2. Salo, A.E., S. Witz, and R.D. MacPhee. Determination of Solvent 
Vapor Concentrations by Total Combustion Analysis: A Comparison of 
Infrared with Flame Ionization Detectors. Paper No. 75-33.2. (Presented 
at the 68th Annual Meeting of the Air Pollution Control Association. 
Boston, MA. June 15, 1975.) 14 p.
    3. Salo, A.E., W.L. Oaks, and R.D. MacPhee. Measuring the Organic 
Carbon Content of Source Emissions for Air Pollution Control. Paper No. 
74-190. (Presented at the 67th Annual Meeting of the Air Pollution 
Control Association. Denver, CO. June 9, 1974.) 25 p.

Method 11--Determination of Hydrogen Sulfide Content of Fuel Gas Streams 
                         in Petroleum Refineries

1. Principle and Applicability

    1.1 Principle. Hydrogen sulfide (H2S) is collected from a 
source in a series of midget impingers and absorbed in pH 3.0 cadmium 
sulfate (CdSO4) solution to form cadmium sulfide (CdS). The 
latter compound is then measured iodometrically. An impinger containing 
hydrogen peroxide is included to remove SO2 as an interfering 
species. This method is a revision of the H2S method 
originally published in the Federal Register, Volume 39, No. 47, dated 
Friday, March 8, 1974.
    1.2 Applicability. This method is applicable for the determination 
of the hydrogen sulfide content of fuel gas streams at petroleum 
refineries.

2. Range and Sensitivity

    The lower limit of detection is approximately 8 mg/m3 (6 
ppm). The maximum of the range is 740 mg/m3 (520 ppm).

3. Interferences

    Any compound that reduces iodine or oxidizes iodide ion will 
interfere in this procedure, provided it is collected in the cadmium 
sulfate impingers. Sulfur dioxide in concentrations of up to 2,600 mg/
m3 is eliminated by the hydrogen peroxide solution. Thiols 
precipitate with hydrogen sulfide. In the absence of H2S, 
only co-traces of thiols are collected. When methane- and ethane-thiols 
at a total level of 300 mg/m3 are present in addition to 
H2S, the results vary from 2 percent low at an H2S 
concentration of 400 mg/m3 to 14 percent high at an 
H2S concentration of 100 mg/m3. Carbon oxysulfide 
at a concentration of 20 percent does not interfere. Certain carbonyl-
containing compounds react with iodine and produce recurring end points. 
However, acetaldehyde and acetone at concentrations of 1 and 3 percent, 
respectively, do not interfere.
    Entrained hydrogen peroxide produces a negative interference 
equivalent to 100 percent of that of an equimolar quantity of hydrogen 
sulfide. Avoid the ejection of hydrogen peroxide into the cadmium 
sulfate impingers.

4. Precision and Accuracy

    Collaborative testing has shown the within-laboratory coefficient of 
variation to be 2.2 percent and the overall coefficient of variation to 
be 5 percent. The method bias was shown to be -4.8 percent when only 
H2S was present. In the presence of the interferences cited 
in section 3, the bias was positive at low H2S concentration 
and negative at higher concentrations. At 230 mg H2S/
m3, the level of the compliance standard, the bias

[[Page 889]]

was +2.7 percent. Thiols had no effect on the precision.

5. Apparatus

    5.1 Sampling Apparatus.
    5.1.1  Sampling Line. Six to 7 mm (\1/4\ in.) Teflon \1\ tubing to 
connect the sampling train to the sampling valve.
---------------------------------------------------------------------------

    \1\ Mention of trade names or specific products does not constitute 
endorsement by the Environmental Protection Agency.
---------------------------------------------------------------------------

    5.1.2  Impingers. Five midget impingers, each with 30 ml capacity. 
The internal diameter of the impinger tip must be 1 mm 
plus-minus0.05 mm. The impinger tip must be positioned 4 to 6 
mm from the bottom of the impinger.
    5.1.3  Tubing. Glass or Teflon connecting tubing for the impingers.
    5.1.4  Ice Bath Container. To maintain absorbing solution at a low 
temperature.
    5.1.5  Drying Tube. Tube packed with 6- to 16-mesh indicating-type 
silica gel, or equivalent, to dry the gas sample and protect the meter 
and pump. If the silica gel has been used previously, dry at 175  deg.C 
(350  deg.F) for 2 hours. New silica gel may be used as received. 
Alternatively, other types of desiccants (equivalent or better) may be 
used, subject to approval of the Administrator.
    Note: Do not use more than 30 g of silica gel. Silica gel absorbs 
gases such as propane from the fuel gas stream, and use of excessive 
amounts of silica gel could result in errors in the determination of 
sample volume.
    5.1.6  Sampling Valve. Needle valve or equivalent to adjust gas flow 
rate. Stainless steel or other corrosion-resistant material.
    5.1.7  Volume Meter. Dry gas meter, sufficiently accurate to measure 
the sample volume within 2 percent, calibrated at the selected flow rate 
(1.0 liter/min) and conditions actually encountered during 
sampling. The meter shall be equipped with a temperature gauge (dial 
thermometer or equivalent) capable of measuring temperature to within 3 
deg.C (5.4  deg.F). The gas meter should have a petcock, or equivalent, 
on the outlet connector which can be closed during the leak check. Gas 
volume for one revolution of the meter must not be more than 10 liters.
    5.1.8  Flow Meter. Rotameter or equivalent, to measure flow rates in 
the range from 0.5 to 2 liters/min (1 to 4 cfh).
    5.1.9  Graduated Cylinder, 25 ml size.
    5.1.10  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg). In many 
cases, the barometric reading may be obtained from a nearby National 
Weather Service station, in which case, the station value (which is the 
absolute barometric pressure) shall be requested and an adjustment for 
elevation differences between the weather station and the sampling point 
shall be applied at a rate of minus 2.5 mm Hg (0.1 in. Hg) per 30 m (100 
ft) elevation increase or vice-versa for elevation decrease.
    5.1.11  U-tube Manometer. 0-30 cm water column. For leak check 
procedure.
    5.1.12  Rubber Squeeze Bulb. To pressurize train for leak check.
    5.1.13  Tee, Pinchclamp, and Connecting Tubing. For leak check.
    5.1.14  Pump. Diaphragm pump, or equivalent. Insert a small surge 
tank between the pump and rate meter to eliminate the pulsation effect 
of the diaphragm pump on the rotameter. The pump is used for the air 
purge at the end of the sample run; the pump is not ordinarily used 
during sampling, because fuel gas streams are usually sufficiently 
pressurized to force sample gas through the train at the required flow 
rate. The pump need not be leak-free unless it is used for sampling.
    5.1.15  Needle Valve or Critical Orifice. To set air purge flow to 1 
liter/min.
    5.1.16  Tube Packed With Active Carbon. To filter air during purge.
    5.1.17  Volumetric Flask. One 1,000 ml.
    5.1.18  Volumetric Pipette. One 15 ml.
    5.1.19  Pressure-Reduction Regulator. Depending on the sampling 
stream pressure, a pressure-reduction regulator may be needed to reduce 
the pressure of the gas stream entering the Teflon sample line to a safe 
level.
    5.1.20  Cold Trap. If condensed water or amine is present in the 
sample stream, a corrosion-resistant cold trap shall be used immediately 
after the sample tap. The trap shall not be operated below 0  deg.C (32 
deg.F) to avoid condensation of C3 or C4 
hydrocarbons.
    5.2  Sample Recovery.
    5.2.1  Sample Container. Iodine flask, glass-stoppered: 500 ml size.
    5.2.2  Pipette. 50 ml volumetric type.
    5.2.3  Graduated Cylinders. One each 25 and 250 ml.
    5.2.4  Flasks. 125 ml, Erlenmeyer.
    5.2.5  Wash Bottle.
    5.2.6  Volumetric Flasks. Three 1,000 ml.
    5.3  Analysis.
    5.3.1  Flask. 500 ml glass-stoppered iodine flask.
    5.3.2  Burette. 50 ml.
    5.3.3  Flask. 125 ml, Erlenmeyer.
    5.3.4  Pipettes, Volumetric. One 25 ml; two each 50 and 100 ml.
    5.3.5  Volumetric Flasks. One 1,000 ml; two 500 ml.
    5.3.6  Graduated Cylinders. One each 10 and 100 ml.

6. Reagents

    Unless otherwise indicated, it is intended that all reagents conform 
to the specifications established by the Committee on Analytical 
Reagents of the American Chemical Society, where such specifications are 
available. Otherwise, use best available grade.
    6.1  Sampling.

[[Page 890]]

    6.1.1  Cadmium Sulfate Absorbing Solution. Dissolve 41 g of 
3CdSO48H2 O and 15 ml of 0.1 M sulfuric 
acid in a 1-liter volumetric flask that contains approximately \3/4\ 
liter of deionized distilled water. Dilute to volume with deionized 
water. Mix thoroughly. pH should be 3plus-minus0.1. Add 10 
drops of Dow-Corning Antifoam B. Shake well before use. If Antifoam B is 
not used, the alternative acidified iodine extraction procedure (Section 
7.2.2) must be used.
    6.1.2  Hydrogen Peroxide, 3 Percent. Dilute 30 percent hydrogen 
peroxide to 3 percent as needed. Prepare fresh daily.
    6.1.3  Water. Deionized, distilled to conform to ASTM specifications 
D1193-72, Type 3. At the option of the analyst, the KMnO4 
test for oxidizable organic matter may be omitted when high 
concentrations of organic matter are not expected to be present.
    6.2  Sample Recovery.
    6.2.1  Hydrochloric Acid Solution (HCl), 3M. Add 240 ml of 
concentrated HCl (specific gravity 1.19) to 500 ml of deionized, 
distilled water in a 1-liter volumetric flask. Dilute to 1 liter with 
deionized water. Mix thoroughly.
    6.2.2  Iodine Solution 0.1 N. Dissolve 24 g of potassium iodide (KI) 
in 30 ml of deionized, distilled water. Add 12.7 g of resublimed iodine 
(I2) to the potassium iodide solution. Shake the mixture 
until the iodine is completely dissolved. If possible, let the solution 
stand overnight in the dark. Slowly dilute the solution to 1 liter with 
deionized, distilled water, with swirling. Filter the solution if it is 
cloudy. Store solution in a brown-glass reagent bottle.
    6.2.3  Standard Iodine Solution, 0.01 N. Pipette 100.0 ml of the 0.1 
N iodine solution into a 1-liter volumetric flask and dilute to volume 
with deionized, distilled water. Standardize daily as in Section 8.1.1. 
This solution must be protected from light. Reagent bottles and flasks 
must be kept tightly stoppered.
    6.3  Analysis.
    6.3.1  Sodium Thiosulfate Solution, Standard 0.1 N. Dissolve 24.8 g 
of sodium thiosulfate pentahydrate 
(Na2S2O35H2O) or 
15.8 g of anhydrous sodium thiosulfate 
(Na2S2O3) in 1 liter of deionized, 
distilled water and add 0.01 g of anhydrous sodium carbonate 
(Na2CO3) and 0.4 ml of chloroform 
(CHCl3) to stabilize. Mix thoroughly by shaking or by 
aerating with nitrogen for approximately 15 minutes and store in a 
glass-stoppered, reagent bottle. Standardize as in Section 8.1.2.
    6.3.2  Sodium Thiosulfate Solution, Standard 0.01 N. Pipette 50.0 ml 
of the standard 0.1 N thiosulfate solution into a volumetric flask and 
dilute to 500 ml with distilled water.
    Note: A 0.01 N phenylarsine oxide solution may be prepared instead 
of 0.01 N thiosulfate (see Section 6.3.3).
    6.3.3  Phenylarsine Oxide Solution, Standard 0.01 N. Dissolve 1.80 g 
of phenylarsine oxide (C6H5AsO) in 150 ml of 0.3 N 
sodium hydroxide. After settling, decant 140 ml of this solution into 
800 ml of distilled water. Bring the solution to pH 6-7 with 6N 
hydrochloric acid and dilute to 1 liter. Standardize as in Section 
8.1.3.
    6.3.4  Starch Indicator Solution. Suspend 10 g of soluble starch in 
100 ml of deionized, distilled water and add 15 g of potassium hydroxide 
(KOH) pellets. Stir until dissolved, dilute with 900 ml of deionized 
distilled water and let stand for 1 hour. Neutralize the alkali with 
concentrated hydrochloric acid, using an indicator paper similar to 
Alkacid test ribbon, then add 2 ml of glacial acetic acid as a 
preservative.
    Note: Test starch indicator solution for decomposition by titrating, 
with 0.01 N iodine solution, 4 ml of starch solution in 200 ml of 
distilled water that contains 1 g potassium iodide. If more than 4 drops 
of the 0.01 N iodine solution are required to obtain the blue color, a 
fresh solution must be prepared.
7. Procedure

    7.1  Sampling.
    7.1.1  Assemble the sampling train as shown in Figure 11-1, 
connecting the five midget impingers in series. Place 15 ml of 3 percent 
hydrogen peroxide solution in the first impinger. Leave the second 
impinger empty. Place 15 ml of the cadmium sulfate absorbing solution in 
the third, fourth, and fifth impingers. Place the impinger assembly in 
an ice bath container and place crushed ice around the impingers. Add 
more ice during the run, if needed.
    7.1.2  Connect the rubber bulb and manometer to first impinger, as 
shown in Figure 11-1. Close the petcock on the dry gas meter outlet. 
Pressurize the train to 25-cm water pressure with the bulb and close off 
tubing connected to rubber bulb. The train must hold a 25-cm water 
pressure with not more than a 1-cm drop in pressure in a 1-minute 
interval. Stopcock grease is acceptable for sealing ground glass joints.
    Note: This leak check procedure is optional at the beginning of the 
sample run, but is mandatory at the conclusion. Note also that if the 
pump is used for sampling, it is recommended (but not required) that the 
pump be leak-checked separately, using a method consistent with the 
leak-check procedure for diaphragm pumps outlined in Section 4.1.2 of 
Method 6, 40 CFR part 60, appendix A.
    7.1.3  Purge the connecting line between the sampling valve and 
first impinger, by disconnecting the line from the first impinger, 
opening the sampling valve, and allowing process gas to flow through the 
line for a minute or two. Then, close the sampling valve and reconnect 
the line to the impinger train. Open the petcock on the dry

[[Page 891]]

gas meter outlet. Record the initial dry gas meter reading.
[GRAPHIC] [TIFF OMITTED] TC01JN92.186

    7.1.4  Open the sampling valve and then adjust the valve to obtain a 
rate of approximately 1 liter/min. Maintain a constant 
(plus-minus10 percent) flow rate during the test. Record the 
meter temperature.
    7.1.5  Sample for at least 10 min. At the end of the sampling time, 
close the sampling valve and record the final volume and temperature 
readings. Conduct a leak check as described in Section 7.1.2 above.
    7.1.6  Disconnect the impinger train from the sampling line. Connect 
the charcoal tube and the pump, as shown in Figure 11-1. Purge the train 
(at a rate of 1 liter/min) with clean ambient air for 15 minutes to 
ensure that all H2S is removed from the hydrogen peroxide. 
For sample recovery, cap the open ends and remove the impinger train to 
a clean area that is away from sources of heat. The area should be well 
lighted, but not exposed to direct sunlight.
    7.2  Sample Recovery.

[[Page 892]]

    7.2.1  Discard the contents of the hydrogen peroxide impinger. 
Carefully rinse the contents of the third, fourth, and fifth impingers 
into a 500 ml iodine flask.
    Note: The impingers normally have only a thin film of cadmium 
sulfide remaining after a water rinse. If Antifoam B was not used or if 
significant quantities of yellow cadmium sulfide remain in the 
impingers, the alternative recovery procedure described below must be 
used.
    7.2.2  Pipette exactly 50 ml of 0.01 N iodine solution into a 125 ml 
Erlenmeyer flask. Add 10 ml of 3 M HCl to the solution. Quantitatively 
rinse the acidified iodine into the iodine flask. Stopper the flask 
immediately and shake briefly.
    7.2.2 (Alternative). Extract the remaining cadmium sulfide from the 
third, fourth, and fifth impingers using the acidified iodine solution. 
Immediately after pouring the acidified iodine into an impinger, stopper 
it and shake for a few moments, then transfer the liquid to the iodine 
flask. Do not transfer any rinse portion from one impinger to another; 
transfer it directly to the iodine flask. Once the acidified iodine 
solution has been poured into any glassware containing cadmium sulfide, 
the container must be tightly stoppered at all times except when adding 
more solution, and this must be done as quickly and carefully as 
possible. After adding any acidified iodine solution to the iodine 
flask, allow a few minutes for absorption of the H2S before 
adding any further rinses. Repeat the iodine extraction until all 
cadmium sulfide is removed from the impingers. Extract that part of the 
connecting glassware that contains visible cadmium sulfide.
    Quantitatively rinse all of the iodine from the impingers, 
connectors, and the beaker into the iodine flask using deionized, 
distilled water. Stopper the flask and shake briefly.
    7.2.3  Allow the iodine flask to stand about 30 minutes in the dark 
for absorption of the H2S into the iodine, then complete the 
titration analysis as in Section 7.3.
    Note: Caution! Iodine evaporates from acidified iodine solutions. 
Samples to which acidified iodine have been added may not be stored, but 
must be analyzed in the time schedule stated in Section 7.2.3.
    7.2.4  Prepare a blank by adding 45 ml of cadmium sulfate absorbing 
solution to an iodine flask. Pipette exactly 50 ml of 0.01 N iodine 
solution into a 125-ml Erlenmeyer flask. Add 10 ml of 3 M HCl. Follow 
the same impinger extracting and quantitative rinsing procedure carried 
out in sample analysis. Stopper the flask, shake briefly, let stand 30 
minutes in the dark, and titrate with the samples.
    Note: The blank must be handled by exactly the same procedure as 
that used for the samples.
    7.3  Analysis.
    Note: Titration analyses should be conducted at the sample-cleanup 
area in order to prevent loss of iodine from the sample. Titration 
should never be made in direct sunlight.
    7.3.1  Using 0.01 N sodium thiosulfate solution (or 0.01 N 
phenylarsine oxide, if applicable), rapidly titrate each sample in an 
iodine flask using gentle mixing, until solution is light yellow. Add 4 
ml of starch indicator solution and continue titrating slowly until the 
blue color just disappears. Record VTT, the volume of sodium 
thiosulfate solution used, or VAT, the volume of phenylarsine 
oxide solution used (ml).
    7.3.2  Titrate the blanks in the same manner as the samples. Run 
blanks each day until replicate values agree within 0.05 ml. Average the 
replicate titration values which agree within 0.05 ml.

8. Calibration and Standards

    8.1  Standardizations.
    8.1.1  Standardize the 0.01 N iodine solution daily as follows: 
Pipette 25 ml of the iodine solution into a 125 ml Erlenmeyer flask. Add 
2 ml of 3 M HCl. Titrate rapidly with standard 0.01 N thiosulfate 
solution or with 0.01 N phenylarsine oxide until the solution is light 
yellow, using gentle mixing. Add four drops of starch indicator solution 
and continue titrating slowly until the blue color just disappears. 
Record VT, the volume of thiosulfate solution used, or 
VAS, the volume of phenylarsine oxide solution used (ml). 
Repeat until replicate values agree within 0.05 ml. Average the 
replicate titration values which agree within 0.05 ml and calculate the 
exact normality of the iodine solution using Equation 11-3. Repeat the 
standardization daily.
    8.1.2  Standardize the 0.1 N thiosulfate solution as follows: Oven-
dry potassium dichromate (K2Cr2O7) at 
180 to 200  deg.C (360 to 390  deg.F). Weigh to the nearest milligram, 2 
g of potassium dichromate. Transfer the dichromate to a 500 ml 
volumetric flask, dissolve in deionized, distilled water and dilute to 
exactly 500 ml. In a 500 ml iodine flask, dissolve approximately 3 g of 
potassium iodide (KI) in 45 ml of deionized, distilled water, then add 
10 ml of 3 M hydrochloric acid solution. Pipette 50 ml of the dichromate 
solution into this mixture. Gently swirl the solution once and allow it 
to stand in the dark for 5 minutes. Dilute the solution with 100 to 200 
ml of deionized distilled water, washing down the sides of the flask 
with part of the water. Titrate with 0.1 N thiosulfate until the 
solution is light yellow. Add 4 ml of starch indicator and continue 
titrating slowly to a green end point. Record VS, the volume 
of thiosulfate solution used (ml). Repeat until replicate analyses agree 
within 0.05 ml. Calculate the normality using Equation 11-1. Repeat the 
standardization each week, or

[[Page 893]]

after each test series, whichever time is shorter.
    8.1.3  Standardize the 0.01 N Phenylarsine oxide (if applicable) as 
follows: oven dry potassium dichromate 
(K2Cr2O7) at 180 to 200  deg.C (360 to 
390  deg.F). Weigh to the nearest milligram, 2 g of the 
K2Cr2O7; transfer the dichromate to a 
500 ml volumetric flask, dissolve in deionized, distilled water, and 
dilute to exactly 500 ml. In a 500 ml iodine flask, dissolve 
approximately 0.3 g of potassium iodide (KI) in 45 ml of deionized, 
distilled water; add 10 ml of 3M hydrochloric acid. Pipette 5 ml of the 
K2Cr2O7 solution into the iodine flask. 
Gently swirl the contents of the flask once and allow to stand in the 
dark for 5 minutes. Dilute the solution with 100 to 200 ml of deionized, 
distilled water, washing down the sides of the flask with part of the 
water. Titrate with 0.01 N phenylarsine oxide until the solution is 
light yellow. Add 4 ml of starch indicator and continue titrating slowly 
to a green end point. Record VA, the volume of phenylarsine 
oxide used (ml). Repeat until replicate analyses agree within 0.05 ml. 
Calculate the normality using Equation 11-2. Repeat the standardization 
each week or after each test series, whichever time is shorter.
    8.2  Sampling Train Calibration. Calibrate the sampling train 
components as follows:
    8.2.1  Dry Gas Meter.
    8.2.1.1  Initial Calibration. The dry gas meter shall be calibrated 
before its initial use in the field. Proceed as follows: First, assemble 
the following components in series: Drying tube, needle valve, pump, 
rotameter, and dry gas meter. Then, leak-check the system as follows: 
Place a vacuum gauge (at least 760 mm Hg) at the inlet to the drying 
tube and pull a vacuum of 250 mm (10 in.) Hg; plug or pinch off the 
outlet of the flow meter, and then turn off the pump. The vacuum shall 
remain stable for at least 30 seconds. Carefully release the vacuum 
gauge before releasing the flow meter end.
    Next, calibrate the dry gas meter (at the sampling flow rate 
specified by the method) as follows: Connect an appropriately sized wet 
test meter (e.g., 1 liter per revolution) to the inlet of the drying 
tube. Make three independent calibration runs, using at least five 
revolutions of the dry gas meter per run. Calculate the calibration 
factor, Y (wet test meter calibration volume divided by the dry gas 
meter volume, both volumes adjusted to the same reference temperature 
and pressure), for each run, and average the results. If any Y value 
deviates by more than 2 percent from the average, the dry gas meter is 
unacceptable for use. Otherwise, use the average as the calibration 
factor for subsequent test runs.
    8.2.1.2  Post-test Calibration Check. After each field test series, 
conduct a calibration check as in Section 8.2.1.1. above, except for the 
following variations: (a) The leak check is not to be conducted, (b) 
three or more revolutions of the dry gas meter may be used, and (c) only 
two independent runs need be made. If the calibration factor does not 
deviate by more than 5 percent from the initial calibration factor 
(determined in Section 8.2.1.1.), then the dry gas meter volumes 
obtained during the test series are acceptable. If the calibration 
factor deviates by more than 5 percent, recalibrate the dry gas meter as 
in Section 8.2.1.1, and for the calculations, use the calibration factor 
(initial or recalibration) that yields the lower gas volume for each 
test run.
    8.2.2  Thermometers. Calibrate against mercury-in-glass 
thermometers.
    8.2.3  Rotameter. The rotameter need not be calibrated, but should 
be cleaned and maintained according to the manufacturer's instruction.
    8.2.4  Barometer. Calibrate against a mercury barometer.

9. Calculations

    Carry out calculations retaining at least one extra decimal figure 
beyond that of the acquired data. Round off results only after the final 
calculation.
    9.1  Normality of the Standard (0.1 N) Thiosulfate 
Solution.
NS=2.039W/VS
                                                          Eq. 11-1

where:

W=Weight of K2Cr2O7 used, g.
VS=Volume of Na2S2O3 
          solution used, ml.
NS=Normality of standard thiosulfate solution, g-eq/liter.
2.039=Conversion factor

  (6 eq. I2/mole K2Cr2O7) 
  (1,000 ml/liter)/ (294.2 g K2Cr2O7/
                        mole) (10 aliquot factor)

    9.2  Normality of Standard Phenylarsine Oxide Solution (if 
applicable).
NA=0.2039 W/VA
                                                          Eq. 11-2

where:

W=Weight of K2Cr2O7 used, g.
VA=Volume of C6H5AsO used, 
          ml.
NA=Normality of standard phenylarsine oxide solution, g-eq/
          liter.
0.2039=Conversion factor

  (6 eq. I2/mole K2Cr2O7) 
(1,000 ml/liter)/(249.2 g K2Cr2O7/mole) 
                          (100 aliquot factor)

    9.3  Normality of Standard Iodine Solution.

            NI=NTVT/VI

                                                              11-3

where:

NI=Normality of standard iodine solution, g-eq/liter.
VI=Volume of standard iodine solution used, ml.

[[Page 894]]

NT=Normality of standard (0.01 N) thiosulfate 
          solution; assumed to be 0.1 NS, g-eq/liter.
VT=Volume of thiosulfate solution used, ml.
    Note: If phenylarsine oxide is used instead of thiosulfate, replace 
NT and VT in Equation 11-3 with NA and 
VAS, respectively (see Sections 8.1.1 and 8.1.3).
    9.4  Dry Gas Volume. Correct the sample volume measured by the dry 
gas meter to standard conditions (20  deg.C and 760 mm Hg.)

  Vm(std)=Vm Y [(Tstd/Tm) 
                   (Pbar/Pstd)]

                                                                Eq. 11-4

Where:

Vm(std)=Volume at standard conditions of gas sample through 
          the dry gas meter, standard liters.
Vm=Volume of gas sample through the dry gas meter (meter 
          conditions), liters.
Tstd=Absolute temperature at standard conditions, 293 deg.K.
Tm=Average dry gas meter temperature,  deg.K.
Pbar=Barometric pressure at the sampling site, mm Hg.
Pstd=Absolute pressure at standard conditions, 760 mm Hg.
Y=Dry gas meter calibration factor.
    9.5  Concentration of H2S. Calculate the concentration of 
H2S in the gas stream at standard conditions using the 
following equation:

CH2S=K[(VITNI-VTTNT)
           sample--
    (VIT NI-VTT NT)]/
          Vm(std)
                                                          Eq. 11-5

Where (metric units):

CH2S=Concentration of H2S at standard conditions, 
          mg/dscm.
K=Conversion factor 17.04 x 10 3

(34.07 g/mole H2S) (1,000 liters/m 3) (1,000 
            mg/g)/(1,000 ml/liter) (2H2S eq/mole)

VIT=Volume of standard iodine solution=50.0 ml.
NI=Normality of standard iodine solution, g-eq/liter.
VTT=Volume of standard (0.01 N) sodium 
          thiosulfate solution, ml.
NT=Normality of standard sodium thiosulfate solution, g-eq/
          liter.
Vm(std)=Dry gas volume at standard conditions, liters.
    Note: If phenylarsine oxide is used instead of thiosulfate, replace 
NT and VTT in Equation 11-5 with NA and 
VAT, respectively (see Sections 7.3.1 and 8.1.3).
10. Stability

    The absorbing solution is stable for at least 1 month. Sample 
recovery and analysis should begin within 1 hour of sampling to minimize 
oxidation of the acidified cadmium sulfide. Once iodine has been added 
to the sample, the remainder of the analysis procedure must be completed 
according to Sections 7.2.2 through 7.3.2.

11. Bibliography

    1.  Determination of Hydrogen Sulfide, Ammoniacal Cadmium Chloride 
Method. API Method 772-54. In: Manual on Disposal of Refinery Wastes, 
Vol. V: Sampling and Analysis of Waste Gases and Particulate Matter, 
American Petroleum Institute, Washington, DC. 1954.
    2.  Tentative Method of Determination of Hydrogen Sulfide and 
Mercaptan Sulfur in Natural Gas, Natural Gas Processors Association, 
Tulsa, OK. NGPA Publication No. 2265-65. 1965.
    3.  Knoll, J. E., and M. R. Midgett. Determination of Hydrogen 
Sulfide in Refinery Fuel Gases, Environmental Monitoring Series, Office 
of Research and Development, USEPA, Research Triangle Park, NC 27711, 
EPA 600/4-77-007.
    4.  Scheil, G. W., and M. C. Sharp. Standardization of Method 11 at 
a Petroleum Refinery, Midwest Research Institute Draft Report for USEPA, 
Office of Research and Development, Research Triangle Park, NC 27711, 
EPA Contract No. 68-02-1098. August 1976, EPA 600/4-77-088a (Volume 1) 
and EPA 600/4-77-088b (Volume 2).

  Method 12--Determination of Inorganic Lead Emissions From Stationary 
                                 Sources

1. Principle and Applicability

    1.1  Applicability. This method applies to the determination of 
inorganic lead (Pb) emissions from specified stationary sources only.
    1.2  Principle. Particulate and gaseous Pb emissions are withdrawn 
isokinetically from the source and collected on a filter and in dilute 
nitric acid. The collected samples are digested in acid solution and 
analyzed by atomic absorption spectrometry using an air acetylene flame.

2. Range, Sensitivity, Precision, and Interferences

    2.1  Range. For a minimum analytical accuracy of 
plus-minus10 percent, the lower limit of the range is 100 
g. The upper limit can be considerably extended by dilution.
    2.2  Analytical Sensitivity. Typical sensitivities for a 1-percent 
change in absorption (0.0044 absorbance units) are 0.2 and 0.5 
g Pb/ml for the 217.0 and 283.3 nm lines, respectively.
    2.3  Precision. The within-laboratory precision, as measured by the 
coefficient of variation ranges from 0.2 to 9.5 percent relative to a 
run-mean concentration. These values were based on tests conducted at a 
gray iron foundry, a lead storage battery manufacturing plant, a 
secondary lead smelter, and a

[[Page 895]]

lead recovery furnace of an alkyl lead manufacturing plant. The 
concentrations encountered during these tests ranged from 0.61 to 123.3 
mg Pb/m3.
    2.4   Interferences. Sample matrix effects may interfere with 
the analysis for Pb by flame atomic absorption. If this interference is 
suspected, the analyst may confirm the presence of these matrix effects 
and frequently eliminate the interference by using the Method of 
Standard Additions.
    High concentrations of copper may interfere with the analysis of Pb 
at 217.0 nm. This interference can be avoided by analyzing the samples 
at 283.3 nm.

3. Apparatus

    3.1  Sampling Train. A schematic of the sampling train is shown in 
Figure 12-1; it is similar to the Method 5 train. The sampling train 
consists of the following components:
    3.1.1  Probe Nozzle, Probe Liner, Pitot Tube, Differential Pressure 
Gauge, Filter Holder, Filter Heating System, Metering System, Barometer, 
and Gas Density Determination Equipment. Same as Method 5, Sections 
2.1.1 to 2.1.6 and 2.1.8 to 2.1.10, respectively.
    3.1.2  Impingers. Four impingers connected in series with leak-free 
ground glass fittings or any similar leak-free noncontaminating 
fittings. For the first, third, and fourth impingers, use the Greenburg-
Smith design, modified by replacing the tip with a 1.3 cm (\1/2\ in.) ID 
glass tube extending to about 1.3 cm (\1/2\ in.) from the bottom of the 
flask. For the second impinger, use the Greenburg-Smith design with the 
standard tip. Place a thermometer, capable of measuring temperature to 
within 1  deg.C (2  deg.F) at the outlet of the fourth impinger for 
monitoring purposes.
[GRAPHIC] [TIFF OMITTED] TC01JN92.187

    3.2  Sample Recovery. The following items are needed:
    3.2.1  Probe-Liner and Probe-Nozzle Brushes, Petri Dishes, Plastic 
Storage Containers, and Funnel and Rubber Policeman. Same as Method 5, 
Sections 2.2.1, 2.2.4, 2.2.6, and 2.2.7, respectively.
    3.2.2  Wash Bottles. Glass (2).
    3.2.3  Sample Storage Containers. Chemically resistant, borosilicate 
glass bottles, for 0.1 N nitric acid (HNO3) impinger and 
probe solutions and washes, 1000-ml. Use screw-cap liners that are 
either rubber-backed Teflon*

[[Page 896]]

or leak-free and resistant to chemical attack by 0.1 N HNO3. 
(Narrow mouth glass bottles have been found to be less prone to 
leakage.)
---------------------------------------------------------------------------

    *Mention of trade names or specific products does not 
constitute endorsement by the U.S. Environmental Protection Agency.
---------------------------------------------------------------------------

    3.2.4  Graduated Cylinder and/or Balance. To measure condensed water 
to within 2 ml or 1 g. Use a graduated cylinder that has a minimum 
capacity of 500 ml, and subdivisions no greater than 5 ml. (Most 
laboratory balances are capable of weighing to the nearest 0.5 g or 
less.)
    3.2.5  Funnel. Glass, to aid in sample recovery.
    3.3  Analysis. The following equipment is needed:
    3.3.1  Atomic Absorption Spectrophotometer. With lead hollow cathode 
lamp and burner for air/acetylene flame.
    3.3.2   Hot Plate.
    3.3.3  Erlenmeyer Flasks. 125-ml, 24/40 $.
    3.3.4  Membrane Filters. Millipore SCWPO 4700 or equivalent.
    3.3.5  Filtration Apparatus. Millipore vacuum filtration unit, or 
equivalent, for use with the above membrane filter.
    3.3.6  Volumetric Flasks. 100-ml, 250-ml, and 1000-ml.

4. Reagents

    4.1  Sampling. The reagents used in sampling are as follows:
    4.1.1  Filter. Gelman Spectro Grade, Reeve Angel 934 AH, MSA 1106 
BH, all with lot assay for Pb, or other high-purity glass fiber filters, 
without organic binder, exhibiting at least 99.95 percent efficiency 
(<0.05 percent penetration) on 0.3 micron dioctyl phthalate smoke 
particles. Conduct the filter efficiency test using ASTM Standard Method 
D2986-71 (incorporated by reference--see Sec. 60.17) or use test data 
from the supplier's quality control program.
    4.1.2  Silica Gel, Crushed Ice, and Stopcock Grease. Same as Method 
5, Sections 3.1.2, 3.1.4, and 3.1.5, respectively.
    4.1.3  Water. Deionized distilled, to conform to ASTM Specification 
D1192-77 (incorporated by reference--see Sec. 60.17), Type 3. If high 
concentrations of organic matter are not expected to be present, the 
analyst may delete the potassium permanganate test for oxidizable 
organic matter.
    4.1.4  Nitric Acid, 0.1 N. Dilute 6.5 ml of concentrated HNO3 
to 1 liter with deionized distilled water. (It may be desirable to run 
blanks before field use to eliminate a high blank on test samples.)
    4.2  Pretest Preparation. 6 N HNO3 is needed. Dilute 390 
ml of concentrated HNO3 to 1 liter with deionized distilled 
water.
    4.3  Sample Recovery. 0.1 N HNO3 (same as 4.1.4 above) is 
needed for sample recovery.
    4.4  Analysis. The following reagents are needed for analysis (use 
ACS reagent grade chemicals or equivalent, unless otherwise specified):
    4.4.1  Water. Same as 4.1.3 above.
    4.4.2  Nitric Acid. Concentrated.
    4.4.3  Nitric Acid, 50 percent (V/V). Dilute 500 ml of concentrated 
HNO3 to 1 liter with deionized distilled water.
    4.4.4  Stock Lead Standard Solution, 1000 g Pb/ml. Dissolve 
0.1598 g of lead nitrate [Pb(NO3)2] in about 60 ml 
of deionized distilled water, add 2 ml concentrated HNO3, and 
dilute to 100 ml with deionized distilled water.
    4.4.5  Working Lead Standards. Pipet 0.0, 1.0, 2.0, 3.0, 4.0, and 
5.0 ml of the stock lead standard solution (4.4.4) into 250-ml 
volumetric flasks. Add 5 ml of concentrated HNO3 to each 
flask and dilute to volume with deionized distilled water. These working 
standards contain 0.0, 4.0, 8.0, 12.0, 16.0, and 20.0 g Pb/ml, 
respectively. Prepare, as needed, additional standards at other 
concentrations in a similar manner.
    4.4.6  Air. Suitable quality for atomic absorption analysis.
    4.4.7  Acetylene. Suitable quality for atomic absorption analysis.
    4.4.8  Hydrogen Peroxide, 3 percent (V/V). Dilute 10 ml of 30 
percent H2O2 to 100 ml with deionized distilled 
water.

5. Procedure

    5.1  Sampling. The complexity of this method is such that, in order 
to obtain reliable results, testers should be trained and experienced 
with the test procedures.
    5.1.1  Pretest Preparation. Follow the same general procedure given 
in Method 5, Section 4.1.1, except the filter need not be weighed.
    5.1.2  Preliminary Determinations. Follow the same general procedure 
given in Method 5, Section 4.1.2.
    5.1.3  Preparation of Collection Train. Follow the same general 
procedure given in Method 5, Section 4.1.3, except place 100 ml of 0.1 N 
HNO3 in each of the first two impingers, leave the third 
impinger empty, and transfer approximately 200 to 300 g of preweighed 
silica gel from its container to the fourth impinger. Set up the train 
as shown in Figure 12-1.
    5.1.4  Leak-Check Procedures. Follow the general leak-check 
procedures given in Method 5, Sections 4.1.4.1. (Pretest Leak-Check), 
4.1.4.2 (Leak-Checks During the Sample Run), and 4.1.4.3 (Post-Test 
Leak-Check).
    5.1.5  Sampling Train Operation. Follow the same general procedure 
given in Method 5, Section 4.1.5. For each run, record the data required 
on a data sheet such as the one shown in EPA Method 5, Figure 5-2.
    5.1.6  Calculation of Percent Isokinetic. Same as Method 5, Section 
4.1.6.
    5.2  Sample Recovery. Begin proper cleanup procedure as soon as the 
probe is removed from the stack at the end of the sampling period.

[[Page 897]]

    Allow the probe to cool. When it can be safely handled, wipe off all 
external particulate matter near the tip of the probe nozzle and place a 
cap over it. Do not cap off the probe tip tightly while the sampling 
train is cooling down as this would create a vacuum in the filter 
holder, thus drawing liquid from the impingers into the filter.
    Before moving the sampling train to the cleanup site, remove the 
probe from the sampling train, wipe off the silicone grease, and cap the 
open outlet of the probe. Be careful not to lose any condensate that 
might be present. Wipe off the silicone grease from the glassware inlet 
where the probe was fastened and cap the inlet. Remove the umbilical 
cord from the last impinger and cap the impinger. The tester may use 
ground-glass stoppers, plastic caps, or serum caps to close these 
openings.
    Transfer the probe and filter-impinger assembly to a cleanup area, 
which is clean and protected from the wind so that the chances of 
contaminating or losing the sample are minimized.
    Inspect the train prior to and during disassembly and note any 
abnormal conditions. Treat the samples as follows:
    5.2.1  Container No. 1 (Filter), Carefully remove the filter from 
the filter holder and place it in its identified petri dish container. 
If it is necessary to fold the filter, do so such that the sample-
exposed side is inside the fold. Carefully transfer to the petri dish 
any visible sample matter and/or filter fibers that adhere to the filter 
holder gasket by using a dry Nylon bristle brush and/or a sharp-edged 
blade. Seal the container.
    5.2.2  Container No. 2 (Probe). Taking care that dust on the outside 
of the probe or other exterior surfaces does not get into the sample, 
quantitatively recover sample matter or any condensate from the probe 
nozzle, probe fitting, probe liner, and front half of the filter holder 
by washing these components with 0.1 N HNO3 and placing the 
wash into a glass sample storage container. Measure and record (to the 
nearest 2-ml) the total amount of 0.1 N HNO3 used for each 
rinse. Perform the 0.1 N HNO3 rinses as follows:
    Carefully remove the probe nozzle and rinse the inside surfaces with 
0.1 N HNO3 from a wash bottle while brushing with a stainless 
steel, Nylon-bristle brush. Brush until the 0.1 N HNO3 rinse 
shows no visible particles, then make a final rinse of the inside 
surface.
    Brush and rinse with 0.1 N HNO3 the inside parts of the 
Swagelok fitting in a similar way until no visible particles remain.
    Rinse the probe liner with 0.1 N HNO3. While rotating the 
probe so that all inside surfaces will be rinsed with 0.1 N 
HNO3, tilt the probe and squirt 0.1 N HNO3 into 
its upper end. Let the 0.1 N HNO3 drain from the lower end 
into the sample container. The tester may use a glass funnel to aid in 
transferring liquid washes to the container. Follow the rinse with a 
probe brush. Hold the probe in an inclined position, squirt 0.1 N 
HNO3 into the upper end of the probe as the probe brush is 
being pushed with a twisting action through the probe; hold the sample 
container underneath the lower end of the probe and catch any 0.1 N 
HNO3 and sample matter that is brushed from the probe. Run 
the brush through the probe three times or more until no visible sample 
matter is carried out with the 0.1 N HNO3 and none remains on 
the probe liner on visual inspection. With stainless steel or other 
metal probes, run the brush through in the above prescribed manner at 
least six times, since metal probes have small crevices in which sample 
matter can be entrapped. Rinse the brush with 0.1 N HNO3 and 
quantitatively collect these washings in the sample container. After the 
brushing make a final rinse of the probe as described above.
    It is recommended that two people clean the probe to minimize loss 
of sample. Between sampling runs, keep brushes clean and protected from 
contamination.
    After insuring that all joints are wiped clean of silicone grease, 
brush and rinse with 0.1 N HNO3 the inside of the front half 
of the filter holder. Brush and rinse each surface three times or more, 
if needed, to remove visible sample matter. Make a final rinse of the 
brush and filter holder. After all 0.1 N HNO3 washings and 
sample matter are collected in the sample container, tighten the lid on 
the sample container so that the fluid will not leak out when it is 
shipped to the laboratory. Mark the height of the fluid level to 
determine whether leakage occurs during transport. Label the container 
to clearly identify its contents.
    5.2.3  Container No. 3 (Silica Gel). Check the color of the 
indicating silica gel to determine if it has been completely spent and 
make a notation of its condition. Transfer the silica gel from the 
fourth impinger to the original container and seal. The tester may use a 
funnel to pour the silica gel and a rubber policeman to remove the 
silica gel from the impinger. It is not necessary to remove the small 
amount of particles that may adhere to the walls and are difficult to 
remove. Since the gain in weight is to be used for moisture 
calculations, do not use any water or other liquids to transfer the 
silica gel. If a balance is available in the field, the tester may 
follow procedure for Container No. 3 under Section 5.4 (Analysis).
    5.2.4  Container No. 4 (Impingers). Due to the large quantity of 
liquid involved, the tester may place the impinger solutions in several 
containers. Clean each of the first three impingers and connecting 
glassware in the following manner:
    1. Wipe the impinger ball joints free of silicone grease and cap the 
joints.

[[Page 898]]

    2. Rotate and agitate each impinger, so that the impinger contents 
might serve as a rinse solution.
    3. Transfer the contents of the impingers to a 500-ml graduated 
cylinder. Remove the outlet ball joint cap and drain the contents 
through this opening. Do not separate the impinger parts (inner and 
outer tubes) while transferring their contents to the cylinder. Measure 
the liquid volume to within plus-minus2 ml. Alternatively, 
determine the weight of the liquid to within plus-minus0.5 g. 
Record in the log the volume or weight of the liquid present, along with 
a notation of any color or film observed in the impinger catch. The 
liquid volume or weight is needed, along with the silica gel data, to 
calculate the stack gas moisture content (see Method 5, Figure 5-3).
    4. Transfer the contents to Container No. 4.
    5. Note: In steps 5 and 6 below, measure and record the total amount 
of 0.1 N HNO3 used for rinsing. Pour approximately 30 ml of 
0.1 N HNO3 into each of the first three impingers and agitate 
the impingers. Drain the 0.1 N HNO3 through the outlet arm of 
each impinger into Container No. 4. Repeat this operation a second time; 
inspect the impingers for any abnormal conditions.
    6. Wipe the ball joints of the glassware connecting the impingers 
free of silicone grease and rinse each piece of glassware twice with 0.1 
N HNO3 ; transfer this rinse into Container No. 4. (Do not 
rinse or brush the glass-fritted filter support.) Mark the height of the 
fluid level to determine whether leakage occurs during transport. Label 
the container to clearly identify its contents.
    5.2.5  Blanks. Save 200 ml of the 0.1 N HNO3 used for 
sampling and cleanup as a blank. Take the solution directly from the 
bottle being used and place into a glass sample container labeled ``0.1 
N HNO3 blank.''
    5.3  Sample Preparation.
    5.3.1  Container No. 1 (Filter). Cut the filter into strips and 
transfer the strips and all loose particulate matter into a 125-ml 
Erlenmeyer flask. Rinse the petri dish with 10 ml of 50 percent 
HNO3 to insure a quantitative transfer and add to the flask. 
(Note: If the total volume required in Section 5.3.3 is expected to 
exceed 80 ml, use a 250-ml Erlenmeyer flask in place of the 125-ml 
flask.)
    5.3.2  Containers No. 2 and No. 4 (Probe and Impingers). (Check the 
liquid level in Containers No. 2 and/or No. 4 and confirm as to whether 
or not leakage occurred during transport; note observation on the 
analysis sheet. If a noticeable amount of leakage had occurred, either 
void the sample or take steps, subject to the approval of the 
Administrator, to adjust the final results.) Combine the contents of 
Containers No. 2 and No. 4 and take to dryness on a hot plate.
    5.3.3  Sample Extraction for Lead. Based on the approximate stack 
gas particulate concentration and the total volume of stack gas sampled, 
estimate the total weight of particulate sample collected. Then transfer 
the residue from Containers No. 2 and No. 4 to the 125-ml Erlenmeyer 
flask that contains the filter using rubber policeman and 10 ml of 50 
percent HNO3 for every 100 mg of sample collected in the 
train or a minimum of 30 ml of 50 percent HNO3 whichever is 
larger.
    Place the Erlenmeyer flask on a hot plate and heat with periodic 
stirring for 30 min at a temperature just below boiling. If the sample 
volume falls below 15 ml, add more 50 percent HNO3. Add 10 ml 
of 3 percent H2O2 and continue heating for 10 min. 
Add 50 ml of hot (80  deg.C) deionized distilled water and heat for 20 
min. Remove the flask from the hot plate and allow to cool. Filter the 
sample through a Millipore membrane filter or equivalent and transfer 
the filtrate to a 250-ml volumetric flask. Dilute to volume with 
deionized distilled water.
    5.3.4  Filter Blank. Determine a filter blank using two filters from 
each lot of filters used in the sampling train. Cut each filter into 
strips and place each filter in a separate 125-ml Erlenmeyer flask. Add 
15 ml of 50 percent HNO3 and treat as described in Section 
5.3.3 using 10 ml of 3 percent H2O2 and 50 ml of 
hot, deionized distilled water. Filter and dilute to a total volume of 
100 ml using deionized distilled water.
    5.3.5  0.1 N HNO3 Blank. Take the entire 200 ml of 0.1 N 
HNO3 to dryness on a steam bath, add 15 ml of 50 percent 
HNO3, and treat as described in Section 5.3.3 using 10 ml of 
3 percent H2O2 and 50 ml of hot, deionized 
distilled water. Dilute to a total volume of 100 ml using deionized 
distilled water.
    5.4  Analysis.
    5.4.1  Lead Determination. Calibrate the spectrophotometer as 
described in Section 6.2 and determine the absorbance for each source 
sample, the filter blank, and 0.1 N HNO3 blank. Analyze each 
sample three times in this manner. Make appropriate dilutions, as 
required, to bring all sample Pb concentrations into the linear 
absorbance range of the spectrophotometer.
    If the Pb concentration of a sample is at the low end of the 
calibration curve and high accuracy is required, the sample can be taken 
to dryness on a hot plate and the residue dissolved in the appropriate 
volume of water to bring it into the optimum range of the calibration 
curve.
    5.4.2 Check for Matrix Effects on the Lead Results. Since the 
analysis for Pb by atomic absorption is sensitive to the chemical 
composition and to the physical properties (viscosity, pH) of the sample 
(matrix effects), the analyst shall check at least one sample from each 
source using the method of additions as follows:
    Add or spike an equal volume of standard solution to an aliquot of 
the sample solution, then measure the absorbance of the resulting 
solution and the absorbance of an aliquot of unspiked sample.

[[Page 899]]

    Next, calculate the Pb concentration Cs in g/ml 
of the sample solution by using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.174

Where:
Ca=Pb concentration of the standard solution, g/ml.
As=Absorbance of the sample solution.
At=Absorbance of the spiked sample solution.

Volume corrections will not be required if the solutions as analyzed 
have been made to the same final volume. Therefore, Cs and 
Ca represent Pb concentration before dilutions.
    Method of additions procedures described on pages 9-4 and 9-5 of the 
section entitled ``General Information'' of the Perkin Elmer Corporation 
Atomic Absorption Spectrophotometry Manual, Number 303-0152 (see 
Citation 1 of Bibliography) may also be used. In any event, if the 
results of the method of additions procedure used on the single source 
sample do not agree to within 5 percent of the value obtained by the 
routine atomic absorption analysis, then reanalyze all samples from the 
source using a method of additions procedure.
    5.4.3  Container No. 3 (Silica Gel). The tester may conduct this 
step in the field. Weigh the spent silica gel (or silica gel plus 
impinger) to the nearest 0.5 g; record this weight.

6. Calibration

    Maintain a laboratory log of all calibrations.
    6.1  Sampling Train Calibration. Calibrate the sampling train 
components according to the indicated sections of Method 5: Probe Nozzle 
(Section 5.1); Pitot Tube (Section 5.2); Metering System (Section 5.3); 
Probe Heater (Section 5.4); Temperature Gauges (Section 5.5); Leak-Check 
of the Metering System (Section 5.6); and Barometer (Section 5.7).
    6.2  Spectrophotometer. Measure the absorbance of the standard 
solutions using the instrument settings recommended by the 
spectrophotometer manufacturer. Repeat until good agreement 
(plus-minus3 percent) is obtained between two consecutive 
readings. Plot the absorbance (y-axis) versus concentration in 
g Pb/ml (x-axis). Draw or compute a straight line through the 
linear portion of the curve. Do not force the calibration curve through 
zero, but if the curve does not pass through the origin or at least lie 
closer to the origin than plus-minus0.003 absorbance units, 
check for incorrectly prepared standards and for curvature in the 
calibration curve.
    To determine stability of the calibration curve, run a blank and a 
standard after every five samples and recalibrate, as necessary.

7. Calculations

    7.1  Dry Gas Volume. Using the data from this test, calculate 
Vm(std), the total volume of dry gas metered corrected to 
standard conditions (20  deg.C and 760 mm Hg), by using Equation 5-1 of 
Method 5. If necessary, adjust Vw(std) for leakages as 
outlined in Section 6.3 of Method 5. See the field data sheet for the 
average dry gas meter temperature and average orifice pressure drop.
    7.2  Volume of Water Vapor and Moisture Content. Using data obtained 
in this test and Equations 5-2 and 5-3 of Method 5, calculate the volume 
of water vapor Vw(std) and the moisture content Bws 
of the stack gas.
    7.3  Total Lead in Source Sample. For each source sample correct the 
average absorbance for the contribution of the filter blank and the 0.1 
N HNO3 blank. Use the calibration curve and this corrected 
absorbance to determine the g Pb concentration in the sample 
aspirated into the spectrophotometer. Calculate the total Pb content 
C deg.Pb (in g) in the original source sample; 
correct for all the dilutions that were made to bring the Pb 
concentration of the sample into the linear range of the 
spectrophotometer.
    7.4  Lead Concentration. Calculate the stack gas Pb concentration 
CPb in mg/dscm as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.175

Where:

K=0.001 mg/g for metric units.
  =2.205 lb/g x 10-9 for English units.
    7.5  Isokinetic Variation and Acceptable Results. Same as Method 5, 
Sections 6.11 and 6.12, respectively. To calculate vs, the 
average stack gas velocity, use Equation 2-9 of Method 2 and the data 
from this field test.

8. Alternative Test Methods for Inorganic Lead

    8.1  Simultaneous Determination of Particulate and Lead Emissions. 
The tester may use Method 5 to simultaneously determine Pb provided that 
(1) he uses acetone to remove particulate from the probe and inside of 
the filter holder as specified by Method 5, (2) he uses 0.1 N HNO3 
in the impingers, (3) he uses a glass fiber filter with a low Pb 
background, and (4) he treats and analyzes the entire train contents, 
including the impingers, for Pb as described in Section 5 of this 
method.
    8.2  Filter Location. The tester may use a filter between the third 
and fourth impinger provided that he includes the filter in the analysis 
for Pb.
    8.3  In-stack Filter. The tester may use an in-stack filter provided 
that (1) he uses a glass-lined probe and at least two impingers, each 
containing 100 ml of 0.1 N HNO3, after the in-stack filter 
and (2) he recovers and analyzes the probe and impinger contents for

[[Page 900]]

Pb. Recover sample from the nozzle with acetone if a particulate 
analysis is to be made.

9. Bibliography

    1.  Perkin Elmer Corporation. Analytical Methods for Atomic 
Absorption Spectrophotometry. Norwalk, CT. September 1976.
    2.  American Society for Testing and Materials. Annual Book of ASTM 
Standards. Part 31; Water, Atmospheric Analysis. Philadelphia, PA. 1974. 
p. 40-42.
    3.  Klein, R. and C. Hach. Standard Additions--Uses and Limitations 
in Spectrophotometric Analysis. Amer. Lab. 9:21-27. 1977.
    4.  Mitchell, W.J. and M.R. Midgett. Determining Inorganic and Alkyl 
Lead Emissions from Stationary Sources. U.S. Environmental Protection 
Agency, Emission Monitoring and Support Laboratory. Research Triangle 
Park, NC. (Presented at National APCA Meeting. Houston. June 26, 1978).
    5.  Same as Method 5, Citations 2 to 5 and 7 of bibliography.

 Method 13A--Determination of Total Fluoride Emissions From Stationary 
                  Sources; SPADNS Zirconium Lake Method

1. Principle and Applicability

    1.1  Applicability.  This method applies to the determination of 
fluoride (F) emissions from sources as specified in the regulations. It 
does not measure fluorocarbons, such as freons.
    1.2  Principle.  Gaseous and particulate F are withdrawn 
isokinetically from the source and collected in water and on a filter. 
The total F is then determined by the SPADNS Zirconium Lake Colorimetric 
Method.

2. Range and Sensitivity

    The range of this method is 0 to 1.4 g F/ml. Sensitivity 
has not been determined.

3. Interferences

    Large quantities of chloride will interfere with the analysis, but 
this interference can be prevented by adding silver sulfate into the 
distillation flask (see Section 7.3.4). If chloride ion is present, it 
may be easier to use the Specific Ion Electrode Method (Method 13B). 
Grease on sample-exposed surfaces may cause low F results due to 
adsorption.

4. Precision, Accuracy, and Stability

    4.1  Precision.  The following estimates are based on a 
collaborative test done at a primary aluminum smelter. In the test, six 
laboratories each sampled the stack simultaneously using two sampling 
trains for a total of 12 samples per sampling run. Fluoride 
concentrations encountered during the test ranged from 0.1 to 1.4 mg F/
m3. The within-laboratory and between-laboratory standard 
deviations, which include sampling and analysis errors, were 0.044 mg F/
m3with 60 degrees of freedom and 0.064 mg F/m3with 
five degrees of freedom, respectively.
    4.2  Accuracy.  The collaborative test did not find any bias in the 
analytical method.
    4.3  Stability.  After the sample and colorimetric reagent are 
mixed, the color formed is stable for approximately 2 hours. A 3  deg.C 
temperature difference between the sample and standard solutions 
produces an error of approximately 0.005 mg F/liter. To avoid this 
error, the absorbances of the sample and standard solutions must be 
measured at the same temperature.

5. Apparatus

    5.1  Sampling Train.  A schematic of the sampling train is shown in 
Figure 13A-1; it is similar to the Method 5 train except the filter 
position is interchangeable. The sampling train consists of the 
following components:
    5.1.1  Probe Nozzle, Pitot Tube, Differential Pressure Gauge, Filter 
Heating System, Metering System, Barometer, and Gas Density 
Determination Equipment.  Same as Method 5, Sections 2.1.1, 2.1.3, 
2.1.4, 2.1.6, 2.1.8, 2.1.9, and 2.1.10. When moisture condensation is a 
problem, the filter heating system is used.
    5.1.2  Probe Liner.  Borosilicate glass or 316 stainless steel. When 
the filter is located immediately after the probe, the tester may use a 
probe heating system to prevent filter plugging resulting from moisture 
condensation, but the tester shall not allow the temperature in the 
probe to exceed 120plus-minus14  deg.C 
(248plus-minus25  deg.F).
    5.1.3  Filter Holder.  With positive seal against leakage from the 
outside or around the filter. If the filter is located between the probe 
and first impinger, use borosilicate glass or stainless steel with a 20-
mesh stainless steel screen filter support and a silicone rubber gasket; 
do not use a glass frit or a sintered metal filter support. If the 
filter is located between the third and fourth impingers, the tester may 
use borosilicate glass with a glass frit filter support and a silicone 
rubber gasket. The tester may also use other materials of construction 
with approval from the Administrator.
    5.1.4  Impingers.  Four impingers connected as shown in Figure 13A-1 
with ground-glass (or equivalent), vacuum-tight fittings. For the first, 
third, and fourth impingers, use the Greenburg-Smith design, modified by 
replacing the tip with a 1.3-cm-inside-diameter (\1/2\ in.) glass tube 
extending to 1.3 cm (\1/2\ in.) from the bottom of the flask. For the 
second impinger, use a Greenburg-Smith impinger with the standard tip. 
The tester may use modifications (e.g., flexible connections between the 
impingers or materials other than glass), subject to the approval of the 
Administrator. Place a thermometer, capable of measuring

[[Page 901]]

temperature to within 1  deg.C (2  deg.F), at the outlet of the fourth 
impinger for monitoring purposes.
    5.2  Sample Recovery.  The following items are needed:
    5.2.1  Probe-Liner and Probe-Nozzle Brushes, Wash Bottles, Graduated 
Cylinder and/or Balance, Plastic Storage Containers, Rubber Policeman, 
Funnel.  Same as Method 5, Sections 2.2.1 to 2.2.2 and 2.2.5 to 2.2.8, 
respectively.
    5.2.2  Sample Storage Container.  Wide-mouth, high-density-
polyethylene bottles for impinger water samples, 1-liter.
    5.3  Analysis.  The following equipment is needed:
    5.3.1  Distillation Apparatus.  Glass distillation apparatus 
assembled as shown in Figure 13A-2.
    5.3.2  Bunsen Burner.
    5.3.3  Electric Muffle Furnace.  Capable of heating to 600  deg.C.
    5.3.4  Crucibles.  Nickel, 75- to 100-ml.
    5.3.5  Beakers.  500-ml and 1500-ml.
    5.3.6  Volumetric Flasks.  50-ml.
    5.3.7  Erlenmeyer Flasks or Plastic Bottles.  500-ml.
    5.3.8  Constant Temperature Bath.  Capable of maintaining a constant 
temperature of plus-minus1.0  deg.C at room temperature 
conditions.
    5.3.9  Balance.  300-g capacity to measure to 
plus-minus0.5 g.
    5.3.10  Spectrophotometer.  Instrument that measures absorbance at 
570 nm and provides at least a 1-cm light path.
    5.3.11  Spectrophotometer Cells.  1-cm pathlength.

6. Reagents

    6.1  Sampling.  Use ACS reagent-grade chemicals or equivalent, 
unless otherwise specified. The reagents used in sampling are as 
follows:
    6.1.1  Filters.
    6.1.1.1  If the filter is located between the third and fourth 
impingers, use a Whatman \1\ No. 1 filter, or equivalent, sized to fit 
the filter holder.
---------------------------------------------------------------------------

    1 Mention of company or product names does not constitute 
endorsement by the U.S. Environmental Protection Agency.

---------------------------------------------------------------------------

[[Page 902]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.188


[[Page 903]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.189

    6.1.1.2  If the filter is located between the probe and first 
impinger, use any suitable medium (e.g., paper, organic membrane) that 
conforms to the following specifications: (1) The filter can withstand 
prolonged exposure to temperatures up to 135  deg.C (275  deg.F). (2) 
The filter has at least 95 percent collection efficiency (5 
percent penetration) for 0.3 m dioctyl phthalate smoke 
particles. Conduct the filter efficiency test before the test series, 
using ASTM Standard Method D 2986-71, or use test data from the 
supplier's quality control program. (3) The filter has a low F blank 
value (0.015 mg F/cm2of filter area). Before the 
test series, determine the average F blank value of at least three 
filters (from the lot to be used for sampling) using the applicable 
procedures described in Sections 7.3 and 7.4 of this method. In general, 
glass fiber filters have high and/or variable F blank values, and will 
not be acceptable for use.
    6.1.2  Water.  Deionized distilled, to conform to ASTM Specification 
D 1193-74, Type 3. If high concentrations of organic matter are not 
expected to be present, the analyst may delete the potassium 
permanganate test for oxidizable organic matter.
    6.1.3  Silica Gel, Crushed Ice, and Stopcock Grease.  Same as Method 
5, Sections 3.1.2, 3.1.4, and 3.1.5, respectively.
    6.2  Sample Recovery.  Water, from same container as described in 
Section 6.1.2, is needed for sample recovery.
    6.3  Sample Preparation and Analysis.  The reagents needed for 
sample preparation and analysis are as follows:
    6.3.1  Calcium Oxide (CaO).  Certified grade containing 0.005 
percent F or less.
    6.3.2  Phenolphthalein Indicator.  Dissolve 0.1 g of phenolphthalein 
in a mixture of 50 ml of 90 percent ethanol and 50 ml of deionized 
distilled water.
    6.3.3  Silver Sulfate (Ag2 SO4).
    6.3.4  Sodium Hydroxide (NaOH).  Pellets.
    6.3.5  Sulfuric Acid (H2SO4), Concentrated.
    6.3.6  Sulfuric Acid, 25 percent (V/V).  Mix 1 part of concentrated 
H2SO4 with 3 parts of deionized distilled water.
    6.3.7  Filters.  Whatman No. 541, or equivalent.
    6.3.8  Hydrochloric Acid (HCl), Concentrated.
    6.3.9  Water.  From same container as described in Section 6.1.2.
    6.3.10  Fluoride Standard Solution, 0.01 mg F/ml.  Dry in an oven at 
110  deg.C for at least 2 hours. Dissolve 0.2210 g of NaF in 1 liter of 
deionized distilled water. Dilute 100 ml of this solution to 1 liter 
with deionized distilled water.
    6.3.11  SPADNS Solution [4, 5 dihydroxy-3-(p-sulfophenylazo)-2,7-
naphthalene-disulfonic acid trisodium salt].  Dissolve 0.960 
plus-minus 0.010 g of SPADNS reagent in 500 ml deionized 
distilled water. If stored in a well-sealed bottle protected from the 
sunlight, this solution is stable for at least 1 month.
    6.3.12  Spectrophotometer Zero Reference Solution.  Prepare daily. 
Add 10 ml of SPADNS solution (6.3.11) to 100 ml deionized distilled 
water, and acidify with a solution prepared by diluting 7 ml of 
concentrated HCl to 10 ml with deionized distilled water.
    6.3.13  SPADNS Mixed Reagent.  Dissolve 0.135 plus-minus 
0.005 g of zirconyl chloride octahydrate (ZrOCl2. 
8H2O) in 25 ml of deionized distilled water. Add 350 ml of 
concentrated HCl, and dilute to 500 ml with deionized distilled water. 
Mix equal volumes of this solution and SPADNS solution to form a single 
reagent. This reagent is stable for at least 2 months.

7. Procedure

    7.1  Sampling.  Because of the complexity of this method, testers 
should be trained and experienced with the test procedures to assure 
reliable results.
    7.1.1  Pretest Preparation.  Follow the general procedure given in 
Method 5, Section 4.1.1, except the filter need not be weighed.
    7.1.2  Preliminary Determinations.  Follow the general procedure 
given in Method 5, Section 4.1.2., except the nozzle size selected must 
maintain isokinetic sampling rates below 28 liters/min (1.0 cfm).
    7.1.3  Preparation of Collection Train.  Follow the general 
procedure given in Method 5, Section 4.1.3, except for the following 
variations:
    Place 100 ml of deionized distilled water in each of the first two 
impingers, and leave the

[[Page 904]]

third impinger empty. Transfer approximately 200 to 300 g of preweighed 
silica gel from its container to the fourth impinger.
    Assemble the train as shown in Figure 13A-1 with the filter between 
the third and fourth impingers. Alternatively, if a 20-mesh stainless 
steel screen is used for the filter support, the tester may place the 
filter between the probe and first impinger. The tester may also use a 
filter heating system to prevent moisture condensation, but shall not 
allow the temperature around the filter holder to exceed 120 
plus-minus 14  deg.C (248 plus-minus 25  deg.F). 
Record the filter location on the data sheet.
    7.1.4  Leak-Check Procedures.  Follow the leak-check procedures 
given in Method 5, Sections 4.1.4.1 (Pretest Leak-Check), 4.1.4.2 (Leak-
Checks During the Sample Run), and 4.1.4.3 (Post-Test Leak-Check).
    7.1.5  Fluoride Train Operation.  Follow the general procedure given 
in Method 5, Section 4.1.5, keeping the filter and probe temperatures 
(if applicable) at 120 plus-minus 14  deg.C (248 
plus-minus 25  deg.F) and isokinetic sampling rates below 28 
liters/min (1.0 cfm). For each run, record the data required on a data 
sheet such as the one shown in Method 5, Figure 5-2.
    7.2  Sample Recovery.  Begin proper cleanup procedure as soon as the 
probe is removed from the stack at the end of the sampling period.
    Allow the probe to cool. When it can be safely handled, wipe off all 
external particulate matter near the tip of the probe nozzle and place a 
cap over it to keep from losing part of the sample. Do not cap off the 
probe tip tightly while the sampling train is cooling down, because a 
vacuum would form in the filter holder, thus drawing impinger water 
backwards.
    Before moving the sample train to the cleanup site, remove the probe 
from the sample train, wipe off the silicone grease, and cap the open 
outlet of the probe. Be careful not to lose any condensate, if present. 
Remove the filter assembly, wipe off the silicone grease from the filter 
holder inlet, and cap this inlet. Remove the umbilical cord from the 
last impinger, and cap the impinger. After wiping off the silicone 
grease, cap off the filter holder outlet and any open impinger inlets 
and outlets. The tester may use ground-glass stoppers, plastic caps, or 
serum caps to close these openings.
    Transfer the probe and filter-impinger assembly to an area that is 
clean and protected from the wind so that the chances of contaminating 
or losing the sample is minimized.
    Inspect the train before and during disassembly, and note any 
abnormal conditions. Treat the samples as follows:
    7.2.1  Container No. 1 (Probe, Filter, and Impinger Catches).  Using 
a graduated cylinder, measure to the nearest ml, and record the volume 
of the water in the first three impingers; include any condensate in the 
probe in this determination. Transfer the impinger water from the 
graduated cylinder into this polyethylene container. Add the filter to 
this container. (The filter may be handled separately using procedures 
subject to the Administrator's approval.) Taking care that dust on the 
outside of the probe or other exterior surfaces does not get into the 
sample, clean all sample-exposed surfaces (including the probe nozzle, 
probe fitting, probe liner, first three impingers, impinger connectors, 
and filter holder) with deionized distilled water. Use less than 500 ml 
for the entire wash. Add the washings to the sampler container. Perform 
the deionized distilled water rinses as follows:
    Carefully remove the probe nozzle and rinse the inside surface with 
deionized distilled water from a wash bottle. Brush with a Nylon bristle 
brush, and rinse until the rinse shows no visible particles, after which 
make a final rinse of the inside surface. Brush and rinse the inside 
parts of the Swagelok fitting with deionized distilled water in a 
similar way.
    Rinse the probe liner with deionized distilled water. While 
squirting the water into the upper end of the probe, tilt and rotate the 
probe so that all inside surfaces will be wetted with water. Let the 
water drain from the lower end into the sample container. The tester may 
use a funnel (glass or polyethylene) to aid in transferring the liquid 
washes to the container. Follow the rinse with a probe brush. Hold the 
probe in an inclined position, and squirt deionized distilled water into 
the upper end as the probe brush is being pushed with a twisting action 
through the probe. Hold the sample container underneath the lower end of 
the probe, and catch any water and particulate matter that is brushed 
from the probe. Run the brush through the probe three times or more. 
With stainless steel or other metal probes, run the brush through in the 
above prescribed manner at least six times since metal probes have small 
crevices in which particulate matter can be entrapped. Rinse the brush 
with deionized distilled water, and quantitatively collect these 
washings in the sample container. After the brushing, make a final rinse 
of the probe as described above.
    It is recommended that two people clean the probe to minimize sample 
losses. Between sampling runs, keep brushes clean and protected from 
contamination.
    Rinse the inside surface of each of the first three impingers (and 
connecting glassware) three separate times. Use a small portion of 
deionized distilled water for each rinse, and brush each sample-exposed 
surface with a Nylon bristle brush, to ensure recovery of fine 
particulate matter. Make a final rinse of each surface and of the brush.
    After ensuring that all joints have been wiped clean of the silicone 
grease, brush and

[[Page 905]]

rinse with deionized distilled water the inside of the filter holder 
(front-half only, if filter is positioned between the third and fourth 
impingers). Brush and rinse each surface three times or more if needed. 
Make a final rinse of the brush and filter holder.
    After all water washings and particulate matter have been collected 
in the sample container, tighten the lid so that water will not leak out 
when it is shipped to the laboratory. Mark the height of the fluid level 
to determine whether leakage occurs during transport. Label the 
container clearly to identify its contents.
    7.2.2  Container No. 2 (Sample Blank).  Prepare a blank by placing 
an unused filter in a polyethylene container and adding a volume of 
water equal to the total volume in Container No. 1. Process the blank in 
the same manner as for Container No. 1.
    7.2.3  Container No. 3 (Silica Gel).  Note the color of the 
indicating silica gel to determine whether it has been completely spent 
and make a notation of its condition. Transfer the silica gel from the 
fourth impinger to its original container and seal. The tester may use a 
funnel to pour the silica gel and a rubber policeman to remove the 
silica gel from the impinger. It is not necessary to remove the small 
amount of dust particles that may adhere to the impinger wall and are 
difficult to remove. Since the gain in weight is to be used for moisture 
calculations, do not use any water or other liquids to transfer the 
silica gel. If a balance is available in the field, the tester may 
follow the analytical procedure for Container No. 3 in Section 7.4.2.
    7.3  Sample Preparation and Distillation.  (Note the liquid levels 
in Containers No. 1 and No. 2 and confirm on the analysis sheet whether 
or not leakage occurred during transport. If noticeable leakage had 
occurred, either void the sample or use methods, subject to the approval 
of the Administrator, to correct the final results.) Treat the contents 
of each sample container as described below:
    7.3.1  Container No. 1 (Probe, Filter, and Impinger Catches).  
Filter this container's contents, including the sampling filter, through 
Whatman No. 541 filter paper, or equivalent, into a 1500-ml beaker.
    7.3.1.1  If the filtrate volume exceeds 900 ml, make the filtrate 
basic (red to phenolphthalein) with NaOH, and evaporate to less than 900 
ml.
    7.3.1.2  Place the filtered material (including sampling filter) in 
a nickel crucible, add a few ml of deionized distilled water, and 
macerate the filters with a glass rod.
    Add 100 mg CaO to the crucible, and mix the contents thoroughly to 
form a slurry. Add two drops of phenolphthalein indicator. Place the 
crucible in a hood under infrared lamps or on a hot plate at low heat. 
Evaporate the water completely. During the evaporation of the water, 
keep the slurry basic (red to phenolphthalein) to avoid loss of F. If 
the indicator turns colorless (acidic) during the evaporation, add CaO 
until the color turns red again.
    After evaporation of the water, place the crucible on a hot plate 
under a hood and slowly increase the temperature until the Whatman No. 
541 and sampling filters char. It may take several hours to completely 
char the filters.
    Place the crucible in a cold muffle furnace. Gradually (to prevent 
smoking) increase the temperature to 600  deg.C, and maintain until the 
contents are reduced to an ash. Remove the crucible from the furnace and 
allow to cool.
    Add approximately 4 g of crushed NaOH to the crucible and mix. 
Return the crucible to the muffle furnace, and fuse the sample for 10 
minutes at 600  deg.C.
    Remove the sample from the furnace, and cool to ambient temperature. 
Using several rinsings of warm deionized distilled water, transfer the 
contents of the crucible to the beaker containing the filtrate. To 
assure complete sample removal, rinse finally with two 20-ml portions of 
25 percent H2SO4, and carefully add to the beaker. 
Mix well, and transfer to a 1-liter volumetric flask. Dilute to volume 
with deionized distilled water, and mix thoroughly. Allow any 
undissolved solids to settle.
    7.3.2  Container No. 2 (Sample Blank).  Treat in the same manner as 
described in Section 7.3.1 above.
    7.3.3  Adjustment of Acid/Water Ratio in Distillation Flask. (Use a 
protective shield when carrying out this procedure.) Place 400 ml of 
deionized distilled water in the distillation flask, and add 200 ml of 
concentrated H2SO4. (Caution: Observe standard 
precautions when mixing H2SO4 with water. Slowly 
add the acid to the flask with constant swirling.) Add some soft glass 
beads and several small pieces of broken glass tubing, and assemble the 
apparatus as shown in Figure 13A-2. Heat the flask until it reaches a 
temperature of 175  deg.C to adjust the acid/water ratio for subsequent 
distillations. Discard the distillate.
    7.3.4  Distillation.  Cool the contents of the distillation flask to 
below 80  deg.C. Pipet an aliquot of sample containing less than 10.0 mg 
F directly into the distillation flask, and add deionized distilled 
water to make a total volume of 220 ml added to the distillation flask. 
(To estimate the appropriate aliquot size, select an aliquot of the 
solution and treat as described in Section 7.4.1. This will be an 
approximation of the F content because of possible interfering ions.)
    Note: If the sample contains chloride, add 5 mg of Ag2 
SO4 to the flask for every mg of chloride.

[[Page 906]]

    Place a 250-ml volumetric flask at the condenser exit. Heat the 
flask as rapidly as possible with a Bunsen burner, and collect all the 
distillate up to 175  deg.C. During heatup, play the burner flame up and 
down the side of the flask to prevent bumping. Conduct the distillation 
as rapidly as possible (15 minutes or less). Slow distillations have 
been found to produce low F recoveries. Caution: Be careful not to 
exceed 175  deg.C to avoid causing H2SO4 to 
distill over.
    If F distillation in the mg range is to be followed by a 
distillation in the fractional mg range, add 220 ml of deionized 
distilled water and distill it over as in the acid adjustment step to 
remove residual F from the distillation system.
    The tester may use the acid in the distillation flask until there is 
carry-over of interferences or poor F recovery. Check for these every 
tenth distillation using a deionized distilled water blank and a 
standard solution. Change the acid whenever the F recovery is less than 
90 percent or the blank value exceeds 0.1 g/ml.
    7.4  Analysis.
    7.4.1  Containers No. 1 and No. 2.  After distilling suitable 
aliquots from Containers No. 1 and No. 2 according to Section 7.3.4, 
dilute the distillate in the volumetric flasks to exactly 250 ml with 
deionized distilled water, and mix thoroughly. Pipet a suitable aliquot 
of each sample distillate (containing 10 to 40 g F/ml) into a 
beaker, and dilute to 50 ml with deionized distilled water. Use the same 
aliquot size for the blank. Add 10 ml of SPADNS mixed reagent (6.3.13), 
and mix thoroughly.
    After mixing, place the sample in a constant-temperature bath 
containing the standard solutions (see Section 8.2) for 30 minutes 
before reading the absorbance on the spectrophotometer.
    Set the spectrophotometer to zero absorbance at 570 nm with the 
reference solution (6.3.12), and check the spectrophotometer calibration 
with the standard solution. Determine the absorbance of the samples, and 
determine the concentration from the calibration curve. If the 
concentration does not fall within the range of the calibration curve, 
repeat the procedure using a different size aliquot.
    7.4.2  Container No. 3 (Silica Gel).  Weigh the spent silica gel (or 
silica gel plus impinger) to the nearest 0.5 g using a balance. The 
tester may conduct this step in the field.

8. Calibration

    Maintain a laboratory log of all calibrations.

    8.1  Sampling Train.  Calibrate the sampling train components 
according to the indicated sections in Method 5: Probe Nozzle (Section 
5.1); Pitot Tube (Section 5.2); Metering System (Section 5.3); Probe 
Heater (Section 5.4); Temperature Gauges (Section 5.5); Leak Check of 
Metering System (Section 5.6); and Barometer (Section 5.7).
    8.2  Spectrophotometer.  Prepare the blank standard by adding 10 ml 
of SPADNS mixed reagent to 50 ml of deionized distilled water. 
Accurately prepare a series of standards from the 0.01 mg F/ml standard 
fluoride solution (6.3.10) by diluting 0, 2, 4, 6, 8, 10, 12, and 14 ml 
to 100 ml with deionized distilled water. Pipet 50 ml from each solution 
and transfer each to a separate 100-ml beaker. Then add 10 ml of SPADNS 
mixed reagent to each. These standards will contain 0, 10, 20, 30, 40 
50, 60, and 70 g F (0 to 1.4 g/ml), respectively.
    After mixing, place the reference standards and reference solution 
in a constant temperature bath for 30 minutes before reading the 
absorbance with the spectrophotometer. Adjust all samples to this same 
temperature before analyzing.
    With the spectrophotometer at 570 nm, use the reference solution 
(6.3.12) to set the absorbance to zero.
    Determine the absorbance of the standards. Prepare a calibration 
curve by plotting g F/50 ml versus absorbance on linear graph 
paper. Prepare the standard curve initially and thereafter whenever the 
SPADNS mixed reagent is newly made. Also, run a calibration standard 
with each set of samples and if it differs from the calibration curve by 
plus-minus2 percent, prepare a new standard curve.

9. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after final 
calculation. Other forms of the equations may be used, provided that 
they yield equivalent results.

    9.1  Nomenclature

Ad = Aliquot of distillate taken for color development, ml.
At = Aliquot of total sample added to still, ml.
Bws = Water vapor in the gas stream, proportion by volume.
Cs = Concentration of F in stack gas, mg/m3 (mg/
          ft3), dry basis, corrected to standard conditions 
          of 760 mm Hg (29.92 in. Hg) and 293 deg.K (528 deg.R).
Ft = Total F in sample, mg.
g F = Concentration from the calibration curve, g.
Tm = Absolute average dry gas meter temperature (see Figure 
          5-2 of Method 5),  deg.K ( deg.R).
Ts = Absolute average stack gas temperature (see Figure 5-2 
          of Method 5),  deg.K ( deg.R).
Vd = Volume of distillate as diluted, ml.
Vm(std) = Volume of gas sample as measured by dry gas meter, 
          corrected to standard conditions, dscm (dscf).
Vt = Total volume of F sample, after final dilution, ml.

[[Page 907]]

Vw(std) = Volume of water vapor in the gas sample, corrected 
          to standard conditions, scm (scf).
    9.2  Average Dry Gas Meter Temperature and Average Orifice Pressure 
Drop. See data sheet (Figure 5-2 of Method 5).
    9.3  Dry Gas Volume. Calculate Vm(std) and adjust for 
leakage, if necessary, using the equation in Section 6.3 of Method 5.
    9.4  Volume of Water Vapor and Moisture Content. Calculate the 
volume of water vapor Vw(std) and moisture content Bws 
from the data obtained in this method (Figure 13A-1); use Equations 5-2 
and 5-3 of Method 5.
    9.5  Concentration.
    9.5.1  Total Fluoride in Sample.  Calculate the amount of F in the 
sample using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.176

    9.5.2  Fluoride Concentration in Stack Gas. Determine the F 
concentration in the stack gas using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.177

    9.6  Isokinetic Variation and Acceptable Results.  Use Method 5, 
Sections 6.11 and 6.12.

10. Bibliography

    1. Bellack, Ervin, Simplified Fluoride Distillation Method. Journal 
of the American Water Works Association. 50:5306. 1958.
    2. Mitchell, W. J., J. C. Suggs, and F. J. Bergman. Collaborative 
Study of EPA Method 13A and Method 13B. Publication No. EPA-600/4-77-
050. Environmental Protection Agency. Research Triangle Park, NC. 
December 1977.
    3. Mitchell, W. J. and M. R. Midgett. Adequacy of Sampling Trains 
and Analytical Procedures Used for Fluoride. Atm. Environ. 10:865-872. 
1976.

 Method 13B--Determination of Total Fluoride Emissions From Stationary 
                 Sources--Specific Ion Electrode Method

1. Principle and Applicability

    1.1  Applicability.  This method applies to the determination of 
fluoride (F) emissions from stationary sources as specified in the 
regulations. It does not measure fluorocarbons, such as freons.
    1.2  Principle.  Gaseous and particulate F are withdrawn 
isokinetically from the source and collected in water and on a filter. 
The total F is then determined by the specific ion electrode method.

2. Range and Sensitivity

    The range of this method is 0.02 to 2,000 g F/ml; however, 
measurements of less than 0.1 g F/ml require extra care. 
Sensitivity has not been determined.

3. Interferences

    Grease on sample-exposed surfaces may cause low F results because of 
adsorption.

4. Precision and Accuracy

    4.1  Precision.  The following estimates are based on a 
collaborative test done at a primary aluminum smelter. In the test, six 
laboratories each sampled the stack simultaneously using two sampling 
trains for a total of 12 samples per sampling run. Fluoride 
concentrations encountered during the test ranged from 0.1 to 1.4 mg F/
m3. The within-laboratory and between-laboratory standard 
deviations, which include sampling and analysis errors, are 0.037 mg F/
m3with 60 degrees of freedom and 0.056 mg F/m3with 
five degrees of freedom, respectively.
    4.2  Accuracy.  The collaborative test did not find any bias in the 
analytical method.

5. Apparatus

    5.1  Sampling Train and Sample Recovery.  Same as Method 13A, 
Sections 5.1 and 5.2, respectively.
    5.2  Analysis.  The following items are needed:
    5.2.1  Distillation Apparatus, Bunsen Burner, Electric Muffle 
Furnace, Crucibles, Beakers, Volumetric Flasks, Erlenmeyer Flasks or 
Plastic Bottles, Constant Temperature Bath, and Balance.  Same as Method 
13A, Sections 5.3.1 to 5.3.9, respectively, except include also 100-ml 
polyethylene beakers.
    5.2.2  Fluoride Ion Activity Sensing Electrode.
    5.2.3  Reference Electrode.  Single junction, sleeve type.
    5.2.4  Electrometer.  A pH meter with millivolt-scale capable of 
plus-minus0.1-mv resolution, or a specific ion meter made 
specifically for specific ion use.
    5.2.5  Magnetic Stirrer and TFE 2 Fluorocarbon-Coated 
Stirring Bars.
---------------------------------------------------------------------------

    2 Mention of any trade name or specific product does not 
constitute endorsement by the U.S. Environmental Protection Agency.

6. Reagents

    6.1  Sampling and Sample Recovery.  Same as Method 13A, Sections 6.1 
and 6.2, respectively.
    6.2  Analysis.  Use ACS reagent grade chemicals (or equivalent), 
unless otherwise specified. The reagents needed for analysis are as 
follows:
    6.2.1  Calcium Oxide (CaO).  Certified grade containing 0.005 
percent F or less.
    6.2.2  Phenolphthalein Indicator.  Dissolve 0.1 g of phenolphthalein 
in a mixture of 50 ml of 90 percent ethanol and 50 ml deionized 
distilled water.
    6.2.3  Sodium Hydroxide (NaOH).  Pellets.

[[Page 908]]

    6.2.4  Sulfuric Acid (H2SO4), Concentrated.
    6.2.5  Filters.  Whatman No. 541, or equivalent.
    6.2.6  Water.  From same container as 6.1.2 of Method 13A.
    6.2.7  Sodium Hydroxide, 5 M.  Dissolve 20 g of NaOH in 100 ml of 
deionized distilled water.
    6.2.8  Sulfuric Acid, 25 percent (V/V).  Mix 1 part of concentrated 
H2SO4 with 3 parts of deionized distilled water.
    6.2.9  Total Ionic Strength Adjustment Buffer (TISAB).  Place 
approximately 500 ml of deionized distilled water in a 1-liter beaker. 
Add 57 ml of glacial acetic acid, 58 g of sodium chloride, and 4 g of 
cyclohexylene dinitrilo tetraacetic acid. Stir to dissolve. Place the 
beaker in a water bath to cool it. Slowly add 5 M NaOH to the solution, 
measuring the pH continuously with a calibrated pH/reference electrode 
pair, until the pH is 5.3. Cool to room temperature. Pour into a 1-liter 
volumetric flask, and dilute to volume with deionized distilled water. 
Commercially prepared TISAB may be substituted for the above.
    6.2.10  Fluoride Standard Solution, 0.1 M.  Oven dry some sodium 
fluoride (NaF) for a minimum of 2 hours at 110  deg.C, and store in a 
desiccator. Then add 4.2 g of NaF to a 1-liter volumetric flask, and add 
enough deionized distilled water to dissolve. Dilute to volume with 
deionized distilled water.

7. Procedure

    7.1  Sampling, Sample Recovery, and Sample Preparation and 
Distillation.  Same as Method 13A, Sections 7.1, 7.2, and 7.3, 
respectively, except the notes concerning chloride and sulfate 
interferences are not applicable.
    7.2  Analysis.
    7.2.1  Containers No. 1 and No. 2.  Distill suitable aliquots from 
Containers No. 1 and No. 2. Dilute the distillate in the volumetric 
flasks to exactly 250 ml with deionized distilled water and mix 
thoroughly. Pipet a 25-ml aliquot from each of the distillate and 
separate beakers. Add an equal volume of TISAB, and mix. The sample 
should be at the same temperature as the calibration standards when 
measurements are made. If ambient laboratory temperature fluctuates more 
than plus-minus2  deg.C from the temperature at which the 
calibration standards were measured, condition samples and standards in 
a constant-temperature bath before measurement. Stir the sample with a 
magnetic stirrer during measurement to minimize electrode response time. 
If the stirrer generates enough heat to change solution temperature, 
place a piece of temperature insulating material such as cork, between 
the stirrer and the beaker. Hold dilute samples (below 10-4M 
fluoride ion content) in polyethylene beakers during measurement.
    Insert the fluoride and reference electrodes into the solution. When 
a steady millivolt reading is obtained, record it. This may take several 
minutes. Determine concentration from the calibration curve. Between 
electrode measurements, rinse the electrode with deionized distilled 
water.
    7.2.2  Container No. 3 (Silica Gel).  Same as Method 13A, Section 
7.4.2.

8. Calibration

    Maintain a laboratory log of all calibrations.
    8.1  Sampling Train.  Same as Method 13A.
    8.2  Fluoride Electrode.  Prepare fluoride standardizing solutions 
by serial dilution of the 0.1 M fluoride standard solution. Pipet 10 ml 
of 0.1 M fluoride standard solution into a 100-ml volumetric flask, and 
make up to the mark with deionized distilled water for a 
10-2M standard solution. Use 10 ml of 10-2M 
solution to make a 10-3M solution in the same manner. Repeat 
the dilution procedure and make 10-4and 
10-5solutions.
    Pipet 50 ml of each standard into a separate beaker. Add 50 ml of 
TISAB to each beaker. Place the electrode in the most dilute standard 
solution. When a steady millivolt reading is obtained, plot the value on 
the linear axis of semilog graph paper versus concentration on the log 
axis. Plot the nominal value for concentration of the standard on the 
log axis, e.g., when 50 ml of 10-2M standard is diluted with 
50 ml of TISAB, the concentration is still designated 
``10-2M.''
    Between measurements soak the fluoride sensing electrode in 
deionized distilled water for 30 seconds, and then remove and blot dry. 
Analyze the standards going from dilute to concentrated standards. A 
straight-line calibration curve will be obtained, with nominal 
concentrations of 10-4, 10-3, 10-2, and 
10-1fluoride molarity on the log axis plotted versus 
electrode potential (in mv) on the linear scale. Some electrodes may be 
slightly nonlinear between 10-5and 10-4M. If this 
occurs, use additional standards between these two concentrations.
    Calibrate the fluoride electrode daily, and check it hourly. Prepare 
fresh fluoride standardizing solutions daily (10-2M or less). 
Store fluoride standardizing solutions in polyethylene or polypropylene 
containers.
    Note: Certain specific ion meters have been designed specifically 
for fluoride electrode use and give a direct readout of fluoride ion 
concentration. These meters may be used in lieu of calibration curves 
for fluoride measurements over narrow concentration ranges. Calibrate 
the meter according to the manufacturer's instructions.)
9. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after final 
calculation.
    9.1  Nomenclature.  Same as Method 13A, Section 9.1. In addition:


[[Page 909]]


M=F concentration from calibration curve, molarity.
    9.2  Average Dry Gas Meter Temperature and Average Orifice Pressure 
Drop, Dry Gas Volume, Volume of Water Vapor and Moisture Content, 
Fluoride Concentration in Stack Gas, and Isokinetic Variation and 
Acceptable Results.  Same as Method 13A, Sections 9.2 to 9.4, 9.5.2, and 
9.6, respectively.
    9.3  Fluoride in Sample.  Calculate the amount of F in the sample 
using the following:
[GRAPHIC] [TIFF OMITTED] TC16NO91.178

Where:

K=19 mg/millimole.

10. Bibliography

    1. Same as Method 13A, Citations 1 and 2 of Bibliography.
    2. MacLeod, Kathryn E. and Howard L. Crist. Comparison of the 
SPADNS--Zirconium Lake and Specific Ion Electrode Methods of Fluoride 
Determination in Stack Emission Samples. Analytical Chemistry. 45:1272-
1273. 1973.

    Method 14--Determination of Fluoride Emissions from Potroom Roof 
                  Monitors for Primary Aluminum Plants

1.  Applicability and Principle

    1.1  Applicability. This method is applicable for the determination 
of fluoride emissions from stationary sources only when specified by the 
test procedures for determining compliance with new source performance 
standards.
    1.2  Principle. Gaseous and particulate fluoride roof monitor 
emissions are drawn into a permanent sampling manifold through several 
large nozzles. The sample is transported from the sampling manifold to 
ground level through a duct. The gas in the duct is sampled using Method 
13A or 13B--Determination of Total Fluoride Emissions from Stationary 
Sources. Effluent velocity and volumetric flow rate are determined with 
anemometers located in the roof monitor.

2.  Apparatus

    2.1  Velocity Measurement Apparatus.
    2.1.1  Anemometers. Propeller anemometers, or equivalent. Each 
anemometer shall meet the following specifications: (1) Its propeller 
shall be made of polystyrene, or similar material of uniform density. To 
insure uniformity of performance among propellers, it is desirable that 
all propellers be made from the same mold; (2) The propeller shall be 
properly balanced, to optimize performance; (3) When the anemometer is 
mounted horizontally, its threshold velocity shall not exceed 15 m/min 
(50 fpm); (4) The measurement range of the anemometer shall extend to at 
least 600 m/min (2,000 fpm); (5) The anemometer shall be able to 
withstand prolonged exposure to dusty and corrosive environments; one 
way of achieving this is to continuously purge the bearings of the 
anemometer with filtered air during operation; (6) All anemometer 
components shall be properly shielded or encased, such that the 
performance of the anemometer is uninfluenced by potroom magnetic field 
effects; (7) A known relationship shall exist between the electrical 
output signal from the anemometer generator and the propeller shaft rpm, 
at a minimum of three evenly spaced rpm settings between 60 and 1800 
rpm; for the 3 settings, use 60plus-minus15, 
900plus-minus100, and 1800plus-minus100 rpm. 
Anemometers having other types of output signals (e.g., optical) may be 
used, subject to the approval of the Administrator. If other types of 
anemometers are used, there must be a known relationship (as described 
above) between output signal and shaft rpm; also, each anemometer must 
be equipped with a suitable readout system (See Section 2.1.3).
    2.1.2  Installation of Anemometers.
    2.1.2.1  If the affected facility consists of a single, isolated 
potroom (or potroom segment), install at least one anemometer for every 
85 m of roof monitor length. If the length of the roof monitor divided 
by 85 m is not a whole number, round the fraction to the nearest whole 
number to determine the number of anemometers needed. For monitors that 
are less than 130 m in length, use at least two anemometers. Divide the 
monitor cross-section into as many equal areas as anemometers and locate 
an anemometer at the centroid of each equal area. See exception in 
Section 2.1.2.3.
    2.1.2.2  If the affected facility consists of two or more potrooms 
(or potroom segments) ducted to a common control device, install 
anemometers in each potroom (or segment) that contains a sampling 
manifold. Install at least one anemometer for every 85 m of roof monitor 
length of the potroom (or segment). If the potroom (or segment) length 
divided by 85 is not a whole number, round the fraction to the nearest 
whole number to determine the number of anemometers needed. If the 
potroom (or segment) length is less than 130 m, use at least two 
anemometers. Divide the potroom (or segment) monitor cross-section into 
as many equal areas as anemometers and locate an anemometer at the 
centroid of each equal area. See exception in Section 2.1.2.3.
    2.1.2.3  At least one anemometer shall be installed in the immediate 
vicinity (i.e., within 10 m) of the center of the manifold (See Section 
2.2.1). For its placement in relation to the width of the monitor, there 
are two alternatives. The first is to make a velocity traverse of the 
width of the roof monitor where an anemometer is to be placed

[[Page 910]]

and install the anemometer at a point of average velocity along this 
traverse. The traverse may be made with any suitable low velocity 
measuring device, and shall be made during normal process operating 
conditions.
    The second alternative, at the option of the tester, is to install 
the anemometer halfway across the width of the roof monitor. In this 
latter case, the velocity traverse need not be conducted.
    2.1.3  Recorders. Recorders, equipped with suitable auxiliary 
equipment (e.g. transducers) for converting the output signal from each 
anemometer to a continuous recording of air flow velocity, or to an 
integrated measure of volumetric flowrate. A suitable recorder is one 
that allows the output signal from the propeller anemometer to be read 
to within 1 percent when the velocity is between 100 and 120 m/min (350 
and 400 fpm). For the purpose of recording velocity, ``continuous'' 
shall mean one readout per 15-minute or shorter time interval. A 
constant amount of time shall elapse between readings. Volumetric flow 
rate may be determined by an electrical count of anemometer revolutions. 
The recorders or counters shall permit identification of the velocities 
or flowrate measured by each individual anemometer.
    2.1.4  Pitot Tube. Standard-type pitot tube, as described in Section 
2.7 of Method 2, and having a coefficient of 
0.99plus-minus0.01.
    2.1.5  Pitot Tube (Optional). Isolated, Type S pitot, as described 
in Section 2.1 of Method 2. The pitot tube shall have a known 
coefficient, determined as outlined in Section 4.1 of Method 2.
    2.1.6  Differential Pressure Gauge. Inclined manometer or 
equivalent, as described in Section 2.1.2 of Method 2.
    2.2  Roof Monitor Air Sampling System.
    2.2.1  Sampling Ductwork. A minimum of one manifold system shall be 
installed for each potroom group (as defined in Subpart S, Section 
60.191). The manifold system and connecting duct shall be permanently 
installed to draw an air sample from the roof monitor to ground level. A 
typical installation of a duct for drawing a sample from a roof monitor 
to ground level is shown in Figure 14-1. A plan of a manifold system 
that is located in a roof monitor is shown in Figure 14.2. These 
drawings represent a typical installation for a generalized roof 
monitor. The dimensions on these figures may be altered slightly to make 
the manifold system fit into a particular roof monitor, but the general 
configuration shall be followed. There shall be eight nozzles, each 
having a diameter of 0.40 to 0.50 m. Unless otherwise specified by the 
Administrator, the length of the manifold system from the first nozzle 
to the eighth shall be 35 m or eight percent of the length of the 
potroom (or potroom segment) roof monitor, whichever is greater. The 
duct leading from the roof monitor manifold shall be round with a 
diameter of 0.30 to 0.40 m. As shown in Figure 14-2, each of the sample 
legs of the manifold shall have a device, such as a blast gate or valve, 
to enable adjustment of the flow into each sample nozzle.

[[Page 911]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.190


[[Page 912]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.191

    The manifold shall be located in the immediate vicinity of one of 
the propeller anemometers (see Section 2.1.2.3) and as close as possible 
to the midsection of the potroom (or potroom segment). Avoid locating 
the manifold near the end of a potroom or in a section where the 
aluminum reduction pot arrangement is not typical of the rest of the 
potroom (or potroom segment). Center the sample nozzles in the throat of 
the roof monitor (see Figure 14-1). Construct all sample-exposed 
surfaces within the nozzles, manifold and sample duct of 316 stainless 
steel. Aluminum may be used if a new ductwork system is conditioned with 
fluoride-laden roof monitor air for a period of six weeks prior to 
initial testing. Other materials of construction may be used if it is 
demonstrated through comparative testing that there is no loss of 
fluorides in the system. All connections in the ductwork shall be leak 
free.
    Locate two sample ports in a vertical section of the duct between 
the roof monitor and exhaust fan. The sample ports shall be at least 10 
duct diameters downstream and three diameters upstream from any flow 
disturbance such as a bend or contraction. The two sample ports shall be 
situated 90 deg. apart. One of the sample ports shall be situated so 
that the duct can be traversed in the plane of the nearest upstream duct 
bend.
    2.2.2  Exhaust Fan. An industrial fan or blower shall be attached to 
the sample duct at ground level (see Figure 14-1). This exhaust fan 
shall have a capacity such that a large enough volume of air can be 
pulled through the ductwork to maintain an isokinetic sampling rate in 
all the sample nozzles for all flow rates normally encountered in the 
roof monitor.
    The exhaust fan volumetric flow rate shall be adjustable so that the 
roof monitor air can be drawn isokinetically into the sample

[[Page 913]]

nozzles. This control of flow may be achieved by a damper on the inlet 
to the exhauster or by any other workable method.
    2.3  Temperature Measurement Apparatus.
    2.3.1  Thermocouple. Install a thermocouple in the roof monitor near 
the sample duct. The thermocouple shall conform to the specifications 
outlined in Section 2.3 of Method 2.
    2.3.2  Signal Transducer. Transducer, to change the thermocouple 
voltage output to a temperature readout.
    2.3.3  Thermocouple Wire. To reach from roof monitor to signal 
transducer and recorder.
    2.3.4  Recorder. Suitable recorder to monitor the output from the 
thermocouple signal transducer.
    2.4  Fluoride Sampling Train. Use the train described in Method 13A 
or 13B.

3. Reagents

    3.1  Sampling and Analysis. Use reagents described in Method 13A or 
13B.

4. Calibration

    4.1  Initial Performance Checks. Conduct these checks within 60 days 
prior to the first performance test.
    4.1.1  Propeller Anemometers. Anemometers which meet the 
specifications outlined in Section 2.1.1 need not be calibrated, 
provided that a reference performance curve relating anemometer signal 
output to air velocity (covering the velocity range of interest) is 
available from the manufacturer. For the purpose of this method, a 
``reference'' performance curve is defined as one that has been derived 
from primary standard calibration data, with the anemometer mounted 
vertically. ``Primary standard'' data are obtainable by: (1) Direct 
calibration of one or more of the anemometers by the National Bureau of 
Standards (NBS); (2) NBS-traceable calibration; or (3) Calibration by 
direct measurement of fundamental parameters such as length and time 
(e.g., by moving the anemometers through still air at measured rates of 
speed, and recording the output signals). If a reference performance 
curve is not available from the manufacturer, such a curve shall be 
generated, using one of the three methods described as above. Conduct a 
performance-check as outlined in Sections 4.1.1.1 through 4.1.1.3, 
below. Alternatively, the tester may use any other suitable method, 
subject to the approval of the Administrator, that takes into account 
the signal output, propeller condition and threshold velocity of the 
anemometer.
    4.1.1.1  Check the signal output of the anemometer by using an 
accurate rpm generator (see Figure 14-3) or synchronous motors to spin 
the propeller shaft at each of the three rpm settings described in 
Section 2.1.1 above (specification No. 7), and measuring the output 
signal at each setting. If, at each setting, the output signal is within 
plus-minus5 percent of the manufacturer's value, the 
anemometer can be used. If the anemometer performance is unsatisfactory, 
the anemometer shall either be replaced or repaired.
    4.1.1.2  Check the propeller condition, by visually inspecting the 
propeller, making note of any significant damage or warpage; damaged or 
deformed propellers shall be replaced.
    4.1.1.3  Check the anemometer threshold velocity as follows: With 
the anemometer mounted as shown in Figure 14-4(A), fasten a known weight 
(a straight-pin will suffice) to the anemometer propeller at a fixed 
distance from the center of the propeller shaft. This will generate a 
known torque; for example, a 0.1 g weight, placed 10 cm from the center 
of the shaft, will generate a torque of 1.0 g-cm. If the known torque 
causes the propeller to rotate downward, approximately 90 deg. [see 
Figure 14-4(B)], then the known torque is greater than or equal to the 
starting torque; if the propeller fails to rotate approximately 90 deg., 
the known torque is less than the starting torque. By trying different 
combinations of weight and distance, the starting torque of a particular 
anemometer can be satisfactorily estimated. Once an estimate of the 
starting torque has been obtained, the threshold velocity of the 
anemometer (for horizontal mounting) can be estimated from a graph such 
as Figure 14-5 (obtained from the manufacturer). If the horizontal 
threshold velocity is acceptable [<15 m/min (50 fpm), when this 
technique is used], the anemometer can be used. If the threshold 
velocity of an anemometer is found to be unacceptably high, the 
anemometer shall either be replaced or repaired.

[[Page 914]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.192


[[Page 915]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.193


[[Page 916]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.194

    4.1.2  Thermocouple. Check the calibration of the thermocouple-
potentiometer system, using the procedures outlined in Section 4.3 of 
Method 2, at temperatures of 0, 100, and 150  deg.C. If the calibration 
is off by more than 5  deg.C at any of the temperatures, repair or 
replace the system; otherwise, the system can be used.
    4.1.3  Recorders and/or Counters. Check the calibration of each 
recorder and/or counter (see Section 2.1.3) at a minimum of three 
points, approximately spanning the expected range of velocities. Use the 
calibration procedures recommended by the manufacturer, or other 
suitable procedures (subject to the approval of the Administrator). If a 
recorder or counter is found to be out of calibration, by an average 
amount greater than 5 percent for the three calibration points, replace 
or repair the system; otherwise, the system can be used.
    4.1.4  Manifold Intake Nozzles. In order to balance the flow rates 
in the eight individual nozzles, proceed as follows: Adjust the exhaust 
fan to draw a volumetric flow rate (refer to Equation 14-1) such that 
the entrance velocity into each manifold nozzle approximates the average 
effluent velocity in the roof monitor. Measure the velocity of the air 
entering each nozzle by inserting a standard pitot tube into a 2.5 cm or 
less diameter hole (see Figure 14-2) located in the manifold

[[Page 917]]

between each blast gate (or valve) and nozzle. Note that a standard 
pitot tube is used, rather than a type S, to eliminate possible velocity 
measurement errors due to cross-section blockage in the small (0.13 m 
diameter) manifold leg ducts. The pitot tube tip shall be positioned at 
the center of each manifold leg duct. Take care to insure that there is 
no leakage around the pitot tube, which could affect the indicated 
velocity in the manifold leg. If the velocity of air being drawn into 
each nozzle is not the same, open or close each blast gate (or valve) 
until the velocity in each nozzle is the same. Fasten each blast gate 
(or valve) so that it will remain in this position and close the pitot 
port holes. This calibration shall be performed when the manifold system 
is installed. Alternatively, the manifold may be preassembled and the 
flow rates balanced on the ground, before being installed.
    4.2  Periodical Performance Checks. Twelve months after their 
initial installation, check the calibration of the propeller 
anemometers, thermocouple-potentiometer system, and the recorders and/or 
counters as in Section 4.1. If the above systems pass the performance 
checks, (i.e., if no repair or replacement of any component is 
necessary), continue with the performance checks on a 12-month interval 
basis. However, if any of the above systems fail the performance checks, 
repair or replace the system(s) that failed and conduct the periodical 
performance checks on a 3-month interval basis, until sufficient 
information (consult with the Administrator) is obtained to establish a 
modified performance check schedule and calculation procedure.
    Note: If any of the above systems fail the initial performance 
checks, the data for the past year need not be recalculated.
5. Procedure

    5.1  Roof Monitor Velocity Determination.
    5.1.1  Velocity Estimate(s) for Setting Isokinetic Flow. To assist 
in setting isokinetic flow in the manifold sample nozzles, the 
anticipated average velocity in the section of the roof monitor 
containing the sampling manifold shall be estimated prior to each test 
run. The tester may use any convenient means to make this estimate 
(e.g., the velocity indicated by the anemometer in the section of the 
roof monitor containing the sampling manifold may be continuously 
monitored during the 24-hour period prior to the test run).
    If there is question as to whether a single estimate of average 
velocity is adequate for an entire test run (e.g., if velocities are 
anticipated to be significantly different during different potroom 
operations), the tester may opt to divide the test run into two or more 
``sub-runs,'' and to use a different estimated average velocity for each 
sub-run (see Section 5.3.2.2.)
    5.1.2  Velocity Determination During a Test Run. During the actual 
test run, record the velocity or volumetric flowrate readings of each 
propeller anemometer in the roof monitor. Readings shall be taken for 
each anemometer every 15 minutes or at shorter equal time intervals (or 
continuously).
    5.2  Temperature Recording. Record the temperature of the roof 
monitor every 2 hours during the test run.
    5.3  Sampling.
    5.3.1  Preliminary Air Flow in Duct. During 24 hours preceding the 
test, turn on the exhaust fan and draw roof monitor air through the 
manifold duct to condition the ductwork. Adjust the fan to draw a 
volumetric flow through the duct such that the velocity of gas entering 
the manifold nozzles approximates the average velocity of the air 
exiting the roof monitor in the vicinity of the sampling manifold.
    5.3.2  Manifold Isokinetic Sample Rate Adjustment(s).
    5.3.2.1  Initial Adjustment. Prior to the test run (or first sub-
run, if applicable; see Sections 5.1.1 and 5.3.2.2), adjust the fan to 
provide the necessary volumetric flowrate in the sampling duct, so that 
air enters the manifold sample nozzles at a velocity equal to the 
appropriate estimated average velocity determined under Section 5.1.1. 
Equation 14-1 gives the correct stream velocity needed in the duct at 
the sampling location, in order for sample gas to be drawn 
isokinetically into the manifold nozzles. Next, verify that the correct 
stream velocity has been achieved, by performing a pitot tube traverse 
of the sample duct (using either a standard or type S pitot tube); use 
the procedure outlined in Method 2.
[GRAPHIC] [TIFF OMITTED] TC16NO91.179

Where:

vd=Desired velocity in duct at sampling location, m/sec.
Dn=Diameter of a roof monitor manifold nozzle, m.
Dd=Diameter of duct at sampling location, m.
vm=Average velocity of the air stream in the roof monitor, m/
          min, as determined under Section 5.1.1.
    5.3.2.2  Adjustments During Run. If the test run is divided into two 
or more ``sub-runs'' (see Section 5.1.1), additional isokinetic rate 
adjustment(s) may become necessary during the run. Any such adjustment 
shall be made just before the start of a sub-run, using the procedure 
outlined in Section 5.3.2.1 above.
    Note: Isokinetic rate adjustments are not permissible during a sub-
run.

[[Page 918]]

    5.3.3  Sample Train Operation. Sample the duct using the standard 
fluoride train and methods described in Methods 13A and 13B. Determine 
the number and location of the sampling points in accordance with Method 
1. A single train shall be used for the entire sampling run. 
Alternatively, if two or more sub-runs are performed, a separate train 
may be used for each sub-run; note, however, that if this option is 
chosen, the area of the sampling nozzle shall be the same 
(plus-minus 2 percent) for each train. If the test run is 
divided into sub-runs, a complete traverse of the duct shall be 
performed during each sub-run.
    5.3.4  Time Per Run. Each test run shall last 8 hours or more; if 
more than one run is to be performed, all runs shall be of approximately 
the same (plus-minus 10 percent) length. If question exists 
as to the representativeness of an 8-hour test, a longer period should 
be selected. Conduct each run during a period when all normal operations 
are performed underneath the sampling manifold. For most recently-
constructed plants, 24 hours are required for all potroom operations and 
events to occur in the area beneath the sampling manifold. During the 
test period, all pots in the potroom group shall be operated such that 
emissions are representative of normal operating conditions in the 
potroom group.
    5.3.5  Sample Recovery. Use the sample recovery procedure described 
in Method 13A or 13B.
    5.4  Analysis. Use the analysis procedures described in Method 13A 
or 13B.

6. Calculations

    6.1  Isokinetic Sampling Check.
    6.1.1  Calculate the mean velocity (vm) for the sampling 
run, as measured by the anemometer in the section of the roof monitor 
containing the sampling manifold. If two or more sub-runs have been 
performed, the tester may opt to calculate the mean velocity for each 
sub-run.
    6.1.2  Using Equation 14-1, calculate the expected average velocity 
(vd) in the sampling duct, corresponding to each value of 
vm obtained under Section 6.1.1.
    6.1.3  Calculate the actual average velocity (vs) in the 
sampling duct for each run or sub-run, according to Equation 2-9 of 
Method 2, and using data obtained from Method 13.
    6.1.4  Express each value vs from Section 6.1.3 as a 
percentage of the corresponding vd value from Section 6.1.2.
    6.1.4.1  If vs is less than or equal to 120 percent of 
vd, the results are acceptable (note that in cases where the 
above calculations have been performed for each sub-run, the results are 
acceptable if the average percentage for all sub-runs is less than or 
equal to 120 percent).
    6.1.4.2  If vs is more than 120 percent of vd, 
multiply the reported emission rate by the following factor.
[GRAPHIC] [TIFF OMITTED] TC16NO91.181

    6.2  Average Velocity of Roof Monitor Gases. Calculate the average 
roof monitor velocity using all the velocity or volumetric flow readings 
from Section 5.1.2.
    6.3  Roof Monitor Temperature. Calculate the mean value of the 
temperatures recorded in Section 5.2.
    6.4  Concentration of Fluorides in Roof Monitor Air.
    6.4.1  If a single sampling train was used throughout the run, 
calculate the average fluoride concentration for the roof monitor using 
Equation 13A-2 of Method 13A.
    6.4.2  If two or more sampling trains were used (i.e., one per sub-
run), calculate the average fluoride concentration for the run, as 
follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.180

Where:

Cs=Average fluoride concentration in roof monitor air, mg F/
          dscm (mg F/dscf).
Ft=Total fluoride mass collected during a particular sub-run, 
          mg F (from Equation 13A-1 of Method 13A or Equation 13B-1 of 
          Method 13B).
Vm(std)=Total volume of sample gas passing through the dry 
          gas meter during a particular sub-run, dscm (dscf) (see 
          Equation 5-1 of Method 5).
n=Total number of sub-runs.
    6.5  Average volumetric flow from the roof monitor of the potroom(s) 
(or potroom segment(s)) containing the anemometers is given in Equation 
14-3.
[GRAPHIC] [TIFF OMITTED] TC16NO91.182


[[Page 919]]


Where:

Qsd=Average volumetric flow from roof monitor at standard 
          conditions on a dry basis, m3/min.
A=Roof monitor open area, m2.
vmt=Average velocity of air in the roof monitor, m/min, 
          from Section 6.2.
Pm=Pressure in the roof monitor; equal to barometric pressure 
          for this application, mm Hg.
tm=Roof monitor temperature,  deg.C, from Section 6.3.
Md=Mole fraction of dry gas, which is given by:
Md=(1- Bws)
    Note: Bws is the proportion by volume of water vapor in 
the gas stream, from Equation 5-3, Method 5.
    6.6  Conversion Factors.
     1 ft\3\=0.02832 m\3\
     1 hr=60 min

7. Bibliography

    1. Shigehara, R. T., A Guideline for Evaluating Compliance Test 
Results (Isokinetic Sampling Rate Criterion). U.S. Environmental 
Protection Agency, Emission Measurement Branch. Research Triangle Park, 
NC. August 1977.

  Method 14A--Determination of Total Fluoride Emissions from Selected 
            Sources at Primary Aluminum Production Facilities

    Note: This method does not include all the specifications (e.g., 
equipment and supplies) and procedures (e.g., sampling) essential to its 
performance. Some material is incorporated by reference from other 
methods in this part. Therefore, to obtain reliable results, persons 
using this method should have a thorough knowledge of at least the 
following additional test methods: Method 5, Methods 13A and 13B, and 
Method 14 of this appendix.
1.0  Scope and Application
    1.1  Analytes.

------------------------------------------------------------------------
             Analyte                    CAS No.           Sensitivity
------------------------------------------------------------------------
Total fluorides.................  None assigned.....  Not determined.
Includes hydrogen fluoride......  007664-39-3.......  Not determined.
------------------------------------------------------------------------

    1.2  Applicability. This method is applicable for the determination 
of total fluorides (TF) emissions from sources specified in the 
applicable regulation. This method was developed by consensus with the 
Aluminum Association and the U.S. Environmental Protection Agency (EPA).
2.0 Summary of Method
    2.1  Total fluorides, in the form of solid and gaseous fluorides, 
are withdrawn from the ascending air stream inside of an aluminum 
reduction potroom and, prior to exiting the potroom roof monitor, into a 
specific cassette arrangement. The cassettes are connected by tubing to 
flowmeters and a manifold system that allows for the equal distribution 
of volume pulled through each cassette, and finally to a dry gas meter. 
The cassettes have a specific internal arrangement of one unaltered 
cellulose filter and support pad in the first section of the cassette 
for solid fluoride retention and two cellulose filters with support pads 
that are impregnated with sodium formate for the chemical absorption of 
gaseous fluorides in the following two sections of the cassette. A 
minimum of eight cassettes shall be used for a potline and shall be 
strategically located at equal intervals across the potroom roof so as 
to encompass a minimum of 8 percent of the total length of the potroom. 
A greater number of cassettes may be used should the regulated facility 
choose to do so. The mass flow rate of pollutants is determined with 
anemometers and temperature sensing devices located immediately below 
the opening of the roof monitor and spaced evenly within the cassette 
group.
3.0 Definitions
    3.1  Cassette. A segmented, styrene acrylonitrile cassette 
configuration with three separate segments and a base, for the purpose 
of this method, to capture and retain fluoride from potroom gases.
    3.2  Cassette arrangement. The cassettes, tubing, manifold system, 
flowmeters, dry gas meter, and any other related equipment associated 
with the actual extraction of the sample gas stream.
    3.3  Cassette group. That section of the potroom roof monitor where 
a distinct group of cassettes is located.
    3.4  Potline. A single, discrete group of electrolytic reduction 
cells electrically connected in series, in which alumina is reduced to 
form aluminum.
    3.5  Potroom. A building unit that houses a group of electrolytic 
reduction cells in which aluminum is produced.
    3.6  Potroom group. An uncontrolled potroom, a potroom that is 
controlled individually, or a group of potrooms or potroom segments 
ducted to a common primary control system.
    3.7  Primary control system. The equipment used to capture the gases 
and particulate matter generated during the reduction process and the 
emission control device(s) used to remove pollutants prior to discharge 
of the cleaned gas to the atmosphere.
    3.8  Roof monitor. That portion of the roof of a potroom building 
where gases, not captured at the cell, exit from the potroom.
    3.9  Total fluorides (TF). Elemental fluorine and all fluoride 
compounds as measured by Methods 13A or 13B of this appendix or by an 
approved alternative method.
4.0 Interferences and Known Limitations
    4.1  There are two principal categories of limitations that must be 
addressed when

[[Page 920]]

using this method. The first category is sampling bias and the second is 
analytical bias. Biases in sampling can occur when there is an 
insufficient number of cassettes located along the roof monitor of a 
potroom or if the distribution of those cassettes is spatially unequal. 
Known sampling biases also can occur when there are leaks within the 
cassette arrangement and if anemometers and temperature devices are not 
providing accurate data. Applicable instruments must be properly 
calibrated to avoid sampling bias. Analytical biases can occur when 
instrumentation is not calibrated or fails calibration and the 
instrument is used out of proper calibration. Additionally, biases can 
occur in the laboratory if fusion crucibles retain residual fluorides 
over lengthy periods of use. This condition could result in falsely 
elevated fluoride values. Maintaining a clean work environment in the 
laboratory is crucial to producing accurate values.
    4.2  Biases during sampling can be avoided by properly spacing the 
appropriate number of cassettes along the roof monitor, conducting leak 
checks of the cassette arrangement, calibrating the dry gas meter every 
30 days, verifying the accuracy of individual flowmeters (so that there 
is no more than 5 percent difference in the volume pulled between any 
two flowmeters), and calibrating or replacing anemometers and 
temperature sensing devices as necessary to maintain true data 
generation.
    4.3  Analytical biases can be avoided by calibrating instruments 
according to the manufacturer's specifications prior to conducting any 
analyses, by performing internal and external audits of up to 10 percent 
of all samples analyzed, and by rotating individual crucibles as the 
``blank'' crucible to detect any potential residual fluoride carry-over 
to samples. Should any contamination be discovered in the blank 
crucible, the crucible shall be thoroughly cleaned to remove any 
detected residual fluorides and a ``blank'' analysis conducted again to 
evaluate the effectiveness of the cleaning. The crucible shall remain in 
service as long as no detectable residual fluorides are present.
5.0 Safety
    5.1  This method may involve the handling of hazardous materials in 
the analytical phase. This method does not purport to address all of the 
potential safety hazards associated with its use. It is the 
responsibility of the user to establish appropriate safety and health 
practices and determine the applicability of regulatory limitations 
prior to performing this test method.
    5.2  Corrosive reagents. The following reagents are hazardous. 
Personal protective equipment and safe procedures are useful in 
preventing chemical splashes. If contact occurs, immediately flush with 
copious amounts of water for at least 15 minutes. Remove clothing under 
shower and decontaminate. Treat residual chemical burn as thermal burn.
    5.3  Sodium Hydroxide (NaOH). Causes severe damage to eyes and skin. 
Inhalation causes irritation to nose, throat, and lungs. Reacts 
exothermically with limited amounts of water.
    5.4  Perchloric Acid (HClO4). Corrosive to eyes, skin, 
nose, and throat. Provide ventilation to limit exposure. Very strong 
oxidizer. Keep separate from water and oxidizable materials to prevent 
vigorous evolution of heat, spontaneous combustion, or explosion. Heat 
solutions containing HClO4 only in hoods specifically designed for 
HClO4.
6.0 Equipment and Supplies
    6.1 Sampling.
    6.1.1  Cassette arrangement. The cassette itself is a three-piece, 
styrene acrylonitrile cassette unit (a Gelman Sciences product), 37 
millimeter (mm), with plastic connectors. In the first section (the 
intake section), an untreated Gelman Sciences 37 mm, 0.8 micrometer 
(m) DM-800 metricel membrane filter and cellulose support pad, 
or equivalent, is situated. In the second and third segments of the 
cassette there is placed one each of Gelman Sciences 37 mm, 5 m 
GLA-5000 low-ash PVC filter with a cellulose support pad or equivalent 
product. Each of these two filters and support pads shall have been 
immersed in a solution of 10 percent sodium formate (volume/volume in an 
ethyl alcohol solution). The impregnated pads shall be placed in the 
cassette segments while still wet and heated at 50  deg.C (122  deg.F) 
until the pad is completely dry. It is important to check for a proper 
fit of the filter and support pad to the cassette segment to ensure that 
there are no areas where gases could bypass the filter. Once all of the 
cassette segments have been prepared, the cassette shall be assembled 
and a plastic plug shall be inserted into the exhaust hole of the 
cassette. Prior to placing the cassette into service, the space between 
each segment shall be taped with an appropriately durable tape to 
prevent the infiltration of gases through the points of connection, and 
an aluminum nozzle shall be inserted into the intake hole of the 
cassette. The aluminum nozzle shall have a short section of tubing 
placed over the opening of the nozzle, with the tubing plugged to 
prevent dust from entering the nozzle and to prepare the nozzle for the 
cassette arrangement leak check. An alternate nozzle type can be used if 
historical results or scientific demonstration of applicability can be 
shown.
    6.1.2  Anemometers and temperature sensing devices. To calculate the 
mass flow rate of TF from the roof monitor under standard conditions, 
anemometers that meet the specifications in section 2.1.1 in Method 14 
of this appendix or an equivalent device yielding

[[Page 921]]

equivalent information shall be used. A recording mechanism capable of 
accurately recording the exit gas temperature at least every 2 hours 
shall be used.
    6.1.3  Barometer. To correct the volumetric flow from the potline 
roof monitor to standard conditions, a mercury (Hg), aneroid, or other 
barometer capable of measuring atmospheric pressure to within 2.5 mm 
[0.1 inch (in)] Hg shall be used.

    Note: The barometric reading may be obtained from a nearby National 
Weather Service Station. In this case, the station value (which is 
absolute barometric pressure) shall be requested and an adjustment for 
elevation differences between the weather station and the sampling point 
shall be made at a rate of minus 2.5 mm (0.1 in) Hg per 30 meters (m) 
[100 feet (ft)] elevation increase or plus 2.5 mm (0.1 in) Hg per 30 m 
(100 ft) elevation decrease.
    6.2  Sample recovery.
    6.2.1  Hot plate.
    6.2.2  Muffle furnace.
    6.2.3  Nickel crucible.
    6.2.4  Stirring rod. Teflon'.
    6.2.5  Volumetric flask. 50-milliliter (ml).
    6.2.6  Plastic vial. 50-ml.
    6.3  Analysis.
    6.3.1  Primary analytical method. An automated analyzer having the 
following components or equivalent: a multichannel proportioning pump, 
multiposition sampler, voltage stabilizer, colorimeter, instrument 
recording device, microdistillation apparatus, flexible Teflon 
heating bath, vacuum pump, pulse suppressers and an air flow system.
    6.3.2  Secondary analytical method. Specific Ion Electrode (SIE).
7.0 Reagents and Standards
    7.1  Water. Deionized distilled to conform to ASTM Specification D 
1193-77, Type 3 (incorporated by reference in Sec. 60.17(a)(22) of this 
part). The KMnO4 test for oxidizable organic matter may be 
omitted when high concentrations of organic matter are not expected to 
be present.
    7.2  Calcium oxide.
    7.3  Sodium hydroxide (NaOH). Pellets.
    7.4  Perchloric acid (HClO4). Mix 1:1 with water. 
Sulfuric acid (H2SO4) may be used in place of 
HClO4.
    7.5  Audit samples. The audit samples discussed in section 9.1 shall 
be prepared from reagent grade, water soluble stock reagents, or 
purchased as an aqueous solution from a commercial supplier. If the 
audit stock solution is purchased from a commercial supplier, the 
standard solution must be accompanied by a certificate of analysis or an 
equivalent proof of fluoride concentration.
8.0 Sample Collection and Analysis
    8.1  Preparing cassette arrangement for sampling. The cassettes are 
initially connected to flexible tubing. The tubing is connected to 
flowmeters and a manifold system. The manifold system is connected to a 
dry gas meter (Research Appliance Company model 201009 or equivalent). 
The length of tubing is managed by pneumatically or electrically 
operated hoists located in the roof monitor, and the travel of the 
tubing is controlled by encasing the tubing in aluminum conduit. The 
tubing is lowered for cassette insertion by operating a control box at 
floor level. Once the cassette has been securely inserted into the 
tubing and the leak check performed, the tubing and cassette are raised 
to the roof monitor level using the floor level control box. 
Arrangements similar to the one described are acceptable if the 
scientific sample collection principles are followed.
    8.2  Test run sampling period. A test run shall comprise a minimum 
of a 24-hour sampling event encompassing at least eight cassettes per 
potline (or four cassettes per potroom group). Monthly compliance shall 
be based on three test runs during the month. Test runs of greater than 
24 hours are allowed; however, three such runs shall be conducted during 
the month.
    8.3  Leak-check procedures.
    8.3.1  Pretest leak check. A pretest leak-check is recommended; 
however, it is not required. To perform a pretest leak-check after the 
cassettes have been inserted into the tubing, isolate the cassette to be 
leak-checked by turning the valves on the manifold to stop all flows to 
the other sampling points connected to the manifold and meter. The 
cassette, with the plugged tubing section securing the intake of the 
nozzle, is subjected to the highest vacuum expected during the run. If 
no leaks are detected, the tubing plug can be briefly removed as the dry 
gas meter is rapidly turned off.
    8.3.2  Post-test leak check. A leak check is required at the 
conclusion of each test run for each cassette. The leak check shall be 
performed in accordance with the procedure outlined in section 8.3.1 of 
this method except that it shall be performed at a vacuum greater than 
the maximum vacuum reached during the test run. If the leakage rate is 
found to be no greater than 4 percent of the average sampling rate, the 
results are acceptable. If the leakage rate is greater than 4 percent of 
the average sampling rate, either record the leakage rate and correct 
the sampling volume as discussed in section 12.4 of this method or void 
the test run if the minimum number of cassettes were used. If the number 
of cassettes used was greater than the minimum required, discard the 
leaking cassette and use the remaining cassettes for the emission 
determination.
    8.3.3  Anemometers and temperature sensing device placement. Install 
the recording mechanism to record the exit gas temperature. Anemometers 
shall be installed as required in section 6.1.2 of Method 14 of this 
appendix, except replace the word ``manifold'' with ``cassette group'' 
in section 6.1.2.3.

[[Page 922]]

These two different instruments shall be located near each other along 
the roof monitor. See conceptual configurations in Figures 14A-1, 14A-2, 
and 14A-3 of this method. Fewer temperature devices than anemometers may 
be used if at least one temperature device is located within the span of 
the cassette group. Other anemometer location siting scenarios may be 
acceptable as long as the exit velocity of the roof monitor gases is 
representative of the entire section of the potline being sampled.
    8.4  Sampling. The actual sample run shall begin with the removal of 
the tubing and plug from the cassette nozzle. Each cassette is then 
raised to the roof monitor area, the dry gas meter is turned on, and the 
flowmeters are set to the calibration point, which allows an equal 
volume of sampled gas to enter each cassette. The dry gas meter shall be 
set to a range suitable for the specific potroom type being sampled that 
will yield valid data known from previous experience or a range 
determined by the use of the calculation in section 12 of this method. 
Parameters related to the test run that shall be recorded, either during 
the test run or after the test run if recording devices are used, 
include: anemometer data, roof monitor exit gas temperature, dry gas 
meter temperature, dry gas meter volume, and barometric pressure. At the 
conclusion of the test run, the cassettes shall be lowered, the dry gas 
meter turned off, and the volume registered on the dry gas meter 
recorded. The post-test leak check procedures described in section 8.3.2 
of this method shall be performed. All data relevant to the test shall 
be recorded on a field data sheet and maintained on file.
    8.5  Sample recovery.
    8.5.1  The cassettes shall be brought to the laboratory with the 
intake nozzle contents protected with the section of plugged tubing 
previously described. The exterior of cassettes shall carefully be wiped 
free of any dust or debris, making sure that any falling dust or debris 
does not present a potential laboratory contamination problem.
    8.5.2  Carefully remove all tape from the cassettes and remove the 
initial filter, support pad, and all loose solids from the first 
(intake) section of the cassette. Fold the filter and support pad 
several times and, along with all loose solids removed from the interior 
of the first section of the cassette, place them into a nickel crucible. 
Using water, wash the interior of the nozzle into the same nickel 
crucible. Add 0.1 gram (g) [0.1 milligram (mg)] of calcium 
oxide and a sufficient amount of water to make a loose slurry. Mix the 
contents of the crucible thoroughly with a Teflon'' stirring rod. After 
rinsing any adhering residue from the stirring rod back into the 
crucible, place the crucible on a hot plate or in a muffle furnace until 
all liquid is evaporated and allow the mixture to gradually char for 1 
hour.
    8.5.3  Transfer the crucible to a cold muffle furnace and ash at 600 
 deg.C (1,112  deg.F). Remove the crucible after the ashing phase and, 
after the crucible cools, add 3.0 g (0.1 g) of NaOH pellets. 
Place this mixture in a muffle furnace at 600  deg.C (1,112  deg.F) for 
3 minutes. Remove the crucible and roll the melt so as to reach all of 
the ash with the molten NaOH. Let the melt cool to room temperature. Add 
10 to 15 ml of water to the crucible and place it on a hot plate at a 
low temperature setting until the melt is soft or suspended. Transfer 
the contents of the crucible to a 50-ml volumetric flask. Rinse the 
crucible with 20 ml of 1:1 perchloric acid or 20 ml of 1:1 sulfuric acid 
in two (2) 10 ml portions. Pour the acid rinse slowly into the 
volumetric flask and swirl the flask after each addition. Cool to room 
temperature. The product of this procedure is particulate fluorides.
      8.5.4 Gaseous fluorides can be isolated for analysis by folding 
the gaseous fluoride filters and support pads to approximately \1/4\ of 
their original size and placing them in a 50-ml plastic vial. To the 
vial add exactly 10 ml of water and leach the sample for a minimum of 1 
hour. The leachate from this process yields the gaseous fluorides for 
analysis.
9.0 Quality Control
    9.1  Laboratory auditing. Laboratory audits of specific and known 
concentrations of fluoride shall be submitted to the laboratory with 
each group of samples submitted for analysis. An auditor shall prepare 
and present the audit samples as a ``blind'' evaluation of laboratory 
performance with each group of samples submitted to the laboratory. The 
audits shall be prepared to represent concentrations of fluoride that 
could be expected to be in the low, medium and high range of actual 
results. Average recoveries of all three audits must equal 90 to 110 
percent for acceptable results; otherwise, the laboratory must 
investigate procedures and instruments for potential problems.

    Note: The analytical procedure allows for the analysis of individual 
or combined filters and pads from the cassettes provided that equal 
volumes (10 percent) are sampled through each cassette.
10.0 Calibrations
    10.1  Equipment evaluations. To ensure the integrity of this method, 
periodic calibrations and equipment replacements are necessary.
    10.1.1  Metering system. At 30-day intervals the metering system 
shall be calibrated. Connect the metering system inlet to the outlet of 
a wet test meter that is accurate to 1 percent. Refer to Figure 5-4 of 
Method 5 of this appendix. The wet-test meter shall have a capacity of 
30 liters/revolution [1 cubic foot (ft\3\)/revolution]. A spirometer of 
400 liters (14 ft\3\) or more capacity, or equivalent, may be used for 
calibration; however, a wet-test meter is usually more practical. The 
wet-test meter shall be periodically tested with a

[[Page 923]]

spirometer or a liquid displacement meter to ensure the accuracy. 
Spirometers or wet-test meters of other sizes may be used, provided that 
the specified accuracies of the procedure are maintained. Run the 
metering system pump for about 15 min. with the orifice manometer 
indicating a median reading as expected in field use to allow the pump 
to warm up and to thoroughly wet the interior of the wet-test meter. 
Then, at each of a minimum of three orifice manometer settings, pass an 
exact quantity of gas through the wet-test meter and record the volume 
indicated by the dry gas meter. Also record the barometric pressure, the 
temperatures of the wet test meter, the inlet temperatures of the dry 
gas meter, and the temperatures of the outlet of the dry gas meter. 
Record all calibration data on a form similar to the one shown in Figure 
5-5 of Method 5 of this appendix and calculate Y, the dry gas meter 
calibration factor, and H@, the orifice calibration factor at 
each orifice setting. Allowable tolerances for Y and H@ are 
given in Figure 5-6 of Method 5 of this appendix.
    10.1.2  Estimating volumes for initial test runs. For a facility's 
initial test runs, the regulated facility must have a target or desired 
volume of gases to be sampled and a target range of volumes to use 
during the calibration of the dry gas meter. Use Equations 14A-1 and 
14A-2 in section 12 of this method to derive the target dry gas meter 
volume (Fv) for these purposes.
    10.1.3  Calibration of anemometers and temperature sensing devices. 
If the standard anemometers in Method 14 of this appendix are used, the 
calibration and integrity evaluations in sections 10.3.1.1 through 
10.3.1.3 of Method 14 of this appendix shall be used as well as the 
recording device described in section 2.1.3 of Method 14. The 
calibrations or complete change-outs of anemometers shall take place at 
a minimum of once per year. The temperature sensing and recording 
devices shall be calibrated according to the manufacturer's 
specifications.
    10.1.4  Calibration of flowmeters. The calibration of flowmeters is 
necessary to ensure that an equal volume of sampled gas is entering each 
of the individual cassettes and that no large differences, which could 
possibly bias the sample, exist between the cassettes.
    10.1.4.1  Variable area, 65 mm flowmeters or equivalent shall be 
used. These flowmeters can be mounted on a common base for convenience. 
These flowmeters shall be calibrated by attaching a prepared cassette, 
complete with filters and pads, to the flowmeter and then to the system 
manifold. This manifold is an aluminum cylinder with valved inlets for 
connections to the flowmeters/cassettes and one outlet to a dry gas 
meter. The connection is then made to the wet-test meter and finally to 
a dry gas meter. All connections are made with tubing.
    10.1.4.2  Turn the dry gas meter on for 15 min. in preparation for 
the calibration. Turn the dry gas meter off and plug the intake hole of 
the cassette. Turn the dry gas meter back on to evaluate the entire 
system for leaks. If the dry gas meter shows a leakage rate of less than 
0.02 ft3/min at 10 in. of Hg vacuum as noted on the dry gas 
meter, the system is acceptable to further calibration.
    10.1.4.3  With the dry gas meter turned on and the flow indicator 
ball at a selected flow rate, record the exact amount of gas pulled 
through the flowmeter by taking measurements from the wet test meter 
after exactly 10 min. Record the room temperature and barometric 
pressure. Conduct this test for all flowmeters in the system with all 
flowmeters set at the same indicator ball reading. When all flowmeters 
have gone through the procedure above, correct the volume pulled through 
each flowmeter to standard conditions. The acceptable difference between 
the highest and lowest flowmeter rate is 5 percent. Should one or more 
flowmeters be outside of the acceptable limit of 5 percent, repeat the 
calibration procedure at a lower or higher indicator ball reading until 
all flowmeters show no more than 5 percent difference among them.
    10.1.4.4  This flowmeter calibration shall be conducted at least 
once per year.
    10.1.5  Miscellaneous equipment calibrations. Miscellaneous 
equipment used such as an automatic recorder/ printer used to measure 
dry gas meter temperatures shall be calibrated according to the 
manufacturer's specifications in order to maintain the accuracy of the 
equipment.
11.0   Analytical Procedure
    11.1  The preferred primary analytical determination of the 
individual isolated samples or the combined particulate and gaseous 
samples shall be performed by an automated methodology. The analytical 
method for this technology shall be based on the manufacturer's 
instructions for equipment operation and shall also include the analysis 
of five standards with concentrations in the expected range of the 
actual samples. The results of the analysis of the five standards shall 
have a coefficient of correlation of at least 0.99. A check standard 
shall be analyzed as the last sample of the group to determine if 
instrument drift has occurred. The acceptable result for the check 
standard is 95 to 105 percent of the standard's true value.
    11.2  The secondary analytical method shall be by specific ion 
electrode if the samples are distilled or if a TISAB IV buffer is used 
to eliminate aluminum interferences. Five standards with concentrations 
in the expected range of the actual samples shall be analyzed, and a 
coefficient of correlation of at least 0.99 is the minimum acceptable 
limit for linearity. An exception for this limit for

[[Page 924]]

linearity is a condition when low-level standards in the range of 0.01 
to 0.48 g fluoride/ml are analyzed. In this situation, a 
minimum coefficient of correlation of 0.97 is required. TISAB II shall 
be used for low-level analyses.
12.0 Data Analysis and Calculations
    12.1  Carry out calculations, retaining at least one extra decimal 
point beyond that of the acquired data. Round off values after the final 
calculation. Other forms of calculations may be used as long as they 
give equivalent results.
    12.2  Estimating volumes for initial test runs.
    [GRAPHIC] [TIFF OMITTED] TR07OC97.000
    
Where

Fv = Desired volume of dry gas to be sampled, ft\3\.
Fd = Desired or analytically optimum mass of TF per cassette, 
          micrograms of TF per cassette (g/cassette).
X = Number of cassettes used.
Fe = Typical concentration of TF in emissions to be sampled, 
          g/ft \3\, calculated from Equation 14A-2.
          [GRAPHIC] [TIFF OMITTED] TR07OC97.001
          
Where

Re = Typical emission rate from the facility, pounds of TF 
          per ton (lb/ton) of aluminum.
Rp = Typical production rate of the facility, tons of 
          aluminum per minute (ton/min).
Vr = Typical exit velocity of the roof monitor gases, feet 
          per minute (ft/min).
Ar=Open area of the roof monitor, square feet 
          (ft2).

    12.2.1  Example calculation. Assume that the typical emission rate 
(Re) is 1.0 lb TF/ton of aluminum, the typical roof vent gas 
exit velocity (Vr) is 250 ft/min, the typical production rate 
(Rp) is 0.10 ton/min, the known open area for the roof 
monitor (Ar) is 8,700 ft2, and the desired 
(analytically optimum) mass of TF per cassette is 1,500 g. 
First calculate the concentration of TF per cassette (Fe) in 
g/ft3 using Equation 14A-2. Then calculate the 
desired volume of gas to be sampled (Fv) using Equation 14A-
1.
[GRAPHIC] [TIFF OMITTED] TR07OC97.002

[GRAPHIC] [TIFF OMITTED] TR07OC97.003

    This is a total of 575.40 ft3 for eight cassettes or 
71.925 ft3/cassette.
    12.3  Calculations of TF emissions from field and laboratory data 
that would yield a production related emission rate can be calculated as 
follows:
    12.3.1  Obtain a standard cubic feet (scf) value for the volume 
pulled through the dry gas meter for all cassettes by using the field 
and calibration data and Equation 5-1 of Method 5 of this appendix.
    12.3.2  Derive the average quantity of TF per cassette (in 
g TF/cassette) by adding all

[[Page 925]]

laboratory data for all cassettes and dividing this value by the total 
number of cassettes used. Divide this average TF value by the corrected 
dry gas meter volume for each cassette; this value then becomes 
TFstd (g/ft3).
    12.3.3  Calculate the production-based emission rate (Re) 
in lb/ton using Equation 14A-5.
[GRAPHIC] [TIFF OMITTED] TR07OC97.004

    12.3.4  As an example calculation, assume eight cassettes located in 
a potline were used to sample for 72 hours during the run. The analysis 
of all eight cassettes yielded a total of 3,000 g of TF. The 
dry gas meter volume was corrected to yield a total of 75 scf per 
cassette, which yields a value for TFstd of 3,000/75=5 
g/ft3. The open area of the roof monitor for the 
potline (Ar) is 17,400 ft2. The exit velocity of 
the roof monitor gases (Vr) is 250 ft/min. The production 
rate of aluminum over the previous 720 hours was 5,000 tons, which is 
6.94 tons/hr or 0.116 ton/min (Rp). Substituting these values 
into Equation 14A-5 yields:
[GRAPHIC] [TIFF OMITTED] TR07OC97.005

    12.4  Corrections to volumes due to leakage. Should the post-test 
leak check leakage rate exceed 4 percent as described in section 8.3.2 
of this method, correct the volume as detailed in Case I in section 6.3 
of Method 5 of this appendix.

[[Page 926]]

[GRAPHIC] [TIFF OMITTED] TR07OC97.020


[[Page 927]]


[GRAPHIC] [TIFF OMITTED] TR07OC97.021


[[Page 928]]


[GRAPHIC] [TIFF OMITTED] TR07OC97.022


[[Page 929]]



  Method 15--Determination of Hydrogen Sulfide, Carbonyl Sulfide, and 
           Carbon Disulfide Emissions from Stationary Sources

Introduction

    The method described below uses the principle of gas chromatographic 
separation and flame photometric detection (FPD). Since there are many 
systems or sets of operating conditions that represent useable methods 
of determining sulfur emissions, all systems which employ this 
principle, but differ only in details of equipment and operation, may be 
used as alternative methods, provided that the calibration precision and 
sample-line loss criteria are met.

1. Principle and Applicability

    1.1 Principle. A gas sample is extracted from the emission source 
and diluted with clean dry air. An aliquot of the diluted sample is then 
analyzed for hydrogen sulfide (H2S), carbonyl sulfide (COS), 
and carbon disulfide (CS2) by gas chromatographic (GC) 
separation and flame photometric detection (FPD).
    1.2 Applicability. This method is applicable for determination of 
the above sulfur compounds from tail gas control units of sulfur 
recovery plants.

2. Range and Sensitivity

    2.1 Range. Coupled with a gas chromtographic system utilizing a 1-
milliliter sample size, the maximum limit of the FPD for each sulfur 
compound is approximately 10 ppm. It may be necessary to dilute gas 
samples from sulfur recovery plants hundredfold (99:1) resulting in an 
upper limit of about 1000 ppm for each compound.
    2.2 Sensitivity. The minimum detectable concentration of the FPD is 
also dependent on sample size and would be about 0.5 ppm for a 1 ml 
sample.

3. Interferences

    3.1  Moisture Condensation. Moisture condensation in the sample 
delivery system, the analytical column, or the FPD burner block can 
cause losses or interferences. This potential is eliminated by heating 
the probe, filter box, and conncections, and by maintaining the 
SO2 scrubber in an ice water bath. Moisture is removed in the 
SO2 scrubber and heating the sample beyond this point is not 
necessary provided the ambient temperature is above 0  deg.C. 
Alternatively, moisture may be eliminated by heating the sample line, 
and by conditioning the sample with dry dilution air to lower its dew 
point below the operating temperature of the GC/FPD analytical system 
prior to analysis.
    3.2 Carbon Monoxide and Carbon Dioxide. CO and CO2 have 
substantial desensitizing effects on the flame photometric detector even 
after 9:1 dilution. (Acceptable systems must demonstrate that they have 
eliminated this interference by some procedure such as eluting CO and 
CO2 before any of the sulfur compounds to be measured.) 
Compliance with this requirement can be demonstrated by submitting 
chromatograms of calibration gases with and without CO2 in 
the diluent gas. The CO2 level should be approximately 10 
percent for the case with CO2 present. The two chromatograms 
should show agreement within the precision limits of Section 4.1.
    3.3  Elemental Sulfur. The condensation of sulfur vapor in the 
sampling system can lead to blockage of the particulate filter. This 
problem can be minimized by observing the filter for buildup and 
changing as needed.
    3.4  Sulfur Dioxide (SO2). Sulfur dioxide is not a 
specific interferent but may be present in such large amounts that it 
cannot be effectively separated from the other compounds of interest. 
The SO2 scrubber described in Section 5.1.3 will effectively 
remove SO2 from the sample.
    3.5  Alkali Mist. Alkali mist in the emissions of some control 
devices may cause a rapid increase in the SO2 scrubber pH to 
give low sample recoveries. Replacing the SO2 scrubber 
contents after each run will minimize the chances of interference in 
these cases.

4. Precision

    4.1 Calibration Precision. A series of three consecutive injections 
of the same calibration gas, at any dilution, shall produce results 
which do not vary by more than plus-minus13 percent from the 
mean of the three injections.
    4.2  Calibration Drift. The calibration drift determined from the 
mean of three injections made at the beginning and end of any run or 
series of runs within a 24-hour period shall not exceed 5 
percent.

5. Apparatus

    5.1  Sampling (Figure 15-1).
    5.1.1  Probe. The probe shall be made of Teflon or Teflon-lined 
stainless steel and heated to prevent moisture condensation. It shall be 
designed to allow calibration gas to enter the probe at or near the 
sample point entry. Any portion of the probe that contacts the stack gas 
must be heated to prevent moisture condensation. The probe described in 
Section 2.1.1 of Method 16A having a nozzle directed away from the gas 
stream is recommended for sources having particulate or mist emissions. 
Where very high stack temperatures prohibit the use of Teflon probe 
components, glass or quartz-lined probes may serve as substitutes.
    Note.-- Mention of trade names or specific products does not 
constitute an endorsement by the Environmental Protection Agency.
    5.1.2  Particulate Filter. 50-mm Teflon filter holder and a 1- to 2-
micron porosity Teflon filter (available through Savillex Corporation, 
5325 Highway 101, Minnetonka, Minnesota 55343). The filter holder must 
be

[[Page 930]]

maintained in a hot box at a temperature of at least 120 deg.C 
(248 deg.F).
    5.1.3  SO2 Scrubber.
    5.1.3.1  Three 300-ml Teflon segment impingers connected in series 
with flexible, thick-walled, Teflon tubing. (Impinger parts and tubing 
available through Savillex.) The first two impingers contain 100 ml of 
citrate buffer, and the third impinger is initially dry. The tip of the 
tube inserted into the solution should be constricted to less than 3-mm 
(\1/8\-in.) ID and should be immersed to a depth of at least 5 cm (2 
in.). Immerse the impingers in an ice water bath and maintain near 
0 deg.C. The scrubber solution will normally last for a 3-hour run 
before needing replacement. This will depend upon the effects of 
moisture and particulate matter on the solution strength and pH.
    5.1.3.2  Connections between the probe, particulate filter, and 
S02 scrubber shall be made of Teflon and as short in length 
as possible. All portions of the probe, particulate filter, and 
connections prior to the S02 scrubber (or alternative point 
of moisture removal) shall be maintained at a temperature of at least 
120  deg.C (248  deg.F).
    5.1.4  Sample Line. Teflon, no greater than 1.3-cm (\1/2\-in.) ID. 
Alternative materials, such as virgin Nylon, may be used provided the 
line loss test is acceptable.
    5.1.5  Sample Pump. The sample pump shall be a leakless Teflon-
coated diaphragm type or equivalent.
    5.2  Dilution System. The dilution system must be constructed such 
that all sample contacts are made of Teflon, glass, or stainless-steel. 
It must be capable of approximately a 9:1 dilution of the sample.

[[Page 931]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.195

    5.3  Gas Chromatograph (Figure 15-2). The gas chromatograph must 
have at least the following components:
    5.3.1 Oven. Capable of maintaining the separation column at the 
proper operating temperature plus-minus1  deg.C.

[[Page 932]]

    5.3.2 Temperature Gauge. To monitor column oven, detector, and 
exhaust temperature plus-minus1  deg.C.
    5.3.3 Flow System. Gas metering system to measure sample, fuel, 
combustion gas, and carrier gas flows.
    5.3.4 Flame Photometric Detector.
    5.3.4.1 Electrometer. Capable of full scale amplification of linear 
ranges of 10-9 to 10-4amperes full scale.
    5.3.4.2 Power Supply. Capable of delivering up to 750 volts.
    5.3.4.3 Recorder. Compatible with the output voltage range of the 
electrometer.
[GRAPHIC] [TIFF OMITTED] TC01JN92.196

    5.3.4.4  Rotary Gas Valves. Multiport Teflon-lined valves equipped 
with sample loop. Sample loop volumes shall be chosen to provide the 
needed analytical range. Teflon tubing and fittings shall be used 
throughout to present an inert surface for sample gas. The gas 
chromatograph shall be calibrated with the sample loop used for sample 
analysis.
    5.4 Gas Chromatograph Columns. The column system must be 
demonstrated to be capable of resolving three major reduced sulfur 
compounds: H2S, COS, and CS2.
    To demonstrate that adequate resolution has been achieved the 
tester must submit a chromatogram of a calibration gas containing all 
three reduced sulfur compounds in the concentration range of the 
applicable standard. Adequate resolution will be defined as base line 
separation of adjacent peaks when the amplifier attenuation is set so 
that the smaller peak is at least 50 percent of full scale. Base line 
separation is defined as a return to zero plus-minus5 percent 
in the interval between peaks. Systems not meeting this criteria may be 
considered alternate methods subject to the approval of the 
Administrator.
    5.5  Calibration System (Figure 15-3). The calibration system must 
contain the following components.
    5.5.1  Flow System. To measure air flow over permeation tubes within 
2 percent. Each flowmeter shall be calibrated after a 
complete test series with a wet-test meter. If the flow measuring device 
differs from the wet-test meter by more than 5 percent, the completed 
test shall be discarded. Alternatively, the tester may elect to use the 
flow data that will yield the lowest flow measurement. Calibration with 
a wet-test meter before a test is optional. Flow over the permeation 
device may also be determined using a soap bubble flowmeter.
    5.5.2  Constant Temperature Bath. Device capable of maintaining the 
permeation tubes at the calibration temperature within 0.1  deg.C.
    5.5.3  Temperature Gauge. Thermometer or equivalent to monitor bath 
temperature within 0.1  deg.C.

[[Page 933]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.197

6. Reagents

    6.1 Fuel. Hydrogen (H2) prepurified grade or better.
    6.2 Combustion Gas. Oxygen (O2) or air, research purity 
or better.
    6.3 Carrier Gas. Prepurified grade or better.
    6.4 Diluent. Air containing less than 0.5 ppm total sulfur compounds 
and less than 10 ppm each of moisture and total hydrocarbons.
    6.5 Calibration Gases. Permeation tubes, one each of H2S, 
COS, and CS2, gravimetrically calibrated and certified at 
some convenient operating temperature. These tubes consist of 
hermetically sealed FEP Teflon tubing in which a liquified gaseous 
substance is enclosed. The enclosed gas permeates through the tubing 
wall at a constant rate. When the temperature is constant, calibration 
gases covering a wide range of known concentrations can be generated by 
varying and accurately measuring the flow rate of diluent gas passing 
over the tubes. These calibration gases are used to calibrate the GC/FPD 
system and the dilution system.
    6.6  Citrate Buffer. Dissolve 300 g of potassium citrate and 41 g of 
anhydrous citric acid in 1 liter of water. Alternatively, 284 g of 
sodium citrate may be substituted for the potassium citrate. Adjust the 
pH to between 5.4 and 5.6 with potassium citrate or citric acid, as 
required.
    6.7  Sample Line Loss Gas (Optional). As an alternative, 
H2S cylinder gas may be used for the sample line loss test. 
The gas shall be calibrated against permeation devices having known 
permeation rates or by the procedure in Section 7 of Method 16A.

7. Pretest Procedures

    The following procedures are optional but would be helpful in 
preventing any problem which might occur later and invalidate the entire 
test.
    7.1 After the complete measurement system has been set up at the 
site and deemed to be operational, the following procedures should be 
completed before sampling is initiated.
    7.1.1 Leak Test. Appropriate leak test procedures should be employed 
to verify the integrity of all components, sample lines, and 
connections. The following leak test procedure is suggested: For 
components upstream of the sample pump, attach the probe end of

[[Page 934]]

the sample line to a manometer or vacuum gauge, start the pump and pull 
greater than 50 mm (2 in.) Hg vacuum, close off the pump outlet, and 
then stop the pump and ascertain that there is no leak for 1 minute. For 
components after the pump, apply a slight positive pressure and check 
for leaks by applying a liquid (detergent in water, for example) at each 
joint. Bubbling indicates the presence of a leak. As an alternative to 
the initial leak-test, the sample line loss test described in Section 
10.1 may be performed to verify the integrity of components.
    7.1.2 System Performance. Since the complete system is calibrated 
following each test, the precise calibration of each component is not 
critical. However, these components should be verified to be operating 
properly. This verification can be performed by observing the response 
of flowmeters or of the GC output to changes in flow rates or 
calibration gas concentrations and ascertaining the response to be 
within predicted limits. If any component or the complete system fails 
to respond in a normal and predictable manner, the source of the 
discrepancy should be identified and corrected before proceeding.

8. Calibration

    Prior to any sampling run, calibrate the system using the following 
procedures. (If more than one run is performed during any 24-hour 
period, a calibration need not be performed prior to the second and any 
subsequent runs. The calibration must, however, be verified as 
prescribed in Section 10, after the last run made within the 24-hour 
period.)
    8.1 General Considerations. This section outlines steps to be 
followed for use of the GC/FPD and the dilution system. The procedure 
does not include detailed instructions because the operation of these 
systems is complex, and it requires an understanding of the individual 
system being used. Each system should include a written operating manual 
describing in detail the operating procedures associated with each 
component in the measurement system. In addition, the operator should be 
familiar with the operating principles of the components; particularly 
the GC/FPD. The citations in the Bibliography at the end of this method 
are recommended for review for this purpose.
    8.2 Calibration Procedure. Insert the permeation tubes into the tube 
chamber. Check the bath temperature to assure agreement with the 
calibration temperature of the tubes within plus-minus0.1 
deg.C. Allow 24 hours for the tubes to equilibrate. Alternatively 
equilibration may be verified by injecting samples of calibration gas at 
1-hour intervals. The permeation tubes can be assumed to have reached 
equilibrium when consecutive hourly samples agree within the precision 
limits of Section 4.1.
    Vary the amount of air flowing over the tubes to produce the desired 
concentrations for calibrating the analytical and dilution systems. The 
air flow across the tubes must at all times exceed the flow requirement 
of the analytical systems. The concentration in parts per million 
generated by a tube containing a specific permeant can be calculated as 
follows:

C=K x Pr/ML
                                                                Eq. 15-1
Where:

C=Concentration of permeant produced in ppm.
Pr=Permeation rate of the tube in g/min.
M=Molecular weight of the permeant: g/g-mole.
L=Flow rate, l/min, of air over permeant @ 20  deg.C, 760 mm Hg.
K=Gas constant at 20  deg.C and 760 mm Hg=24.04 l/g mole.
    8.3 Calibration of Analysis System. Generate a series of three or 
more known concentrations spanning the linear range of the FPD 
(approximately 0.5 to 10 ppm for a 1--ml sample) for each of the three 
major sulfur compounds. Bypassing the dilution system, inject these 
standards into the GC/FPD analyzers and monitor the responses. Three 
injects for each concentration must yield the precision described in 
Section 4.1. Failure to attain this precision is an indication of a 
problem in the calibration or analytical system. Any such problem must 
be identified and corrected before proceeding.
    8.4 Calibration Curves. Plot the GC/FPD response in current 
(amperes) versus their causative concentrations in ppm on log-log 
coordinate graph paper for each sulfur compound. Alternatively, a least 
squares equation may be generated from the calibration data. 
Alternatively, a least squares equation may be generated from the 
calibration data using concentrations versus the appropriate instrument 
response units.
    8.5 Calibration of Dilution System. Generate a known concentration 
of hydrogen sulfied using the permeation tube system. Adjust the flow 
rate of diluent air for the first dilution stage so that the desired 
level of dilution is approximated. Inject the diluted calibration gas 
into the GC/FPD system and monitor its response. Three injections for 
each dilution must yield the precision described in Section 4.1. Failure 
to attain this precision in this step is an indication of a problem in 
the dilution system. Any such problem must be identified and corrected 
before proceeding. Using the calibration data for H2S 
(developed under 8.3) determine the diluted calibration gas 
concentration in ppm. Then calculate the dilution factor as the ratio of 
the calibration gas concentration before dilution to the diluted 
calibration gas concentration determined under this section. Repeat this 
procedure for

[[Page 935]]

each stage of dilution required. Alternatively, the GC/FPD system may be 
calibrated by generating a series of three or more concentrations of 
each sulfur compound and diluting these samples before injecting them 
into the GC/FPD system. This data will then serve as the calibration 
data for the unknown samples and a separate determination of the 
dilution factor will not be necessary. However, the precision 
requirements of Section 4.1 are still applicable.

9. Sampling and Analysis Procedure

    9.1 Sampling. Insert the sampling probe into the test port making 
certain that no dilution air enters the stack through the port. Begin 
sampling and dilute the sample approximately 9:1 using the dilution 
system. Note that the precise dilution factor is that which is 
determined in section 8.5. Condition the entire system with sample for a 
minimum of 15 minutes prior to commencing analysis.
    9.2 Analysis. Aliquots of diluted sample are injected into the GC/
FPD analyzer for analysis.
    9.2.1 Sample Run. A sample run is composed of 16 individual analyses 
(injects) performed over a period of not less than 3 hours or more than 
6 hours.
    9.2.2  Observation for Clogging of Probe or Filter. If reductions in 
sample concentrations are observed during a sample run that cannot be 
explained by process conditions, the sampling must be interrupted to 
determine if the probe or filter is clogged with particulate matter. If 
either is found to be clogged, the test must be stopped and the results 
up to that point discarded. Testing may resume after cleaning or 
replacing the probe and filter. After each run, the probe and filter 
shall be inspected and, if necessary, replaced.

10. Post-Test Procedures

    10.1 Sample Line Loss. A known concentration of hydrogen sulfide at 
the level of the applicable standard, plus-minus20 percent, 
must be introduced into the sampling system at the opening of the probe 
in sufficient quantities to ensure that there is an excess of sample 
which must be vented to the atmosphere. The sample must be transported 
through the entire sampling system to the measurement system in the 
normal manner. The resulting measured concentration should be compared 
to the known value to determine the sampling system loss. A sampling 
system loss of more than 20 percent is unacceptable. Sampling losses of 
0-20 percent must be corrected by dividing the resulting sample 
concentration by the fraction of recovery. The known gas sample may be 
generated using permeation tubes. Alternatively, cylinders of hydrogen 
sulfide mixed in nitrogen and verified according to Section 6.7 may be 
used. The optional pretest procedures provide a good guideline for 
determining if there are leaks in the sampling system.
    10.2 Recalibration. After each run, or after a series of runs made 
within a 24-hour period, perform a partial recalibration using the 
procedures in Section 8. Only H2S (or other permeant) need be 
used to recalibrate the GC/FPD analysis system (8.3) and the dilution 
system (8.5).
    10.3 Determination of Calibration Drift. Compare the calibration 
curves obtained prior to the runs, to the calibration curves obtained 
under Section 10.2. The calibration drift should not exceed the limits 
set forth in Section 4.2. If the drift exceeds this limit, the 
intervening run or runs should be considered not valid. The tester, 
however, may instead have the option of choosing the calibration data 
set which would give the highest sample values.

11. Calculations

    11.1 Determine the concentrations of each reduced sulfur compound 
detected directly from the calibration curves. Alternatively, the 
concentrations may be calculated using the equation for the least 
squares line.
    11.2 Calculation of SO2 Equivalent. SO2 
equivalent will be determined for each analysis made by summing the 
concentrations of each reduced sulfur compound resolved during the given 
analysis.

SO2 equivalent=(H2S, COS, 2 
CS2)d
                                                                Eq. 15-2
Where:

SO2 equivalent=The sum of the concentration of each of the 
          measured compounds (COS, H2S, CS2) 
          expressed as sulfur dioxide in ppm.
H2S=Hydrogen sulfide, ppm.
COS=Carbonyl sulfide, ppm.
CS2=Carbon disulfide, ppm.
d=Dilution factor, dimensionless.
    11.3  Average SO2 Equivalent. This is determined using 
the following equation. Systems that do not remove moisture from the 
sample but conditions the gas to prevent condensation must correct the 
average SO2 equivalent for the fraction of water vapor 
present.
[GRAPHIC] [TIFF OMITTED] TC01JN92.198

where:

Average SO2 equivalent = Average SO2 equivalent in 
          ppm, dry basis.
Average SO2 equivalent i = SO2 in ppm 
          as determined by Equation 15-2.
    N = Number of analyses performed.

12. Bibliography


[[Page 936]]


    12.1 O'Keeffe, A. E. and G. C. Ortman. ``Primary Standards for Trace 
Gas Analysis.'' Anal. Chem. 38,760 (1966).
    12.2  Stevens,  R.  K.,  A.  E.  O'Keeffe,  and G. C. Ortman. 
``Absolute Calibration of a Flame Photometric Detector to Volatile 
Sulfur Compounds at Sub-Part-Per-Million Levels.'' Environmental Science 
and Technology 3:7 (July 1969).
    12.3  Mulik,  J.  D.,  R.  K.  Stevens,  and R. Baumgardner. ``An 
Analytical System Designed to Measure Multiple Malodorous Compounds 
Related to Kraft Mill Activities.'' Presented at the 12th Conference on 
Methods in Air Pollution and Industrial Hygiene Studies, University of 
Southern California, Los Angeles, CA, April 6-8, 1971.
    12.4 Devonald, R. H., R. S. Serenius, and A. D. McIntyre. 
``Evaluation of the Flame Photometric Detector for Analysis of Sulfur 
Compounds.'' Pulp and Paper Magazine of Canada, 73,3 (March, 1972).
    12.5 Grimley,  K.  W.,  W.  S.  Smith,  and R. M. Martin. ``The Use 
of a Dynamic Dilution System in the Conditioning of Stack Gases for 
Automated Analysis by a Mobile Sampling Van.'' Presented at the 63rd 
Annual APCA Meeting in St. Louis, MO. June 14-19, 1970.
    12.6 General Reference. Standard Methods of Chemical Analysis Volume 
III A and B Instrumental Methods. Sixth Edition. Van Nostrand Reinhold 
Co.

Method 15A--Determination of Total Reduced Sulfur Emissions From Sulfur 
                 Recovery Plants in Petroleum Refineries

1.  Applicability, Principle, Interferences, Precision, and Bias
    1.1  Applicability. This method is applicable to the determination 
of total reduced sulfur (TRS) emissions from sulfur recovery plants 
where the emissions are in a reducing atmosphere, such as in Stretford 
units. The lower detectable limit is 0.1 ppm of sulfur dioxide 
(SO2) when sampling at 2 liters/min for 3 hours or 0.3 ppm 
when sampling at 2 liters/min for 1 hour. The upper concentration limit 
of the method exceeds TRS levels generally encountered in sulfur 
recovery plants.
    1.2  Principle. An integrated gas sample is extracted from the 
stack, and combustion air is added to the oxygen (O2)-
deficient gas at a known rate. The TRS compounds (hydrogen sulfide, 
carbonyl sulfide, and carbon disulfide) are thermally oxidized to sulfur 
dioxide, collected in hydrogen peroxide as sulfate ion, and then 
analyzed according to the Method 6 barium-thorin titration procedure.
    1.3  Interferences. Reduced sulfur compounds, other than TRS, that 
are present in the emissions will also be oxidized to SO2. 
For example, thiophene has been identified in emissions from a Stretford 
unit and produced a positive bias of 30 percent in the Method 15A 
result. However, these biases may not affect the outcome of the test at 
units where emissions are low relative to the standard.
    Calcium and aluminum have been shown to interfere in the Method 6 
titration procedure. Since these metals have been identified in 
particulate matter emissions from Stretford units, a Teflon filter is 
required to remove this interference.
    Note: Mention of trade name or commercial products in this 
publication does not constitute the endorsement or recommendation for 
use by the Environmental Protection Agency.
    When used to sample emissions containing 7 percent moisture or less, 
the midget impingers have sufficient volume to contain the condensate 
collected during sampling. Dilution of the H2O2 
does not affect the collection of SO2. At higher moisture 
contents, the potassium citrate-citric acid buffer system used with 
Method 16A should be used to collect the condensate.
    1.4  Precision and bias. Relative standard deviations of 2.8 and 6.9 
percent at 41 ppm TRS have been obtained when sampling for 1 and 3 
hours, respectively. Results obtained with this method are likely to 
contain a positive bias due to the presence of nonregulated sulfur 
compounds (that are present in petroleum) in the emissions.

2.  Apparatus

    2.1  Sampling. The sampling train is shown in Figure 15A-1, and 
component parts are discussed below. Modifications to this sampling 
train are acceptable provided that the system performance check is met.

[[Page 937]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.199

    2.1.1  Probe. 0.6-cm (\1/4\-in.) OD Teflon tubing sequentially 
wrapped with heat-resistant fiber strips, a rubberized heating tape 
(with a plug at one end), and heat-resistant adhesive tape. A flexible 
thermocouple or some other suitable temperature-measuring device shall 
be placed between the Teflon tubing and the fiber strips so that the 
temperature

[[Page 938]]

can be monitored. The probe should be sheathed in stainless steel to 
provide in-stack rigidity. A series of bored-out stainless steel 
fittings placed at the front of the sheath will prevent flue gas from 
entering between the probe and sheath. The sampling probe is depicted in 
Figure 15A-2.
[GRAPHIC] [TIFF OMITTED] TC01JN92.200

                Figure 15A-2. Method 15A sampling probe.
    2.1.2  Particulate filter. A 50-mm Teflon filter holder and a 1- to 
2-m porosity Teflon filter (available through Savillex 
Corporation, 5325 Highway 101, Minnetonka, Minnesota 55345). The filter 
holder must be maintained in a hot box at a high enough temperature to 
prevent condensation.
    2.1.3  Combustion air delivery system. As shown in the schematic 
diagram in Figure 15A-3. The rotameter should be selected to measure an 
air flow rate of 0.5 liter/min.

[[Page 939]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.201

    2.1.4  Combustion tube. Quartz glass tubing with an expanded 
combustion chamber 2.54 cm (1 in.) in diameter and at least 30.5 cm (12 
in.) long. The tube ends should have an outside diameter of 0.6 cm (\1/
4\ in.) and be at least 15.3 cm (6 in.) long. This length is necessary 
to maintain the quartz-glass connector at ambient temperature and 
thereby avoid leaks. Alternatively, the outlet may be constructed with a 
90-degree glass elbow and socket that would fit directly onto the inlet 
of the first peroxide impinger.
    2.1.5  Furnace. Of sufficient size to enclose the combustion tube. 
The furnace shall have a temperature regulator capable of maintaining 
the temperature at 1100  50 deg.C. The furnace operating 
temperature shall be checked with a thermocouple to ensure accuracy. 
Lindberg furnaces have been found to be satisfactory.
    2.1.6  Peroxide impingers, stopcock grease, thermometer, drying 
tube, valve, pump, barometer, and vacuum gauge. Same as in Method 6, 
Sections 2.1.2, 2.1.4, 2.1.5, 2.1.6, 2.1.7, 2.1.8, 2.1.11, and 2.1.12, 
respectively.
    2.1.7  Rate meters. Rotameters (or equivalent) capable of measuring 
flow rate to within 5 percent of the selected flow rate and calibrated 
as in Section 5.2.
    2.1.8  Volume meter. Dry gas meter capable of measuring the sample 
volume under the particular sampling conditions with an accuracy of 
 2 percent.
    2.1.9  U-tube manometer. To measure the pressure at the exit of the 
combustion gas dry gas meter.
    2.2  Sample recovery and analysis. Same as in Method 6, Sections 2.2 
and 2.3, except a 10-ml buret with 0.05-ml graduations is required for 
titrant volumes of less than 10.0 ml, and the spectrophotometer is not 
needed.

3.  Reagents

    Unless otherwise indicated, all reagents must conform to the 
specifications established by the Committee on Analytical Reagents of 
the American Chemical Society. When such specifications are not 
available, the best available grade shall be used.
    3.1  Sampling. The following reagents are needed:
    3.1.1 Water. Same as in Method 6, Section 3.1.1.
    3.1.2  Hydrogen peroxide, 3 percent. Same as in Method 6, Section 
3.1.5 (40 ml is needed per sample).
    3.1.3  Recovery check gas. Carbonyl sulfide (COS) in nitrogen (100 
ppm or greater, if necessary) in an aluminum cylinder. Verify the

[[Page 940]]

concentration by gas chromatography where the instrument is calibrated 
with a COS permeation tube.
    3.1.4  Combustion gas. Air, contained in a gas cylinder equipped 
with a two-stage regulator. The gas should contain less than 50 ppb of 
reduced sulfur compounds and less than 10 ppm total hydrocarbons.
    3.2  Sample recovery and analysis. Same as in Method 6, Sections 3.2 
and 3.3.
4.  Procedure
    4.1  Sampling. Before any source sampling is done, conduct two 30-
minute system performance checks in the field, as detailed in Section 
4.3, to validate the sampling train components and procedures 
(optional).
    4.1.1  Preparation of sampling train. For the Method 6 part of the 
train, measure 20 ml of 3 percent hydrogen peroxide into the first and 
second midget impingers. Leave the third midget impinger empty and add 
silica gel to the fourth impinger. Alternatively, a silica gel drying 
tube may be used in place of the fourth impinger. Place crushed ice and 
water around all impingers. Maintain the oxidation furnace at 1100 
 50 deg.C to ensure 100 percent oxidation of COS. Maintain 
the probe and filter temperatures at a high enough level (no visible 
condensation) to prevent moisture condensation and monitor the 
temperatures with a thermocouple.
    4.1.2  Leak-check procedure. Assemble the sampling train and leak-
check as described in Method 6, Section 4.1.2. Include the combustion 
air delivery system from the needle valve forward in the leak-check.
    4.1.3  Sample collection. Adjust the pressure on the second stage of 
the regulator on the combustion air cylinder to 10 psig. Adjust the 
combustion air flow rate to 0.50 liter/min (10 percent) 
before injecting combustion air into the sampling train. Then inject 
combustion air into the sampling train, start the sample pump, and open 
the stack sample gas valve. Carry out these three operations within 15 
to 30 seconds to avoid pressurizing the sampling train. Adjust the total 
sample flow rate to 2.0 liters/min (10 percent). The 
combustion air flow rate of 0.50 liter/min and the total sample flow 
rate of 2.0 liters/min produce an 02 concentration of 5.0 
percent in the stack gas. This 02 concentration must be 
maintained constantly to allow oxidation of TRS to SO2. 
Adjust these flow rates during sampling as necessary. Monitor and record 
the combustion air manometer reading at regular intervals during the 
sampling period. Sample for 1 or 3 hours. At the end of sampling, turn 
off the sample pump and combustion air simultaneously (within 15 to 30 
seconds of each other). All other procedures are the same as in Method 
6, Section 4.1.3, except that the sampling train should not be purged. 
After collecting the sample, remove the probe from the stack and conduct 
a leak-check (mandatory).
    After each 3-hour test run (or after three 1-hour samples), conduct 
one system performance check (see Section 4.3). After this system 
performance check and before the next test run, it is recommended that 
the probe be rinsed and brushed and the filter replaced.
    In Method 15, a test run is composed of 16 individual analyses 
(injects) performed over a period of not less than 3 hours or more than 
6 hours. For Method 15A to be consistent with Method 15, the following 
may be used to obtain a test run: (1) Collect three 60-minute samples or 
(2) collect one 3-hour sample. (Three test runs constitute a test.)
    4.2  Sample recovery. Recover the hydrogen peroxide-containing 
impingers as detailed in Method 6, Section 4.2.
    4.3  System performance check. A system performance check is done 
(1) to validate the sampling train components and procedure (before 
testing, optional) and (2) to validate a test run (after a run). Perform 
a check in the field before testing consisting of at least two samples 
(optional), and perform an additional check after each 3-hour run or 
after three 1-hour samples (mandatory).
    The checks involve sampling a known concentration of COS and 
comparing the analyzed concentration with the known concentration. Mix 
the recovery gas with N2 as shown in Figure 15A-4 if dilution 
is required. Adjust the flow rates to generate a COS concentration in 
the range of the stack gas or within 20 percent of the applicable 
standard at a total flow rate of at least 2.5 liters/min. Use Equation 
15A-4 to calculate the concentration of recovery gas generated. 
Calibrate the flow rate from both sources with a soap bubble flow tube 
so that the diluted concentration of COS can be accurately calculated. 
Collect 30-minute samples, and analyze in the normal manner. Collect the 
samples through the probe of the sampling train using a manifold or some 
other suitable device that will ensure extraction of a representative 
sample.

[[Page 941]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.202

    The recovery check must be performed in the field before replacing 
the particulate filter and before cleaning the probe. A sample recovery 
of 100  20 percent must be obtained for the data to be valid 
and should be reported with the emission data, but should not be used to 
correct the data. However, if the performance check results do not 
affect the compliance or noncompliance status of the affected facility, 
the Administrator may decide to accept the results of the compliance 
test. Use Equation 15A-5 to calculate the recovery efficiency.
    4.4  Sample analysis. Same as in Method 6, Section 4.3. For 
compliance tests only, an EPA SO2 field audit sample shall be 
analyzed with each set of samples. Such audit samples are available from 
the Quality Assurance Division, Environmental Monitoring Systems 
Laboratory, U.S. Environmental Protection Agency, Research Triangle 
Park, NC 27711.
5.  Calibration.
    5.1  Metering system, thermometers, barometer, and barium 
perchlorate solution. Calibration procedures are presented in Method 6, 
Sections 5.1, 5.2, 5.4, and 5.5.
    5.2  Rotameters. Calibrate with a bubble flow tube.
6.  Calculations.
    In the calculations, retain at least one extra decimal figure beyond 
that of the acquired data. Round off figures after final calculations.
    6.1  Nomenclature.

CTRS=Concentration of TRS as SO2, dry basis, 
          corrected to standard conditions, ppm.
N=Normality of barium perchlorate titrant, milliequivalents/ml.
Pbar=Barometric pressure at exit orifice of the dry gas 
          meter, mm Hg.
Pstd=Standard absolute pressure, 760 mm Hg.
Tm=Average dry gas meter absolute temperature,  deg..
Tstd=Standard absolute temperature, 293 deg..
Va=Volume of sample aliquot titrated, ml.
Vms=Dry gas volume as measured by the sample train dry gas 
          meter, liters.
Vmc=Dry gas volume as measured by the combustion air dry gas 
          meter, liters.
Vms(std)=Dry gas volume measured by the sample train dry gas 
          meter, corrected to standard conditions, liters.
Vmc(std)=Dry gas volume measured by the combustion air dry 
          gas meter, corrected to standard conditions, liters.

[[Page 942]]

Vsoln=Total volume of solution in which the sulfur dioxide 
          sample is contained, 100 ml.
Vt=Volume of barium perchlorate titrant used for the sample 
          (average of replicate titrations), ml.
Vtb=Volume of barium perchlorate titrant used for the blank, 
          ml.
Y=Calibration factor for sampling train dry gas meter.
Yc=Calibration factor for combustion air dry gas meter.
CRG=Concentration of generated recovery gas, ppm.
CCOS=Concentration of COS recovery gas, ppm.
QCOS=Flow rate of COS recovery gas, liters/min.
QN2=Flow rate of diluent N2, liters/min.
R=Recovery efficiency for the system performance check, percent.
32.03=Equivalent weight of sulfur dioxide, mg/meq.
[GRAPHIC] [TIFF OMITTED] TC16NO91.183

[GRAPHIC] [TIFF OMITTED] TC16NO91.184

where: K1=0.3858 deg./mm Hg for metric units.

6.3  Combustion Air Gas Volume, Gorrected to Standard Conditions.
[GRAPHIC] [TIFF OMITTED] TC16NO91.185

    Note: Correct Pbar for the average pressure of the 
manometer during the sampling period.
    6.4  Concentration of TRS as ppm SO2.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.186
    
where: K2=12025 l/meq for metric units.
    6.5  Concentration of Generated Recovery Gas.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.187
    
    6.6  Recovery Efficiency.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.188
    
7.  Bibliography

    1. American Society for Testing and Materials
    Annual Book of ASTM Standards. Part 31: Water, Atmospheric Analysis. 
Philadelphia, Pennsylvania. 1974. p. 40-42.

    2. Blosser, R.O., H.S. Oglesby, and A.K. Jain
    A Study of Alternate SO2 Scrubber Designs Used for TRS 
Monitoring. National Council of the Paper Industry for Air and Stream 
Improvement, Inc., New York, New York. Special Report 77-05. July 1977.

    3. Curtis, F., and G.D. McAlister
    Development and Evaluation of an Oxidation/Method 6 TRS Emission 
Sampling Procedure. Emission Measurement Branch, Emission Standards and 
Engineering Division, U.S. Environmental Protection Agency,

[[Page 943]]

Research Triangle Park, North Carolina 27711. February 1980.

    4. Gellman, I.
    A Laboratory and Field Study of Reduced Sulfur Sampling and 
Monitoring Systems.
    National Council of the Paper Industry for Air and Stream 
Improvement, Inc., New York, New York. Atmospheric Quality Improvement 
Technical Bulletin No. 81. October 1975.

    5. Margeson, J.H., J.E. Knoll, M.R. Midgett, B.B. Ferguson, and P.J. 
Schworer
    A Manual Method for TRS Determination. Journal of Air Pollution 
Control Association. 35:1280-1286. December 1985.

    Method 16--Semicontinuous Determination of Sulfur Emissions From 
                           Stationary Sources

Introduction

    The method described below uses the principle of gas chromatographic 
separation and flame photometric detection (FPD). Since there are many 
systems or sets of operating conditions that represent useable methods 
of determining sulfur emissions, all systems which employ this 
principle, but differ only in details of equipment and operation, may be 
used as alternative methods, provided that the calibration precision and 
sample line loss criteria are met.

1. Principle and Applicability

    1.1  Principle. A gas sample is extracted from the emission source 
and an aliquot is analyzed for hydrogen sulfide (H2S), methyl 
mercaptan (MeSH), dimethly sulfide (DMS), and dimethyl disulfide (DMDS) 
by gas chromatographic (GC) separation and flame photometric detection 
(FPD). These four compounds are know collectively as total reduced 
sulfur (TRS).
    1.2  Applicability. This method is applicable for determination of 
TRS compounds from recovery furnaces, lime kilns, and smelt dissolving 
tanks at kraft pulp mills.

2. Range and Sensitivity

    2.1  Range. The analytical range will vary with the sample loop 
size. Typically, the analytical range may extend from 0.1 to 100 ppm 
using 10 to 0.1-ml sample loop sizes. This eliminates the need for 
sample dilution in most cases.
    2.2  Sensitivity. Using the 10-ml sample size, the minimum 
detectable concentration is approximately 50 ppb.

3. Interferences

    3.1  Moisture Condensation. Moisture condensation in the sample 
delivery system, the analytical column, or the FPD burner block can 
cause losses or interferences. This is prevented by maintaining the 
probe, filter box, and connections at a temperature of at least 120 
deg.C (248  deg.F). Moisture is removed in the SO2 scrubber 
and heating the sample beyond this point is not necessary provided the 
ambient temperature is above 0  deg.C. Alternatively, moisture may be 
eliminated by heating the sample line, and by conditioning the sample 
with dry dilution air to lower its dew point below the operating 
temperature of the GC/FPD analytical system prior to analysis.
    3.2  Carbon Monoxide and Carbon Dioxide. CO and CO2 have 
a substantial desensitizing effect on the flame photometric detector 
even after dilution. Acceptable systems must demonstrate that they have 
eliminated this interference by some procedure such as eluting these 
compounds before any of the compounds to be measured. Compliance with 
this requirement can be demonstrated by submitting chromatograms of 
calibration gases with and without CO2 in the diluent gas. 
The CO2 level should be approximately 10 percent for the case 
with CO2 present. The two chromatograms should show agreement 
within the precision limits of Section 4.1.
    3.3  Particulate Matter. Particulate matter in gas samples can cause 
interference by eventual clogging of the analytical system. This 
interference is eliminated by using the Teflon filter after the probe.
    3.4  Sulfur Dioxide (SO2). Sulfur dioxide is not a 
specific interferent but may be present in such large amounts that it 
cannot be effectively separated from the other compounds of interest. 
The SO2 scrubber described in Section 5.1.3 will effectively 
remove SO2 from the sample.

4. Precision and Accuracy

    4.1  GC/FPD Calibration Precision. A series of three consecutive 
injections of the same calibration gas, at any dilution, shall produce 
results which do not vary by more than plus-minus5 percent 
from the mean of the three injections.
    4.2  Calibration Drift. The calibration drift determined from the 
mean of three injections made at the beginning and end of any run or 
series of runs within a 24-hour period shall not exceed 5 
percent.
    4.3  System Calibration Accuracy. Losses through the sample 
transport system must be measured and a correction factor developed to 
adjust the calibration accuracy to 100 percent.

5. Apparatus

    5.1.  Sampling.
    5.1.1  Probe.

[[Page 944]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.203

    5.1.1.1  Teflon or Teflon-lined stainless steel. The probe must be 
heated to prevent moisture condensation. It shall be designed to allow 
calibration gas to enter the probe at or near the sample point entry. 
Any portion of the probe that contacts the stack gas must be heated to 
prevent moisture condensation.

[[Page 945]]

    5.1.1.2  Figure 16-1 illustrates the probe used in lime kilns and 
other sources where significant amounts of particulate matter are 
present. The probe is designed with the deflector shield placed between 
the sample and the gas inlet holes to reduce clogging of the filter and 
possible adsorption of sample gas. As an alternative, the probe 
described in Section 2.1.1 of Methods 16A having a nozzle directed away 
from the gas stream may be used at sources having significant amounts of 
particulate matter.
    5.1.1.3  Note: Mention of trade names or specific products does not 
constitute an endorsement by the Environmental Protection Agency.
    5.1.2  Particulate Filter. 50-mm Teflon filter holder and a 1- to 2-
micron porosity Teflon filter (available through Savillex Corporation, 
5325 Highway 101, Minnetonka, Minnesota 55343). The filter holder must 
be maintained in a hot box at a temperature of at least 120  deg.C (248 
deg.F).
    5.1.3  SO2 Scrubber.
    5.1.3.1  Three 300-ml Teflon segmented impingers connected in series 
with flexible, thick-walled, Teflon tubing. (Impinger parts and tubing 
available through Savillex.) The first two impingers contain 100 ml of 
citrate buffer and the third impinger is initially dry. The tip of the 
tube inserted into the solution should be constricted to less than 3-mm 
(\1/8\-in.) ID and should be immersed to a depth of at least 5 cm (2 
in.). Immerse the impingers in an ice water bath and maintain near 0 
deg.C. The scrubber solution will normally last for a 3-hour run before 
needing replacement. This will depend upon the effects of moisture and 
particulate matter on the solution strength and pH.
    5.1.3.2  Connections between the probe, particulate filter, and 
SO2 scrubber shall be made of Teflon and as short in length 
as possible. All portions of the probe, particulate filter, and 
connections prior to the SO2 scrubber (or alternative point 
of moisture removal) shall be maintained at a temperature of at least 
120  deg.C (248  deg.F).
    5.1.4  Sample Line. Teflon, no greater than 1.3-cm (\1/2\-in.) ID. 
Alternative materials, such as virgin Nylon, may be used provided the 
line loss test is acceptable.
    5.1.5  Sample Pump. The sample pump shall be leakless Teflon-coated 
diaphragm type or equivalent.
    5.2  Dilution System. Needed only for high sample concentrations. 
The dilution system must be constructed such that all sample contacts 
are made of Teflon, glass, or stainless steel.
    5.3  Gas Chromatograph. The gas chromatograph must have at least the 
following components:
    5.3.1  Oven. Capable of maintaining the separation column at the 
proper operating temperature plus-minus1  deg.C.
    5.3.2  Temperature Gauge. To monitor column oven, detector, and 
exhaust temperature plus-minus1  deg.C.
    5.3.3  Flow System. Gas metering system to measure sample, fuel, 
combustion gas, and carrier gas flows.
    5.3.4  Flame Photometric Detector.
    5.3.4.1  Electrometer. Capable of full scale amplification of linear 
ranges of 10-9 to 10-4 amperes full scale.
    5.3.4.2  Power Supply. Capable of delivering up to 750 volts.
    5.3.4.3  Recorder. Compatible with the output voltage range of the 
electrometer.
    5.3.4.4  Rotary Gas Valves. Multiport Teflon-lined valves equipped 
with sample loop. Sample loop volumes shall be chosen to provide the 
needed analytical range. Teflon tubing and fittings shall be used 
throughout to present an inert surface for sample gas. The gas 
chromatograph shall be calibrated with the sample loop used for sample 
analysis.
    5.4  Gas Chromatogram Columns. The column system must be 
demonstrated to be capable of resolving the four major reduced sulfur 
compounds: H2S, MeSH, DMS, and DMDS. It must also demonstrate 
freedom from known interferences.
    To demonstrate that adequate resolution has been achieved, the 
tester must submit a chromatogram of a calibration gas containing all 
four of the TRS compounds in the concentration range of the applicable 
standard. Adequate resolution will be defined as base line separation of 
adjacent peaks when the amplifier attenuation is set so that the smaller 
peak is at least 50 percent of full scale. Baseline separation is 
defined as a return to zero 5 percent in the interval 
between peaks. Systems not meeting this criteria may be considered 
alternate methods subject to the approval of the Administrator.
    5.5  Calibration System. The calibration system must contain the 
following components. (Figure 16-2)
    5.5.1  Tube Chamber. Chamber of glass or Teflon of sufficient 
dimensions to house permeation tubes.
    5.5.2  Flow System. To measure air flow over permeation tubes at 
plus-minus2 percent. Each flowmeter shall be calibrated after 
a complete test series with a wet test meter. If the flow measuring 
device differs from the wet test meter by 5 percent, the completed test 
shall be discarded. Alternatively, the tester may elect to use the flow 
data that would yield the lower flow measurement. Calibration with a wet 
test meter before a test is optional. Flow over the permeation device 
may also be determined using a soap bubble flowmeter.
    5.5.3  Constant Temperature Bath. Device capable of maintaining the 
permeation tubes at the calibration temperature within 
plus-minus0.1  deg.C.

[[Page 946]]

    5.5.4  Temperature Gauge. Thermometer or equivalent to monitor bath 
temperature within plus-minus1  deg.C.

6. Reagents

    6.1  Fuel. Hydrogen (H2), prepurified grade or better.
    6.2  Combustion Gas. Oxygen (O2) or air, research purity 
or better.
    6.3  Carrier Gas. Prepurified grade or better.
    6.4  Diluent (If required). Air containing less than 50 ppb total 
sulfur compounds and less than 10 ppm each of moisture and total 
hydrocarbons.
    6.5  Calibration Gases. Permeation tubes, one each of 
H2S, MeSH, DMS, and DMDS, gravimetrically calibrated and 
certified at some convenient operating temperature. These tubes consist 
of hermetically sealed FEP Teflon tubing in which a liquified gaseous 
substance is enclosed. The enclosed gas permeates through the tubing 
wall at a constant rate. When the temperature is constant, calibration 
gases covering a wide range of known concentrations can be generated by 
varying and accurately measuring the flow rate of diluent gas passing 
over the tubes. These calibration gases are used to calibrate the GC/FPD 
system and the dilution system.
    6.6  Citrate Buffer. Dissolve 300 grams of potassium citrate and 41 
grams of anhydrous citric acid in 1 liter of deionized water. 284 grams 
of sodium citrate may be substituted for the potassium citrate. Adjust 
the pH to between 5.4 and 5.6 with potassium citrate or citric acid, as 
required.
    6.7  Sample Line Loss Gas (Optional). As an alternative to 
permeation gas, H2S cylinder gas may be used for the sample 
line loss test. The gas shall be calibrated against permeation devices 
having known permeation rates or by the procedure in Section 7 of Method 
16A.

7. Pretest Procedures

    The following procedures are optional but would be helpful in 
preventing any problem which might occur later and invalidate the entire 
test.

    7.1  After the complete measurement system has been set up at the 
site and deemed to be operational, the following procedures should be 
completed before sampling is initiated.
    7.1.1  Leak Test. Appropriate leak test procedures should be 
employed to verify the integrity of all components, sample lines, and 
connections. The following leak test procedure is suggested: For 
components upstream of the sample pump, attach the probe end of the 
sample line to a manometer or vacuum gauge, start the pump and pull 
greater than 50 mm (2 in.) Hg vacuum, close off the pump outlet, and 
then stop the pump and ascertain that there is no leak for 1 minute. For 
components after the pump, apply a slight positive pressure and check 
for leaks by applying a liquid (detergent in water, for example) at each 
joint. Bubbling indicates the presence of a leak. As an alternative to 
the initial leak-test, the sample line loss test described in Section 
10.1 may be performed to verify the integrity of components.
    7.1.2  System Performance. Since the complete system is calibrated 
following each test, the precise calibration of each component is not 
critical. However, these components should be verified to be operating 
properly. This verification can be performed by observing the response 
of flowmeters or of the GC output to changes in flow rates or 
calibration gas concentrations and ascertaining the response to be 
within predicted limits. In any component, or if the complete system 
fails to respond in a normal and predictable manner, the source of the 
discrepancy should be identified and corrected before proceeding.

8. Calibration

    Prior to any sampling run, calibrate the system using the following 
procedures. (If more than one run is performed during any 24-hour 
period, a calibration need not be performed prior to the second and any 
subsequent runs. The calibration must, however, be verified as 
prescribed in Section 10, after the last run made within the 24-hour 
period.)

    8.1  General Considerations. This section outlines steps to be 
followed for use of the GC/FPD and the dilution system (if applicable). 
The procedure does not include detailed instructions because the 
operation of these systems is complex, and it requires an understanding 
of the individual system being used. Each system should include a 
written operating manual describing in detail the operating procedures 
associated with each component in the measurement system. In addition, 
the operator should be familiar with the operating principles of the 
components, particularly the GC/FPD. The citations in the Bibliography 
at the end of this method are recommended for review for this purpose.
    8.2  Calibration Procedure. Insert the permeation tubes into the 
tube chamber. Check the bath temperature to assure agreement with the 
calibration temperature of the tubes within plus-minus0.1 
deg.C. Allow 24 hours for the tubes to equilibrate. Alternatively 
equilibration may be verified by injecting samples of calibration gas at 
1-hour intervals. The permeation tubes can be assumed to have reached 
equilibrium when consecutive hourly samples agree within the precision 
limits of Section 4.1.
    Vary the amount of air flowing over the tubes to produce the desired 
concentrations for calibrating the analytical and dilution systems. The 
air flow across the tubes must at all times exceed the flow requirement 
of the analytical systems. The concentration in

[[Page 947]]

parts per million generated by a tube containing a specific permeant can 
be calculated as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.189

Where:

C=Concentration of permeant produced in ppm.
Pr=Permeation rate of the tube in g/min.
M=Molecular weight of the permeant (g/g-mole).
L=Flow rate, 1/min, of air over permeant @ 20  deg.C, 760 mm Hg.
K=Gas constant at 20  deg.C and 760 mm Hg=24.04 1/g mole.
    8.3  Calibration of Analysis System. Generate a series of three or 
more known concentrations spanning the linear range of the FPD 
(approximately 0.5 to 10 ppm for a 1-ml sample) for each of the four 
major sulfur compounds. Inject these standards into the GC/FPD analyzer 
and monitor the responses. Three injects for each concentration must not 
vary by more than 5 percent from the mean of the three injections. 
Failure to attain this precision is an indication of a problem in the 
calibration or analytical system. Any such problem must be identified 
and corrected before proceeding.
    8.4  Calibration Curves. Plot the GC/FPD response in current 
(amperes) versus their causative concentrations in ppm on log-log 
coordinate graph paper for each sulfur compound. Alternatively, a least 
squares equation may be generated from the calibration data. 
Alternatively, a least squares equation may be generated from the 
calibration data using concentrations versus the appropriate instrument 
response units.

9. Sampling and Analysis Procedure

    9.1  Sampling. Insert the sampling probe into the test port making 
certain that no dilution air enters the stack through the port. Begin 
sampling. Condition the entire system with sample for a minimum of 15 
minutes prior to commencing analysis.
    9.2  Analysis. Aliquots of sample are injected into the GC/FPD 
analyzer for analysis.
    9.2.1  Sample Run. A sample run is composed of 16 individual 
analyses (injects) performed over a period of not less than 3 hours or 
more than 6 hours.
    9.2.2  Observation for Clogging of Probe or Filter. If reductions in 
sample concentrations are observed during a sample run that cannot be 
explained by process conditions, the sampling must be interrupted to 
determine if the probe or filter is clogged with particulate matter. If 
either is found to be clogged, the test must be stopped and the results 
up to that point discarded. Testing may resume after cleaning or 
replacing the probe and filter. After each run, the probe and filter 
shall be inspected and, if necessary, replaced.

10. Post-Test Procedures

    10.1  Sample line loss. A known concentration of hydrogen sulfide at 
the level of the applicable standard, 20 percent, must be 
introduced into the sampling system at the opening of the probe in 
sufficient quantities to ensure that there is an excess of sample which 
must be vented to the atmosphere. The sample must be transported through 
the entire sampling system to the measurement system in the normal 
manner. (See figure 16-1). The resulting measured concentration should 
be compared to the known value to determine the sampling system loss.
    For sampling losses greater than 20 percent in a sample run, the 
sample run is not to be used when determining the arithmetic mean of the 
performance test. For sampling losses of 0-20 percent, the sample 
concentration must be corrected by dividing the sample concentration by 
the fraction of recovery. The fraction of recovery is equal to one minus 
the ratio of the measured concentration to the known concentration of 
hydrogen sulfide in the sample line loss procedure. The known gas sample 
may be generated using permeation tubes. Alternatively, cylinders of 
hydrogen sulfide mixed in nitrogen and certified according to section 
6.7 may be used. The optional pretest procedures provide a good 
guideline for determining if there are leaks in the sampling system.

[[Page 948]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.204

    10.2  Recalibration. After each run, or after a series of runs made 
within a 24-hour period, perform a partial recalibration using the 
procedures in Section 8. Only H2S (or other calibration gas) 
need be used to recalibrate the GC/FPD analysis system (Section 8.3).
    10.3  Determination of Calibration Drift. Compare the calibration 
curves obtained prior to the runs, to the calibration curves obtained 
under Section 10.2. The calibration drift should not exceed the limits 
set forth in Section 4.2. If the drift exceeds this limit, the 
intervening run or runs should be considered not valid. The tester, 
however, may instead have the option of choosing the calibration data 
set which would give the highest sample values.

11. Calculations

    11.1  Determine the concentrations of each reduced sulfur compound 
detected directly from the calibration curves. Alternatively, the 
concentrations may be calculated using the equation for the least 
squares line.
    11.2 Calculation of TRS. Total reduced sulfur will be determined for 
each analysis made by summing the concentrations of each reduced sulfur 
compound resolved during a given analysis.
TRS= (H2S, MeSH, DMS, 2DMDS)d
                                                                Eq. 16-2
Where:

TRS=Total reduced sulfur in ppm, dry basis.
H2S=Hydrogen sulfide, ppm.
MeSH=Methyl mercaptan, ppm.
DMS=Dimethyl sulfide, ppm.
DMDS=Dimethyl disulfide, ppm.
d=Dilution factor, dimensionless.
    11.3  Average TRS. The average TRS will be determined as follows:
    [GRAPHIC] [TIFF OMITTED] TC16NO91.190
    
Where:

Average TRS=Average total reduced sulfur in ppm, dry basis.
TRSi=Total reduced sulfur in ppm as determined by Equation 
          16-2.
N=Number of samples.
Bwo=Fraction of volume of water vapor in the gas stream as 
          determined by reference Method 4--Determination of Moisture in 
          Stack Gases.
    11.4 Average Concentration of Individual Reduced Sulfur Compounds.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.191
    

[[Page 949]]


Where:

Si=Concentration of any reduced sulfur compound from the ith 
          sample injection, ppm.
C=Average concentration of any one of the reduced sulfur compounds for 
          the entire run, ppm.
N=Number of injections in any run period.

12. Bibliography

    12.1  O'Keeffe, A. E. and G. C. Ortman. ``Primary Standards for 
Trace Gas Analysis.'' Analytical Chemical Journal, 38,760 (1966).
    12.2  Stevens, R. K., A. E. O'Keeffe, and G. C. Ortman. ``Absolute 
Calibration of a Flame Photometric Detector to Volatile Sulfur Compounds 
at Sub-Part-Per-Million Levels.'' Environmental Science and Technology, 
3:7 (July, 1969).
    12.3  Mulik, J. D., R. K. Stevens, and R. Baumgardner. ``An 
Analytical System Designed to Measure Multiple Malodorous Compounds 
Related to Kraft Mill Activities.'' Presented at the 12th Conference on 
Methods in Air Pollution and Industrial Hygiene Studies, University of 
Southern California, Los Angeles, CA. April 6-8, 1971.
    12.4  Devonald, R. H., R. S. Serenius, and A. D. McIntyre. 
``Evaluation of the Flame Photometric Detector for Analysis of Sulfur 
Compounds.'' Pulp and Paper Magazine of Canada, 73,3 (March, 1972).
    12.5  Grimley, K. W., W. S. Smith, and R. M. Martin. ``The Use of a 
Dynamic Dilution System in the Conditioning of Stack Gases for Automated 
Analysis by a Mobile Sampling Van.'' Presented at the 63rd Annual APCA 
Meeting in St. Louis, MO. June 14-19, 1970.
    12.6  General Reference. Standard Methods of Chemical Analysis 
Volume III A and B Instrumental Methods. Sixth Edition. Van Nostrand 
Reinhold Co.

    Method 16A--Determination of Total Reduced Sulfur Emissions From 
                 Stationary Sources (Impinger Technique)

1. Applicability, Principle, Interferences, Precision, and Bias

    1.1  Applicability. This method is applicable to the determination 
of total reduced sulfur (TRS) emissions from recovery boilers, lime 
kilns, and smelt dissolving tanks at kraft pulp mills, and from other 
sources when specified in an applicable subpart of the regulations. The 
TRS compounds include hydrogen sulfide, methyl mercaptan, dimethyl 
sulfide, and dimethyl disulfide.
    The flue gas must contain at least 1 percent oxygen for complete 
oxidation of all TRS to sulfur dioxide (SO2). The lower 
detectable limit is 0.1 ppm SO2 when sampling at 2 liters/min 
for 3 hours or 0.3 ppm when sampling at 2 liters/min for 1 hour. The 
upper concentration limit of the method exceeds TRS levels generally 
encountered at kraft pulp mills.
    1.2  Principle. An integrated gas sample is extracted from the 
stack. SO2 is removed selectively from the sample using a 
citrate buffer solution. TRS compounds are then thermally oxidized to 
SO2, collected in hydrogen peroxide as sulfate, and analyzed 
by the Method 6 barium-thorin titration procedure.
    1.3  Interferences. TRS compounds other than those regulated by the 
emission standards, if present, may be measured by this method. 
Therefore, carbonyl sulfide, which is partially oxidized to 
SO2 and may be present in a lime kiln exit stack, would be a 
positive interferent.
    Particulate matter from the lime kiln stack gas (primarily calcium 
carbonate) can cause a negative bias if it is allowed to enter the 
citrate scrubber; the particulate matter will cause the pH to rise and 
H2S to be absorbed prior to oxidation. Furthermore, if the 
calcium carbonate enters the hydrogen peroxide impingers, the calcium 
will precipitate sulfate ion. Proper use of the particulate filter 
described in Section 2.1.3 will eliminate this interference.
    1.4  Precision and Bias. Relative standard deviations of 2.0 and 2.6 
percent were obtained when sampling a recovery boiler for 1 and 3 hours, 
respectively.
    In a separate study at a recovery boiler, Method 16A was found to be 
unbiased relative to Method 16. Comparison of Method 16A with Method 16 
at a lime kiln indicated that there was no bias in Method 16A. However, 
instability of the source emissions adversely affected the comparison. 
The precision of Method 16A at the lime kiln was similar to that 
obtained at the recovery boiler.
    Relative standard deviations of 2.7 and 7.7 percent have been 
obtained for system performance checks.

2. Apparatus

    2.1  Sampling. The sampling train is shown in Figure 16A-1 and 
component parts are discussed below. Modifications to this sampling 
train are acceptable provided the system performance check (Section 4.3) 
is met.

[[Page 950]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.205

    2.1.1  Probe. Teflon (mention of trade names or specific products 
does not constitute endorsement by the U.S. Environmental Protection 
Agency) tubing, 0.6-cm (\1/4\-in.) diameter, sequentially wrapped with 
heat-resistant fiber strips, a rubberized heat tape (plug at one end), 
and heat-resistant adhesive tape. A flexible thermocouple or other 
suitable temperature measuring device should be placed between the 
Teflon tubing and the fiber strips so that the temperature can be 
monitored to prevent softening of the probe. The probe should be 
sheathed in stainless steel to provide in-stack rigidity. A series of 
bored-out stainless steel fittings placed at the front of the sheath 
will prevent moisture and particulate from entering between the probe 
and sheath. A 0.6-cm (\1/4\-in.) Teflon elbow (bored out) should be 
attached to the inlet of the probe, and a 2.54-cm (1-in.) piece of 
Teflon tubing should be attached at the open end of the elbow to permit 
the opening of the probe to be turned away from the particulate stream; 
this will reduce the amount of particulate drawn into the sampling 
train. The sampling probe is depicted in Figure 16A-2.
[GRAPHIC] [TIFF OMITTED] TC01JN92.206


[[Page 951]]


    2.1.2  Probe Brush. Nylon bristle brush with handle inserted into a 
3.2-mm (\1/8\-in.) Teflon tubing. The Teflon tubing should be long 
enough to pass the brush through the length of the probe.
    2.1.3  Particulate Filter. 50-mm Teflon filter holder and a 1- to 2-
 porosity, Teflon filter (available through Savillex 
Corporation, 5325 Highway 101, Minnetonka, Minnesota 55343). The filter 
holder must be maintained in a hot box at a temperature sufficient to 
prevent moisture condensation. A temperature of 121  deg.C (250  deg.F) 
was found to be sufficient when testing a lime kiln under sub-freezing 
ambient conditions.
    2.1.4  SO2 Scrubber. Three 300-ml Teflon segmented 
impingers connected in series with flexible, thick-walled, Teflon 
tubing. (Impinger parts and tubing available through Savillex.) The 
first two impingers contain 100 ml of citrate buffer and the third 
impinger is initially dry. The tip of the tube inserted into the 
solution should be constricted to less than 3 mm (\1/8\ in.) ID and 
should be immersed to a depth of at least 5 cm (2 in.).
    2.1.5  Combustion Tube. Quartz glass tubing with an expanded 
combustion chamber 2.54 cm (1 in.) in diameter and at least 30.5 cm (12 
in.) long. The tube ends should have an outside diameter of 0.6 cm (\1/
4\ in.) and be at least 15.3 cm (6 in.) long. This length is necessary 
to maintain the quartz-glass connector at ambient temperature and 
thereby avoid leaks. Alternatively, the outlet may be constructed with a 
90-degree glass elbow and socket that would fit directly onto the inlet 
of the first peroxide impinger.
    2.1.6  Furnace. A furnace of sufficient size to enclose the 
combustion chamber of the combustion tube with a temperature regulator 
capable of maintaining the temperature at 800100  deg.C. The 
furnace operating temperature should be checked with a thermocouple to 
ensure accuracy.
    2.1.7  Peroxide Impingers, Stopcock Grease, Thermometer, Drying 
Tube, Valve, Pump, Barometer, and Vacuum Gauge. Same as in Method 6, 
Sections 2.1.2, 2.1.4, 2.1.6, 2.1.7, 2.1.8, 2.1.11, and 2.1.12, 
respectively.
    2.1.8  Rate Meter. Rotameter, or equivalent, accurate to within 5 
percent at the selected flow rate of 2 liters/min.
    2.1.9  Volume Meter. Dry gas meter capable of measuring the sample 
volume under the sampling conditions of 2 liters/min with an accuracy of 
2 percent.
    2.1.10  Polyethylene Bottles. 250-ml bottles for hydrogen peroxide 
solution recovery.
    2.2  Sample Preparation and Analysis. Same as in Method 6, Section 
2.3, except a 10-ml buret with 0.05-ml graduations is required and the 
spectrophotometer is not needed.

3. Reagents

    Unless otherwise indicated, all reagents must conform to the 
specifications established by the Committee on Analytical Reagents of 
the American Chemical Society. When such specifications are not 
available, the best available grade shall be used.
    3.1  Sampling. The following reagents are needed:
    3.1.1  Water. Same as in Method 6, Section 3.1.1.
    3.1.2  Citrate Buffer. 300 g of potassium citrate (or 284 g of 
sodium citrate) and 41 g of anhydrous citric acid dissolved in 1 liter 
of water (200 ml is needed per test). Adjust the pH to between 5.4 and 
5.6 with potassium citrate or citric acid, as required.
    3.1.3  Hydrogen Peroxide, 3 percent. Same as in Method 6, Section 
3.1.3 (40 ml is needed per sample).
    3.1.4  Recovery Check Gas. Hydrogen sulfide (100 ppm or less) in 
nitrogen, stored in aluminum cylinders. Verify the concentration by 
Method 11 or by gas chromatography where the instrument is calibrated 
with an H2S permeation tube as described below. For Method 
11, the standard deviation should not exceed 5 percent on at least three 
20-minute runs.
    Alternatively, hydrogen sulfide recovery gas generated from a 
permeation device gravimetrically calibrated and certified at some 
convenient operating temperature may be used. The permeation rate of the 
device must be such that at a dilution gas flow rate of 3 liters/min, an 
H2S concentration in the range of the stack gas or within 20 
percent of the standard can be generated.
    3.1.5  Combustion Gas. Gas containing less than 50 ppb reduced 
sulfur compounds and less than 10 ppm total hydrocarbons. The gas may be 
generated from a clean-air system that purifies ambient air and consists 
of the following components: Diaphragm pump, silica gel drying tube, 
activated charcoal tube, and flow rate measuring device. Flow from a 
compressed air cylinder is also acceptable.
    3.2  Sample Recovery and Analysis. Same as in Method 6, Sections 
3.2.1 and 3.3.

4. Procedure

    4.1  Sampling. Before any source sampling is done, conduct two 30-
minute system performance checks in the field as detailed in Section 4.3 
to validate the sampling train components and procedure (optional).
    4.1.1  Preparation of Collection Train. For the SO2 
scrubber, measure 100 ml of citrate buffer into the first and second 
impingers; leave the third impinger empty. Immerse the impingers in an 
ice bath, and locate them as close as possible to the filter heat box. 
The connecting tubing should be free of loops. Maintain the probe and 
filter temperatures sufficiently high to prevent moisture condensation, 
and monitor with a suitable temperature indicator.
    For the Method 6 part of the train, measure 20 ml of 3 percent 
hydrogen peroxide into

[[Page 952]]

the first and second midget impingers. Leave the third midget impinger 
empty, and place silica gel in the fourth midget impinger. 
Alternatively, a silica gel drying tube may be used in place of the 
fourth impinger. Maintain the oxidation furnace at 800100 
deg.C. Place crushed ice and water around all impingers.
    4.1.2  Citrate Scrubber Conditioning Procedure. Condition the 
citrate buffer scrubbing solution by pulling stack gas through the 
Teflon impingers and bypassing all other sampling train components. A 
purge rate of 2 liters/min for 10 minutes has been found to be 
sufficient to obtain equilibrium. After the citrate scrubber has been 
conditioned, assemble the sampling train, and conduct (optional) a leak-
check as described in Method 6, Section 4.1.2.
    4.1.3  Sample Collection. Same as in Method 6, Section 4.1.3, except 
the sampling rate is 2 liters/min ( 10 percent) for 1 or 3 
hours. After the sample is collected, remove the probe from the stack, 
and conduct (mandatory) a post-test leak check as described in Method 6, 
Section 4.1.2. The 15-minute purge of the train following collection 
should not be performed. After each 3-hour test run (or after three 1-
hour samples), conduct one system performance check (see Section 4.3) to 
determine the reduced sulfur recovery efficiency through the sampling 
train. After this system performance check and before the next test run, 
rinse and brush the probe with water, replace the filter, and change the 
citrate scrubber (recommended but optional).
    In Method 16, a test run is composed of 16 individual analyses 
(injects) performed over a period of not less than 3 hours or more than 
6 hours. For Method 16A to be consistent with Method 16, the following 
may be used to obtain a test run: (1) collect three 60-minute samples or 
(2) collect one 3-hour sample. (Three test runs constitute a test.)
    4.2  Sample Recovery. Disconnect the impingers. Quantitatively 
transfer the contents of the midget impingers of the Method 6 part of 
the train into a leak-free polyethylene bottle for shipment. Rinse the 
three midget impingers and the connecting tubes with water and add the 
washings to the same storage container. Mark the fluid level. Seal and 
identify the sample container.
    4.3  System Performance Check. A system performance check is done 
(1) to validate the sampling train components and procedure (prior to 
testing; optional) and (2) to validate a test run (after a run). Perform 
a check in the field prior to testing consisting of a least two samples 
(optional), and perform an additional check after each 3-hour run or 
after three 1-hour samples (mandatory).
    The checks involve sampling a known concentration of H2S 
and comparing the analyzed concentration with the known concentration. 
Mix the H2S recovery gas (Section 3.1.4) and combustion gas 
in a dilution system such as is shown in Figure 16A-3. Adjust the flow 
rates to generate an H2S concentration in the range of the 
stack gas or within 20 percent of the applicable standard and an oxygen 
concentration greater than 1 percent at a total flow rate of at least 
2.5 liters/min. Use Equation 16A-3 to calculate the concentration of 
recovery gas generated. Calibrate the flow rate from both sources with a 
soap bubble flow tube so that the diluted concentration of 
H2S can be accurately calculated. Collect 30-minute samples, 
and analyze in the normal manner (as discussed in Section 4.1.3). 
Collect the sample through the probe of the sampling train using a 
manifold or some other suitable device that will ensure extraction of a 
representative sample.

[[Page 953]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.207

    The recovery check must be performed in the field prior to replacing 
the SO2 scrubber and particulate filter and before the probe 
is cleaned. A sample recovery of 100 20 percent must be 
obtained for the data to be valid and should be reported with the 
emission data, but should not be used to correct the data. However, if 
the performance check results do not affect the compliance or 
noncompliance status of the affected facility, the Administrator may 
decide to accept the results of the compliance test. Use Equation 16A-4 
to calculate the recovery efficiency.
    4.4  Sample Analysis. Same as in Method 6, Section 4.3, except for 
1-hour sampling, take a 40-ml aliquot, add 160 ml of 100 percent 
isopropanol, and four drops of thorin. Analyze an EPA SO2 
field audit sample with each set of samples. Such audit samples are 
available from the Source Branch, Quality Assurance Division, 
Environmental Monitoring Systems Laboratory, U. S. Environmental 
Protection Agency, Research Triangle Park, North Carolina 27711.

5. Calibration

    5.1  Metering System, Thermometers, Rotameters, Barometers, and 
Barium Perchlorate Solution. Calibration procedures are presented in 
Method 6, Sections 5.1 through 5.5.

6. Calculations


[[Page 954]]


    In the calculations, at least one extra decimal figure should be 
retained beyond that of the acquired data. Figures should be rounded off 
after final calculations.
    6.1  Nomenclature.

CTRS=Concentration of TRS as SO2, dry basis 
          corrected to standard conditions, ppm.
CRG=Concentration of recovery gas generated, ppm.
CH2S=Verified concentration of H2S recovery gas.
N=Normality of barium perchlorate titrant, milliequivalents/ml.
Pbar=Barometric pressure at exit orifice of the dry gas 
          meter, mm Hg (in. Hg).
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
QH2S=Calibrated flow rate of H2S recovery gas, 
          liters/min.
QCG=Calibrated flow rate of combustion gas, liters/min.
R=Recovery efficiency for the system performance check, percent.
Tm=Average dry gas meter absolute temperature,  deg.K 
          ( deg.R).
Tstd=Standard absolute temperature, 293  deg.K, (528  deg.R).
Va=Volume of sample aliquot titrated, ml.
Vm=Dry gas volume as measured by the dry gas meter, liters 
          (dcf).
Vm(std)=Dry gas volume measured by the dry gas meter, 
          corrected to standard conditions, liters (dscf).
Vsoln=Total volume of solution in which the sulfur dioxide 
          sample is contained, 100 ml.
Vt=Volume of barium perchlorate titrant used for the sample, 
          ml (average of replicate titrations).
Vtb=Volume of barium perchlorate titrant used for the blank, 
          ml.
Y=Dry gas meter calibration factor.
32.03=Equivalent weight of sulfur dioxide, mg/meq.
    6.2  Dry Sample Gas Volume, Corrected to Standard Conditions.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.194
    
Where: K1=0.3858  deg.K/mm Hg for metric units.

    6.3 Concentration of TRS as ppm SO2.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.195
    
Where:
[GRAPHIC] [TIFF OMITTED] TC16NO91.192

    6.4  Concentration of Recovery Gas Generated in the System 
Performance Check.
[GRAPHIC] [TIFF OMITTED] TC16NO91.193

    6.5  Recovery Efficiency for the System Performance Check.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.196
    
7. Alternative Procedures
    7.1  Determination of H2S Content in Cylinder Gases. As 
an alternative to the procedures specified in section 3.1.4, the 
following procedure may be used to verify the concentration of the 
recovery check gas. The H2S is collected from the calibration 
gas cylinder and is absorbed in zinc acetate solution to form zinc 
sulfide. The latter compound is then measured iodometrically. The method 
has been examined in the range of 5 to 1500 ppm. There are no known 
interferences to this method when used to analyze cylinder gases 
containing H2S in nitrogen. Laboratory tests have shown a 
relative standard deviation of less than 3 percent. The method showed no 
bias when compared to a gas chromatographic method that used 
gravimetrically certified permeation tubes for calibration.

[[Page 955]]

    7.1.1  Sampling Apparatus. The sampling train is shown in Figure 
16A-4 and consists of the following components:
[GRAPHIC] [TIFF OMITTED] TC01JN92.208


[[Page 956]]


    7.1.1.1  Sampling Line. Teflon tubing (\1/4\-in.) to connect the 
cylinder regulator to the sampling valve.
    7.1.1.2  Needle Valve. Stainless steel or Teflon needle valve to 
control the flow rate of gases to the impingers.
    7.1.1.3  Impingers. Three impingers of approximately 100-ml 
capacity, constructed to permit the addition of reagents through the gas 
inlet stem. The impingers shall be connected in series with leak-free 
glass or Teflon connectors. The impinger bottoms have a standard \24/25\ 
ground-glass fitting. The stems are from standard \1/4\-in. (0.64-cm) 
ball joint midget impingers, custom lengthened by about 1 in. When 
fitted together, the stem end should be approximately \1/2\ in. (1.27-
cm) from the bottom (Southern Scientific, Inc., Micanopy, Florida: Set 
Number S6962-048). The third in-line impinger acts as a drop-out bottle.
    7.1.1.4  Drying Tube, Flowmeter, and Barometer. Same as in Method 
11, Sections 5.1.5, 5.1.8, and 5.1.10.
    7.1.1.5  Cylinder Gas Regulator. Stainless steel, to reduce the 
pressure of the gas stream entering the Teflon sampling line to a safe 
level.
    7.1.1.6  Soap Bubble Meter. Calibrated for 100 and 500 ml, or two 
separate bubble meters.
    7.1.1.7  Critical Orifice. For volume and rate measurements. The 
critical orifice may be fabricated according to Section 7.1.4.3 and must 
be calibrated as specified in Section 7.1.8.4.
    7.1.1.8  Graduated Cylinder. 50-ml size.
    7.1.1.9  Volumetric Flask. 1-liter size.
    7.1.1.10  Volumetric Pipette. 15-ml size.
    7.1.1.11  Vacuum Gauge. Minimum 20-in. Hg capacity.
    7.1.1.12  Stopwatch.
    7.1.2  Sample Recovery and Analysis Apparatus.
    7.1.2.1  Erlenmeyer Flasks. 125- and 250-ml sizes.
    7.1.2.2  Pipettes. 2-, 10-, 20-, and 100-ml volumetric.
    7.1.2.3  Burette. 50-ml size.
    7.1.2.4  Volumetric Flask. 1-liter size.
    7.1.2.5  Graduated Cylinder. 50-ml size.
    7.1.2.6  Wash Bottle.
    7.1.2.7  Stirring Plate and Bars.
    7.1.3  Reagents. Unless otherwise indicated, all reagents shall 
conform to the specifications established by the Committee on Analytical 
Reagents of the American Chemical Society, where such specifications are 
available. Otherwise, use the best available grade.
    7.1.3.1  Water. Same as in Method 11, Section 6.1.3.
    7.1.3.2  Zinc Acetate Absorbing Solution. Dissolve 20 g zinc acetate 
in water and dilute to 1 liter.
    7.1.3.3  Potassium Bi-iodate [KH(IO3)2 
Solution, Standard 0.100 N. Dissolve 3.249 g anhydrous 
KH(IO3)2 in water, and dilute to 1 liter.
    7.1.3.4  Sodium Thiosulfate 
(Na2S203) Solution, Standard 0.1 N. 
Same as in Method 11, Section 6.3.1. Standardize according to Section 
7.1.8.2.
    7.1.3.5  Na2S203 Solution, Standard 
0.01 N. Pipette 100.0 ml of 0.1 N 
Na2S203 solution into a 1-liter 
volumetric flask, and dilute to the mark with water.
    7.1.3.6  Iodine Solution, 0.1 N. Same as in Method 11, Section 
6.2.2.
    7.1.3.7  Standard Iodine Solution, 0.01 N. Same as in Method 11, 
Section 6.2.3. Standardize according to Section 7.1.8.3.
    7.1.3.8  Hydrochloric Acid (HCl) Solution, 10 Percent by Weight. Add 
230 ml concentrated HCl (specific gravity 1.19) to 770 ml water.
    7.1.3.9  Starch Indicator Solution. To 5 g starch (potato, 
arrowroot, or soluble), add a little cold water, and grind in a mortar 
to a thin paste. Pour into 1 liter of boiling water, stir, and let 
settle overnight. Use the clear supernatant. Preserve with 1.25 g 
salicylic acid, 4 g zinc chloride, or a combination of 4 g sodium 
propionate and 2 g sodium azide per liter of starch solution. Some 
commercial starch substitutes are satisfactory.
    7.1.4  Sampling Procedure.
    7.1.4.1  Selection of Gas Sample Volumes. This procedure has been 
validated for estimating the volume of cylinder gas sample needed when 
the H2S concentration is in the range of 5 to 1500 ppm. The 
sample volume ranges were selected in order to ensure a 35 to 60 percent 
consumption of the 20 ml of 0.01 N iodine (thus ensuring a 0.01 N 
Na2S2O3 titer of approximately 7 to 12 
ml). The sample volumes for various H2S concentrations can be 
estimated by dividing the approximate ppm-liters desired for a given 
concentration range by the H2S concentration stated by the 
manufacturer.

------------------------------------------------------------------------
                                                             Approximate
      Approximate cylinder gas H2S concentration (ppm)        ppm-liters
                                                               desired
------------------------------------------------------------------------
5 to <30...................................................          650
30 to <500.................................................          800
500 to <1500...............................................         1000
------------------------------------------------------------------------

    For example, for analyzing a cylinder gas containing approximately 
10 ppm H2S, the optimum sample volume is 65 liters (650 ppm-
liters/10 ppm). For analyzing a cylinder gas containing approximately 
1000 ppm H2S, the optimum sample volume is 1 liter (1000 ppm-
liters/1000 ppm).
    7.1.4.2  Critical Orifice Flow Rate Selection. The following table 
shows the ranges of sample flow rates that are desirable in order to 
ensure capture of H2S in the impinger solution. Slight 
deviations from these ranges will not have an impact on measured 
concentrations.

[[Page 957]]



------------------------------------------------------------------------
                                                             Critical
          Cylinder gas H2S concentration (ppm)             orifice flow
                                                           rate (ml/min)
------------------------------------------------------------------------
5 to <50 ppm............................................     1500  500
50 to <250 ppm..........................................      500  250
250 to <1000 ppm........................................      200  50
1000 ppm................................................       75  25
------------------------------------------------------------------------

    7.1.4.3  Critical Orifice Fabrication. Critical orifice of desired 
flow rates may be fabricated by selecting an orifice tube of desired 
length and connecting \1/16\-in. x \1/4\-in. (0.16-cm x 0.64-cm) 
reducing fittings to both ends. The inside diameters and lengths of 
orifice tubes needed to obtain specific flow rates are shown below.

------------------------------------------------------------------------
                                                         Flow
                                        Tube    Length   rate    Altech
            Tube (in. OD)               (in.    (in.)    (ml/    catalog
                                         ID)             min)    No.\1\
------------------------------------------------------------------------
1/16.................................   0.007      1.2      85    301430
1/16.................................   0.01       3.2     215    300530
1/16.................................   0.01       1.2     350    300530
1/16.................................   0.02       1.2    1400    300230
------------------------------------------------------------------------
\1\ Altech Associates, 2051 Waukegon Road., Deerfield, Illinois 60015.

    7.1.4.4  Determination of Critical Orifice Approximate Flow Rate. 
Connect the critical orifice to the sampling system as shown in Figure 
16A-4 but without the H2S cylinder. Connect a rotameter in 
the line to the first impinger. Turn on the pump, and adjust the valve 
to give a reading of about half atmospheric pressure. Observe the 
rotameter reading. Slowly increase the vacuum until a stable flow rate 
is reached, and record this as the critical vacuum. The measured flow 
rate indicates the expected critical flow rate of the orifice. If this 
flow rate is in the range shown in Section 7.1.4.2, proceed with the 
critical orifice calibration according to Section 7.1.8.4.
    7.1.4.5  Determination of Approximate Sampling Time. Determine the 
approximate sampling time for a cylinder of known concentration. Use the 
optimum sample volume obtained in Section 7.1.4.1.
[GRAPHIC] [TIFF OMITTED] TC16NO91.197

    7.1.4.6  Sample Collection. Connect the Teflon tubing, Teflon tee, 
and rotameter to the flow control needle valve as shown in Figure 16A-4. 
Vent the rotameter to an exhaust hood. Plug the open end of the tee. 
Five to 10 minutes prior to sampling, open the cylinder valve while 
keeping the flow control needle valve closed. Adjust the delivery 
pressure to 20 psi. Open the needle valve slowly until the rotameter 
shows a flow rate approximately 50 to 100 ml above the flow rate of the 
critical orifice being used in the system.
    Place 50 ml of zinc acetate solution in two of the impingers, 
connect them and the empty third impinger (dropout bottle) and the rest 
of the equipment as shown in Figure 16A-4. Make sure the ground-glass 
fittings are tight. The impingers can be easily stabilized by using a 
small cardboard box in which three holes have been cut, to act as a 
holder. Connect the Teflon sample line to the first impinger. Cover the 
impingers with a dark cloth or piece of plastic to protect the absorbing 
solution from light during sampling.
    Record the temperature and barometric pressure. Note the gas flow 
rate through the rotameter. Open the closed end of the tee. Connect the 
sampling tube to the tee, ensuring a tight connection. Start the 
sampling pump and stopwatch simultaneously. Note the decrease in flow 
rate through the excess flow rotameter. This decrease should equal the 
known flow rate of the critical orifice being used. Continue sampling 
for the period determined in Section 7.1.4.5.
    When sampling is complete, turn off the pump and stopwatch. 
Disconnect the sampling line from the tee and plug it. Close the needle 
valve followed by the cylinder valve. Record the sampling time.
    7.1.5  Blank Analysis. While the sample is being collected, run a 
blank as follows: To a 250-ml Erlenmeyer flask, add 100 ml of zinc 
acetate solution, 20.0 ml. 0.01 N iodine solution, and 2 ml HCl 
solution. Titrate, while stirring, with 0.01 N 
Na2S203 until the solution is light 
yellow. Add starch, and continue titrating until the blue color 
disappears. Analyze a blank with each sample, as the blank titer has 
been observed to change over the course of a day.
    Note: Iodine titration of zinc acetate solutions is difficult to 
perform because the solution turns slightly white in color near the end 
point, and the disappearance of the blue color is hard to recognize. In 
addition, a blue color may reappear in the solution about 30 to 45 
seconds after the titration endpoint is reached. This should not be 
taken to mean the original endpoint was in error. It is recommended that 
persons conducting this test

[[Page 958]]

perform several titrations to be able to correctly identify the 
endpoint. The importance of this should be recognized because the 
results of this analytical procedure are extremely sensitive to errors 
in titration.
    7.1.6  Sample Analysis. Sample treatment is similar to the blank 
treatment. Before detaching the stems from the bottoms of the impingers, 
add 20.0 ml of 0.01 N iodine solution through the stems of the impingers 
holding the zinc acetate solution, dividing it between the two (add 
about 15 ml to the first impinger and the rest to the second). Add 2 ml 
HCl solution through the stems, dividing it as with the iodine. 
Disconnect the sampling line, and store the impingers for 30 minutes. At 
the end of 30 minutes, rinse the impinger stems into the impinger 
bottoms. Titrate the impinger contents with 0.01 N 
Na2S203. Do not transfer the contents 
of the impinger to a flask because this may result in a loss of iodine 
and cause a positive bias.
    7.1.7  Post-test Orifice Calibration. Conduct a post-test critical 
orifice calibration run using the calibration procedures outlined in 
Section 7.1.8.4. If the Qstd obtained before and after the 
test differs by more than 5 percent, void the sample; if not, proceed to 
perform the calculations.
    7.1.8  Calibrations and Standardizations.
    7.1.8.1  Rotameter and Barometer. Same as in Method 11, Sections 
8.2.3 and 8.2.4.
    7.1.8.2  Na2S2O3 Solution, 0.1 N. 
Standardize the 0.1 N Na2S2O3 solution 
as follows: To 80 ml water, stirring constantly, add 1 ml concentrated 
H2SO4, 10.0 ml 0.100 N 
KH(IO3)2 and 1 g potassium iodide. Titrate 
immediately with 0.1 N Na2S2O3 until 
the solution is light yellow. Add 3 ml starch solution, and titrate 
until the blue color just disappears. Repeat the titration until 
replicate analyses agree within 0.05 ml. Take the average volume of 
Na2S2O3 consumed to calculate the 
normality to three decimal figures using Equation 16A-5.
    7.1.8.3  Iodine Solution, 0.01 N. Standardize the 0.01 N iodine 
solution as follows: Pipet 20.0 ml of 0.01 N iodine solution into a 125-
ml Erlenmeyer flask. Titrate with standard 0.01 N 
Na2S2O3 solution until the solution is 
light yellow. Add 3 ml starch solution, and continue titrating until the 
blue color just disappears.
    If the normality of the iodine tested is not 0.010, add a few ml of 
0.1 N iodine solution if it is low, or a few ml of water if it is high, 
and standardize again. Repeat the titration until replicate values agree 
within 0.05 ml. Take the average volume to calculate the normality to 
three decimal figures using Equation 16A-6.
    7.1.8.4  Critical Orifice. Calibrate the critical orifice using the 
sampling train shown in Figure 16A-4 but without the H2S 
cylinder and vent rotameter. Connect the soap bubble meter to the Teflon 
line that is connected to the first impinger. Turn on the pump, and 
adjust the needle valve until the vaccum is higher than the critical 
vacuum determined in Section 7.1.4.4. Record the time required for gas 
flow to equal the soap bubble meter volume (use the 100-ml soap bubble 
meter for gas flow rates below 100 ml/min, otherwise use the 500-ml soap 
bubble meter). Make three runs, and record the data listed in Table 1. 
Use these data to calculate the volumetric flow rate of the orifice.
    7.1.9  Calculations.
    7.1.9.1  Nomenclature.

Bwa=Fraction of water vapor in ambient air during orifice 
          calibration.
CH2S=H2S concentration in cylinder gas, ppm.
[GRAPHIC] [TIFF OMITTED] TC16NO91.198

Ma=Molecular weight of ambient air saturated at impinger 
          temperature, g/g-mole.
Ms=Molecular weight of sample gas (nitrogen) saturated at 
          impinger temperature, g/g-mole. (For tests carried out in a 
          laboratory where the impinger temperature is 25  deg.C, 
          Ma=28.5 g/g-mole and Ms=27.7 g/g-mole.)
NI=Normality of standard iodine solution (0.01 N), g-eq/
          liter.
NT=Normality of standard 
          Na2S2O3 solution (0.01 N), g-
          eq/liter.
Pbar=Barometric pressure, mm Hg.
Pstd=Standard absolute pressure, 760 mm Hg.
Qstd=Volumetric flow rate through critical orifice, liters/
          min.

Date____________________

Critical orifice ID____________________

Soap bubble meter volume, Vsb ______ liters
Time, sb
    Run no. 1 ______ min ______ sec
    Run no. 2 ______ min ______ sec
    Run no. 3 ______ min ______ sec
      Average ______ min ______ sec
    Convert the seconds to fraction of minute:
Time
    = ______ min + ______ Sec/60
    = ______ min

[[Page 959]]

Barometric pressure, Pbar = ______ mm Hg
Ambient temperature, tamb = 273 + ______  deg.C
         = ______  deg.K
Pump vacuum, = ______ mm Hg. (This should be approximately 0.4 times 
barometric pressure.)
[GRAPHIC] [TIFF OMITTED] TC16NO91.199

[GRAPHIC] [TIFF OMITTED] TC16NO91.200


Table 1--Critical orifice calibration data.

Qstd, average= Average standard flow rate through critical 
          orifice, liters/min.
Qstd, before= Average standard flow rate through critical 
          orifice determined before H2S sampling (Section 
          7.1.4.4), liters/min.
Qstd, after= Average standard flow rate through critical 
          orifice determined after H2S sampling (Section 
          7.1.7), liters/min.
Tamb = Absolute ambient temperature,  deg.K.
Tstd = Standard absolute temperature, 293  deg.K.
s = Sampling time, min.
sb = Time for soap bubble meter flow rate 
          measurement, min.
Vm(std) = Sample gas volume measured by the critical orifice, 
          corrected to standard conditions, liters.
Vsb = Volume of gas as measured by the soap bubble meter, ml.
Vsb(std) = Volume of gas as measured by the soap bubble 
          meter, corrected to standard conditions, liters.
VI = Volume of standard iodine solution (0.01 N) used, ml.
VT = Volume of standard 
          Na2S2O3 solution (0.01 N) 
          used, ml.
VTB = Volume of standard 
          Na2S2O3 solution (0.01 N) 
          used for the blank, ml.
    7.1.9.2  Normality of Standard 
Na2S2O3 Solution (0.1. N).
[GRAPHIC] [TIFF OMITTED] TC16NO91.201

    7.1.9.3  Normality of Standard Iodine Solution (0.01 N).
    [GRAPHIC] [TIFF OMITTED] TC16NO91.202
    
    7.1.9.4  Sample Gas Volume.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.203
    
    7.1.9.5  Concentration of H2S in the Gas Cylinder.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.204
    

                             8. Bibliography

    1. American Public Health Association, American Water Works 
Association, and Water Pollution Control Federation. Standard Methods 
for the Examination of Water and Wastewater. Washington, DC. American 
Public Health Association. 1975. p. 316-317.
    2. American Society for Testing and Materials. Annual Book of ASTM 
Standards. Part 31: Water, Atmospheric Analysis. Philadelphia, PA. 1974. 
p. 40-42.
    3. Blosser, R.O. A Study of TRS Measurement Methods. National 
Council of the Paper Industry for Air and Stream Improvement, Inc., New 
York, NY. Technical Bulletin No. 434. May 1984. 14 p.
    4. Blosser, R.O., H.S. Oglesby, and A.K. Jain. A Study of Alternate 
SO2 Scrubber Designs Used for TRS Monitoring. A Special 
Report by the National Council of the Paper Industry for Air and Stream 
Improvement, Inc., New York, NY. July 1977.
    5. Curtis, F., and G.D. McAlister. Development and Evaluation of an 
Oxidation/Method 6 TRS Emission Sampling Procedure. Emission Measurement 
Branch, Emission Standards and Engineering Division, U.S. Environmental 
Protection Agency, Research Triangle Park, NC 27711. February 1980.
    6. Gellman, I. A Laboratory and Field Study of Reduced Sulfur 
Sampling and Monitoring Systems. National Council of the Paper Industry 
for Air and Stream Improvement, Inc., New York, NY. Atmospheric Quality 
Improvement Technical Bulletin No. 81. October 1975.
    7. Margeson, J.H., J.E. Knoll, and M.R. Midgett. A Manual Method for 
TRS Determination. Draft Available from the authors. Source Branch, 
Quality Assurance Division, U.S. Environmental Protection Agency, 
Research Triangle Park, NC 27711.
    8. National Council of the Paper Industry for Air and Stream 
Improvement. An Investigation of H2S and SO2 
Calibration Cylinder Gas Stability and Their Standardization

[[Page 960]]

Using Wet Chemical Techniques. Special Report 76-06. New York, NY. 
August 1976.
    9. National Council of the Paper Industry for Air and Stream 
Improvement. Wet Chemical Method for Determining the H2S 
Concentration of Calibration Cylinder Gases. Technical Bulletin Number 
450. New York, NY. January 1985. 23 p.
    10. National Council of the Paper Industry for Air and Stream 
Improvement. Modified Wet Chemcial Method for Determining the 
H2S Concentration of Calibration Cylinder Gases. Draft 
Report. New York, NY. March 1987. 29 p.

    Method 16B--Determination of Total Reduced Sulfur Emissions From 
                           Stationary Sources

1. Applicability, Principle, Range and Sensitivity, Interferences, and 
Precision and Accuracy
    1.1  Applicability. This method is applicable to the determination 
of total reduced sulfur (TRS) emissions from recovery furnaces, lime 
kilns, and smelt dissolving tanks at kraft pulp mills, and from other 
sources when specified in an applicable subpart of the regulations. The 
TRS compounds include hydrogen sulfide (H2S), methyl 
mercaptan, dimethyl sulfide, and dimethyl disulfide.
    The flue gas must contain at least 1 percent oxygen for complete 
oxidation of all TRS to sulfur dioxide (SO2).
    1.2  Principle. An integrated gas sample is extracted from the 
stack. The SO2 is removed selectively from the sample using a 
citrate buffer solution. The TRS compounds are then thermally oxidized 
to SO2 and analyzed as SO2 by gas chromatography 
(GC) using flame photometric detection (FPD).
    1.3  Range and Sensitivity. Coupled with a GC utilizing a 1-ml 
sample size, the maximum limit of the FPD for SO2 is 
approximately 10 ppm. This limit is expanded by dilution of the sample 
gas before analysis or by reducing the sample aliquot size. For sources 
with emission levels between 10 and 100 ppm, the measuring range can be 
best extended by reducing the sample size.
    1.4  Interferences. The TRS compounds other than those regulated by 
the emission standards, if present, may be measured by this method. 
Therefore, carbonyl sulfide, which is partially oxidized to 
SO2 and may be present in a lime kiln exit stack, would be a 
positive interferent.
    Particulate matter from the lime kiln stack gas (primarily calcium 
carbonate) can cause a negative bias if it is allowed to enter the 
citrate scrubber; the particulate matter will cause the pH to rise and 
H2S to be absorbed before oxidation. Proper use of the 
particulate filter, described in Section 2.1.3 of Method 16A, will 
eliminate this interference.
    Carbon monoxide (CO) and carbon dioxide (CO2) have 
substantial desensitizing effects on the FPD even after dilution. 
Acceptable systems must demonstrate that they have eliminated this 
interference by some procedure such as eluting these compounds before 
the SO2. Compliance with this requirement can be demonstrated 
by submitting chromatograms of calibration gases with and without 
CO2 in diluent gas. The CO2 level should be 
approximately 10 percent for the case with CO2 present. The 
two chromatograms should show agreement within the precision limits of 
Section 1.5.
    1.5  Precision and Accuracy. The GC/FPD and dilution calibration 
precision and drift, and the system calibration accuracy are the same as 
in Method 16, Sections 4.1 to 4.3.
    Field tests between this method and Method 16A showed an average 
difference of less than 4.0 percent. This difference was not determined 
to be significant.
2. Apparatus
    2.1 Sampling. A sampling train is shown in Figure 16B-1. 
Modifications to the apparatus are accepted provided the system 
performance check is met.

[[Page 961]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.209

    2.1.1  Probe, Probe Brush, Particulate Filter, SO2 
Scrubber, Combustion Tube, and Furnace. Same as in Method 16A, Sections 
2.1.1 to 2.1.6.
    2.1.2  Sampling Pump. Leakless Teflon-coated diaphragm type or 
equivalent.
    2.2  Analysis.
    2.2.1  Dilution System (optional), Gas Chromatograph, Oven, 
Temperature Gauges, Flow System, Flame Photometric Detector, 
Electrometer, Power Supply, Recorder, Calibration System, Tube Chamber, 
Flow System, and Constant Temperature Bath. Same as in Method 16, 
Sections 5.2, 5.4, and 5.5.
    2.2.2  Gas Chromatograph Columns. Same as in Method 16, Section 
12.1.4.1.1. Other columns with demonstrated ability to resolve 
SO2 and be free from known interferences are acceptable 
alternatives.
3. Reagents
    Same as in Method 16, Section 6, except the following:
    3.1  Calibration Gas. SO2 permeation tube gravimetrically 
calibrated and certified at some convenient operating temperature. These 
tubes consist of hermetically sealed FEP Teflon tubing in which a 
liquefied gaseous substance is enclosed. The enclosed gas permeates 
through the tubing wall at a constant rate. When the temperature is 
constant, calibration gases covering a wide range of known 
concentrations can be generated by varying and accurately measuring the 
flow rate of diluent gas passing over the tubes. In place of 
SO2 permeation tubes, National Bureau of Standards traceable 
cylinder gases containing SO2 in nitrogen may be used for 
calibration. The calibration gas is used to calibrate the GC/FPD system 
and the dilution system.
    3.2  Recovery Check Gas. Hydrogen sulfide (100 ppm or less) in 
nitrogen, stored in aluminum cylinders. Verify the concentration by 
Method 11, the procedure discussed in Section 7.1 of Method 16A, or gas 
chromatography where the instrument is calibrated with an H2S 
permeation tube as described below. For the wet-chemical methods, the 
standard deviation should not exceed 5 percent on at least three 20-
minute runs.
    Hydrogen sulfide recovery gas generated from a permeation device 
gravimetically calibrated and certified at some convenient operation 
temperature may be used. The permeation rate of the device must be such 
that at a dilution gas flow rate of 3 liters/min, an H2S 
concentration in the range of the stack gas or within 20 percent of the 
standard can be generated.
    3.3  Combustion Gas. Gas containing less than 50 ppb reduced sulfur 
compounds and less than 10 ppm total hydrocarbons. The gas may be 
generated from a clean-air system that purifies ambient air and consists 
of the following components: diaphragm pump, silica gel drying tube, 
activated charcoal tube, and flow rate measuring device. Gas from a 
compressed air cylinder is also acceptable.
4. Pretest Procedures
    Same as in Method 16, Section 7.
5. Calibration
    Same as in Method 16, Section 8, except SO2 is used 
instead of H2S.
6. Sampling and Analysis Procedure

[[Page 962]]

    6.1  Sampling. Before any source sampling is done, conduct a system 
performance check as detailed in Section 7.1 to validate the sampling 
train components and procedures. Although this test is optional, it 
would significantly reduce the possibility of rejecting tests as a 
result of failing the post-test performance check. At the completion of 
the pretest system performance check, insert the sampling probe into the 
test port making certain that no dilution air enters the stack through 
the port. Condition the entire system with sample for a minimum of 15 
minutes before beginning analysis. If the sample is diluted, determine 
the precise dilution factor as in Section 8.5 of Method 16.
    6.2  Analysis. Pass aliquots of diluted sample through the 
SO2 scrubber and oxidation furnace, and then inject into the 
GC/FPD analyzer for analysis. The rest of the analysis is the same as in 
Method 16, Sections 9.2.1 and 9.2.2.
7. Post-Test Procedures
    7.1  System Performance Check. Same as in Method 16A, Section 4.3. 
Sufficient numbers of sample injections should be made so that the 
precision requirements of Section 4.1 of Method 16 are satisfied.
    7.2  Recalibration. Same as in Method 16, Section 10.2.
    7.3  Determination of Calibration Drift. Same as in Method 16, 
Section 10.3.
8. Calculations
    8.1  Nomenclature.

CSO2 = Sulfur dioxide concentration, ppm.
CTRS = Total reduced sulfur concentration as determined by 
          Equation 16B-1, ppm.
d = Dilution factor, dimensionless.
N = Number of samples.
    8.2  SO2 Concentration. Determine the concentration of 
SO2 (CSO2) directly from the calibration curves. 
Alternatively, the concentration may be calculated using the equation 
for the least-squares line.
    8.3  TRS Concentration.

    CTRS = (CSO2) (d)
                                                               Eq. 16B-1
    8.4  Average TRS Concentration.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.210
    
9. Example System
    Same as in Method 16, Section 12. Single column systems using the 
column in Section 12.1.4.1.1 of Method 16 or a 7-ft Carbosorb B HT 100 
column have been found satisfactory in resolving SO2 from 
CO2.
10. Bibliography
    1. Same as in Method 16, Sections 13.1 to 13.6.
    2. National Council of the Paper Industry for Air and Stream 
Improvement, Inc. A Study of TRS Measurement Methods. Technical Bulletin 
No. 434. New York, NY. May 1984. 12 p.
    3. Margeson, J.H., J.E. Knoll, and M.R. Midgett. A Manual Method for 
TRS Determination. Draft available from the authors. Source Branch, 
Quality Assurance Division, U.S. Environmental Protection Agency, 
Research Triangle Park, NC 27711.

   Method 17--Determination of Particulate Emissions From Stationary 
                  Sources (In-stack Filtration Method)

Introduction

    Particulate matter is not an absolute quantity; rather, it is a 
function of temperature and pressure. Therefore, to prevent variability 
in particulate matter emission regulations and/or associated test 
methods, the temperature and pressure at which particulate matter is to 
be measured must be carefully defined. Of the two variables (i.e., 
temperature and pressure), temperature has the greater effect upon the 
amount of particulate matter in an effluent gas stream; in most 
stationary source categories, the effect of pressure appears to be 
negligible.
    In Method 5, 250  deg.F is established as a nominal reference 
temperature. Thus, where Method 5 is specified in an applicable subpart 
of the standards, particulate matter is defined with respect to 
temperature. In order to maintain a collection temperature of 250 
deg.F, Method 5 employs a heated glass sample probe and a heated filter 
holder. This equipment is somewhat cumbersome and requires care in its 
operation. Therefore, where particulate matter concentrations (over the 
normal range of temperature associated with a specified source category) 
are known to be independent of temperature, it is desirable to eliminate 
the glass probe and heating systems, and sample at stack temperature.
    This method describes an in-stack sampling system and sampling 
procedures for use in such cases. It is intended to be used only when 
specified by an applicable subpart of the standards, and only within the 
applicable temperature limits (if specified), or when otherwise approved 
by the Administrator.

1. Principle and Applicability

    1.1  Principle. Particulate matter is withdrawn isokinetically from 
the source and collected on a glass fiber filter maintained at stack 
temperature. The particulate mass is determined gravimetrically after 
removal of uncombined water.
    1.2  Applicability. This method applies to the determination of 
particulate emissions from stationary sources for determining compliance 
with new source performance standards, only when specifically provided 
for in an applicable subpart of the standards. This method is not 
applicable to stacks that contain liquid droplets or are saturated with 
water vapor. In addition, this method shall

[[Page 963]]

not be used as written if the projected cross-sectional area of the 
probe extension-filter holder assembly covers more than 5 percent of the 
stack cross-sectional area (see Section 4.1.2).

2. Apparatus

    2.1  Sampling Train. A schematic of the sampling train used in this 
method is shown in Figure 17-1. Construction details for many, but not 
all, of the train components are given in APTD-0581 (Citation 2 in 
Bibliography); for changes from the APTD-0581 document and for allowable 
modifications to Figure 17-1, consult with the Administrator.
[GRAPHIC] [TIFF OMITTED] TC01JN92.211


[[Page 964]]


    The operating and maintenance procedures for many of the sampling 
train components are described in APTD-0576 (Citation 3 in 
Bibliography). Since correct usage is important in obtaining valid 
results, all users should read the APTD-0576 document and adopt the 
operating and maintenance procedures outlined in it, unless otherwise 
specified herein. The sampling train consists of the following 
components:
    2.1.1  Probe Nozzle. Stainless steel (316) or glass, with sharp, 
tapered leading edge. The angle of taper shall be 30 deg. and the taper 
shall be on the outside to preserve a constant internal diameter. The 
probe nozzle shall be of the button-hook or elbow design, unless 
otherwise specified by the Administrator. If made of stainless steel, 
the nozzle shall be constructed from seamless tubing. Other materials of 
construction may be used subject to the approval of the Administrator.
    A range of sizes suitable for isokinetic sampling should be 
available, e.g., 0.32 to 1.27 cm (\1/8\ to \1/2\ in.)--or larger if 
higher volume sampling trains are used--inside diameter (ID) nozzles in 
increments of 0.16 cm (\1/16\ in.). Each nozzle shall be calibrated 
according to the procedures outlined in Section 5.1.
    2.1.2  Filter Holder. The in-stack filter holder shall be 
constructed of borosilicate or quartz glass, or stainless steel; if a 
gasket is used, it shall be made of silicone rubber, Teflon, or 
stainless steel. Other holder and gasket materials may be used subject 
to the approval of the Administrator. The filter holder shall be 
designed to provide a positive seal against leakage from the outside or 
around the filter.
    2.1.3  Probe Extension. Any suitable rigid probe extension may be 
used after the filter holder.
    2.1.4  Pitot Tube. Type S, as described in Section 2.1 of Method 2, 
or other device approved by the Administrator; the pitot tube shall be 
attached to the probe extension to allow constant monitoring of the 
stack gas velocity (see Figure 17-1). The impact (high pressure) opening 
plane of the pitot tube shall be even with or above the nozzle entry 
plane during sampling (see Method 2, Figure 2-6b). It is recommended: 
(1) that the pitot tube have a known baseline coefficient, determined as 
outlined in Section 4 of Method 2; and (2) that this known coefficient 
be preserved by placing the pitot tube in an interference-free 
arrangement with respect to the sampling nozzle, filter holder, and 
temperature sensor (see Figure 17-1). Note that the 1.9 cm (0.75 in.) 
free-space between the nozzle and pitot tube shown in Figure 17-1, is 
based on a 1.3 cm (0.5 in.) ID nozzle. If the sampling train is designed 
for sampling at higher flow rates than that described in APTD-0581, thus 
necessitating the use of larger sized nozzles, the free-space shall be 
1.9 cm (0.75 in.) with the largest sized nozzle in place.
    Source-sampling assemblies that do not meet the minimum spacing 
requirements of Figure 17-1 (or the equivalent of these requirements, 
e.g., Figure 2-7 of Method 2) may be used; however, the pitot tube 
coefficients of such assemblies shall be determined by calibration, 
using methods subject to the approval of the Administrator.
    2.1.5  Differential Pressure Gauge. Inclined manometer or equivalent 
device (two), as described in Section 2.2 of Method 2. One manometer 
shall be used for velocity head ( p) readings, and the other, 
for orifice differential pressure readings.
    2.1.6  Condenser. It is recommended that the impinger system 
described in Method 5 be used to determine the moisture content of the 
stack gas. Alternatively, any system that allows measurement of both the 
water condensed and the moisture leaving the condenser, each to within 1 
ml or 1 g, may be used. The moisture leaving the condenser can be 
measured either by: (1) monitoring the temperature and pressure at the 
exit of the condenser and using Dalton's law of partial pressures; or 
(2) passing the sample gas stream through a silica gel trap with exit 
gases kept below 20  deg.C (68  deg.F) and determining the weight gain.
    Flexible tubing may be used between the probe extension and 
condenser. If means other than silica gel are used to determine the 
amount of moisture leaving the condenser, it is recommended that silica 
gel still be used between the condenser system and pump to prevent 
moisture condensation in the pump and metering devices and to avoid the 
need to make corrections for moisture in the metered volume.
    2.1.7  Metering System. Vacuum gauge, leak-free pump, thermometers 
capable of measuring temperature to within 3  deg.C (5.4  deg.F), dry 
gas meter capable of measuring volume to within 2 percent, and related 
equipment, as shown in Figure 17-1. Other metering systems capable of 
maintaining sampling rates within 10 percent of isokinetic and of 
determining sample volumes to within 2 percent may be used, subject to 
the approval of the Administrator. When the metering system is used in 
conjunction with a pitot tube, the system shall enable checks of 
isokinetic rates.
    Sampling trains utilizing metering systems designed for higher flow 
rates than that described in APTD-0581 or APTD-0576 may be used provided 
that the specifications of this method are met.
    2.1.8  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg). In many 
cases, the barometric reading may be obtained from a nearby National 
Weather Service station, in which case the station value (which is the 
absolute barometric pressure) shall be requested and an adjustment for 
elevation differences between

[[Page 965]]

the weather station and sampling point shall be applied at a rate of 
minus 2.5 mm Hg (0.1 in. Hg) per 30 m (100 ft) elevation increase or 
vice versa for elevation decrease.
    2.1.9  Gas Density Determination Equipment. Temperature sensor and 
pressure gauge, as described in Sections 2.3 and 2.4 of Method 2, and 
gas analyzer, if necessary, as described in Method 3.
    The temperature sensor shall be attached to either the pitot tube or 
to the probe extension, in a fixed configuration. If the temperature 
sensor is attached in the field, the sensor shall be placed in an 
interference-free arrangement with respect to the Type S pitot tube 
openings (as shown in Figure 17-1 or in Figure 2-7 of Method 2). 
Alternatively, the temperature sensor need not be attached to either the 
probe extension or pitot tube during sampling, provided that a 
difference of not more than 1 percent in the average velocity 
measurement is introduced. This alternative is subject to the approval 
of the Administrator.
    2.2  Sample Recovery.
    2.2.1  Probe Nozzle Brush. Nylon bristle brush with stainless steel 
wire handle. The brush shall be properly sized and shaped to brush out 
the probe nozzle.
    2.2.2  Wash Bottles--Two. Glass wash bottles are recommended; 
polyethylene wash bottles may be used at the option of the tester. It is 
recommended that acetone not be stored in polyethylene bottles for 
longer than a month.
    2.2.3  Glass Sample Storage Containers. Chemically resistant, 
borosilicate glass bottles, for acetone washes, 500 ml or 1000 ml. Screw 
cap liners shall either be rubber-backed Teflon or shall be constructed 
so as to be leak-free and resistant to chemical attack by acetone. 
(Narrow mouth glass bottles have been found to be less prone to 
leakage.) Alternatively, polyethylene bottles may be used.
    2.2.4  Petri Dishes. For filter samples; glass or polyethylene, 
unless otherwise specified by the Administrator.
    2.2.5  Graduated Cylinder and/or Balance. To measure condensed water 
to within 1 ml or 1 g. Graduated cylinders shall have subdivisions no 
greater than 2 ml. Most laboratory balances are capable of weighing to 
the nearest 0.5 g or less. Any of these balances is suitable for use 
here and in Section 2.3.4.
    2.2.6  Plastic Storage Containers. Air tight containers to store 
silica gel.
    2.2.7  Funnel and Rubber Policeman. To aid in transfer of silica gel 
to container; not necessary if silica gel is weighed in the field.
    2.2.8  Funnel. Glass or polyethylene, to aid in sample recovery.
    2.3  Analysis.
    2.3.1  Glass Weighing Dishes.
    2.3.2  Desiccator.
    2.3.3  Analytical Balance. To measure to within 0.1 mg.
    2.3.4  Balance. To measure to within 0.5 mg.
    2.3.5  Beakers. 250 ml.
    2.3.6  Hygrometer. To measure the relative humidity of the 
laboratory environment.
    2.3.7  Temperature Gauge. To measure the temperature of the 
laboratory environment.

3. Reagents

    3.1  Sampling.
    3.1.1  Filters. The in-stack filters shall be glass mats or thimble 
fiber filters, without organic binders, and shall exhibit at least 99.95 
percent efficiency (0.05 percent penetration) on 0.3 micron dioctyl 
phthalate smoke particles. The filter efficiency tests shall be 
conducted in accordance with ASTM Standard Method D2986-71 (Reapproved 
1978) (incorporated by reference--see Sec. 60.17). Test data from the 
supplier's quality control program are sufficient for this purpose.
    3.1.2  Silica Gel. Indicating type, 6- to 16-mesh. If previously 
used, dry at 175  deg.C (350  deg.F) for 2 hours. New silica gel may be 
used as received. Alternatively, other types of desiccants (equivalent 
or better) may be used, subject to the approval of the Administrator.
    3.1.3  Crushed Ice.
    3.1.4  Stopcock Grease. Acetone-insoluble, heat-stable silicone 
grease. This is not necessary if screw-on connectors with Teflon 
sleeves, or similar, are used. Alternatively, other types of stopcock 
grease may be used, subject to the approval of the Administrator.
    3.1.5  Water. Same as in Method 5, section 3.1.3.
    3.2  Sample Recovery. Acetone, reagent grade, 0.001 percent residue, 
in glass bottles. Acetone from metal containers generally has a high 
residue blank and should not be used. Sometimes, suppliers transfer 
acetone to glass bottles from metal containers. Thus, acetone blanks 
shall be run prior to field use and only acetone with low blank values ( 
0.001 percent) shall be used. In no case shall a blank value of greater 
than 0.001 percent of the weight of acetone used be subtracted from the 
sample weight.
    3.3  Analysis.
    3.3.1  Acetone. Same as 3.2.
    3.3.2  Desiccant. Anhydrous calcium sulfate, indicating type. 
Alternatively, other types of desiccants may be used, subject to the 
approval of the Administrator.

4. Procedure

    4.1  Sampling. The complexity of this method is such that, in order 
to obtain reliable results, testers should be trained and experienced 
with the test procedures.
    4.1.1  Pretest Preparation. All components shall be maintained and 
calibrated according to the procedure described in APTD-0576, unless 
otherwise specified herein.
    Weigh several 200 to 300 g portions of silica gel in air-tight 
containers to the nearest 0.5 g. Record the total weight of the silica 
gel

[[Page 966]]

plus container, on each container. As an alternative, the silica gel 
need not be preweighed, but may be weighed directly in its impinger or 
sampling holder just prior to train assembly.
    Check filters visually against light for irregularities and flaws or 
pinhole leaks. Label filters of the proper size on the back side near 
the edge using numbering machine ink. As an alternative, label the 
shipping containers (glass or plastic petri dishes) and keep the filters 
in these containers at all times except during sampling and weighing.
    Desiccate the filters at 20plus-minus5.6  deg.C 
(68plus-minus10  deg.F) and ambient pressure for at least 24 
hours and weigh at intervals of at least 6 hours to a constant weight, 
i.e., 0.5 mg change from previous weighing; record results to the 
nearest 0.1 mg. During each weighing the filter must not be exposed to 
the laboratory atmosphere for a period greater than 2 minutes and a 
relative humidity above 50 percent. Alternatively (unless otherwise 
specified by the Administrator), the filters may be oven dried at 105 
deg.C (220  deg.F) for 2 to 3 hours, desiccated for 2 hours, and 
weighed. Procedures other than those described, which account for 
relative humidity effects, may be used, subject to the approval of the 
Administrator.
    4.1.2  Preliminary Determinations. Select the sampling site and the 
minimum number of sampling points according to Method 1 or as specified 
by the Administrator. Make a projected-area model of the probe 
extension-filter holder assembly, with the pitot tube face openings 
positioned along the centerline of the stack, as shown in Figure 17-2. 
Calculate the estimated cross-section blockage, as shown in Figure 17-2. 
If the blockage exceeds 5 percent of the duct cross sectional area, the 
tester has the following options: (1) a suitable out-of-stack filtration 
method may be used instead of in-stack filtration; or (2) a special in-
stack arrangement, in which the sampling and velocity measurement sites 
are separate, may be used; for details concerning this approach, consult 
with the Administrator (see also Citation 10 in Bibliography). Determine 
the stack pressure, temperature, and the range of velocity heads using 
Method 2; it is recommended that a leak-check of the pitot lines (see 
Method 2, Section 3.1) be performed. Determine the moisture content 
using Approximation Method 4 or its alternatives for the purpose of 
making isokinetic sampling rate settings. Determine the stack gas dry 
molecular weight, as described in Method 2, Section 3.6; if integrated 
Method 3 sampling is used for molecular weight determination, the 
integrated bag sample shall be taken simultaneously with, and for the 
same total length of time as, the particulate sample run.

[[Page 967]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.212

    Select a nozzle size based on the range of velocity heads, such that 
it is not necessary to change the nozzle size in order to maintain 
isokinetic sampling rates. During the run, do not change the nozzle 
size. Ensure that the proper differential pressure gauge is chosen for 
the range of velocity heads encountered (see Section 2.2 of Method 2).
    Select a probe extension length such that all traverse points can be 
sampled. For large stacks, consider sampling from opposite

[[Page 968]]

sides of the stack to reduce the length of probes.
    Select a total sampling time greater than or equal to the minimum 
total sampling time specified in the test procedures for the specific 
industry such that (1) the sampling time per point is not less than 2 
minutes (or some greater time interval if specified by the 
Administrator), and (2) the sample volume taken (corrected to standard 
conditions) will exceed the required minimum total gas sample volume. 
The latter is based on an approximate average sampling rate.
    It is recommended that the number of minutes sampled at each point 
be an integer or an integer plus one-half minute, in order to avoid 
timekeeping errors.
    In some circumstances, e.g., batch cycles, it may be necessary to 
sample for shorter times at the traverse points and to obtain smaller 
gas sample volumes. In these cases, the Administrator's approval must 
first be obtained.
    4.1.3  Preparation of Collection Train. During preparation and 
assembly of the sampling train, keep all openings where contamination 
can occur covered until just prior to assembly or until sampling is 
about to begin.
    If impingers are used to condense stack gas moisture, prepare them 
as follows: place 100 ml of water in each of the first two impingers, 
leave the third impinger empty, and transfer approximately 200 to 300 g 
of preweighed silica gel from its container to the fourth impinger. More 
silica gel may be used, but care should be taken to ensure that it is 
not entrained and carried out from the impinger during sampling. Place 
the container in a clean place for later use in the sample recovery. 
Alternatively, the weight of the silica gel plus impinger may be 
determined to the nearest 0.5 g and recorded.
    If some means other than impingers is used to condense moisture, 
prepare the condenser (and, if appropriate, silica gel for condenser 
outlet) for use.
    Using a tweezer or clean disposable surgical gloves, place a labeled 
(identified) and weighed filter in the filter holder. Be sure that the 
filter is properly centered and the gasket properly placed so as not to 
allow the sample gas stream to circumvent the filter. Check filter for 
tears after assembly is completed. Mark the probe extension with heat 
resistant tape or by some other method to denote the proper distance 
into the stack or duct for each sampling point.
    Assemble the train as in Figure 17-1, using a very light coat of 
silicone grease on all ground glass joints and greasing only the outer 
portion (see APTD-0576) to avoid possibility of contamination by the 
silicone grease. Place crushed ice around the impingers.
    4.1.4  Leak Check Procedures.
    4.1.4.1  Pretest Leak-Check. A pretest leak-check is recommended, 
but not required. If the tester opts to conduct the pretest leak-check, 
the following procedure shall be used.
    After the sampling train has been assembled, plug the inlet to the 
probe nozzle with a material that will be able to withstand the stack 
temperature. Insert the filter holder into the stack and wait 
approximately 5 minutes (or longer, if necessary) to allow the system to 
come to equilibrium with the temperature of the stack gas stream. Turn 
on the pump and draw a vacuum of at least 380 mm Hg (15 in. Hg); note 
that a lower vacuum may be used, provided that it is not exceeded during 
the test. Determine the leakage rate. A leakage rate in excess of 4 
percent of the average sampling rate or 0.00057 m 3/min. 
(0.02 cfm), whichever is less, is unacceptable.
    The following leak-check instructions for the sampling train 
described in APTD-0576 and APTD-0581 may be helpful. Start the pump with 
by-pass valve fully open and coarse adjust valve completely closed. 
Partially open the coarse adjust valve and slowly close the by-pass 
valve until the desired vacuum is reached. Do not reverse direction of 
by-pass valve. If the desired vacuum is exceeded, either leak-check at 
this higher vacuum or end the leak-check as shown below and start over.
    When the leak-check is completed, first slowly remove the plug from 
the inlet to the probe nozzle and immediately turn off the vacuum pump. 
This prevents water from being forced backward and keeps silica gel from 
being entrained backward.
    4.1.4.2  Leak-Checks During Sample Run. If, during the sampling run, 
a component (e.g., filter assembly or impinger) change becomes 
necessary, a leak-check shall be conducted immediately before the change 
is made. The leak-check shall be done according to the procedure 
outlined in Section 4.1.4.1 above, except that it shall be done at a 
vacuum equal to or greater than the maximum value recorded up to that 
point in the test. If the leakage rate is found to be no greater than 
0.00057 m3/min (0.02 cfm) or 4 percent of the average 
sampling rate (whichever is less), the results are acceptable, and no 
correction will need to be applied to the total volume of dry gas 
metered; if, however, a higher leakage rate is obtained, the tester 
shall either record the leakage rate and plan to correct the sample 
volume as shown in Section 6.3 of this method, or shall void the 
sampling run.
    Immediately after component changes, leak-checks are optional; if 
such leak-checks are done, the procedure outlined in Section 4.1.4.1 
above shall be used.
    4.1.4.3  Post-Test Leak-Check. A leak-check is mandatory at the 
conclusion of each sampling run. The leak-check shall be done in 
accordance with the procedures outlined

[[Page 969]]

in Section 4.1.4.1, except that it shall be conducted at a vacuum equal 
to or greater than the maximum value reached during the sampling run. If 
the leakage rate is found to be no greater than 0.00057 m3/
min (0.02 cfm) or 4 percent of the average sampling rate (whichever is 
less), the results are acceptable, and no correction need be applied to 
the total volume of dry gas metered. If, however, a higher leakage rate 
is obtained, the tester shall either record the leakage rate and correct 
the sample volume as shown in Section 6.3 of this method, or shall void 
the sampling run.
    4.1.5  Particulate Train Operation. During the sampling run, 
maintain a sampling rate such that sampling is within 10 percent of true 
isokinetic, unless otherwise specified by the Administrator.
    For each run, record the data required on the example data sheet 
shown in Figure 17-3. Be sure to record the initial dry gas meter 
reading. Record the dry gas meter readings at the beginning and end of 
each sampling time increment, when changes in flow rates are made, 
before and after each leak check, and when sampling is halted. Take 
other readings required by Figure 17-3 at least once at each sample 
point during each time increment and additional readings when 
significant changes (20 percent variation in velocity head readings) 
necessitate additional adjustments in flow rate. Level and zero the 
manometer. Because the manometer level and zero may drift due to 
vibrations and temperature changes, make periodic checks during the 
traverse.

[[Page 970]]



                                       Figure 17-3--Particulate Field Data
 
                                  --------------------------------------
Plant............................                                        Barometric pressure..............  ....
Location.........................                                        Assumed moisture, %..............  ....
Operator.........................                                        Probe extension length, m (ft.)..  ....
Date.............................                                        Nozzle identification No.........  ....
Run No...........................                                        Average calibrated nozzle          ....
                                                                          diameter cm (in.).
Sample box No....................                                        Filter No........................  ....
Meter box No.....................                                        Leak rate, m\3\/min, (cfm).......  ....
Meter  H@...............                                        Static pressure, mm Hg (in. Hg)..  ....
C factor.                                                                                                   ....
Pitot tube coefficient, Cp.                                              .................................
                                  ---------------------------------------
                                     Schematic of Stack Cross Section


------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                                            Pressure                         Gas sample temperature at dry gas   Temperature of
                                                                          Stack         Velocity head     differential-      Gas sample                    meter                   gas leaving
     Traverse point number        Sampling time        Vacuum       temperature (TS)    ( P)    across orifice        volume      ------------------------------------   condenser or
                                                                                                              meter                               Inlet            Outlet         last impinger
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                (),     mm Hg (in. Hg)..    deg.C (         mm H20 (in H20).  mm H20 (in H20).  m\3\ (ft\3\)....    deg.C (           deg.C (           deg.C (
                                 min..                               deg.F).                                                                 deg.F).           deg.F).           deg.F)
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Total                                                                                                                                       Avg.              Avg.
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Average                                                                                                                                     Avg.


[[Page 971]]

    Clean the portholes prior to the test run to minimize the chance of 
sampling the deposited material. To begin sampling, remove the nozzle 
cap and verify that the pitot tube and probe extension are properly 
positioned. Position the nozzle at the first traverse point with the tip 
pointing directly into the gas stream. Immediately start the pump and 
adjust the flow to isokinetic conditions. Nomographs are available, 
which aid in the rapid adjustment to the isokinetic sampling rate 
without excessive computations. These nomographs are designed for use 
when the Type S pitot tube coefficient is 0.85plus-minus0.02, 
and the stack gas equivalent density (dry molecular weight) is equal to 
29plus-minus4. APTD-0576 details the procedure for using the 
nomographs. If Cp and Md are outside the above 
stated ranges, do not use the nomographs unless appropriate steps (see 
Citation 7 in Bibliography) are taken to compensate for the deviations.
    When the stack is under significant negative pressure (height of 
impinger stem), take care to close the coarse adjust valve before 
inserting the probe extension assembly into the stack to prevent water 
from being forced backward. If necessary, the pump may be turned on with 
the coarse adjust valve closed.
    When the probe is in position, block off the openings around the 
probe and porthole to prevent unrepresentative dilution of the gas 
stream.
    Traverse the stack cross section, as required by Method 1 or as 
specified by the Administrator, being careful not to bump the probe 
nozzle into the stack walls when sampling near the walls or when 
removing or inserting the probe extension through the portholes, to 
minimize chance of extracting deposited material.
    During the test run, take appropriate steps (e.g., adding crushed 
ice to the impinger ice bath) to maintain a temperature of less than 20 
deg.C (68  deg.F) at the condenser outlet; this will prevent excessive 
moisture losses. Also, periodically check the level and zero of the 
manometer.
    If the pressure drop across the filter becomes too high, making 
isokinetic sampling difficult to maintain, the filter may be replaced in 
the midst of a sample run. It is recommended that another complete 
filter holder assembly be used rather than attempting to change the 
filter itself. Before a new filter holder is installed, conduct a leak 
check, as outlined in Section 4.1.4.2. The total particulate weight 
shall include the summation of all filter assembly catches.
    A single train shall be used for the entire sample run, except in 
cases where simultaneous sampling is required in two or more separate 
ducts or at two or more different locations within the same duct, or, in 
cases where equipment failure necessitates a change of trains. In all 
other situations, the use of two or more trains will be subject to the 
approval of the Administrator. Note that when two or more trains are 
used, a separate analysis of the collected particulate from each train 
shall be performed, unless identical nozzle sizes were used on all 
trains, in which case the particulate catches from the individual trains 
may be combined and a single analysis performed.
    At the end of the sample run, turn off the pump, remove the probe 
extension assembly from the stack, and record the final dry gas meter 
reading. Perform a leak-check, as outlined in Section 4.1.4.3. Also, 
leak-check the pitot lines as described in Section 3.1 of Method 2; the 
lines must pass this leak-check, in order to validate the velocity head 
data.
    4.1.6  Calculation of Percent Isokinetic. Calculate percent 
isokinetic (see Section 6.11) to determine whether another test run 
should be made. If there is difficulty in maintaining isokinetic rates 
due to source conditions, consult with the Administrator for possible 
variance on the isokinetic rates.
    4.2  Sample Recovery. Proper cleanup procedure begins as soon as the 
probe extension assembly is removed from the stack at the end of the 
sampling period. Allow the assembly to cool.
    When the assembly can be safely handled, wipe off all external 
particulate matter near the tip of the probe nozzle and place a cap over 
it to prevent losing or gaining particulate matter. Do not cap off the 
probe tip tightly while the sampling train is cooling down as this would 
create a vacuum in the filter holder, forcing condenser water backward.
    Before moving the sample train to the cleanup site, disconnect the 
filter holder-probe nozzle assembly from the probe extension; cap the 
open inlet of the probe extension. Be careful not to lose any 
condensate, if present. Remove the umbilical cord from the condenser 
outlet and cap the outlet. If a flexible line is used between the first 
impinger (or condenser) and the probe extension, disconnect the line at 
the probe extension and let any condensed water or liquid drain into the 
impingers or condenser. Disconnect the probe extension from the 
condenser; cap the probe extension outlet. After wiping off the silicone 
grease, cap off the condenser inlet. Ground glass stoppers, plastic 
caps, or serum caps (whichever are appropriate) may be used to close 
these openings.
    Transfer both the filter holder-probe nozzle assembly and the 
condenser to the cleanup area. This area should be clean and protected 
from the wind so that the chances of contaminating or losing the sample 
will be minimized.
    Save a portion of the acetone used for cleanup as a blank. Take 200 
ml of this acetone directly from the wash bottle being

[[Page 972]]

used and place it in a glass sample container labeled ``acetone blank.''
    Inspect the train prior to and during disassembly and note any 
abnormal conditions. Treat the samples as follows:
    Container No. 1. Carefully remove the filter from the filter holder 
and place it in its identified petri dish container. Use a pair of 
tweezers and/or clean disposable surgical gloves to handle the filter. 
If it is necessary to fold the filter, do so such that the particulate 
cake is inside the fold. Carefully transfer to the petri dish any 
particulate matter and/or filter fibers which adhere to the filter 
holder gasket, by using a dry Nylon bristle brush and/or a sharp-edged 
blade. Seal the container.
    Container No. 2. Taking care to see that dust on the outside of the 
probe nozzle or other exterior surfaces does not get into the sample, 
quantitatively recover particulate matter or any condensate from the 
probe nozzle, fitting, and front half of the filter holder by washing 
these components with acetone and placing the wash in a glass container. 
Distilled water may be used instead of acetone when approved by the 
Administrator and shall be used when specified by the Administrator; in 
these cases, save a water blank and follow Administrator's directions on 
analysis. Perform the acetone rinses as follows:
    Carefully remove the probe nozzle and clean the inside surface by 
rinsing with acetone from a wash bottle and brushing with a Nylon 
bristle brush. Brush until acetone rinse shows no visible particles, 
after which make a final rinse of the inside surface with acetone.
    Brush and rinse with acetone the inside parts of the fitting in a 
similar way until no visible particles remain. A funnel (glass or 
polyethylene) may be used to aid in transferring liquid washes to the 
container. Rinse the brush with acetone and quantitatively collect these 
washings in the sample container. Between sampling runs, keep brushes 
clean and protected from contamination.
    After ensuring that all joints are wiped clean of silicone grease 
(if applicable), clean the inside of the front half of the filter holder 
by rubbing the surfaces with a Nylon bristle brush and rinsing with 
acetone. Rinse each surface three times or more if needed to remove 
visible particulate. Make final rinse of the brush and filter holder. 
After all acetone washings and particulate matter are collected in the 
sample container, tighten the lid on the sample container so that 
acetone will not leak out when it is shipped to the laboratory. Mark the 
height of the fluid level to determine whether or not leakage occurred 
during transport. Label the container to clearly identify its contents.
    Container No. 3. If silica gel is used in the condenser system for 
mositure content determination, note the color of the gel to determine 
if it has been completely spent; make a notation of its condition. 
Transfer the silica gel back to its original container and seal. A 
funnel may make it easier to pour the silica gel without spilling, and a 
rubber policeman may be used as an aid in removing the silica gel. It is 
not necessary to remove the small amount of dust particles that may 
adhere to the walls and are difficult to remove. Since the gain in 
weight is to be used for moisture calculations, do not use any water or 
other liquids to transfer the silica gel. If a balance is available in 
the field, follow the procedure for Container No. 3 under ``Analysis.''
    Condenser Water. Treat the condenser or impinger water as follows: 
make a notation of any color or film in the liquid catch. Measure the 
liquid volume to within plus-minus1 ml by using a graduated 
cylinder or, if a balance is available, determine the liquid weight to 
within plus-minus0.5 g. Record the total volume or weight of 
liquid present. This information is required to calculate the moisture 
content of the effluent gas. Discard the liquid after measuring and 
recording the volume or weight.
    4.3  Analysis. Record the data required on the example sheet shown 
in Figure 17-4. Handle each sample container as follows:
    Container No. 1. Leave the contents in the shipping container or 
transfer the filter and any loose particulate from the sample container 
to a tared glass weighing dish. Desiccate for 24 hours in a desiccator 
containing anhydrous calcium sulfate. Weigh to a constant weight and 
report the results to the nearest 0.1 mg. For purposes of this Section, 
4.3, the term ``constant weight'' means a difference of no more than 0.5 
mg or 1 percent of total weight less tare weight, whichever is greater, 
between two consecutive weighings, with no less than 6 hours of 
desiccation time between weighings.
    Alternatively, the sample may be oven dried at the average stack 
temperature or 105  deg.C (220  deg.F), whichever is less, for 2 to 3 
hours, cooled in the desiccator, and weighed to a constant weight, 
unless otherwise specified by the Administrator. The tester may also opt 
to oven dry the sample at the average stack temperature or 105  deg.C 
(220  deg.F), whichever is less, for 2 to 3 hours, weigh the sample, and 
use this weight as a final weight.

                      Figure 17-4--Analytical Data

 Plant__________________________________________________________________
 Date___________________________________________________________________
 Run No.________________________________________________________________
 Filter No._____________________________________________________________
 Amount liquid lost during transport____________________________________
 Acetone blank volume, ml_______________________________________________
 Acetone wash volume, ml________________________________________________
 Acetone blank concentration, mg/mg (Equation 17-4)_____________________
 Acetone wash blank, mg (Equation 17-5)

[[Page 973]]

________________________________________________________________________

----------------------------------------------------------------------------------------------------------------
                                                          Weight of particulate collected, mg
           Container number           --------------------------------------------------------------------------
                                             Final weight             Tare weight              Weight gain
----------------------------------------------------------------------------------------------------------------
1....................................
----------------------------------------------------------------------------------------------------------------
 
2....................................
----------------------------------------------------------------------------------------------------------------
 
  Total..............................
                                      --------------------------
 
    Less acetone blank...............
                                      --------------------------
    Weight of particulate matter.....
                                                                                        ------------------------


------------------------------------------------------------------------
                                     Volume of liquid water collected
                                 ---------------------------------------
                                   Impinger volume,   Silica gel weight,
                                          ml                   g
------------------------------------------------------------------------
Final...........................
Initial.........................
Liquid collected................
Total volume collected..........                        g*      ml
------------------------------------------------------------------------
*Convert weight of water to volume by dividing total weight increase by
  density of water (1 g/ml).


                Increase, g
                 ----------       =      Volume water, ml
                  (1 g/ml)
 

    Container No. 2. Note the level of liquid in the container and 
confirm on the analysis sheet whether or not leakage occurred during 
transport. If a noticeable amount of leakage has occurred, either void 
the sample or use methods, subject to the approval of the Administrator, 
to correct the final results. Measure the liquid in this container 
either volumetrically to plus-minus1 ml or gravimetrically to 
plus-minus0.5 g. Transfer the contents to a tared 250-ml 
beaker and evaporate to dryness at ambient temperature and pressure. 
Desiccate for 24 hours and weigh to a constant weight. Report the 
results to the nearest 0.1 mg.
    Container No. 3. This step may be conducted in the field. Weigh the 
spent silica gel (or silica gel plus impinger) to the nearest 0.5 g 
using a balance.
    ``Acetone Blank'' Container. Measure acetone in this container 
either volumetrically or gravimetrically. Transfer the acetone to a 
tared 250-ml beaker and evaporate to dryness at ambient temperature and 
pressure. Desiccate for 24 hours and weigh to a constant weight. Report 
the results to the nearest 0.1 mg.
    Note: At the option of the tester, the contents of Container No. 2 
as well as the acetone blank container may be evaporated at temperatures 
higher than ambient. If evaporation is done at an elevated temperature, 
the temperature must be below the boiling point of the solvent; also, to 
prevent ``bumping,'' the evaporation process must be closely supervised, 
and the contents of the beaker must be swirled occasionally to maintain 
an even temperature. Use extreme care, as acetone is highly flammable 
and has a low flash point.
5. Calibration

    Maintain a laboratory log of all calibrations.

    5.1  Probe Nozzle. Probe nozzles shall be calibrated before their 
initial use in the field. Using a micrometer, measure the inside 
diameter of the nozzle to the nearest 0.025 mm (0.001 in.). Make three 
separate measurements using different diameters each time, and obtain 
the average of the measurements. The difference between the high and low 
numbers shall not exceed 0.1 mm (0.004 in.). When nozzles become nicked, 
dented, or corroded, they shall be reshaped, sharpened, and recalibrated 
before use. Each nozzle shall be permanently and uniquely identified.
    5.2  Pitot Tube. If the pitot tube is placed in an interference-free 
arrangement with respect to the other probe assembly components, its 
baseline (isolated tube) coefficient shall be determined as outlined in 
Section 4 of Method 2. If the probe assembly is not interference-free, 
the pitot tube assembly coefficient shall be determined by calibration, 
using methods subject to the approval of the Administrator.
    5.3  Metering System. Before its initial use in the field, the 
metering system shall be calibrated according to the procedure outlined 
in APTD-0576. Instead of physically adjusting the dry gas meter dial 
readings to correspond to the wet test meter readings, calibration 
factors may be used to mathematically correct the gas meter dial 
readings to the proper values.
    Before calibrating the metering system, it is suggested that a leak-
check be conducted. For metering systems having diaphragm pumps, the 
normal leak-check procedure will not detect leakages within the pump. 
For these cases the following leak-check procedure is suggested: make a 
10-minute calibration run at 0.00057 m 3/min (0.02 cfm); at 
the end of the run, take the difference of the measured wet test meter 
and dry gas meter volumes; divide the difference by 10, to get the leak 
rate. The leak rate should not exceed 0.00057 m 3/min (0.02 
cfm).
    After each field use, the calibration of the metering system shall 
be checked by performing three calibration runs at a single, 
intermediate orifice setting (based on the previous field test), with 
the vacuum set at the maximum value reached during the test series. To 
adjust the vacuum, insert a valve between the wet test meter and the 
inlet of the metering system. Calculate the average

[[Page 974]]

value of the calibration factor. If the calibration has changed by more 
than 5 percent, recalibrate the meter over the full range of orifice 
settings, as outlined in APTD-0576.
    Alternative procedures, e.g., using the orifice meter coefficients, 
may be used, subject to the approval of the Administrator.
    Note: If the dry gas meter coefficient values obtained before and 
after a test series differ by more than 5 percent, the test series shall 
either be voided, or calculations for the test series shall be performed 
using whichever meter coefficient value (i.e., before or after) gives 
the lower value of total sample volume.
    5.4  Temperature Gauges. Use the procedure in Section 4.3 of Method 
2 to calibrate in-stack temperature gauges. Dial thermometers, such as 
are used for the dry gas meter and condenser outlet, shall be calibrated 
against mercury-in-glass thermometers.
    5.5  Leak Check of Metering System Shown in Figure 17-1. That 
portion of the sampling train from the pump to the orifice meter should 
be leak checked prior to initial use and after each shipment. Leakage 
after the pump will result in less volume being recorded than is 
actually sampled. The following procedure is suggested (see Figure 17-
5). Close the main valve on the meter box. Insert a one-hole rubber 
stopper with rubber tubing attached into the orifice exhaust pipe. 
Disconnect and vent the low side of the orifice manometer. Close off the 
low side orifice tap. Pressurize the system to 13 to 18 cm (5 to 7 in.) 
water column by blowing into the rubber tubing. Pinch off the tubing and 
observe the manometer for one minute. A loss of pressure on the 
manometer indicates a leak in the meter box; leaks, if present, must be 
corrected.

[[Page 975]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.213

    5.6  Barometer. Calibrate against a mercury barometer.

6. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after the

[[Page 976]]

final calculation. Other forms of the equations may be used as long as 
they give equivalent results.

    6.1  Nomenclature.

An=Cross-sectional area of nozzle, m 
          2(ft2).
Bws=Water vapor in the gas stream, proportion by volume.
Ca=Acetone blank residue concentration, mg/mg.
cs=Concentration of particulate matter in stack gas, dry 
          basis, corrected to standard conditions, g/dscm (g/dscf).
I=Percent of isokinetic sampling.
La=Maximum acceptable leakage rate for either a pretest leak 
          check or for a leak check following a component change; equal 
          to 0.00057 m 3/min (0.02 cfm) or 4 percent of the 
          average sampling rate, whichever is less.
Li=Individual leakage rate observed during the leak check 
          conducted prior to the ``ith'' component change 
          (i=1, 2, 3 . . . n), m 3/min (cfm).
Lp=Leakage rate observed during the post-test leak check, m 
          3/min (cfm).
ma=Mass of residue of acetone after evaporation, mg.
mn=Total amount of particulate matter collected, mg.
Mw=Molecular weight of water, 18.0 g/g-mole (18.0 lb/lb-
          mole).
Pbar=Barometric pressure at the sampling site, mm Hg (in. 
          Hg).
Ps=Absolute stack gas pressure, mm Hg (in. Hg).
Pstd=Standard absolute pressure, 760 mm Hg (29.92 in. Hg).
R=Ideal gas constant, 0.06236 mm Hg-m3/ deg.K-g-mole (21.85 
          in. Hg-ft 3/ deg.R-lb-mole).
Tm=Absolute average dry gas meter temperature (see Figure 17-
          3),  deg.K ( deg.R).
Ts=Absolute average stack gas temperature (see Figure 17-3), 
          deg.K ( deg.R).
Tstd=Standard absolute temperature, 293 deg.K (528 deg.R).
Va=Volume of acetone blank, ml.
Vaw=Volume of acetone used in wash, ml.
Vlc=Total volume of liquid collected in impingers and silica 
          gel (see Figure 17-4), ml.
Vm=Volume of gas sample as measured by dry gas meter, dcm 
          (dcf).
Vm(std)=Volume of gas sample measured by the dry gas meter, 
          corrected to standard conditions, dscm (dscf).
Vw(std)=Volume of water vapor in the gas sample, corrected to 
          standard conditions, scm (scf).
vs=Stack gas velocity, calculated by Method 2, Equation 2-9, 
          using data obtained from Method 17, m/sec (ft/sec).
Wa=Weight of residue in acetone wash, mg.
Y=Dry gas meter calibration coefficient.
 H=Average pressure differential across the orifice meter (see 
          Figure 17-3), mm H2O (in. H2O).
a=Density of acetone, mg/ml (see label on bottle).
w=Density of water, 0.9982 g/ml (0.002201 lb/ml).
1=Sampling time interval, from the beginning of a 
          run until the first component change, min.
i=Sampling time interval, between two successive 
          component changes, beginning with the interval between the 
          first and second changes, min.
p=Sampling time interval, from the final 
          (nth) component change until the end of the 
          sampling run, min.
13.6=Specific gravity of mercury.
60=Sec/min.
100=Conversion to percent.
    6.2  Average Dry Gas Meter Temperature and Average Orifice Pressure 
Drop. See data sheet (Figure 17-3).
    6.3  Dry Gas Volume. Correct the sample volume measured by the dry 
gas meter to standard conditions (20  deg.C, 760 mm Hg or 68  deg.F, 
29.92 in. Hg) by using Equation 17-1.
[GRAPHIC] [TIFF OMITTED] TC01JN92.214

                                                                Eq. 17-1
Where:

K1=0.3858 deg.K/mm Hg for metric units; 17.64 deg.R/in. Hg 
          for English units.
    Note: Equation 17-1 can be used as written unless the leakage rate 
observed during any of the mandatory leak checks (i.e., the post-test 
leak check or leak checks conducted prior to component changes) exceeds 
La. If Lp or Li exceeds La, 
Equation 17-1 must be modified as follows:
    (a) Case I. No component changes made during sampling run. In this 
case, replace Vm in Equation 17-1 with the expression:

[Vm-(Lp-La)m in Equation 17-1 by the 
expression:
[GRAPHIC] [TIFF OMITTED] TC01JN92.215

and substitute only for those leakage rates (Li or 
Lp) which exceed La.
    6.4  Volume of Water Vapor.

[[Page 977]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.216

                                                                Eq. 17-2
Where:

K2=0.001333 m 3/ml for metric units; 0.04707 ft 
          3/ml for English units.
    6.5  Moisture Content.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.205
    
    6.6  Acetone Blank Concentration.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.206
    
    6.7  Acetone Wash Blank.
Wa=Ca Vawa
                                                          Eq. 17-5
    6.8  Total Particulate Weight. Determine the total particulate catch 
from the sum of the weights obtained from Containers 1 and 2 less the 
acetone blank (see Figure 17-4).
    Note: Refer to Section 4.1.5 to assist in calculation of results 
involving two or more filter assemblies or two or more sampling trains.
    6.9  Particulate Concentration.
cs=(0.001 g/mg) (mn/Vm(std))
                                                                Eq. 17-6
    6.10  Conversion Factors:

------------------------------------------------------------------------
              From                         To             Multiply by
------------------------------------------------------------------------
scf.............................  m 3................  0.02832
g/ft 3..........................  gr/ft 3............  15.43
g/ft 3..........................  lb/ft 3............  2.205 x 10-3
g/ft 3..........................  g/m 3..............  35.31
------------------------------------------------------------------------

    6.11  Isokinetic Variation.
    6.11.1  Calculation from Raw Data.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.217
    
                                                                Eq. 17-7
Where:

K3=0.003454 mm Hg-m 3/ml- deg.K for metric units; 
          0.002669 in. Hg-ft 3/ml- deg.R for English units.
    6.11.2  Calculation from Intermediate Values.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.218
    
                                                                Eq. 17-8
Where:

K4=4.320 for metric units; 0.09450 for English units.
    6.12  Acceptable  Results.  If  90  percent < I <110 percent, the 
results are acceptable. If the results are low in comparison to the 
standard and I is beyond the acceptable range, or, if I is less than 90 
percent, the Administrator may opt to accept the results. Use Citation 4 
in Bibliography to make judgments. Otherwise, reject the results and 
repeat the test.

7. Bibliography

    1. Addendum to Specifications for Incinerator Testing at Federal 
Facilities. PHS, NCAPC. December 6, 1967.
    2. Martin, Robert M., Construction Details of Isokinetic Source-
Sampling Equipment. Environmental Protection Agency. Research Triangle 
Park, NC, APTD-0581. April, 1971.
    3. Rom, Jerome J., Maintenance, Calibration, and Operation of 
Isokinetic Source-Sampling Equipment. Environmental Protection Agency. 
Research Triangle Park, NC APTD-0576. March, 1972.
    4. Smith, W. S., R. T. Shigehara, and W. F. Todd. A Method of 
Interpreting Stack Sampling Data. Paper Presented at the 63rd Annual 
Meeting of the Air Pollution Control Association, St. Louis, MO June 14-
19, 1970.
    5. Smith, W. S., et al., Stack Gas Sampling Improved and Simplified 
with New Equipment. APCA Paper No. 67-119. 1967.
    6. Specifications for Incinerator Testing at Federal Facilities. 
PHS, NCAPC. 1967.
    7. Shigehara, R. T., Adjustments in the EPA Nomograph for Different 
Pitot Tube Coefficients and Dry Molecular Weights. Stack Sampling News 
2:4-11. October, 1974.
    8. Vollaro, R. F., A Survey of Commercially Available 
Instrumentation for the Measurement of Low-Range Gas Velocities. U.S. 
Environmental Protection Agency, Emission Measurement Branch. Research 
Triangle Park, NC, November, 1976 (unpublished paper).
    9. Annual Book of ASTM Standards. Part 26. Gaseous Fuels; Coal and 
Coke; Atmospheric Analysis. American Society for Testing and Materials. 
Philadelphia, PA 1974. pp. 617-622.
    10. Vollaro, R. F., Recommended Procedure for Sample Traverses in 
Ducts Smaller than 12 Inches in Diameter. U.S. Environmental Protection 
Agency, Emission Measurement Branch. Research Triangle Park, NC, 
November, 1976.

  Method 18--Measurement of Gaseous Organic Compound Emissions by Gas 
                             Chromatography

Introduction

    This method should not be attempted by persons unfamiliar with the 
performance characteristics of gas chromatography, nor by those persons 
who are unfamiliar with

[[Page 978]]

source sampling. Particular care should be exercised in the area of 
safety concerning choice of equipment and operation in potentially 
explosive atmospheres.

1. Applicability and Principle

    1.1  Applicability. This method applies to the analysis of 
approximately 90 percent of the total gaseous organics emitted from an 
industrial source. It does not include techniques to identify and 
measure trace amounts of organic compounds, such as those found in 
building air and fugitive emission sources.
    This method will not determine compounds that (1) are polymeric 
(high molecular weight), (2) can polymerize before analysis, or (3) have 
very low vapor pressures at stack or instrument conditions.
    1.2  Principle.

    The major organic components of a gas mixture are separated by gas 
chromatography (GC) and individually quantified by flame ionization, 
photoionization, electron capture, or other appropriate detection 
principles.
    The retention times of each separated component are compared with 
those of known compounds under identical conditions. Therefore, the 
analyst confirms the identity and approximate concentrations of the 
organic emission components beforehand. With this information, the 
analyst then prepares or purchases commercially available standard 
mixtures to calibrate the GC under conditions identical to those of the 
samples. The analyst also determines the need for sample dilution to 
avoid detector saturation, gas stream filtration to eliminate 
particulate matter, and prevention of moisture condensation.

2. Range and Sensitivity

    2.1  Range. The lower range of this method is determined by the 
sampling system; adsorbents may be used to concentrate the sample, thus 
lowering the limit of detection below the 1 part per million (ppm) 
typically achievable with direct interface or bag sampling. The upper 
limit is governed by GC detector saturation or column overloading; the 
upper range can be extended by dilution of sample with an inert gas or 
by using smaller volume gas sampling loops. The upper limit can also be 
governed by condensation of higher boiling compounds.
    2.2  Sensitivity. The sensitivity limit for a compound is defined as 
the minimum detectable concentration of that compound, or the 
concentration that produces a signal-to-noise ratio of three to one. The 
minimum detectable concentration is determined during the presurvey 
calibration for each compound.

3. Precision and Accuracy

    Gas chromatographic techniques typically provide a precision of 5 to 
10 percent relative standard deviation (RSD), but an experienced GC 
operator with a reliable instrument can readily achieve 5 percent RSD. 
For this method, the following combined GC/operator values are required.
    (a) Precision. Duplicate analyses are within 5 percent of their mean 
value.
    (b) Accuracy. Analysis results of prepared audit samples are within 
10 percent of preparation values.
    (c) Recovery. After developing an appropriate sampling and 
analytical system for the pollutants of interest, conduct the procedure 
in Section 7.6. Conduct the appropriate recovery study in Section 7.6 at 
each sampling point where the method is being applied. Submit the data 
and results of the recovery procedure with the reporting of results 
under Section 7.5.

4. Interferences

    Resolution interferences that may occur can be eliminated by 
appropriate GC column and detector choice or by shifting the retention 
times through changes in the column flow rate and the use of temperature 
programming.
    The analytical system is demonstrated to be essentially free from 
contaminants by periodically analyzing blanks that consist of 
hydrocarbon-free air or nitrogen.
    Sample cross-contamination that occurs when high-level and low-level 
samples or standards are analyzed alternately, is best dealt with by 
thorough purging of the GC sample loop between samples.
    To assure consistent detector response, calibration gases are 
contained in dry air. To adjust gaseous organic concentrations when 
water vapor is present in the sample, water vapor concentrations are 
determined for those samples, and a correction factor is applied.

5. Presurvey and Presurvey Sampling.

    Perform a presurvey for each source to be tested. Refer to Figure 
18-1. Some of the information can be collected from literature surveys 
and source personnel. Collect gas samples that can be analyzed to 
confirm the identities and approximate concentrations of the organic 
emissions.
    5.1  Apparatus. This apparatus list also applies to Sections 6 and 
7.
    5.1.1  Teflon Tubing. (Mention of trade names or specific products 
does not constitute endorsement by the U.S. Environmental Protection 
Agency.) Diameter and length determined by connection requirements of 
cylinder regulators and the GC. Additional tubing is necessary to 
connect the GC sample loop to the sample.
    5.1.2  Gas Chromatograph. GC with suitable detector, columns, 
temperature-controlled sample loop and valve assembly, and temperature 
programable oven, if necessary. The GC shall achieve sensitivity 
requirements for the compounds under study.

[[Page 979]]

    5.1.3  Pump. Capable of pumping 100 ml/min. For flushing sample 
loop.
    5.1.4  Flowmeters. To measure flow rates.
    5.1.5  Regulators. Used on gas cylinders for GC and for cylinder 
standards.
    5.1.6  Recorder. Recorder with linear strip chart is minimum 
acceptable. Integrator (optional) is recommended.
    5.1.7  Syringes. 0.5-ml, 1.0- and 10-microliter sizes, calibrated, 
maximum accuracy (gas tight), for preparing calibration standards. Other 
appropriate sizes can be used.
    5.1.8  Tubing Fittings. To plumb GC and gas cylinders.
    5.1.9  Septums. For syringe injections.
    5.1.10  Glass Jars. If necessary, clean-colored glass jars with 
Teflon-lined lids for condensate sample collection. Size depends on 
volume of condensate.
    5.1.11  Soap Film Flow Meter. To determine flow rates.
    5.1.12  Tedlar Bags. 10- and 50-liter capacity, for preparation of 
standards.
    5.1.13  Dry Gas Meter with Temperature and Pressure Gauges. Accurate 
to 2 percent, for perparation of gas standards.
    5.1.14  Midget Impinger/Hot Plate Assembly. For preparation of gas 
standards.
    5.1.15  Sample Flasks. For presurvey samples, must have gas-tight 
seals.
    5.1.16  Adsorption Tubes. If necessary, blank tubes filled with 
necessary adsorbent (charcoal, Tenax, XAD-2, etc.) for presurvey 
samples.
    5.1.17  Personnel Sampling Pump. Calibrated, for collecting 
adsorbent tube presurvey samples.
    5.1.18  Dilution System. Calibrated, the dilution system is to be 
constructed following the specifications of an acceptable method.
    5.1.19  Sample Probes. Pyrex or stainless steel, of sufficient 
length to reach centroid of stack, or a point no closer to the walls 
than 1 m.
    5.1.20  Barometer. To measure barometric pressure.
    5.2  Reagents.
    5.2.1  Deionized Distilled Water.
    5.2.2  Methylene Dichloride.
    5.2.3  Calibration Gases. A series of standards prepared for every 
compound of interest.
    5.2.4  Organic Compound Solutions. Pure (99.9 percent), or as pure 
as can reasonably be obtained, liquid samples of all the organic 
compounds needed to prepare calibration standards.
    5.2.5  Extraction Solvents. For extraction of adsorbent tube samples 
in preparation for analysis.
    5.2.6  Fuel. As recommended by the manufacturer for operation of the 
GC.
    5.2.7  Carrier Gas. Hydrocarbon free, as recommended by the 
manufacturer for operation of the detector and compatability with the 
column.
    5.2.8  Zero Gas. Hydrocarbon free air or nitrogen, to be used for 
dilutions, blank preparation, and standard preparation.
    5.3  Sampling.
    5.3.1  Collection of Samples with Glass Sampling Flasks. Presurvey 
samples can be collected in precleaned 250-ml double-ended glass 
sampling flasks. Teflon stopcocks, without grease, are preferred. Flasks 
should be cleaned as follows: Remove the stopcocks from both ends of the 
flasks, and wipe the parts to remove any grease. Clean the stopcocks, 
barrels, and receivers with methylene dichloride. Clean all glass ports 
with a soap solution, then rinse with tap and deionized distilled water. 
Place the flask in a cool glass annealing furnace and apply heat up to 
500  deg.C. Maintain at this temperature for 1 hour. After this time 
period, shut off and open the furnace to allow the flask to cool. Grease 
the stopcocks with stopcock grease and return them to the flask 
receivers. Purge the assembly with high-purity nitrogen for 2 to 5 
minutes. Close off the stopcocks after purging to maintain a slight 
positive nitrogen pressure. Secure the stopcocks with tape.
    Presurvey samples can be obtained either by drawing the gases into 
the previously evacuated flask or by drawing the gases into and purging 
the flask with a rubber suction bulb.
    5.3.1.1  Evacuated Flask Procedure. Use a high-vacuum pump to 
evacuate the flask to the capacity of the pump; then close off the 
stopcock leading to the pump. Attach a 6-mm outside diameter (OD) glass 
tee to the flask inlet with a short piece of Teflon tubing. Select a 6-
mm OD borosilicate sampling probe, enlarged at one end to a 12-mm OD and 
of sufficient length to reach the centroid of the duct to be sampled. 
Insert a glass wool plug in the enlarged end of the probe to remove 
particulate matter. Attach the other end of the probe to the tee with a 
short piece of Teflon tubing. Connect a rubber suction bulb to the third 
leg of the tee. Place the filter end of the probe at the centroid of the 
duct, or at a point no closer to the walls than 1 m, and purge the probe 
with the rubber suction bulb. After the probe is completely purged and 
filled with duct gases, open the stopcock to the grab flask until the 
pressure in the flask reaches duct pressure. Close off the stopcock, and 
remove the probe from the duct. Remove the tee from the flask and tape 
the stopcocks to prevent leaks during shipment. Measure and record the 
duct temperature and pressure.
    5.3.1.2  Purged Flask Procedure. Attach one end of the sampling 
flask to a rubber suction bulb. Attach the other end to a 6-mm OD glass 
probe as described in Section 5.3.1.1. Place the filter end of the probe 
at the centroid of the duct, or at a point no closer to the walls than 1 
m, and apply suction with the bulb to completely purge the probe and

[[Page 980]]

flask. After the flask has been purged, close off the stopcock near the 
suction bulb, and then close the stopcock near the probe. Remove the 
probe from the duct, and disconnect both the probe and suction bulb. 
Tape the stopcocks to prevent leakage during shipment. Measure and 
record the duct temperature and pressure.
    5.3.2  Flexible Bag Procedure. Tedlar or aluminized Mylar bags can 
also be used to obtain the presurvey sample. Use new bags, and leak 
check them before field use. In addition, check the bag before use for 
contamination by filling it with nitrogen or air, and analyzing the gas 
by GC at high sensitivity. Experience indicates that it is desirable to 
allow the inert gas to remain in the bag about 24 hours or longer to 
check for desorption of organics from the bag. Follow the leak check and 
sample collection procedures given in Section 7.1.
    5.3.3  Determination of Moisture Content. For combustion or water-
controlled processes, obtain the moisture content from plant personnel 
or by measurement during the presurvey. If the source is below 59 
deg.C, measure the wet bulb and dry bulb temperatures, and calculate the 
moisture content using a psychrometric chart. At higher temperatures, 
use Method 4 to determine the moisture content.
    5.4  Determination of Static Pressure. Obtain the static pressure 
from the plant personnel or measurement. If a type S pitot tube and an 
inclined manometer are used, take care to align the pitot tube 90 deg. 
from the direction of the flow. Disconnect one of the tubes to the 
manometer, and read the static pressure; note whether the reading is 
positive or negative.
    5.5  Collection of Presurvey Samples with Adsorption Tube. Follow 
Section 7.4 for presurvey sampling.

6. Analysis Development

    6.1  Selection of GC Parameters.
    6.1.1  Column Choice. Based on the initial contact with plant 
personnel concerning the plant process and the anticipated emissions, 
choose a column that provides good resolution and rapid analysis time. 
The choice of an appropriate column can be aided by a literature search, 
contact with manufacturers of GC columns, and discussion with personnel 
at the emission source.
    Most column manufacturers keep excellent records of their products. 
Their technical service departments may be able to recommend appropriate 
columns and detector type for separating the anticipated compounds, and 
they may be able to provide information on interferences, optimum 
operating conditions, and column limitations.
    Plants with analytical laboratories may also be able to provide 
information on appropriate analytical procedures.
    6.1.2  Preliminary GC Adjustment. Using the standards and column 
obtained in Section 6.1.1, perform initial tests to determine 
appropriate GC conditions that provide good resolution and minimum 
analysis time for the compounds of interest.
    6.1.3  Preparation of Presurvey Samples. If the samples were 
collected on an adsorbent, extract the sample as recommended by the 
manufacturer for removal of the compounds with a solvent suitable to the 
type of GC analysis. Prepare other samples in an appropriate manner.
    6.1.4  Presurvey Sample Analysis. Before analysis, heat the 
presurvey sample to the duct temperature to vaporize any condensed 
material. Analyze the samples by the GC procedure, and compare the 
retention times against those of the calibration samples that contain 
the components expected to be in the stream. If any compounds cannot be 
identified with certainty by this procedure, identify them by other 
means such as GC/mass spectroscopy (GC/MS) or GC/infrared techniques. A 
GC/MS system is recommended.
    Use the GC conditions determined by the procedures of Section 6.1.2 
for the first injection. Vary the GC parameters during subsequent 
injections to determine the optimum settings. Once the optimum settings 
have been determined, perform repeat injections of the sample to 
determine the retention time of each compound. To inject a sample, draw 
sample through the loop at a constant rate (100 ml/min for 30 seconds). 
Be careful not to pressurize the gas in the loop. Turn off the pump and 
allow the gas in the sample loop to come to ambient pressure. Activate 
the sample valve, and record injection time, loop temperature, column 
temperature, carrier flow rate, chart speed, and attenuator setting. 
Calculate the retention time of each peak using the distance from 
injection to the peak maximum divided by the chart speed. Retention 
times should be repeatable within 0.5 seconds.
    If the concentrations are too high for appropriate detector 
response, a smaller sample loop or dilutions may be used for gas 
samples, and, for liquid samples, dilution with solvent is appropriate. 
Use the standard curves (Section 6.3) to obtain an estimate of the 
concentrations.
    Identify all peaks by comparing the known retention times of 
compounds expected to be in the retention times of peaks in the sample. 
Identify any remaining unidentified peaks which have areas larger than 5 
percent of the total using a GC/MS, or estimation of possible compounds 
by their retention times compared to known compounds, with confirmation 
by further GC analysis.
    6.2  Calibration Standards. Prepare or obtain enough calibration 
standards so that there are three different concentrations of

[[Page 981]]

each organic compound expected to be measured in the source sample. For 
each organic compound, select those concentrations that bracket the 
concentrations expected in the source samples. A calibration standard 
may contain more than one organic compound. If available, commercial 
cylinder gases may be used if their concentrations have been certified 
by direct analysis.
    If samples are collected in adsorbent tubes (charcoal, XAD-2, Tenax, 
etc.), prepare or obtain standards in the same solvent used for the 
sample extraction procedure. Refer to Section 7.4.3.
    Verify the stability of all standards for the time periods they are 
used. If gas standards are prepared in the laboratory, use one or more 
of the following procedures.
    6.2.1  Preparation of Standards from High Concentration Cylinder 
Standards. Obtain enough high concentration cylinder standards to 
represent all the organic compounds expected in the source samples.
    Use these high concentration standards to prepare lower 
concentration standards by dilution, as shown by Figures 18-5 and 18-6.
    To prepare the diluted calibration samples, calibrated rotameters 
are normally used to meter both the high concentration calibration gas 
and the diluent gas. Other types of flowmeters and commercially 
available dilution systems can also be used.
    Calibrate each flowmeter before use by placing it between the 
diluent gas supply and suitably sized bubble meter, spirometer, or wet 
test meter. Record all data shown on Figure 18-4. While it is desirable 
to calibrate the cylinder gas flowmeter with cylinder gas, the available 
quantity and cost may preclude it. The error introduced by using the 
diluent gas for calibration is insignificant for gas mixtures of up to 
1,000 to 2,000 ppm of each organic component.
    Once the flowmeters are calibrated, connect the flowmeters to the 
calibration and diluent gas supplies using 6-mm Teflon tubing. Connect 
the outlet side of the flowmeters through a connector to a leak-free 
Tedlar bag as shown in Figure 18-5. (See Section 7.1 for bag leak-check 
procedures.) Adjust the gas flow to provide the desired dilution, and 
fill the bag with sufficient gas for GC calibration. Be careful not to 
overfill and cause the bag to apply additional pressure on the dilution 
system. Record the flow rates of both flowmeters, and the laboratory 
temperature and atmospheric pressure. Calculate the concentration 
Cs in ppm of each organic in the diluted gas as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.219

where:

10\6\=Conversion to ppm.
X=Mole or volume fraction of the organic in the calibration gas to be 
          diluted.
qc=Flow rate of the calibration gas to be diluted.
qd=Diluent gas flow rate.

Single-stage dilutions should be used to prepare calibration mixtures up 
to about 1:20 dilution factor.
    For greater dilutions, a double dilution system is recommended, as 
shown in Figure 18-6. Fill the Tedlar bag with the dilute gas from the 
second stage. Record the laboratory temperature, barometric pressure, 
and static pressure readings. Correct the flow reading for temperature 
and pressure. Calculate the concentration Cs in ppm of the 
organic in the final gas mixture as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.220

Where:

10\6\=Conversion to ppm.
X=Mole or volume fraction of the organic in the calibration gas to be 
          diluted.
qc1=Flow rate of the calibration gas to be diluted in stage 
          1.
qc2=Flow rate of the calibration gas to be diluted in stage 
          2.
qd1=Flow rate of diluent gas in stage 1.
qd2=Flow rate of diluent gas in stage 2.
    Further details of the calibration methods for flowmeters and the 
dilution system can be found in Citation 21 in the Bibliography.
    6.2.2  Preparation of Standards from Volatile Materials. Record all 
data shown on Figure 18-3.
    6.2.2.1  Gas Injection Technique. This procedure is applicable to 
organic compounds that exist entirely as a gas at ambient conditions. 
Evacuate a 10-liter Tedlar bag that has

[[Page 982]]

passed a leak-check (see Section 7.1), and meter in 5.0 liters of air or 
nitrogen through a dry gas meter that has been calibrated in a manner 
consistent with the procedure described in Section 5.1.1 of Method 5. 
While the bag is filling use a 0.5-ml syringe to inject a known quantity 
of ``pure'' gas of the organic compound through the wall of the bag, or 
through a septum-capped tee at the bag inlet. Withdraw the syringe 
needle, and immediately cover the resulting hole with a piece of masking 
tape. In a like manner, prepare dilutions having other concentrations. 
Prepare a minimum of three concentrations. Place each bag on a smooth 
surface, and alternately depress opposite sides of the bag 50 times to 
mix the gases. Record the average meter temperature and pressure, the 
gas volume and the barometric pressure. Record the syringe temperature 
and pressure before injection.
    Calculate each organic standard concentration Cs in ppm 
as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.221

where:

Gv=Gas volume or organic compound injected, ml.
106=Conversion to ppm.
Ps=Absolute pressure of syringe before injection, mm Hg.
Ts=Absolute temperature of syringe before injection,  deg.K.
Vm=Gas volume indicated by dry gas meter, liters.
Y=Dry gas meter calibration factor, dimensionless.
Pm=Absolute pressure of dry gas meter, mm Hg.
Tm=Absolute temperature of dry gas meter,  deg.K.
1000=Conversion factor, ml/liter.
    6.2.2.2  Liquid Injection Technique. Use the equipment shown in 
Figure 18-8. Calibrate the dry gas meter as described in Section 6.2.2.1 
with a wet test meter or a spirometer. Use a water manometer for the 
pressure gauge and glass, Teflon, brass, or stainless steel for all 
connections. Connect a valve to the inlet of the 50-liter Tedlar bag.
    To prepare the standards, assemble the equipment as shown in Figure 
18-8, and leak-check the system. Completely evacuate the bag. Fill the 
bag with hydrocarbon-free air, and evacuate the bag again. Close the 
inlet valve.
    Turn on the hot plate, and allow the water to reach boiling, Connect 
the bag to the impinger outlet. Record the initial meter reading, open 
the bag inlet valve, and open the cylinder. Adjust the rate so that the 
bag will be completely filled in approximately 15 minutes. Record meter 
pressure and temperature, and local barometric pressure.
    Allow the liquid organic to equilibrate to room temperature. Fill 
the 1.0- or 10-microliter syringe to the desired liquid volume with the 
organic. Place the syringe needle into the impinger inlet using the 
septum provided, and inject the liquid into the flowing air stream. Use 
a needle of sufficient length to permit injection of the liquid below 
the air inlet branch of the tee. Remove the syringe.
    When the bag is filled, stop the pump, and close the bag inlet 
valve. Record the final meter reading, temperature, and pressure.
    Disconnect the bag from the impinger outlet, and either set it aside 
for at least 1 hour, or massage the bag to insure complete mixing.
    Measure the solvent liquid density at room temperature by accurately 
weighing a known volume of the material on an analytical balance to the 
nearest 1.0 milligram. A ground-glass stoppered 25-mil volumetric flask 
or a glass-stoppered specific gravity bottle is suitable for weighing. 
Calculate the result in terms of g/ml. As an alternative, literature 
values of the density of the liquid at 20  deg.C may be used.
    Calculate each organic standard concentration Cs in ppm 
as follows:

[[Page 983]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.222

where:

Lv=Liquid volume of organic injected, l.
l=Liquid organic density as determined, g/ml.
M=Molecular weight of organic, g/g-mole.
24.055=Ideal gas molar volume at 293  deg.K and 760 mm Hg, liters/g-
          mole.
106=Conversion to ppm.
1000=Conversion factor, l/ml.
    6.3  Preparation of Calibration Curves. Establish proper GC 
conditions, then flush the sampling loop for 30 seconds at a rate of 100 
ml/min. Allow the sample loop pressure to equilibrate to atmospheric 
pressure, and activate the injection valve. Record the standard 
concentration, attenuator factor, injection time, chart speed, retention 
time, peak area, sample loop temperature, column temperature, and 
carrier gas flow rate. Repeat the standard injection until two 
consecutive injections give area counts within 5 percent of their 
average. The average value multipled by the attenuator factor is then 
the calibration area value for the concentration.
    Repeat this procedure for each standard. Prepare a graphical plot of 
concentration (Cs) versus the calibration area values. 
Perform a regression analysis, and draw the least squares line.
    6.4  Relative Response Factors. The calibration curve generated from 
the standards for a single organic can usually be related to each of the 
individual GC response curves that are developed in the laboratory for 
all the compounds in the source. In the field, standards for that single 
organic can then be used to ``calibrate'' the GC for all the organics 
present. This procedure should first be confirmed in the laboratory by 
preparing and analyzing calibration standards containing multiple 
organic compounds.
    6.5  Quality Assurance for Laboratory Procedures. Immediately after 
the preparation of the calibration curves and prior to the presurvey 
sample analysis, the analysis audit described in 40 CFR Part 61, 
Appendix C, Procedure 2: ``Procedure for Field Auditing GC Analysis,'' 
should be performed. The information required to document the analysis 
of the audit samples has been included on the example data sheets shown 
in Figures 18-3 and 18-7. The audit analyses should agree with the audit 
concentrations within 10 percent. When available, the tester may obtain 
audit cylinders by contacting: U.S. Environmental Protection Agency, 
Environmental Monitoring Systems Laboratory, Quality Assurance Division 
(MD-77), Research Triangle Park, North Carolina 27711. Audit cylinders 
obtained from a commercial gas manufacturer may be used provided that 
(a) the gas manufacturer certifies the audit cylinder in a manner 
similar to the procedure described in 40 CFR Part 61, Appendix B, Method 
106, Section 5.2.3.1, and (b) the gas manufacturer obtains an 
independent analysis of the audit cylinders to verify this analysis. 
Independent analysis is defined as an analysis performed by an 
individual other than the individual who performs the gas manufacturer's 
analysis, while using calibration standards and analysis equipment 
different from those used for the gas manufacturer's analysis. 
Verification is complete and acceptable when the independent analysis 
concentration is within 5 percent of the gas manufacturer's 
concentration.

7. Final Sampling and Analysis Procedure

    Considering safety (flame hazards) and the source conditions, select 
an appropriate sampling and analysis procedure (Sections 7.1, 7.2, 7.3, 
or 7.4). In situations where a hydrogen flame is a hazard and no 
intrinsically safe GC is suitable, use the flexible bag collection 
technique or an adsorption technique. If the source temperature is below 
100  deg.C, and the organic concentrations are suitable for the detector 
to be used, use the direct interface method. If the source gases require 
dilution, use a dilution interface and either the bag sample or 
adsorption tubes. The choice between these two techniques will depend on 
the physical layout of the site, the source temperature, and the storage 
stability of the compounds if collected in the bag. Sample polar 
compounds by direct interfacing or dilution interfacing to prevent 
sample loss by adsorption on the bag.
    7.1  Integrated Bag Sampling and Analysis.
    7.1.1  Evacuated Container Sampling Procedure. In this procedure, 
the bags are filled by evacuating the rigid air-tight containers that 
hold the bags. Use a field sample data sheet as shown in Figure 18-10. 
Collect triplicate sample from each sample location.
    7.1.1.1  Apparatus.
    7.1.1.1.1  Probe. Stainless steel, Pyrex glass, or Teflon tubing 
probe, according to the duct temperature, with 6.4-mm OD Teflon tubing 
of sufficient length to connect to

[[Page 984]]

the sample bag. Use stainless steel or Teflon unions to connect probe 
and sample line.
    7.1.1.1.2  Quick Connects. Male (2) and female (2) of stainless 
steel construction.
    7.1.1.1.3  Needle Valve. To control gas flow.
    7.1.1.1.4  Pump. Leakless Teflon-coated diaphragm-type pump or 
equivalent. To deliver at least 1 liter/min.
    7.1.1.1.5  Charcoal Adsorption Tube. Tube filled with activated 
charcoal, with glass wool plugs at each end, to adsorb organic vapors.
    7.1.1.1.6  Flowmeter. 0 to 500-ml flow range; with manufacturer's 
calibration curve.
    7.1.1.2  Sampling Procedure. To obtain a sample, assemble the sample 
train as shown in Figure 18-9. Leak check both the bag and the 
container. Connect the vacuum line from the needle valve to the Teflon 
sample line from the probe. Place the end of the probe at the centroid 
of the stack, or at a point no closer to the walls than 1 m, and start 
the pump with the needle valve adjusted to yield a flow of 0.5 liter/
minute. After allowing sufficient time to purge the line several times, 
connect the vacuum line to the bag, and evacuate until the rotameter 
indicates no flow. Then position the sample and vacuum lines for 
sampling, and begin the actual sampling, keeping the rate proportional 
to the stack velocity. As a precaution, direct the gas exiting the 
rotameter away from sampling personnel. At the end of the sample period, 
shut off the pump, disconnect the sample line from the bag, and 
disconnect the vacuum line from the bag container, Record the source 
temperature, barometric pressure, ambient temperature, sampling flow 
rate, and initial and final sampling time on the data sheet shown in 
Figure 18-10. Protect the Tedlar bag and its container from sunlight. 
When possible, perform the analysis within 2 hours of sample collection.
    7.1.2  Direct Pump Sampling Procedure. Follow 7.1.1, except place 
the pump and needle valve between the probe and the bag. Use a pump and 
needle valve constructed of stainless steel or some other material not 
affected by the stack gas. Leak check the system, and then purge with 
stack gas before the connecting to the previously evacuated bag.
    7.1.3  Explosion Risk Area Bag Sampling Procedure. Follow 7.1.1 
except replace the pump with another evacuated can (see Figure 18-9a). 
Use this method whenever there is a possibility of an explosion due to 
pumps, heated probes, or other flame producing equipment.
    7.1.4  Other Modified Bag Sampling Procedures. In the event that 
condensation is observed in the bag while collecting the sample and a 
direct interface system cannot be used, heat the bag during collection, 
and maintain it at a suitably elevated temperature during all subsequent 
operations. (Note: Take care to leak check the system prior to the 
dilutions so as not to create a potentially explosive atmosphere.) As an 
alternative, collect the sample gas, and simultaneously dilute it in the 
Tedlar bag.
    In the first procedure, heat the box containing the sample bag to 
the source temperature, provided the components of the bag and the 
surrounding box can withstand this temperature. Then transport the bag 
as rapidly as possible to the analytical area while maintaining the 
heating, or cover the box with an insulating blanket. In the analytical 
area, keep the box heated to source temperature until analysis. Be sure 
that the method of heating the box and the control for the heating 
circuit are compatible with the safety restrictions required in each 
area.
    To use the second procedure, prefill the Tedlar bag with a known 
quantity of inert gas. Meter the inert gas into the bag according to the 
procedure for the preparation of gas concentration standards of volatile 
liquid materials (Section 6.2.2.2), but eliminate the midget impinger 
section. Take the partly filled bag to the source, and meter the source 
gas into the bag through heated sampling lines and a heated flowmeter, 
or Teflon positive displacement pump. Verify the dilution factors 
periodically through dilution and analysis of gases of known 
concentration.
    7.1.5  Analysis of Bag Samples.
    7.1.5.1  Apparatus. Same as Section 5. A minimum of three gas 
standards are required.
    7.1.5.2  Procedure. Establish proper GC operating conditions as 
described in Section 6.3, and record all data listed in Figure 18-7. 
Prepare the GC so that gas can be drawn through the sample valve. Flush 
the sample loop with gas from one of the three calibration mixtures, and 
activate the valve. Obtain at least two chromatograms for the mixture. 
The results are acceptable when the peak areas from two consecutive 
injections agree to within 5 percent of their average. If they do not, 
run additional analyses or correct the analytical techniques until this 
requirement is met. Then analyze the other two calibration mixtures in 
the same manner. Prepare a calibration curve as described in the same 
manner. Prepare a calibration curve as described in Section 6.3.
    Analyze the source gas samples by connecting each bag to the 
sampling valve with a piece of Teflon tubing identified for that bag. 
Follow the specifications on replicate analyses specified for the 
calibration gases. Record the data listed in Figure 18-11. If certain 
items do not apply, use the notation ``N.A.'' After all samples have 
been analyzed, repeat the analyses of the calibration gas mixtures, and 
generate a second calibration curve. Use an average of the two curves to 
determine the sample gas concentrations. If the two calibration curves 
differ by more than 5 percent from their mean value, then

[[Page 985]]

report the final results by comparison to both calibration curves.
    7.1.6  Determination of Bag Water Vapor Content. Measure and record 
the ambient temperature and barometric pressure near the bag. From a 
water saturation vapor pressure table, determine and record the water 
vapor content as a decimal figure. (Assume the relative humidity to be 
100 percent unless a lesser value is known.) If the bag has been 
maintained at an elevated temperature as described in Section 7.1.4, 
determine the stack gas water content by Method 4.
    7.1.7  Quality Assurance. Immediately prior to the analysis of the 
stack gas samples, perform audit analyses as described in Section 6.5. 
The audit analyses must agree with the audit concentrations within 10 
percent. If the results are acceptable, proceed with the analyses of the 
source samples. If they do not agree within 10 percent, then determine 
the reason for the discrepancy, and take corrective action before 
proceeding.
    7.1.8  Emission Calculations. From the average calibration curve 
described in Section 7.1.5., select the value of Cs that 
corresponds to the peak area. Calculate the concentration Cc 
in ppm, dry basis, of each organic in the sample as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.223

where:

Cs=Concentration of the organic from the calibration curve, 
          ppm.
Pr=Reference pressure, the barometric pressure or absolute 
          sample loop pressure recorded during calibration, mm Hg.
Ti=Sample loop temperature at the time of sample analysis, 
          deg.K.
Fr=Relative response factor (if applicable, see Section 6.4).
Pi=Barometric or absolute sample loop pressure at time of 
          sample analysis, mm Hg.
Tr=Reference temperature, the termperature of the sample loop 
          recorded during calibration,  deg.K.
Bws=Water vapor content of the bag sample or stack gas, 
          proportion by volume.
    7.2  Direct Interface Sampling and Analysis Procedure. The direct 
interface procedure can be used provided that the moisture content of 
the gas does not interfere with the analysis procedure, the physical 
requirements of the equipment can be met at the site, and the source gas 
concentration is low enough that detector saturation is not a problem. 
Adhere to all safety requirements with this method.
    7.2.1  Apparatus.
    7.2.1.1  Probe. Constructed of stainless steel, Pyrex glass, or 
Teflon tubing as required by duct temperature, 6.4-mm OD, enlarged at 
duct end to contain glass wool plug. If necessary, heat the probe with 
heating tape or a special heating unit capable of maintaining duct 
temperature.
    7.2.1.2  Sample Lines. 6.4-mm OD Teflon lines, heat-traced to 
prevent condensation of material.
    7.2.1.3  Quick Connects. To connect sample line to gas sampling 
valve on GC instrument and to pump unit used to withdraw source gas. Use 
a quick connect or equivalent on the cylinder or bag containing 
calibration gas to allow connection of the calibration gas to the gas 
sampling valve.
    7.2.1.4  Thermocouple Readout Device. Potentiometer or digital 
thermometer, to measure source temperature and probe temperature.
    7.2.1.5  Heated Gas Sampling Valve. Of two-position, six-port 
design, to allow sample loop to be purged with source gas or to direct 
source gas into the GC instrument.
    7.2.1.6  Needle Valve. To control gas sampling rate from the source.
    7.2.1.7  Pump. Leakless Teflon-coated diaphragm-type pump or 
equivalent, capable of at least 1 liter/minute sampling rate.
    7.2.1.8  Flowmeter. Of suitable range to measure sampling rate.
    7.2.1.9  Charcoal Adsorber. To adsorb organic vapor collected from 
the source to prevent exposure of personnel to source gas.
    7.2.1.10  Gas Cylinders. Carrier gas (helium or nitrogen), and 
oxygen and hydrogen for a flame ionization detector (FID) if one is 
used.
    7.2.1.11  Gas Chromatograph. Capable of being moved into the field, 
with detector, heated gas sampling valve, column required to complete 
separation of desired components, and option for temperature 
programming.
    7.2.1.12  Recorder/Integrator. To record results.
    7.2.2  Procedure. To obtain a sample, assemble the sampling system 
as shown in Figure 18-12. Make sure all connections are tight. Turn on 
the probe and sample line heaters. As the temperature of the probe and 
heated line approaches the source temperature as indicated on the 
thermocouple readout device, control the heating to maintain a 
temperature of 0 to 3  deg.C above the source temperature. While the 
probe and heated line are being heated, disconnect the sample line from 
the gas sampling valve, and attach the line from the calibration gas 
mixture. Flush the sample loop with calibration gas and analyze a 
portion of that gas. Record the results. After the calibration gas 
sample has been flushed into the GC instrument, turn the gas sampling 
valve to flush position, then reconnect the probe sample line to the 
valve. Place the inlet of the probe at the centroid of the duct, or at a 
point no closer to the walls than 1 m, and draw source gas into the 
probe, heated line, and sample loop. After thorough flushing, analyze 
the sample

[[Page 986]]

using the same conditions as for the calibration gas mixture. Repeat the 
analysis on an additional sample. Measure the peak areas for the two 
samples, and if they do not agree to within 5 percent of their mean 
value, analyze additional samples until two consecutive analyses meet 
this criteria. Record the data. After consistent results are obtained, 
remove the probe from the source and analyze a second calibration gas 
mixture. Record this calibration data and the other required data on the 
data sheet shown in Figure 18-11, deleting the dilution gas information.
    (Note: Take care to draw all samples, calibration mixtures, and 
audits through the sample loop at the same pressure.)
    7.2.3  Determination of Stack Gas Moisture Content. Use Method 4 to 
measure the stack gas moisture content.
    7.2.4  Quality Assurance. Same as Section 7.1.7. Introduce the audit 
gases in the sample line immediately following the probe.
    7.2.5  Emission Calculations. Same as Section 7.1.8.
    7.3  Dilution Interface Sampling and Analysis Procedure. Source 
samples that contain a high concentration of organic materials may 
require dilution prior to analysis to prevent saturating the GC 
detector. The apparatus required for this direct interface procedure is 
basically the same as that described in the Section 7.2, except a 
dilution system is added between the heated sample line and the gas 
sampling valve. The apparatus is arranged so that either a 10:1 or 100:1 
dilution of the source gas can be directed to the chromatograph. A pump 
of larger capacity is also required, and this pump must be heated and 
placed in the system between the sample line and the dilution apparatus.
    7.3.1  Apparatus. The equipment required in addition to that 
specified for the direct interface system is as follows:
    7.3.1.1  Sample Pump. Leakless Teflon-coated diaphragm-type that can 
withstand being heated to 120  deg.C and deliver 1.5 liters/minute.
    7.3.1.2  Dilution Pumps. Two Model A-150 Komhyr Teflon positive 
displacement type delivering 150 cc/minute, or equivalent. As an option, 
calibrated flowmeters can be used in conjunction with Teflon-coated 
diaphragm pumps.
    7.3.1.3  Valves. Two Teflon three-way valves, suitable for 
connecting to 6.4-mm OD Teflon tubing.
    7.3.1.4  Flowmeters. Two, for measurement of diluent gas, expected 
delivery flow rate to be 1,350 cc/min.
    7.3.1.5  Diluent Gas with Cylinders and Regulators. Gas can be 
nitrogen or clean dry air, depending on the nature of the source gases.
    7.3.1.6  Heated Box. Suitable for being heated to 120  deg.C, to 
contain the three pumps, three-way valves, and associated connections. 
The box should be equipped with quick connect fittings to facilitate 
connection of: (1) The heated sample line from the probe, (2) the gas 
sampling valve, (3) the calibration gas mixtures, and (4) diluent gas 
lines. A schematic diagram of the components and connections is shown in 
Figure 18-13.
    (Note: Care must be taken to leak check the system prior to the 
dilutions so as not to create a potentially explosive atmosphere.)
    The heated box shown in Figure 18-13 is designed to receive a heated 
line from the probe. An optional design is to build a probe unit that 
attaches directly to the heated box. In this way, the heated box 
contains the controls for the probe heaters, or, if the box is placed 
against the duct being sampled, it may be possible to eliminate the 
probe heaters. In either case, a heated Teflon line is used to connect 
the heated box to the gas sampling valve on the chromatograph.
    7.3.2  Procedure. Assemble the apparatus by connecting the heated 
box, shown in Figure 18-13, between the heated sample line from the 
probe and the gas sampling valve on the chromatograph. Vent the source 
gas from the gas sampling valve directly to the charcoal filter, 
eliminating the pump and rotameter. Heat the sample probe, sample line, 
and heated box. Insert the probe and source thermocouple to the centroid 
of the duct, or to a point no closer to the walls than 1 m. Measure the 
source temperature, and adjust all heating units to a temperature 0 to 3 
 deg.C above this temperature. If this temperature is above the safe 
operating temperature of the Teflon components, adjust the heating to 
maintain a temperature high enough to prevent condensation of water and 
organic compounds. Verify the operation of the dilution system by 
analyzing a high concentration gas of known composition through either 
the 10:1 or 100:1 dilution stages, as appropriate. (If necessary, vary 
the flow of the diluent gas to obtain other dilution ratios.) Determine 
the concentration of the diluted calibration gas using the dilution 
factor and the calibration curves prepared in the laboratory. Record the 
pertinent data on the data sheet shown in Figure 18-11. If the data on 
the diluted calibration gas are not within 10 percent of the expected 
values, determine whether the chromatograph or the dilution system is in 
error, and correct it. Verify the GC operation using a low concentration 
standard by diverting the gas into the sample loop, bypassing the 
dilution system. If these analyses are not within acceptable limits, 
correct the dilution system to provide the desired dilution factors. 
Make this correction by diluting a high-concentration standard gas 
mixture to adjust the dilution ratio as required.
    Once the dilution system and GC operations are satisfactory, proceed 
with the analysis of source gas, maintaining the same dilution settings 
as used for the standards.

[[Page 987]]

Repeat the analyses until two consecutive values do not vary by more 
than 5 percent from their mean value are obtained.
    Repeat the analysis of the calibration gas mixtures to verify 
equipment operation. Analyze the two field audit samples using either 
the dilution system, or directly connect to the gas sampling valve as 
required. Record all data and report the results to the audit 
supervisor.
    7.3.3  Determination of Stack Gas Moisture Content. Same as Section 
7.2.3.
    7.3.4  Quality Assurance. Same as Section 7.2.4.
    7.3.5  Emission Calculations. Same as Section 7.2.5, with the 
dilution factor applied.
    7.4  Adsorption Tube Procedure (Alternative Procedure). It is 
suggested that the tester refer to the National Institute of 
Occupational Safety and Health (NIOSH) method for the particular 
organics to be sampled. The principal interferent will be water vapor. 
If water vapor is present at concentrations above 3 percent, silica gel 
should be used in front of the charcoal. Where more than one compound is 
present in the emissions, then develop relative adsorptive capacity 
information.
    7.4.1  Additional Apparatus. In addition to the equipment listed in 
the NIOSH method for the particular organic(s) to be sampled, the 
following items (or equivalent) are suggested.
    7.4.1.1  Probe (Optional). Borosilicate glass or stainless steel, 
approximately 6-mm ID, with a heating system if water condensation is a 
problem, and a filter (either in-stack or out-stack heated to stack 
temperature) to remove particulate matter. In most instances, a plug of 
glass wool is a satisfactory filter.
    7.4.1.2  Flexible Tubing. To connect probe to adsorption tubes. Use 
a material that exhibits minimal sample adsorption.
    7.4.1.3  Leakless Sample Pump. Flow controlled, constant rate pump, 
with a set of limiting (sonic) orifices to provide pumping rates from 
approximately 10 to 100 cc/min.
    7.4.1.4  Bubble-Tube Flowmeter. Volume accuracy within  
1 percent, to calibrate pump.
    7.4.1.5  Stopwatch. To time sampling and pump rate calibration.
    7.4.1.6  Adsorption Tubes. Similar to ones specified by NIOSH, 
except the amounts of adsorbent per primary/backup sections are 800/200 
mg for charcoal tubes and 1040/260 mg for silica gel tubes. As an 
alternative, the tubes may contain a porous polymer adsorbent such as 
Tenax GC or XAD-2.
    7.4.1.7  Barometer. Accurate to 5 mm Hg, to measure atmospheric 
pressure during sampling and pump calibration.
    7.4.1.8  Rotameter. 0 to 100 cc/min, to detect changes in flow rate 
during sampling.
    7.4.2  Sampling and Analysis. It is suggested that the tester follow 
the sampling and analysis portion of the respective NIOSH method section 
entitled ``Procedure.'' Calibrate the pump and limiting orifice flow 
rate through adsorption tubes with the bubble tube flowmeter before 
sampling. The sample system can be operated as a ``recirculating loop'' 
for this operation. Record the ambient temperature and barometric 
pressure. Then, during sampling, use the rotameter to verify that the 
pump and orifice sampling rate remains constant.
    Use a sample probe, if required, to obtain the sample at the 
centroid of the duct, or at a point no closer to the walls than 1 m. 
Minimize the length of flexible tubing between the probe and adsorption 
tubes. Several adsorption tubes can be connected in series, if the extra 
adsorptive capacity is needed. Provide the gas sample to the sample 
system at a pressure sufficient for the limiting orifice to function as 
a sonic orifice. Record the total time and sample flow rate (or the 
number of pump strokes), the barometric pressure, and ambient 
temperature. Obtain a total sample volume commensurate with the expected 
concentration(s) of the volatile organic(s) present, and recommended 
sample loading factors (weight sample per weight adsorption media). 
Laboratory tests prior to actual sampling may be necessary to 
predetermine this volume. When more than one organic is present in the 
emissions, then develop relative adsorptive capacity information. If 
water vapor is present in the sample at concentrations above 2 to 3 
percent, the adsorptive capacity may be severely reduced. Operate the 
gas chromatograph according to the manufacture's instructions. After 
establishing optimum conditions, verify and document these conditions 
during all operations. Analyze the audit samples (see Section 7.4.4.3), 
then the emission samples. Repeat the analysis of each sample until the 
relative deviation of two consecutive injections does not exceed 5 
percent.
    7.4.3  Standards and Calibration. The standards can be prepared 
according to the respective NIOSH method. Use a minimum of three 
different standards; select the concentrations to bracket the expected 
average sample concentration. Perform the calibration before and after 
each day's sample analyses. Prepare the calibration curve by using the 
least squares method.
    7.4.4  Quality Assurance.
    7.4.4.1  Determine the recovery efficiency of the pollutants of 
interest according to Section 7.6.
    7.4.4.2  Determination of Sample Collection Efficiency. For the 
source samples, analyze the primary and backup portions of the 
adsorption tubes separately. If the backup portion exceeds 10 percent of 
the total amount (primary and backup), repeat the sampling with a larger 
sampling portion.
    7.4.4.3  Analysis Audit. Immediately before the sample analyses, 
analyze the two audits

[[Page 988]]

in accordance with Section 7.4.2. The analysis audit shall agree with 
the audit concentration within 10 percent.
    7.4.4.4  Pump Leak Checks and Volume Flow Rate Checks. Perform both 
of these checks immediately after sampling with all sampling train 
components in place. Perform all leak checks according to the 
manufacturer's instructions, and record the results. Use the bubble-tube 
flowmeter to measure the pump volume flow rate with the orifice used in 
the test sampling, and the result. If it has changed by more than 5 but 
less than 20 percent, calculate an average flow rate for the test. If 
the flow rate has changed by more than 20 percent, recalibrate the pump 
and repeat the sampling.
    7.4.4.5  Calculations. All calculations can be performed according 
to the respective NIOSH method. Correct all sample volumes to standard 
conditions. If a sample dilution system has been used, multiply the 
results by the appropriate dilution ratio. Correct all results according 
to the applicable procedure in Section 7.6. Report results as ppm by 
volume, dry basis.
    7.5  Reporting of Results. At the completion of the field analysis 
portion of the study, ensure that the data sheets shown in Figure 18-11 
have been completed. Summarize this data on the data sheets shown in 
Figure 18-15.
    7.6  Recovery Study. After conducting the presurvey and identifying 
all of the pollutants of interest, conduct the appropriate recovery 
study during the test based on the sampling system chosen for the 
compounds of interest.
    7.6.1  Recovery Study for Direct Interface or Dilution Interface 
Sampling. If the procedures in Section 7.2 or 7.3 are to be used to 
analyze the stack gas, conduct the calibration procedure as stated in 
Section 7.2.2 or 7.3.2, as appropriate. Upon successful completion of 
the appropriate calibration procedure, attach the mid-level calibration 
gas for at least one target compound to the inlet of the probe or as 
close as possible to the inlet of the probe, but before the filter. 
Repeat the calibration procedure by sampling and analyzing the mid-level 
calibration gas through the entire sampling and analytical system until 
two consecutive samples are within 5 percent of their mean value. The 
mean of the calibration gas response directly to the analyzer and the 
mean of the calibration gas response sampled through the probe shall be 
within 10 percent of each other. If the difference in the two means is 
greater than 10 percent, check for leaks throughout the sampling system 
and repeat the analysis of the standard through the sampling system 
until this criterion is met.
    7.6.2  Recovery Study for Bag Sampling. Follow the procedures for 
bag sampling and analysis in Section 7.1. After analyzing all three bag 
samples, choose one of the bag samples and analyze twice more (this bag 
will become the spiked bag). Spike the chosen bag sample with a known 
mixture (gaseous or liquid) of all of the target pollutants. Follow a 
procedure similar to the calibration standard preparation procedure 
listed in Section 6.2, as appropriate. The theoretical concentration, in 
ppm, of each spiked compound in the bag shall be 40 to 60 percent of the 
average concentration measured in the three bag samples. If a target 
compound was not detected in the bag samples, the concentration of that 
compound to be spiked shall be 5 times the limit of detection for that 
compound. Analyze the bag three times after spiking. Calculate the 
average fraction recovered (R) of each spiked target compound with the 
following equation:
[GRAPHIC] [TIFF OMITTED] TR22AP94.006

where

    t = measured average concentration (ppm) of target compound and 
source sample (analysis results subsequent to bag spiking)
    u = source sample average concentration (ppm) of target compound in 
the bag (analysis results before bag spiking)
    s = theoretical concentration (ppm) of spiked target compound in the 
bag
    For the bag sampling technique to be considered valid for a 
compound, 0.70R1.30. If the R value does not meet 
this criterion for a target compound, the sampling technique is not 
acceptable for that compound, and therefore another sampling technique 
shall be evaluated for acceptance (by repeating the recovery study with 
another sampling technique). Report the R value in the test report and 
correct all field measurements with the calculated R value for that 
compound by using the following equation:
[GRAPHIC] [TIFF OMITTED] TR22AP94.007

    7.6.3  Recovery Study for Adsorption Tube Sampling. If following the 
adsorption tube procedure in Section 7.4, conduct a recovery study of 
the compounds of interest during

[[Page 989]]

the actual field test. Set up two identical sampling trains. Collocate 
the two sampling probes in the stack. The probes shall be placed in the 
same horizontal plane, where the first probe tip is 2.5 cm from the 
outside edge of the other and with a pitot tube on the outside of each 
probe. One of the sampling trains shall be designated the spiked train 
and the other the unspiked train. Spike all of the compounds of interest 
(in gaseous or liquid form) onto the adsorbent tube(s) in the spiked 
train before sampling. The mass of each spiked compound shall be 40 to 
60 percent of the mass expected to be collected with the unspiked train. 
Sample the stack gas into the two trains simultaneously. Analyze the 
adsorbents from the two trains utilizing the same analytical procedure 
and instrumentation. Determine the fraction of spiked compound recovered 
(R) using the following equations.
[GRAPHIC] [TIFF OMITTED] TR22AP94.008

where

    mv = mass per volume of spiked compound measured 
(g/L).
    ms = total mass of compound measured on adsorbent with 
spiked train (g).
    vs = volume of stack gas sampled with spiked train (L).
    mu = total mass of compound measured on adsorbent with 
unspiked train (g).
    vu = volume of stack gas sampled with unspiked train (L).
    [GRAPHIC] [TIFF OMITTED] TR22AP94.009
    

where S = theoretical mass of compound spiked onto adsorbent in spiked 
          train (g).
    7.6.3.1  Repeat the procedure in Section 7.6.3 twice more, for a 
total of three runs. In order for the adsorbent tube sampling and 
analytical procedure to be acceptable for a compound, 
0.70R1.30 (R in this case is the average of three 
runs). If the average R value does not meet this criterion for a target 
compound, the sampling technique is not acceptable for that compound, 
and therefore another sampling technique shall be evaluated for 
acceptance (by repeating the recovery study with another sampling 
technique). Report the R value in the test report and correct all field 
measurements with the calculated R value for that compound by using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TR22AP94.010

8. Bibliography

    1. American Society for Testing and Materials. C1 Through 
C5 Hydrocarbons in the Atmosphere by Gas Chromatography. ASTM 
D 2820-72, Part 23. Philadelphia, Pa. 23:950-958. 1973.
    2. Corazon, V. V. Methodology for Collecting and Analyzing Organic 
Air Pollutants. U.S. Environmental Protection Agency. Publication No. 
EPA-600/2-79-042. February 1979.
    3. Dravnieks, A., B. K. Krotoszynski, J. Whitfield, A. O'Donnell, 
and T. Burgwald. Environmental Science and Technology. 5(12):1200-1222. 
1971.
    4. Eggertsen, F. T., and F. M. Nelsen. Gas Chromatographic Analysis 
of Engine Exhaust and Atmosphere. Analytical Chemistry. 30(6): 1040-
1043. 1958.
    5. Feairheller, W. R., P. J. Marn, D. H. Harris, and D. L. Harris. 
Technical Manual for Process Sampling Strategies for Organic Materials. 
U.S. Environmental Protection Agency. Research Triangle Park, NC. 
Publication No. EPA 600/2-76-122. April 1976. 172 p.
    6. FR, 39 FR 9319-9323. 1974.
    7. FR, 39 FR 32857-32860. 1974.
    8. FR, 41 FR 23069-23072 and 23076-23090. 1976.
    9. FR, 41 FR 46569-46571. 1976.
    10. FR, 42 FR 41771-41776. 1977.
    11. Fishbein, L. Chromatography of Environmental Hazards, Volume II. 
Elsevier Scientific Publishing Company. NY, NY. 1973.
    12. Hamersma, J. W., S. L. Reynolds, and R. F. Maddalone. EPA/IERL-
RTP Procedures Manual: Level 1 Environmental Assessment. U.S. 
Environmental Protection Agency. Research Triangle Park, NC. Publication 
No. EPA 600/276-160a. June 1976. 130 p.
    13. Harris, J. C., M. J. Hayes, P. L. Levins, and D. B. Lindsay. 
EPA/IERL-RTP Procedures for Level 2 Sampling and Analysis of Organic 
Materials. U.S. Environmental Protection Agency. Research Triangle Park, 
NC. Publication No. EPA 600/7-79-033. February 1979. 154 p.
    14. Harris, W. E., H. W. Habgood. Programmed Temperature Gas 
Chromatography. John Wiley & Sons, Inc. New York. 1966.
    15. Intersociety Committee. Methods of Air Sampling and Analysis. 
American Health Association. Washington, DC. 1972.

[[Page 990]]

    16. Jones, P. W., R. D. Grammar, P. E. Strup, and T. B. Stanford. 
Environmental Science and Technology.------ 10:806-810. 1976.
    17. McNair Han Bunelli, E. J. Basic Gas Chromatography. Consolidated 
Printers. Berkeley. 1969.
    18. Nelson, G. O. Controlled Test Atmospheres, Principles and 
Techniques. Ann Arbor. Ann Arbor Science Publishers. 1971. 247 p.
    19. NIOSH Manual of Analytical Methods, Volumes 1, 2, 3, 4, 5, 6, 7. 
U.S. Department of Health and Human Services National Institute for 
Occupational Safety and Health. Center for Disease Control. 4676 
Columbia Parkway, Cincinnati, Ohio 45226. April 1977-August 1981. May be 
available from the Superintendent of Documents, Government Printing 
Office, Washington, DC 20402. Stock Number/Price: Volume 1--017-033-
00267-3/$13, Volume 2--017-033-00260-6/$11, Volume 3--017-033-00261-4/
$14, Volume 4--017-033-00317-3/$7.25, Volume 5--017-033-00349-1/$10, 
Volume 6--017-033-00369-6/$9, and Volume 7--017-033-00396-5/$7. Prices 
subject to change. Foreign orders add 25 percent.
    20. Schuetzle, D., T. J. Prater, and S. R. Ruddell. Sampling and 
Analysis of Emissions from Stationary Sources; I. Odor and Total 
Hydrocarbons. Journal of the Air Pollution Control Association. 
25(9):925-932. 1975.
    21. Snyder, A. D., F. N. Hodgson, M. A. Kemmer and J. R. McKendree. 
Utility of Solid Sorbents for Sampling Organic Emissions from Stationary 
Sources. U.S. Environmental Protection Agency. Research Triangle Park, 
NC Publication No. EPA 600/2-76-201. July 1976. 71 p.
    22. Tentative Method for Continuous Analysis of Total Hydrocarbons 
in the Atmosphere. Intersociety Committee, American Public Health 
Association. Washington, DC 1972. p. 184-186.
    23. Zwerg, G., CRC Handbook of Chromatography, Volumes I and II. 
Sherma, Joseph (ed.). CRC Press. Cleveland. 1972.

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[[Page 1008]]



            Gaseous Organic Sampling and Analysis Check List

            (Respond with initials or number as appropriate)

 
                                                                  Date
 
1. Presurvey data:
    A. Grab sample collected..........................
    B. Grab sample analyzed for composition...........
        Method GC.....................................
            GC/MS.....................................
            Other.....................................
    C. GC-FID analysis performed......................         .........
2. Laboratory calibration data:
    A. Calibration curves prepared....................         .........
        Number of components..........................
        Number of concentrations/component (3
         required)....................................
    B. Audit samples (optional):
        Analysis completed............................         .........
        Verified for concentration....................         .........
        OK obtained for field work....................         .........
3. Sampling procedures:
    A. Method:
        Bag sample....................................
        Direct interface..............................
        Dilution interface............................
    B. Number of samples collected....................         .........
4. Field analysis:
    A. Total hydrocarbon analysis performed...........         .........
    B. Calibration curve prepared.....................         .........
        Number of components..........................
        Number of concentrations per component (3
         required)....................................
 

Figure 18-14. Sampling and analysis check.

               Gaseous Organic Sampling and Analysis Data

Plant___________________________________________________________________
Date____________________________________________________________________
Location________________________________________________________________

 
                                             Source    Source    Source
                                            sample 1  sample 2  sample 3
 
1. General information:
    Source temperature (  deg.C)..........  ........  ........  ........
    Probe temperature (  deg.C)...........  ........  ........  ........
    Ambient temperature (  deg.C).........  ........  ........  ........
    Atmospheric pressure (mm Hg)..........  ........  ........  ........
    Source pressure (mm Hg)...............  ........  ........  ........
    Sampling rate (ml/min)................  ........  ........  ........
    Sample loop volume (ml)...............  ........  ........  ........
    Sample loop temperature (  deg.C).....  ........  ........  ........
    Sample collection time (24-hr basis)..  ........  ........  ........
    Column temperature:
        Initial (  deg.C).................  ........  ........  ........
        Program rate (  deg.C/min)........  ........  ........  ........
        Final (  deg.C)...................  ........  ........  ........
    Carrier gas flow rate (ml/min)........  ........  ........  ........
    Detector temperature (  deg.C)........  ........  ........  ........
    Chart speed (cm/min)..................  ........  ........  ........
 
    Dilution gas flow rate (ml/min).......  ........  ........  ........
    Diluent gas used (symbol).............  ........  ........  ........
    Dilution ratio........................  ........  ........  ........
 
Performed by (signature):.................  ........
 
Date:.....................................  ........
 


Figure 18-14. Sampling and analysis sheet.

   Method 19--Determination of Sulfur Dioxide Removal Efficiency and 
 Particulate Matter, Sulfur Dioxide, and Nitrogen Oxides Emission Rates

                     1. Applicability and Principle

    1.1  Applicability. This method is applicable for (a) determining 
particulate matter (PM), sulfur dioxide (SO2), and nitrogen 
oxides (NOx) emission rates; (b) determining sulfur removal 
efficiencies of fuel pretreatment and SO2 control devices; 
(c) determining overall reduction of potential SO2 emissions 
from steam generating units or other sources as specified in applicable 
regulations; and (d) determining SO2 rates based on fuel 
sampling and analysis procedures.
    1.2  Principle.
    1.2.1  Pollutant emission rates are determined from concentrations 
of PM, SO2, or NOx, and oxygen (O2) or 
carbon dioxide (CO2) along with F factors (ratios of 
combustion gas volumes to heat inputs).
    1.2.2  An overall SO2 emission reduction efficiency is 
computed from the efficiency of fuel pretreatment systems (optional) and 
the efficiency of SO2 control devices.
    1.2.3  The sulfur removal efficiency of a fuel pretreatment system 
is determined by fuel sampling and analysis of the sulfur and heat 
contents of the fuel before and after the pretreatment system.
    1.2.4  The SO2 removal efficiency of a control device is 
determined by measuring the SO2 rates before and after the 
control device.
    1.2.5  The inlet rates to SO2 control systems and when 
SO2 control systems are not

[[Page 1009]]

used, SO2 emission rates to the atmosphere may be determined 
by fuel sampling and analysis (optional).

 2. Emission Rates of Particulate Matter, Sulfur Dioxide, and Nitrogen 
                                 Oxides

    Select from the following sections the applicable procedure to 
compute the PM, SO2, or NOx emission rate (E) in 
ng/J (lb/million Btu). The pollutant concentration must be in ng/scm 
(lb/scf) and the F factor must be in scm/J (scf/million Btu). If the 
pollutant concentration (C) is not in the appropriate units, use the 
following table to make the proper conversion:

                  Conversion Factors for Concentration
------------------------------------------------------------------------
              From                         To             Multiply by
------------------------------------------------------------------------
g/scm...........................  ng/scm.............  10\9\
mg/scm..........................  ng/scm.............  10\6\
lb/scf..........................  ng/scm.............  1.602 x 10\13\
ppm SO2.........................  ng/scm.............  2.66 x 10\6\
ppm NOx.........................  ng/scm.............  1.912 x 10\6\
ppm SO2.........................  lb/scf.............  1.660 x 10-7
ppm NOx.........................  lb/scf.............  1.194 x 10-7
------------------------------------------------------------------------

    An F factor is the ratio of the gas volume of the products of 
combustion to the heat content of the fuel. The dry F factor 
(Fd) includes all components of combustion less water, the 
wet F factor (Fw) includes all components of combustion, and 
the carbon F factor (Fc) includes only carbon dioxide.
    Note: Since Fw factors include water resulting only from 
the combustion of hydrogen in the fuel, the procedures using 
Fw factors are not applicable for computing E from steam 
generating units with wet scrubbers or with other processes that add 
water (e.g., steam injection)
    2.1  Oxygen-Based F Factor, Dry Basis. When measurements are on a 
dry basis for both O2 (%O2d) and pollutant 
(Cd) concentrations, use the following equation:

E=Cd Fd [20.9/(20.9-%O2d)]    
                                                                Eq. 19-1
    2.2  Oxygen-Based F Factor, Wet Basis. When measurements are on a 
wet basis for both O2 (%O2w) and pollutant 
(Cw) concentrations, use either of the following:
    2.2.1  If the moisture fraction of ambient air (Bwa) is 
measured:

E=[Cw Fw20.9]/
          [20.9(1-Bwa)-%O2w]    
                                                                Eq. 19-2
    Instead of actual measurement, Bwa may be estimated 
according to the procedure below.
    (Note: The estimates are selected to ensure that negative errors 
will not be larger than -1.5 percent. However, positive errors, or over-
estimation of emissions, of as much as 5 percent may be introduced 
depending upon the geographic location of the facility and the 
associated range of ambient moisture):
    2.2.1.1  Bwa=0.027. This value may be used at any 
location at all times.
    2.2.1.2  Bwa=Highest monthly average of Bwa 
that occurred within the previous calendar year at the nearest Weather 
Service Station. This value shall be determined annually and may be used 
as an estimate for the entire current calendar year.
    2.2.1.3  Bwa=Highest daily average of Bwa that 
occurred within a calendar month at the nearest Weather Service Station, 
calculated from the data from the past 3 years. This value shall be 
computed for each month and may be used as an estimate for the current 
respective calendar month.
    2.2.2  If the moisture fraction (Bws) of the effluent gas 
is measured:

E=Cw Fd {20.9/
          [20.9(1-Bws)-%O2w]}    
                                                                Eq. 19-3
    2.3  Oxygen-Based F Factor, Dry/Wet Basis.
    2.3.1  When the pollutant concentration is measured on a wet basis 
(Cw) and O2 concentration is measured on a dry 
basis (%O2d), use the following equation:

E=[(Cw Fd)/(1-Bws)]/[20.9/
          (20.9-%O2d)]    
                                                                Eq. 19-4
    2.3.2   When the pollutant concentration is measured on a dry basis 
(Cd) and the O2 concentration is measured on a wet 
basis (%O2w), use the following equation:

E=[Cd Fd20.9]/[20.9-O2w/
          (1-Bws)]
                                                                Eq. 19-5
    2.4  Carbon Dioxide-Based F Factor, Dry Basis. When measurements are 
on a dry basis for both CO2 (%CO2d) and pollutant 
(Cd) concentrations, use the following equation:

E=Cd Fc(100/%CO2d)    
                                                                Eq. 19-6
    2.5  Carbon Dioxide-Based F Factor, Wet Basis. When measurements are 
on a wet basis for both CO2 (%CO2w) and pollutant 
(Cw) concentrations, use the following equation:

E=Cw Fc (100/%CO2w)    
                                                                Eq. 19-7
    2.6  Carbon Dioxide-Based F Factor, Dry/Wet Basis.
    2.6.1  When the pollutant concentration is measured on a wet basis 
(Cw) and CO2 concentration is measured on a dry 
basis (%CO2d), use the following equation:

E=[Cw Fc/(1-Bws)] (100/
          %CO2d)    
                                                                Eq. 19-8
    2.6.2  When the pollutant concentration is measured on a dry basis 
(Cd) and CO2 concentration is measured on a wet 
basis (%CO2w), use the following equation:

E=Cd(1-Bws)Fc(100/%CO2w)    

[[Page 1010]]

                                                                Eq. 19-9
    2.7  Direct-Fired Reheat Fuel Burning. The effect of direct-fired 
reheat fuel burning (for the purpose of raising the temperature of the 
exhaust effluent from wet scrubbers to above the moisture dew-point) on 
emission rates will be less than 1.0 percent and, therefore, 
may be ignored.
    2.8  Combined Cycle-Gas Turbine Systems. For gas turbine-steam 
generator combined cycle systems, determine the emissions from the steam 
generating unit or the percent reduction in potential SO2 
emissions as follows:
    2.8.1  Compute the emission rate from the steam generating unit 
using the following equation:

Ebo=Eco+(Hg/
          Hb)(Eco-Eg)    
                                                               Eq. 19-10

where:

Ebo=pollutant emission rate from the steam generating unit, 
          ng/J (lb/million Btu).
Eco=pollutant emission rate in combined effluent, ng/J (lb/
          million Btu).
Eg=pollutant rate from gas turbine, ng/J (lb/million Btu).
Hb=heat input rate to the steam generating unit from fuels 
          fired in the steam generating unit, J/hr (million Btu/hr).
Hg=heat input rate to gas turbine from all fuels fired in the 
          gas turbine, J/hr (million Btu/hr).
    2.8.1.1  Use the test methods and procedures section of Subpart GG 
to obtain Eco and Eg. Do not use Fw 
factors for determining Eg or Eco. If an 
SO2 control device is used, measure Eco after the 
control device.
    2.8.1.2  Suitable methods shall be used to determine the heat input 
rates to the steam generating units (Hb) and the gas turbine 
(Hg).
    2.8.2  If a control device is used, compute the percent of potential 
SO2 emissions (% Ps) using the following 
equations:

Ebi=Eci-(Hg/
          Hb)(Eci-Eg)    
                                                               Eq. 19-11

% Ps=100 (1-Ebo/Ebi)    
                                                               Eq. 19-12

where:

Ebi=pollutant rate from the steam generating unit, ng/J (lb/
          million Btu)
Eci=pollutant rate in combined effluent, ng/J (lb/million 
          Btu).
    Use the test methods and procedures section of Subpart GG to obtain 
Eci and Eg. Do not use Fw factors for 
determining Eg or Eci.

                              3. F Factors

    Use an average F factor according to Section 3.1 or determine an 
applicable F factor according to Section 3.2. If combined fuels are 
fired, prorate the applicable F factors using the procedure in Section 
3.3.
    3.1 Average F Factors. Average F factors (Fd, 
Fw, or Fc) from Table 19-1 may be used.

                                   Table 19-1--F Factors for Various Fuels \1\
----------------------------------------------------------------------------------------------------------------
                                             Fd                         Fw                         Fc
                                --------------------------------------------------------------------------------
           Fuel type                            dscf/10 6                  wscf/10 6                   scf/10 6
                                    dscm/J         Btu         wscm/J         Btu          scm/J         Btu
----------------------------------------------------------------------------------------------------------------
Coal:
  Anthracite \2\...............   2.71 x 10-\       10,100   2.83 x 10-\       10,540   0.530 x 10-        1,970
                                           7\                         7\                        \7\
  Bituminous \2\...............   2.63 x 10-\        9,780  2.86 x 10-\7       10,640   0.484 x 10-        1,800
                                           7\                          \                        \7\
  Lignite......................   2.65 x 10-\        9,860   3.21 x 10-\       11,950   0.513 x 10-        1,910
                                           7\                         7\                        \7\
Oil \3\........................   2.47 x 10-\        9,190   2.77 x 10-\       10,320   0.383 x 10-        1,420
                                           7\                         7\                        \7\
Gas:
  Natural......................   2.43 x 10-\        8,710   2.85 x 10-\       10,610   0.287 x 10-        1,040
                                           7\                         7\                        \7\
  Propane......................   2.34 x 10-\        8,710   2.74 x 10-\       10,200   0.321 x 10-        1,190
                                           7\                         7\                        \7\
  Butane.......................   2.34 x 10-\        8,710   2.79 x 10-\       10,390   0.337 x 10-        1,250
                                           7\                         7\                        \7\
Wood...........................   2.48 x 10-\        9,240  ............  ...........  0.492 x 10-\        1,830
                                           7\                                                    7\
Wood Bark......................   2.58 x 10-\        9,600  ............  ...........   0.516 x 10-        1,920
                                           7\                                                   \7\
Municipal......................   2.57 x 10-\        9,570  ............  ...........   0.488 x 10-        1,820
                                           7\                                                   \7\
Solid Waste....................  ............
----------------------------------------------------------------------------------------------------------------
\1\ Determined at standard conditions: 20  deg.C (68  deg.F) and 760 mm Hg (29.92 in. Hg).
\2\ As classified according to ASTM D388-77.
\3\ Crude, residual, or distillate.


    3.2 Determined F Factors. If the fuel burned is not listed in Table 
19-1 or if the owner or operator chooses to determine an F factor rather 
than use the values in Table 19-1, use the procedure below:
    3.2.1 Equations. Use the equations below, as appropriate, to compute 
the F factors:

Fd = K[(Khd%H) + (Kc%C) + 
          (Ks%S) + (Kn%N) - (Ko%0)]/
          GCVw
                                                               Eq. 19-13

Fw = K[(Khw%H) + (Kc%C) + 
          (Ks%S) + (Kn%N) - (Ko%0) + 
          (Kw%H2O)]/GCVw
                                                               Eq. 19-14
Fc=K(Kcc%C)/GCV

[[Page 1011]]

                                                               Eq. 19-15
    (Note.-- Omit the %H2O term in the equations for 
Fw if %H and %0 include the unavailable hydrogen and oxygen 
in the form of H2O.)
where:

Fd,Fw,Fc=volumes of combustion 
          components per unit of heat content, scm/J (scf/million Btu).
%H, %C, %S, %N, %0, and %H2O=concentrations of hydrogen, 
          carbon, sulfur, nitrogen, oxygen, and water from an ultimate 
          analysis of fuel, weight percent.
GCV=gross calorific value of the fuel consistent with the ultimate 
          analysis, kJ/kg (Btu/lb).
K=conversion factor, 10-\5\ (kJ/J)/(%) [10 \6\ Btu/million 
          Btu].
Khd=22.7 (scm/kg))[(3.64 (scf/lb)/(%)].
Kc=9.57 (scm/kg)[(1.53 (scf/lb)/(%)].
Ks=3.54 (scm/kg) [(0.57 (scf/lb)/(%)].
Kn=0.86 (scm/kg [0.14 (scf/lb)/(%)].
Ko=2.85 (scm/kg) [0.46 (scf/lb)/(%)].
Khw=34.74 (scm/kg) [(5.57 (scf/lb)/(%)].
Kw=1.30 (scm/kg) [(0.21 (scf/lb)/(%)].
Kcc=2.0 (scm/kg) [(0.321 (scf/lb)/(%)].
    3.2.2 Use applicable sampling procedures in Section 5.2.1 or 5.2.2 
to obtain samples for analyses.
    3.2.3 Use ASTM D3176-74 (incorporated by reference--see Sec. 60.17) 
for ultimate analysis of the fuel.
    3.2.4 Use applicable methods in Section 5.2.1 or 5.2.2 to determine 
the heat content of solid or liquid fuels. For gaseous fuels, use ASTM 
D1826-77 (IBR--see Sec. 60.17) to determine the heat content.
    3.3 F Factors for Combination of Fuels. If combinations of fuels are 
burned, use the following equations, as applicable unless otherwise 
specified in applicable subpart:
[GRAPHIC] [TIFF OMITTED] TC01JN92.241

where:

Xk=fraction of total heat input from each type of fuel k.
n=number of fuels being burned in combination.

               4. Determination of Average Pollutant Rates

    4.1  Average Pollutant Rates from Hourly Values. When hourly average 
pollutant rates (Eh), inlet or outlet, are obtained (e.g., 
CEMS values), compute the average pollutant rate (Ea) for the 
performance test period (e.g., 30 days) specified in the applicable 
regulation using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.242

where:
Ea=average pollutant rate for the specified performance test 
          period, ng/J (lb/million Btu).
Eh=hourly average pollutant, ng/J (lb/million Btu).
H=total number of operating hours for which pollutant rates are 
          determined in the performance test period.
    4.2  Average Pollutant Rates from Other than Hourly Averages. When 
pollutant rates

[[Page 1012]]

are determined from measured values representing longer than 1-hour 
periods (e.g., daily fuel sampling and analyses or Method 6B values), or 
when pollutant rates are determined from combinations of 1-hour and 
longer than 1-hour periods (e.g., CEMS and Method 6B values), compute 
the average pollutant rate (Ea) for the performance test 
period (e.g., 30 days) specified in the applicable regulation using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.243

where:

Ed=average pollutant rate for each sampling period (e.g., 24-
          hr Method 6B sample or 24-hr fuel sample) or for each fuel lot 
          (e.g., amount of fuel bunkered), ng/J (lb/million Btu).
nd=number of operating hours of the affected facility within 
          the performance test period for each Ed determined.
D=number of sampling periods during the performance test period.
    4.3  Daily Geometric Average Pollutant Rates from Hourly Values. The 
geometric average pollutant rate (Ega) is computed using the 
following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.207

where:

Ega = daily geometric average pollutant rate, ng/J (lbs/
          million Btu) or ppm corrected to 7 percent O2.
Ehj = hourly arithmetic average pollutant rate for hour 
          ``j,'' ng/J (lb/million Btu) or ppm corrected to 7 percent 
          O2.
n = total number of hourly averages for which pollutant rates are 
          available within the 24 hr midnight to midnight daily period.
ln = natural log of indicated value.
EXP = the natural logarithmic base (2.718) raised to the value enclosed 
          by brackets.

   5. Determination of Overall Reduction in Potential Sulfur Dioxide 
                                Emission

    5.1  Overall Percent Reduction. Compute the overall percent 
SO2 reduction (%Ro) using the following equation:

%Ro=100 [1.0-(1.0-%Rf/100)(1.0-%Rg/
          100)]    
                                                               Eq. 19-21

where:
%Rf=SO2 removal efficiency from fuel pretreatment, 
          percent.
%Rg=SO2 removal efficiency of the control device, 
          percent.
    5.2  Pretreatment Removal Efficiency (Optional). Compute the 
SO2 removal efficiency from fuel pretreatment 
(%Rf) for the averaging period (e.g., 90 days) as specified 
in the applicable regulation using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.244

where:

%Sp, %Sr=sulfur content of the product and raw 
          fuel lots, respectively, dry basis weight percent.
GCVp, GCVr=gross calorific value for the product 
          and raw fuel lots, respectively, dry basis, kg/kg (Btu/lb).
Lp, Lr=weight of the product and raw fuel lots, 
          respectively, metric ton (ton).
n=number of fuel lots during the averaging period.
    Note: In calculating %Rf, include %S and GCV values for 
all fuel lots that are not pretreated and are used during the averaging 
period.
    5.2.1  Solid Fossil (Including Waste) Fuel--Sampling and Analysis.

[[Page 1013]]

    Note: For the purposes of this method, raw fuel (coal or oil) is the 
fuel delivered to the desulfurization (pretreatment) facility. For oil, 
the input oil to the oil desulfurization process (e.g., hydrotreatment) 
is considered to be the raw fuel.
    5.2.1.1  Sample Increment Collection. Use ASTM D2234-76 (IBR--see 
Sec. 60.17), Type I, Conditions A, B, or C, and systematic spacing. As 
used in this method, systematic spacing is intended to include evenly 
spaced increments in time or increments based on equal weights of coal 
passing the collection area.
    As a minimum, determine the number and weight of increments required 
per gross sample representing each coal lot according to Table 2 or 
Paragraph 7.1.5.2 of ASTM D2234-76. Collect one gross sample for each 
lot of raw coal and one gross sample for each lot of product coal.
    5.2.1.2  ASTM Lot Size. For the purpose of Section 5.2 (fuel 
pretreatment), the lot size of product coal is the weight of product 
coal from one type of raw coal. The lot size of raw coal is the weight 
of raw coal used to produce one lot of product coal. Typically, the lot 
size is the weight of coal processed in a 1-day (24-hour) period. If 
more than one type of coal is treated and produced in 1 day, then gross 
samples must be collected and analyzed for each type of coal. A coal lot 
size equaling the 90-day quarterly fuel quantity for a steam generating 
unit may be used if representative sampling can be conducted for each 
raw coal and product coal.
    Note: Alternative definitions of lot sizes may be used, subject to 
prior approval of the Administrator.
    5.2.1.3  Gross Sample Analysis. Use ASTM D2013-72 to prepare the 
sample, ASTM D3177-75 or ASTM D4239-85 to determine sulfur content (%S), 
ASTM D3173-73 to determine moisture content, and ASTM D2015-77 or ASTM 
D3286-85 to determine gross calorific value (GCV) (all methods cited 
IBR--see Sec. 60.17) on a dry basis for each gross sample.
    5.2.2  Liquid Fossil Fuel--Sampling and Analysis. See Note under 
Section 5.2.1.
    5.2.2.1  Sample Collection. Follow the procedures for continuous 
sampling in ASTM D270-65 (Reapproved 1975) (IBR--see Sec. 60.17) for 
each gross sample from each fuel lot.
    5.2.2.2  Lot Size. For the purpose of Section 5.2 (fuel 
pretreatment), the lot size of a product oil is the weight of product 
oil from one pretreatment facility and intended as one shipment (ship 
load, barge load, etc.). The lot size of raw oil is the weight of each 
crude liquid fuel type used to produce a lot of product oil.
    Note: Alternative definitions of lot sizes may be used, subject to 
prior approval of the Administrator.
    5.2.2.3  Sample Analysis. Use ASTM D129-64 (Reapproved 1978), ASTM 
D1552-83, or ASTM D4057-81 to determine the sulfur content (%S) and ASTM 
D240-76 (all methods cited IBR--see Sec. 60.17) to determine the GCV of 
each gross sample. These values may be assumed to be on a dry basis. The 
owner or operator of an affected facility may elect to determine the GCV 
by sampling the oil combusted on the first steam generating unit 
operating day of each calendar month and then using the lowest GCV value 
of the three GCV values per quarter for the GCV of all oil combusted in 
that calendar quarter.
    5.2.3  Use appropriate procedures, subject to the approval of the 
Administrator, to determine the fraction of total mass input derived 
from each type of fuel.
    5.3  Control Device Removal Efficiency. Compute the percent removal 
efficiency (%Rg of the control device using the following 
equation:

%Rg=100[1.0-Eao/Eai]    
                                                               Eq. 19-23

where:

Eao, Eai=average pollutant rate of the control 
          device, outlet and inlet, respectively, for the performance 
          test period, ng/J (lb/million Btu).
    5.3.1  Use continuous emission monitoring systems or test methods, 
as appropriate, to determine the outlet SO2 rates and, if 
appropriate, the inlet SO2 rates. The rates may be determined 
as hourly (Eh) or other sampling period averages 
(Ed). Then, compute the average pollutant rates for the 
performance test period (Eao and Eai) using the 
procedures in Section 4.
    5.3.2  As an alternative, as-fired fuel sampling and analysis may be 
used to determine inlet SO2 rates as follows:
    5.3.2.1   Compute the average inlet SO2 rate 
(Edi) for each sampling period using the following equation:

Edi=K (%S/GCV)    
                                                               Eq. 19-24

where:

Edi=average inlet SO2 rate for each sampling 
          period d, ng/J (lb/million Btu)
% S=sulfur content of as-fired fuel lot, dry basis, weight percent.
GCV=gross calorific value of the fuel lot consistent with the sulfur 
          analysis, kJ/kg (Btu/lb).
K=2 x 10\7\[(kg)(ng)/(%)(J)]{2 x 10\4\(lb)(Btu/(%))(million Btu)}

After calculating Edi use the procedures in Section 4.2 to 
determine the average inlet SO2 rate for the performance test 
period (Eai).
    5.3.2.2  Collect the fuel samples from a location in the fuel 
handling system that provides a sample representative of the fuel 
bunkered or consumed during a steam generating unit operating day.

[[Page 1014]]

    For the purpose of as-fired fuel sampling under Section 5.3.2 or 
Section 6, the lot size for coal is the weight of coal bunkered or 
consumed during each steam generating unit operating day. The lot size 
for oil is the weight of oil supplied to the ``day'' tank or consumed 
during each steam generating unit operating day.
    For reporting and calculation purposes, the gross sample shall be 
identified with the calendar day on which sampling began. For steam 
generating unit operating days when a coal-fired steam generating unit 
is operated without coal being added to the bunkers, the coal analysis 
from the previous ``as bunkered'' coal sample shall be used until coal 
is bunkered again. For steam generating unit operating days when an oil-
fired steam generating unit is operated without oil being added to the 
oil ``day'' tank, the oil analysis from the previous day shall be used 
until the ``day'' tank is filled again.
    Alternative definitions of fuel lot size may be used, subject to 
prior approval of the Administrator.
    5.3.2.3  Use ASTM procedures specified in Section 5.2.1 or 5.2.2 to 
determine the sulfur contents (%S) and gross calorific values (GCV).
    5.4  Daily Geometric Average Percent Reduction from Hourly Values. 
The geometric average percent reduction (%Rga) is computed 
using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.208

where:

%Rga = daily geometric average percent reduction.
Ejo, Eji = matched pair hourly arithmetic average 
          pollutant rate, outlet and inlet, respectively, ng/J (lb/
          million Btu) or ppm corrected to 7 percent O2.
n = total number of hourly averages for which paired inlet and outlet 
          pollutant rates are available within the 24-hr midnight to 
          midnight daily period.
ln=natural log of indicated value.
EXP = the natural logarithmic base (2.718) raised to the value enclosed 
          by brackets.
    Note: The calculation includes only paired data sets (hourly 
average) for the inlet and outlet pollutant measurements.

             6. Sulfur Retention Credit for Compliance Fuel

    If fuel sampling and analysis procedures in Section 5.2.1 are being 
used to determine average SO2 emission rates (Eas) 
to the atmosphere from a coal-fired steam generating unit when there is 
no SO2 control device, the following equation may be used to 
adjust the emission rate for sulfur retention credits (no credits are 
allowed for oil-fired systems) (Edi) for each sampling period 
using the following equation:

Edi=0.97 K (%S/GCV)    
                                                               Eq. 19-25

where:

Edi=average inlet SO2 rate for each sampling 
          period d, ng/J (lb/million Btu)
%S=sulfur content of as-fired fuel lot, dry basis, weight percent.
GCV=gross calorific value of the fuel lot consistent with the sulfur 
          analysis, kJ/kg (Btu/lb).
K=2 x 10\7\[(kg)(ng)/(%)(J)] {2 x 10\4\(lb)(Btu/(%))(million Btu)}

After calculating Edi use the procedures in Section 4-2 to 
determine the average SO2 emission rate to the atmosphere for 
the performance test period (Eao).

 7. Determination of Compliance When Minimum Data Requirement Is Not Met

    7.1  Adjusted Emission Rates and Control Device Removal Efficiency. 
When the minimum data requirement is not met, the Administrator may use 
the following adjusted emission rates or control device removal 
efficiencies to determine compliance with the applicable standards.
    7.1.1  Emission Rate. Compliance with the emission rate standard may 
be determined by using the lower confidence limit of the emission rate 
(Eao*) as follows:

Eao*=Eao-t0.95 So    
                                                               Eq. 19-26

where:

So=standard deviation of the hourly average emission rates 
          for each performance test period, ng/J (lb/million Btu).
t0.95=values shown in Table 19-2 for the indicated number of 
          data points n.
    7.1.2  Control Device Removal Efficiency. Compliance with the 
overall emission reduction (%Ro) may be determined by using 
the lower confidence limit of the emission rate (Eao*) and 
the upper confidence limit of the inlet pollutant rate (Eai*) 
in calculating the

[[Page 1015]]

control device removal efficiency (%Rg) as follows:

%Rg=100 [1.0-Eao*/Eai*]    
                                                               Eq. 19-27

Eai*=Eai+t0.95 Si    
                                                               Eq. 19-28

where:

Si=standard deviation of the hourly average inlet pollutant 
          rates for each performance test period, ng/J (lb/million Btu).

                      Table 19-2--Values for t0.95
------------------------------------------------------------------------
    n\1\        t0.95        n\1\        t0.95       n\1\        t0.95
------------------------------------------------------------------------
         2         6.31           8        1.89       22-26        1.71
         3         2.42           9        1.86       27-31        1.70
         4         2.35          10        1.83       32-51        1.68
         5         2.13          11        1.81       59-91        1.67
         6         2.02       12-16        1.77      92-151        1.66
         7         1.94       17-21        1.73      152 or       1.65
                                                       more
------------------------------------------------------------------------
\1\ The values of this table are corrected for n-1 degrees of freedom.
  Use n equal to the number (H) of hourly average data points.

    7.2  Standard Deviation of Hourly Average Pollutant Rates. Compute 
the standard deviation (Se) of the hourly average pollutant 
rates using the following equation:
[GRAPHIC] [TIFF OMITTED] TC01JN92.245

where:

S=standard deviation of the hourly average pollutant rates for each 
          performance test period, ng/J (lb/million Btu).
Hr=total numbers of hours in the performance test period 
          (e.g., 720 hours for 30-day performance test period).
    Equation 19-29 may be used to compute the standard deviation for 
both the outlet (So) and, if applicable, inlet 
(Si) pollutant rates.

Method 20--Determination of Nitrogen Oxides, Sulfur Dioxide, and Diluent 
                 Emissions from Stationary Gas Turbines

1. Principle and Applicability

    1.1  Applicability. This method is applicable for the determination 
of nitrogen oxides (NOx), sulfur dioxide (SO2), 
and a diluent gas, either oxygen (O2) or carbon dioxide 
(CO2), emissions from stationary gas turbines. For the 
NOx and diluent concentration determinations, this method 
includes: (1) Measurement system design criteria; (2) Analyzer 
performance specifications and performance test procedures; and (3) 
Procedures for emission testing.

    1.2  Principle. A gas sample is continuously extracted from the 
exhaust stream of a stationary gas turbine; a portion of the sample 
stream is conveyed to instrumental analyzers for determination of 
NOx and diluent content. During each NOx and 
diluent determination, a separate measurement of SO2 
emissions is made, using Method 6, or its equivalent. The diluent 
determination is used to adjust the NOx and SO2 
concentrations to a reference condition.

2. Definitions

    2.1  Measurement System. The total equipment required for the 
determination of a gas concentration or a gas emission rate. The system 
consists of the following major subsystems:
    2.1.1  Sample Interface. That portion of a system that is used for 
one or more of the following: sample acquisition, sample transportation, 
sample conditioning, or protection of the analyzers from the effects of 
the stack effluent.
    2.1.2  NOx Analyzer. That portion of the system that 
senses NOx and generates an output proportional to the gas 
concentration.
    2.1.3  O2 Analyzer. That portion of the system that 
senses O2 and generates an output proportional to the gas 
concentration.
    2.1.4  CO2 Analyzer. That portion of the system that 
senses CO2 and generates an output proportional to the gas 
concentration.
    2.1.5  Data Recorder. That portion of the measurement system that 
provides a permanent record of the analyzer(s) output. The data recorder 
may include automatic data reduction capabilities.
    2.2  Span Value. The upper limit of a gas concentration measurement 
range that is specified for affected source categories in the applicable 
part of the regulations.

[[Page 1016]]

    2.3  Calibration Gas. A known concentration of a gas in an 
appropriate diluent gas.
    2.4  Calibration Error. The difference between the gas concentration 
indicated by the measurement system and the known concentration of the 
calibration gas.
    2.5  Zero Drift. The difference in the measurement system output 
readings from zero after a stated period of operation during which no 
unscheduled maintenance, repair, or adjustment took place and the input 
concentration at the time of the measurements was zero.
    2.6  Calibration Drift. The difference in the measurement system 
output readings from the known concentration of the calibration gas 
after a stated period of operation during which no unscheduled 
maintenance, repair, or adjustment took place and the input at the time 
of the measurements was a high-level value.
    2.7  Response Time. The amount of time required for the measurement 
system to display on the data output 95 percent of a step change in 
pollutant concentration.
    2.8  Interference Response. The output response of the measurement 
system to a component in the sample gas, other than the gas component 
being measured.

3. Measurement System Performance Specifications

    3.1  NO2 to NO Converter. Greater than 90 percent 
conversion efficiency of NO2 to NO.
    3.2  Interference Response. Less than plus-minus2 percent 
of the span value.
    3.3  Response Time. No greater than 30 seconds.
    3.4  Zero Drift. Less than plus-minus2 percent of the 
span value over the period of each test run.
    3.5  Calibration Drift. Less than plus-minus2 percent of 
the span value over the period of each test run.

4. Apparatus and Reagents

    4.1  Measurement System. Use any measurement system for NOx 
and diluent that is expected to meet the specifications in this method. 
A schematic of an acceptable measurement system is shown in Figure 20-1. 
The essential components of the measurement system are described below:

[[Page 1017]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.246

    4.1.1  Sample Probe. Heated stainless steel, or equivalent, open-
ended, straight tube of sufficient length to traverse the sample points.
    4.1.2  Sample Line. Heated (>95  deg.C) stainless steel or Teflon 
tubing to transport the sample gas to the sample conditioners and 
analyzers.
    4.1.3  Calibration Valve Assembly. A three-way valve assembly to 
direct the zero and calibration gases to the sample conditioners and to 
the analyzers. The calibration valve assembly shall be capable of 
blocking the sample gas flow and of introducing calibration gases to the 
measurement system when in the calibration mode.
    4.1.4  NO2 to NO Converter. That portion of the system 
that converts the nitrogen dioxide (NO2) in the sample gas to 
nitrogen oxide (NO). Some analyzers are designed to measure NOx 
as NO2 on a wet basis and can be used without an NO2 
to NO converter or a moisture removal trap provided the sample line to 
the analyzer is heated (>95  deg.C) to the inlet of the analyzer. In 
addition, an NO2 to NO converter is not necessary if the 
NO2 portion of the exhaust gas is less than 5 percent of the 
total NOx concentration. As a guideline, an NO2 to 
NO converter is not necessary if the gas turbine is operated at 90 
percent or more of peak load capacity. A converter is necessary under 
lower load conditions.
    4.1.5  Moisture Removal Trap. A refrigerator-type condenser or other 
type device designed to continuously remove condensate from the sample 
gas while maintaining minimal contact between any condensate and the 
sample gas. The moisture removal trap is not necessary for analyzers 
that can measure NOx concentrations on a wet basis; for these 
analyzers, (a) heat the sample line up to the inlet of the analyzers, 
(b) determine the moisture content using methods subject to the approval 
of the Administrator, and (c) correct the NOx and diluent 
concentrations to a dry basis.
    4.1.6  Particulate Filter. An in-stack or an out-of-stack glass 
fiber filter, of the type specified in EPA Method 5; however, an out-

[[Page 1018]]

of-stack filter is recommended when the stack gas temperature exceeds 
250 to 300  deg.C.
    4.1.7  Sample Pump. A nonreactive leak-free sample pump to pull the 
sample gas through the system at a flow rate sufficient to minimize 
transport delay. The pump shall be made from stainless steel or coated 
with Teflon or equivalent.
    4.1.8  Sample Gas Manifold. A sample gas manifold to divert portions 
of the sample gas stream to the analyzers. The manifold may be 
constructed of glass, Teflon, stainless steel, or equivalent.
    4.1.9  Diluent Gas Analyzer. An analyzer to determine the percent 
O2 or CO2 concentration of the sample gas.
    4.1.10  Nitrogen Oxides Analyzer. An analyzer to determine the ppm 
NOx concentration in the sample gas stream.
    4.1.11  Data Recorder. A strip-chart recorder, analog computer, or 
digital recorder for recording measurement data.
    4.2  Sulfur Dioxide Analysis. EPA Method 6 apparatus and reagents.
    4.3  NOx Calibration Gases. The calibration gases for the 
NOx analyzer shall be NO in N2. Use four 
calibration gas mixtures as specified below:
    4.3.1  High-level Gas. A gas concentration that is equivalent to 80 
to 90 percent of the span value.
    4.3.2  Mid-level Gas. A gas concentration that is equivalent to 45 
to 55 percent of the span value.
    4.3.3  Low-level Gas. A gas concentration that is equivalent to 20 
to 30 percent of the span value.
    4.3.4  Zero Gas. A gas concentration of less than 0.25 percent of 
the span value. Ambient air may be used for the NOx zero gas.
    4.4  Diluent Calibration Gases.
    4.4.1  For O2 calibration gases, use purified air at 20.9 
percent O2 as the high-level O2 gas. Use a gas 
concentration between 11 and 15 percent O2 in nitrogen for 
the mid-level gas, and use purified nitrogen for the zero gas.
    4.4.2  For CO2 calibration gases, use a gas concentration 
between 8 and 12 percent CO2 in air for the high-level 
calibration gas. Use a gas concentration between 2 and 5 percent 
CO2 in air for the mid-level calibration gas, and use 
purified air (<100 ppm CO2) as the zero level calibration 
gas.

5. Measurement System Performance Test Procedures

    Perform the following procedures prior to measurement of emissions 
(Section 6) and only once for each test program, i.e., the series of all 
test runs for a given gas turbine engine.
    5.1  Calibration Gas Checks. There are two alternatives for checking 
the concentrations of the calibration gases. (a) The first is to use 
calibration gases that are documented traceable to National Bureau of 
Standards Reference Materials. Use Traceability Protocol for 
Establishing True Concentrations of Gases Used for Calibrations and 
Audits of Continuous Source Emission Monitors (Protocol Number 1) that 
is available from the Environmental Monitoring Systems Laboratory, 
Quality Assurance Branch, Mail Drop 77, Environmental Protection Agency, 
Research Triangle Park, NC 27711. Obtain a certification from the gas 
manufacturer that the protocol was followed. These calibration gases are 
not to be analyzed with the Reference Methods. (b) The second 
alternative is to use calibration gases not prepared according to the 
protocol. If this alternative is chosen, within 1 month prior to the 
emission test, analyze each of the calibration gas mixtures in 
triplicate using Method 7 or the procedure outlined in Citation 1 for 
NOx and use Method 3 for O2 or CO2. 
Record the results on a data sheet (example is shown in Figure 20-2). 
For the low-level, mid-level, or high-level gas mixtures, each of the 
individual NOx analytical results must be within 10 percent 
(or 10 ppm, whichever is greater) of the triplicate set average 
(O2 or CO2 test results must be within 0.5 percent 
O2 or CO2); otherwise, discard the entire set and 
repeat the triplicate analyses. If the average of the triplicate 
reference method test results is within 5 percent for NOx gas 
or 0.5 percent O2 or CO2 for the O2 or 
CO2 gas of the calibration gas manufacturer's tag value, use 
the tag value; otherwise, conduct at least three additional reference 
method test analyses until the results of six individual NOx 
runs (the three original plus three additional) agree within 10 percent 
(or 10 ppm, whichever is greater) of the average (O2 or 
CO2 test results must be within 0.5 percent O2 or 
CO2). Then use this average for the cylinder value.
    5.2  Measurement System Preparation. Prior to the emission test, 
assemble the measurement system following the manufacturer's written 
instructions in preparing and operating the NO2 to NO 
converter, the NOx analyzer, the diluent analyzer, and other 
components.

               Figure 20-2--Analysis of Calibration Gases

Date ---------- (Must be within 1 month prior to the test period)
Reference method used___________________________________________________

----------------------------------------------------------------------------------------------------------------
                                                                 Gas concentration, ppm
              Sample run              --------------------------------------------------------------------------
                                              Low levela               Mid levelb              High levelc
----------------------------------------------------------------------------------------------------------------
1
----------------------------------------------------------------------------------------------------------------
2
----------------------------------------------------------------------------------------------------------------
3
----------------------------------------------------------------------------------------------------------------
Average
----------------------------------------------------------------------------------------------------------------
Maximum % deviationd.................
----------------------------------------------------------------------------------------------------------------
a Average must be 20 to 30% of span value.

[[Page 1019]]

 
b Average must be 45 to 55% of span value.
c Average must be 80 to 90% of span value.
d Must be >plus-minus10% of applicable average or 10 ppm, whichever is greater.

    5.3  Calibration Check. Conduct the calibration checks for both the 
NOx and the diluent analyzers as follows:
    5.3.1  After the measurement system has been prepared for use 
(Section 5.2), introduce zero gases and the mid-level calibration gases; 
set the analyzer output responses to the appropriate levels. Then 
introduce each of the remainder of the calibration gases described in 
Sections 4.3 or 4.4, one at a time, to the measurement system. Record 
the responses on a form similar to Figure 20-3.
    5.3.2  If the linear curve determined from the zero and mid-level 
calibration gas responses does not predict the actual response of the 
low-level (not applicable for the diluent analyzer) and high-level gases 
within 2 percent of the span value, the calibration shall be considered 
invalid. Take corrective measures on the measurement system before 
proceeding with the test.
    5.4  Interference Response. Introduce the gaseous components listed 
in Table 20-1 into the measurement system separately, or as gas 
mixtures. Determine the total interference output response of the system 
to these components in concentration units; record the values on a form 
similar to Figure 20-4. If the sum of the interference responses of the 
test gases for either the NOx or diluent analyzers is greater 
than 2 percent of the applicable span value, take corrective measure on 
the measurement system.

                 Figure 20-3--Zero and Calibration Data
Turbine type.........................      Identification number....
Date.................................      Test number..............
Analyzer type........................      Identification number....
 



----------------------------------------------------------------------------------------------------------------
                            Cylinder value, ppm    Initial analyzer       Final analyzer     Difference: initial-
                                   or %           response, ppm or %    responses, ppm or %    final, ppm or %
----------------------------------------------------------------------------------------------------------------
Zero gas.................
----------------------------------------------------------------------------------------------------------------
 
Low-level gas............
----------------------------------------------------------------------------------------------------------------
 
Mid-level gas............
----------------------------------------------------------------------------------------------------------------
 
High-level gas...........
----------------------------------------------------------------------------------------------------------------

[GRAPHIC] [TIFF OMITTED] TC16NO91.209



                                 Table 20-1--Interference Test Gas Concentration
 
 
----------------------------------------------------------------------------------------------------------------
CO...................................  50050 ppm..  CO2....................  101
                                                                                          percent.
SO2..................................  20020 ppm..  O2.....................  20.91
                                                                                          percent.
----------------------------------------------------------------------------------------------------------------

                   Figure 20-4--Interference Response

Date of test ----------
Analyzer type___________________________________________________________
Serial No.______________________________________________________________

----------------------------------------------------------------------------------------------------------------
                                                                    Analyzer output
            Test gas type                 Concentration, ppm            response                % of span
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------

[GRAPHIC] [TIFF OMITTED] TC16NO91.210

    Conduct an interference response test of each analyzer prior to its 
initial use in the field. Thereafter, recheck the measurement system if 
changes are made in the instrumentation that could alter the 
interference response, e.g., changes in the type of gas detector.
    In lieu of conducting the interference response test, instrument 
vendor data, which demonstrate that for the test gases of Table

[[Page 1020]]

20-1 the interference performance specification is not exceeded, are 
acceptable.
    5.5  Response Time. To determine response time, first introduce zero 
gas into the system at the calibration valve until all readings are 
stable; then, switch to monitor the stack effluent until a stable 
reading can be obtained. Record the upscale response time. Next, 
introduce high-level calibration gas into the system. Once the system 
has stabilized at the high-level concentration, switch to monitor the 
stack effluent and wait until a stable value is reached. Record the 
downscale response time. Repeat the procedure three times. A stable 
value is equivalent to a change of less than 1 percent of span value for 
30 seconds or less than 5 percent of the measured average concentration 
for 2 minutes. Record the response time data on a form similar to Figure 
20-5, the readings of the upscale or downscale reponse time, and report 
the greater time as the ``response time'' for the analyzer. Conduct a 
response time test prior to the initial field use of the measurement 
system, and repeat if changes are made in the measurement system.

                       Figure 20-5--Response Time

Date of test ----------

Analyzer type___________________________________________________________

S/N_____________________________________________________________________

Span gas concentration: -------- ppm.
Analyzer span setting: -------- ppm.
Upscale:
    1 -------- seconds.
    2 -------- seconds.
    3 -------- seconds.
      Average upscale response ---- seconds.

Downscale:
    1 -------- seconds.
    2 -------- seconds.
    3 -------- seconds.
      Average downscale response ---- seconds.

System response time=
slower average time=
-------- seconds.

    5.6  NO2 to NO Conversion Efficiency.
    5.6.1  Add gas from the mid-level NO in N2 calibration 
gas cylinder to a clean, evacuated, leak-tight Tedlar bag. Dilute this 
gas approximately 1:1 with 20.9 percent O2, purified air. 
Immediately attach the bag outlet to the calibration valve assembly and 
begin operation of the sampling system. Operate the sampling system, 
recording the NOx response, for at least 30 minutes. If the 
NO2 to NO conversion is 100 percent, the instrument response 
will be stable at the highest peak value observed. If the response at 
the end of 30 minutes decreases more than 2.0 percent of the highest 
peak value, the system is not acceptable and corrections must be made 
before repeating the check.
    5.6.2  Alternatively, the NO2 to NO converter check 
described in Title 40, Part 86: Certification and Test Procedures for 
Heavy-duty Engines for 1979 and Later Model Years may be used. Other 
alternative procedures may be used with approval of the Administrator.

6. Emission Measurement Test Procedure

    6.1  Preliminaries.
    6.1.1  Selection of a Sampling Site. Select a sampling site as close 
as practical to the exhaust of the turbine. Turbine geometry, stack 
configuration, internal baffling, and point of introduction of dilution 
air will vary for different turbine designs. Thus, each of these factors 
must be given special consideration in order to obtain a representative 
sample. Whenever possible, the sampling site shall be located upstream 
of the point of introduction of dilution air into the duct. Sample ports 
may be located before or after the upturn elbow, in order to accommodate 
the configuration of the turning vanes and baffles and to permit a 
complete, unobstructed traverse of the stack. The sample ports shall not 
be located within 5 feet or 2 diameters (whichever is less) of the gas 
discharge to atmosphere. For supplementary-fired, combined-cycle plants, 
the sampling site shall be located between the gas turbine and the 
boiler. The diameter of the sample ports shall be sufficient to allow 
entry of the sample probe.
    6.1.2  A preliminary O2 or CO2 traverse is 
made for the purpose of selecting sampling points of low O2 
or high CO2 concentrations, as appropriate for the 
measurement system. Conduct this test at the turbine operating condition 
that is the lowest percentage of peak load operation included in the 
test program. Follow the procedure below, or use an alternative 
procedure subject to the approval of the Administrator.
    6.1.2.1  Minimum Number of Points. Select a minimum number of points 
as follows: (1) Eight, for stacks having cross-sectional areas less than 
1.5 m2 (16.1 ft2); (2) eight plus one additional 
sample point for each 0.2 m2 (2.2 ft2 of areas, 
for stacks of 1.5 m2 to 10.0 m2 (16.1-107.6 
ft2) in cross-sectional area; and (3) 49 sample points (48 
for circular stacks) for stacks greater than 10.0 m 2 (107.6 
ft 2) in cross-sectional area. Note that for circular ducts, 
the number of sample points must be a multiple of 4, and for rectangular 
ducts, the number of points must be one of those listed in Table 20-2; 
therefore, round off the number of points (upward), when appropriate.
    6.1.2.2  Cross-sectional Layout and Location of Traverse Points. 
After the number of traverse points for the preliminary diluent sampling 
has been determined, use Method 1 to located the traverse points.
    6.1.2.3  Preliminary Diluent Measurement. While the gas turbine is 
operating at the

[[Page 1021]]

lowest percent of peak load, conduct a preliminary diluent measurement 
as follows: Position the probe at the first traverse point and begin 
sampling. The minimum sampling time at each point shall be 1 minute plus 
the average system response time. Determine the average steady-state 
concentration of diluent at each point and record the data on Figure 20-
6.
    6.1.2.4  Selection of Emission Test Sampling Points. Select the 
eight sampling points at which the lowest O2 concentrations 
or highest CO2 concentrations were obtained. Sample at each 
of these selected points during each run at the different turbine load 
conditions. More than eight points may be used, if desired, providing 
that the points selected as described above are included.

        Table 20-2--Cross-sectional Layout for Rectangular Stacks
------------------------------------------------------------------------
                                                                Matrix
                                                                layout
------------------------------------------------------------------------
No. of traverse points:
  9.........................................................       3 x 3
  12........................................................       4 x 3
  16........................................................       4 x 4
  20........................................................       5 x 4
  25........................................................       5 x 5
  30........................................................       6 x 5
  36........................................................       6 x 6
  42........................................................       7 x 6
  49........................................................       7 x 7
------------------------------------------------------------------------

                Figure 20-6--Preliminary Diluent Traverse

Date ----------

Location:
Plant___________________________________________________________________
City, State_____________________________________________________________

Turbine identification:
Manufacturer____________________________________________________________
Model, serial number____________________________________________________

------------------------------------------------------------------------
               Sample point                  Diluent concentration, ppm
------------------------------------------------------------------------
 
 
------------------------------------------------------------------------

    6.2  NOx and Diluent Measurement. This test is to be 
conducted at each of the specified load conditions. Three test runs at 
each load condition constitute a complete test.
    6.2.1  At the beginning of each NOx test run and, as 
applicable, during the run, record turbine data as indicated in Figure 
20-7. Also, record the location and number of the traverse points on a 
diagram.
    6.2.2  Position the probe at the first point determined in the 
preceding section and begin sampling. The minimum sampling time at each 
point shall be at least 1 minute plus the average system response time. 
Determine the average steady-state concentration of diluent and NOx 
at each point and record the data on Figure 20-8.

                Figure 20-7--Stationary Gas Turbine Data

                        turbine operation record

Test operator -------------------- Date_________________________________

Turbine identification:
Type____________________________________________________________________
Serial No.______________________________________________________________

Location:
Plant___________________________________________________________________
City____________________________________________________________________

Ambient temperature_____________________________________________________
Ambient humidity________________________________________________________
Test time start_________________________________________________________
Test time finish________________________________________________________
Fuel flow ratea____________________________________________________
Water or steam flow ratea____________________________________
Ambient pressure__________________________________________________
Ultimate fuel analysis:
C_______________________________________________________________________
H_______________________________________________________________________
O_______________________________________________________________________
N_______________________________________________________________________
S_______________________________________________________________________
Ash_____________________________________________________________________
H20__________________________________________________________

Trace metals:
Na______________________________________________________________________
Va______________________________________________________________________
K_______________________________________________________________________
etcb_______________________________________________________________

Operating load____________________________________________________
    aDescribe measurement method, i.e., continuous flow 
meter, start finish volumes, etc.
    bi.e., additional elements added for smoke suppression.

         Figure 20-8--Stationary Gas Turbine Sample Point Record

Turbine identification:
Manufacturer____________________________________________________________
Model, serial No._______________________________________________________

Location:
Plant___________________________________________________________________
City, State_____________________________________________________________

Ambient temperature_____________________________________________________
Ambient pressure________________________________________________________
Date ----------
Test time: start________________________________________________________
Test time: finish_______________________________________________________
Test operator name______________________________________________________

Diluent instrument type_________________________________________________
Serial No_______________________________________________________________

NOx instrument type__________________________________________
Serial No.

[[Page 1022]]

________________________________________________________________________

----------------------------------------------------------------------------------------------------------------
             Sample point                     Time, min               Diluenta, %               NOx a, ppm
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
 
 
----------------------------------------------------------------------------------------------------------------
aAverage steady-state value from recorder or instrument readout.

    6.2.3  After sampling the last point, conclude the test run by 
recording the final turbine operating parameters and by determining the 
zero and calibration drift, as follows:
    Immediately following the test run at each load condition, or if 
adjustments are necessary for the measurement system during the tests, 
reintroduce the zero and mid-level calibration gases as described in 
Sections 4.3 and 4.4, one at a time, to the measurement system at the 
calibration valve assembly. (Make no adjustments to the measurement 
system until after the drift checks are made). Record the analyzers' 
responses on a form similar to Figure 20-3. If the drift values exceed 
the specified limits, the test run preceding the check is considered 
invalid and will be repeated following corrections to the measurement 
system. Alternatively, recalibrate the measurement system and 
recalculate the measurement data. Report the test results based on both 
the initial calibration and the recalibration data.
    6.3  SO2 Measurement. This test is conducted only at the 
100 percent peak load condition. Determine SO2 using Method 
6, or equivalent, during the test. Select a minimum of six total points 
from those required for the NOx measurements; use two points 
for each sample run. The sample time at each point shall be at least 10 
minutes. Average the diluent readings taken during the NOx 
test runs at sample points corresponding to the SO2 traverse 
points (see Section 6.2.2) and use this average diluent concentration to 
correct the integrated SO2 concentration obtained by Method 6 
to 15 percent diluent (see Equation 20-1).
    If the applicable regulation allows fuel sampling and analysis for 
fuel sulfur content to demonstrate compliance with sulfur emission unit, 
emission sampling with Method 6 is not required, provided the fuel 
sulfur content meets the limits of the regulation.

7. Emission Calculations
    7.1  Moisture Correction. Measurement data used in most of these 
calculations must be on a dry basis. If measurements must be corrected 
to dry conditions, use the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.211


where:
Cd=Pollutant or diluent concentration adjusted to dry 
          conditions, ppm or percent.
Cw=Pollutant or diluent concentration measured under moist 
          sample conditions, ppm or percent.
Bws=Moisture content of sample gas as measured with Method 4, 
          reference method, or other approved method, percent/100.

    7.2  CO2 Correction Factor. If pollutant concentrations 
are to be corrected to 15 percent O2 and CO2 
concentration is measured in lieu of O2 concentration 
measurement, a CO2 correction factor is needed. Calculate the 
CO2 correction factor as follows:
    7.2.1  Calculate the fuel-specific F0 value for the fuel 
burned during the test using values obtained from Method 19, Section 
5.2, and the following equation.
[GRAPHIC] [TIFF OMITTED] TC16NO91.212

where:

FO=Fuel factor based on the ratio of oxygen volume to the 
          ultimate CO2 volume produced by the fuel at zero 
          percent excess air, dimensionless.
0.209=Fraction of air that is oxygen, percent/100.
Fd=Ratio of the volume of dry effluent gas to the gross 
          calorific value of the fuel from Method 19, dsm\3\/J (dscf/
          10\6\ Btu).
Fc=Ratio of the volume of carbon dioxide produced to the 
          gross calorific value of the fuel from Method 19, dsm\3\/J 
          (dscf\6\ Btu).
    7.2.2.  Calculate the CO2 correction factor for 
correcting measurement data to 15 percent oxygen, as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.213

where:
XCO2=CO2 Correction factor, percent.
5.9=20.9 percent O2-15 percent O2, the defined 
          O2 correction value, percent.

    7.3  Correction of Pollutant Concentrations to 15 percent 
O2. Calculate the NOx and SO2 gas 
concentrations adjusted to 15 percent O2 using Equation 20-4 
or 20-5, as appropriate. The correction to 15 percent O2 is 
very sensitive to the accuracy of the O2 or CO2 
concentration measurement. At the level of the analyzer drift specified 
in Section 3, the O2 or CO2 correction can exceed 
5 percent at the concentration levels expected in gas turbine exhaust 
gases. Therefore, O2

[[Page 1023]]

or CO2 analyzer stability and careful calibration are 
necessary.
    7.3.1  Correction of Pollutant Concentration Using O2 
Concentration. Calculate the O2 corrected pollutant 
concentration, as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.214

where:

Cadj=Pollutant concentration corrected to 15 percent 
          O2 ppm.
Cd=Pollutant concentration measured, dry basis, ppm.
%O2=Measured O2 concentration dry basis, percent.
    7.3.2  Correction of Pollutant Concentration Using CO2 
Concentration. Calculate the CO2 corrected pollutant 
concentration, as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.215

where:

%CO2=Measured CO2 concentration measured, dry 
          basis, percent.
    7.4  Average Adjusted NOx Concentration. Calculate the 
average adjusted NOx concentration by summing the adjusted 
values for each sample point and dividing by the number of points for 
each run.
    7.5  NOx and SO2 Emission Rate Calculations. 
The emission rates for NOx and SO2 in units of 
pollutant mass per quantity of heat input can be calculated using the 
pollutant and diluent concentrations and fuel-specific F-factors based 
on the fuel combustion characteristics. The measured concentrations of 
pollutant in units of parts per million by volume (ppm) must be 
converted to mass per unit volume concentration units for these 
calculations. Use the following table for such conversions:

                  Conversion Factors for Concentration
------------------------------------------------------------------------
              From                        To              Multiply by
------------------------------------------------------------------------
g/sm\3\.........................  ng/sm\3\..........  10\9\
mg/sm\3\........................  ng/sm\3\..........  10\6\
lb/scf..........................  ng/sm\3\..........  1.602 x 10\1\\3\
ppm (SO2).......................  ng/sm\3\..........  2.660 x 10\6\
ppm (NOx).......................  ng/sm\3\..........  1.912 x 10\6\
ppm (SO2).......................  lb/scf............  1.660 x 10-\7\
ppm (NOx).......................  lb/scf............  1.194 x 10-\7\
------------------------------------------------------------------------

    7.5.1  Calculation of Emission Rate Using Oxygen Correction. Both 
the O2 concentration and the pollutant concentration must be 
on a dry basis. Calculate the pollutant emission rate, as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.216

where:

E=Mass emission rate of pollutant, ng/J (lb/10\6\ Btu).
    7.5.2  Calculation of Emission Rate Using Carbon Dioxide Correction. 
The CO2 concentration and the pollutant concentration may be 
on either a dry basis or a wet basis, but both concentrations must be on 
the same basis for the calculations. Calculate the pollutant emission 
rate using Equation 20-7 or 20-8:
[GRAPHIC] [TIFF OMITTED] TC16NO91.217

[GRAPHIC] [TIFF OMITTED] TC16NO91.218

where:

Cw=Pollutant concentration measured on a moist sample basis, 
          ng/sm\3\ (lb/scf).
%CO2w=Measured CO2 concentration measured on a 
          moist sample basis, percent.

8. Bibliography

    1. Curtis, F. A Method for Analyzing NOx Cylinder Gases-
Specific Ion Electrode Procedure, Monograph available from Emission 
Measurement Laboratory, ESED, Research Triangle Park, NC 27711, October 
1978.
    2. Sigsby, John E., F. M. Black, T. A. Bellar, and D. L. Klosterman. 
Chemiluminescent Method for Analysis of Nitrogen Compounds in Mobile 
Source Emissions (NO, NO2, and NH3 ). 
``Environmental Science and Technology,'' 7:51-54. January 1973.
    3. Shigehara, R.T., R.M. Neulicht, and W.S. Smith. Validating Orsat 
Analysis Data from Fossil Fuel-Fired Units. Emission Measurement Branch, 
Emission Standards and Engineering Division, Office of Air Quality 
Planning and Standards, U.S. Environmental Protection Agency, Research 
Triangle Park, NC 27711. June 1975.

      Method 21--Determination of Volatile Organic Compounds Leaks

1. Applicability and Principle

    1.1  Applicability. This method applies to the determination of 
volatile organic compound (VOC) leaks from process equipment. These 
sources include, but are not limited to, valves, flanges and other 
connections, pumps and compressors, pressure relief devices, process 
drains, open-ended valves, pump and compressor seal system degassing 
vents, accumulator vessel vents, agitator seals, and access door seals.
    1.2  Principle. A portable instrument is used to detect VOC leaks 
from individual sources. The instrument detector type is not specified, 
but it must meet the specifications and performance criteria contained 
in Section 3. A leak definition concentration based on a reference 
compound is specified in each

[[Page 1024]]

applicable regulation. This procedure is intended to locate and classify 
leaks only, and is not to be used as a direct measure of mass emission 
rates from individual sources.

2. Definitions

    2.1  Leak Definition Concentration. The local VOC concentration at 
the surface of a leak source that indicates that a VOC emission (leak) 
is present. The leak definition is an instrument meter reading based on 
a reference compound.
    2.2  Reference Compound. The VOC species selected as an instrument 
calibration basis for specification of the leak definition 
concentration. (For example: If a leak definition concentration is 
10,000 ppmv as methane, then any source emission that results in a local 
concentration that yields a meter reading of 10,000 on an instrument 
calibrated with methane would be classified as a leak. In this example, 
the leak definition is 10,000 ppmv, and the reference compound is 
methane.)
    2.3  Calibration Gas. The VOC compound used to adjust the instrument 
meter reading to a known value. The calibration gas is usually the 
reference compound at a concentration approximately equal to the leak 
definition concentration.
    2.4  No Detectable Emission. Any VOC concentration at a potential 
leak source (adjusted for local VOC ambient concentration) that is less 
than a value corresponding to the instrument readability specification 
of section 3.1.1(c) indicates that a leak is not present.
    2.5  Response Factor. The ratio of the known concentration of a VOC 
compound to the observed meter reading when measured using an instrument 
calibrated with the reference compound specified in the application 
regulation.
    2.6  Calibration Precision. The degree of agreement between 
measurements of the same known value, expressed as the relative 
percentage of the average difference between the meter readings and the 
known concentration to the known concentration.
    2.7  Response Time. The time interval from a step change in VOC 
concentration at the input of the sampling system to the time at which 
90 percent of the corresponding final value is reached as displayed on 
the instrument readout meter.

3. Apparatus

    3.1  Monitoring Instrument.
    3.1.1  Specifications.
    a. The VOC instrument detector shall respond to the compounds being 
processed. Detector types which may meet this requirement include, but 
are not limited to, catalytic oxidation, flame ionization, infrared 
absorption, and photoionization.
    b. Both the linear response range and the measurable range of the 
instrument for each of the VOC to be measured, and for the VOC 
calibration gas that is used for calibration, shall encompass the leak 
definition concentration specified in the regulation. A dilution probe 
assembly may be used to bring the VOC concentration within both ranges; 
however, the specifications for instrument response time and sample 
probe diameter shall still be met.
    c. The scale of the instrument meter shall be readable to 
2.5 percent of the specified leak definition concentration 
when performing a no detectable emission survey.
    d. The instrument shall be equipped with an electrically driven pump 
to insure that a sample is provided to the detector at a constant flow 
rate. The nominal sample flow rate, as measured at the sample probe tip, 
shall be 0.10 to 3.0 liters per minute when the probe is fitted with a 
glass wool plug or filter that may be used to prevent plugging of the 
instrument.
    e. The instrument shall be intrinsically safe as defined by the 
applicable U.S.A. standards (e.g., National Electric Code by the 
National Fire Prevention Association) for operation in any explosive 
atmospheres that may be encountered in its use. The instrument shall, at 
a minimum, be intrinsically safe for Class 1, Division 1 conditions, and 
Class 2, Division 1 conditions, as defined by the example Code. The 
instrument shall not be operated with any safety device, such as an 
exhaust flame arrestor, removed.
    f. The instrument shall be equipped with a probe or probe extension 
for sampling not to exceed \1/4\ in. in outside diameter, with a single 
end opening for admission of sample.
    3.1.2  Performance Criteria.
    (a) The instrument response factors for each of the VOC to be 
measured shall be less than 10. When no instrument is available that 
meets this specification when calibrated with the reference VOC 
specified in the applicable regulation, the available instrument may be 
calibrated with one of the VOC to be measured, or any other VOC, so long 
as the instrument then has a response factor of less than 10 for each of 
the VOC to be measured.
    (b) The instrument response time shall be equal to or less than 30 
seconds. The instrument pump, dilution probe (if any), sample probe, and 
probe filter, that will be used during testing, shall all be in place 
during the response time determination.
    c. The calibration precision must be equal to or less than 10 
percent of the calibration gas value.
    d. The evaluation procedure for each parameter is given in Section 
4.4.
    3.1.3  Performance Evaluation Requirements.
    a. A response factor must be determined for each compound that is to 
be measured, either by testing or from reference sources. The response 
factor tests are required before

[[Page 1025]]

placing the analyzer into service, but do not have to be repeated at 
subsequent intervals.
    b. The calibration precision test must be completed prior to placing 
the analyzer into service, and at subsequent 3-month intervals or at the 
next use whichever is later.
    c. The response time test is required prior to placing the 
instrument into service. If a modification to the sample pumping system 
or flow configuration is made that would change the response time, a new 
test is required prior to further use.
    3.2  Calibration Gases. The monitoring instrument is calibrated in 
terms of parts per million by volume (ppmv) of the reference compound 
specified in the applicable regulation. The calibration gases required 
for monitoring and instrument performance evaluation are a zero gas 
(air, less than 10 ppmv VOC) and a calibration gas in air mixture 
approximately equal to the leak definition specified in the regulation. 
If cylinder calibration gas mixtures are used, they must be analyzed and 
certified by the manufacturer to be within plus-minus2 
percent accuracy, and a shelf life must be specified. Cylinder standards 
must be either reanalyzed or replaced at the end of the specified shelf 
life. Alternately, calibration gases may be prepared by the user 
according to any accepted gaseous standards preparation procedure that 
will yield a mixture accurate to within plus-minus2 percent. 
Prepared standards must be replaced each day of use unless it can be 
demonstrated that degradation does not occur during storage.
    Calibrations may be performed using a compound other than the 
reference compound if a conversion factor is determined for that 
alternative compound so that the resulting meter readings during source 
surveys can be converted to reference compound results.

4. Procedures

    4.1  Pretest Preparations. Perform the instrument evaluation 
procedures given in Section 4.4 if the evaluation requirements of 
Section 3.1.3 have not been met.
    4.2  Calibration Procedures. Assemble and start up the VOC analyzer 
according to the manufacturer's instructions. After the appropriate 
warmup period and zero internal calibration procedure, introduce the 
calibration gas into the instrument sample probe. Adjust the instrument 
meter readout to correspond to the calibration gas value.
    Note: If the meter readout cannot be adjusted to the proper value, a 
malfunction of the analyzer is indicated and corrective actions are 
necessary before use.
    4.3  Individual Source Surveys.
    4.3.1  Type I--Leak Definition Based on Concentration. Place the 
probe inlet at the surface of the component interface where leakage 
could occur. Move the probe along the interface periphery while 
observing the instrument readout. If an increased meter reading is 
observed, slowly sample the interface where leakage is indicated until 
the maximum meter reading is obtained. Leave the probe inlet at this 
maximum reading location for approximately two times the instrument 
response time. If the maximum observed meter reading is greater than the 
leak definition in the applicable regulation, record and report the 
results as specified in the regulation reporting requirements. Examples 
of the application of this general technique to specific equipment types 
are:
    a. Valves--The most common source of leaks from valves is at the 
seal between the stem and housing. Place the probe at the interface 
where the stem exits the packing gland and sample the stem 
circumference. Also, place the probe at the interface of the packing 
gland take-up flange seat and sample the periphery. In addition, survey 
valve housings of multipart assembly at the surface of all interfaces 
where a leak could occur.
    b. Flanges and Other Connections--For welded flanges, place the 
probe at the outer edge of the flange-gasket interface and sample the 
circumference of the flange. Sample other types of nonpermanent joints 
(such as threaded connections) with a similar traverse.
    c. Pumps and Compressors--Conduct a circumferential traverse at the 
outer surface of the pump or compressor shaft and seal interface. If the 
source is a rotating shaft, position the probe inlet within 1 cm of the 
shaft-seal interface for the survey. If the housing configuration 
prevents a complete traverse of the shaft periphery, sample all 
accessible portions. Sample all other joints on the pump or compressor 
housing where leakage could occur.
    d. Pressure Relief Devices--The configuration of most pressure 
relief devices prevents sampling at the sealing seat interface. For 
those devices equipped with an enclosed extension, or horn, place the 
probe inlet at approximately the center of the exhaust area to the 
atmosphere.
    e. Process Drains--For open drains, place the probe inlet at 
approximately the center of the area open to the atmosphere. For covered 
drains, place the probe at the surface of the cover interface and 
conduct a peripheral traverse.
    f. Open-Ended Lines or Valves--Place the probe inlet at 
approximately the center of the opening to the atmosphere.
    g. Seal System Degassing Vents and Accumulator Vents--Place the 
probe inlet at approximately the center of the opening to the 
atmosphere.
    h. Access Door Seals--Place the probe inlet at the surface of the 
door seal interface and conduct a peripheral traverse.
    4.3.2  Type II--``No Detectable Emission''.

[[Page 1026]]

    Determine the local ambient concentration around the source by 
moving the probe inlet randomly upwind and downwind at a distance of one 
to two meters from the source. If an interference exists with this 
determination due to a nearby emission or leak, the local ambient 
concentration may be determined at distances closer to the source, but 
in no case shall the distance be less than 25 centimeters. Then move the 
probe inlet to the surface of the source and determine the concentration 
described in 4.3.1. The difference between these concentrations 
determines whether there are no detectable emissions. Record and report 
the results as specified by the regulation.
    For those cases where the regulation requires a specific device 
installation, or that specified vents be ducted or piped to a control 
device, the existence of these conditions shall be visually confirmed. 
When the regulation also requires that no detectable emissions exist, 
visual observations and sampling surveys are required. Examples of this 
technique are:
    (a) Pump or Compressor Seals--If applicable, determine the type of 
shaft seal. Preform a survey of the local area ambient VOC concentration 
and determine if detectable emissions exist as described above.
    (b) Seal System Degassing Vents, Accumulator Vessel Vents, Pressure 
Relief Devices--If applicable, observe whether or not the applicable 
ducting or piping exists. Also, determine if any sources exist in the 
ducting or piping where emissions could occur prior to the control 
device. If the required ducting or piping exists and there are no 
sources where the emissions could be vented to the atmosphere prior to 
the control device, then it is presumed that no detectable emissions are 
present. If there are sources in the ducting or piping where emissions 
could be vented or sources where leaks could occur, the sampling surveys 
described in this paragraph shall be used to determine if detectable 
emissions exist.
    4.3.3  Alternative Screening Procedure. A screening procedure based 
on the formation of bubbles in a soap solution that is sprayed on a 
potential leak source may be used for those sources that do not have 
continuously moving parts, that do not have surface temperatures greater 
than the boiling point or less than the freezing point of the soap 
solution, that do not have open areas to the atmosphere that the soap 
solution cannot bridge, or that do not exhibit evidence of liquid 
leakage. Sources that have these conditions present must be surveyed 
using the instrument techniques of 4.3.1 or 4.3.2.
    Spray a soap solution over all potential leak sources. The soap 
solution may be a commercially available leak detection solution or may 
be prepared using concentrated detergent and water. A pressure sprayer 
or a squeeze bottle may be used to dispense the solution. Observe the 
potential leak sites to determine if any bubbles are formed. If no 
bubbles are observed, the source is presumed to have no detectable 
emissions or leaks as applicable. If any bubbles are observed, the 
instrument techniques of 4.3.1 or 4.3.2 shall be used to determine if a 
leak exists, or if the source has detectable emissions, as applicable.
    4.4 Instrument Evaluation Procedures. At the beginning of the 
instrument performance evaluation test, assemble and start up the 
instrument according to the manufacturer's instructions for recommended 
warmup period and preliminary adjustments.
    4.4.1 Response Factor. Calibrate the instrument with the reference 
compound as specified in the applicable regulation. For each organic 
species that is to be measured during individual source surveys, obtain 
or prepare a known standard in air at a concentration of approximately 
80 percent of the applicable leak definition unless limited by 
volatility or explosivity. In these cases, prepare a standard at 90 
percent of the saturation concentration, or 70 percent of the lower 
explosive limit, respectively. Introduce this mixture to the analyzer 
and record the observed meter reading. Introduce zero air until a stable 
reading is obtained. Make a total of three measurements by alternating 
between the known mixture and zero air. Calculate the response factor 
for each repetition and the average response factor.
    Alternatively, if response factors have been published for the 
compounds of interest for the instrument or detector type, the response 
factor determination is not required, and existing results may be 
referenced. Examples of published response factors for flame ionization 
and catalytic oxidation detectors are included in Bibliography.
    4.4.2 Calibration Precision. Make a total of three measurements by 
alternately using zero gas and the specified calibration gas. Record the 
meter readings. Calculate the average algebraic difference between the 
meter readings and the known value. Divide this average difference by 
the known calibration value and mutiply by 100 to express the resulting 
calibration precision as a percentage.
    4.4.3 Response Time. Introduce zero gas into the instrument sample 
probe. When the meter reading has stabilized, switch quickly to the 
specified calibration gas. Measure the time from switching to when 90 
percent of the final stable reading is attained. Perform this test 
sequence three times and record the results. Calculate the average 
response time.

5. Bibliography

    1.  DuBose, D.A., and G.E. Harris. Response Factors of VOC Analyzers 
at a Meter Reading of 10,000 ppmv for Selected Organic Compounds. U.S. 
Environmental Protection Agency, Research Triangle Park, NC. Publication 
No. EPA 600/2-81-051. September 1981.

[[Page 1027]]

    2.  Brown, G.E., et al. Response Factors of VOC Analyzers Calibrated 
with Methane for Selected Organic Compounds. U.S. Environmental 
Protection Agency, Research Triangle Park, NC. Publication No. EPA 600/
2-81-022. May 1981.
    3.  DuBose, D.A., et al. Response of Portable VOC Analyzers to 
Chemical Mixtures. U.S. Environmental Protection Agency, Research 
Triangle Park, NC. Publication No. EPA 600/2-81-110. September 1981.

  Method 22--Visual Determination of Fugitive Emissions From Material 
                 Sources and Smoke Emissions from Flares

1. Introduction

    This method involves the visual determination of fugitive emissions, 
i.e., emissions not emitted directly from a process stack or duct. 
Fugitive emissions include emissions that (1) escape capture by process 
equipment exhaust hoods; (2) are emitted during material transfer; (3) 
are emitted from buildings housing material processing or handling 
equipment; and (4) are emitted directly from process equipment. This 
method is used also to determine visible smoke emissions from flares 
used for combustion of waste process materials.
    This method determines the amount of time that any visible emissions 
occur during the observation period, i.e., the accumulated emission 
time. This method does not require that the opacity of emissions be 
determined. Since this procedure requires only the determination of 
whether a visible emission occurs and does not require the determination 
of opacity levels, observer certification according to the procedures of 
Method 9 are not required. However, it is necessary that the observer is 
educated on the general procedures for determining the presence of 
visible emissions. As a minimum, the observer must be trained and 
knowledgeable regarding the effects on the visibility of emissions 
caused by background contrast, ambient lighting, observer position 
relative to lighting, wind, and the presence of uncombined water 
(condensing water vapor). This training is to be obtained from written 
materials found in Citations 1 and 2 of Bibliography or from the lecture 
portion of the Method 9 certification course.

2. Applicability and Principle

    2.1  Applicability. This method applies to the determination of the 
frequency of fugitive emissions from stationary sources (located indoors 
or outdoors) when specified as the test method for determining 
compliance with new source performance standards.
    This method also is applicable for the determination of the 
frequency of visible smoke emissions from flares.
    2.2  Principle. Fugitive emissions produced during material 
processing, handling, and transfer operations or smoke emissions from 
flares are visually determined by an observer without the aid of 
instruments.

3. Definitions

    3.1  Emission Frequency. Percentage of time that emissions are 
visible during the observation period.
    3.2  Emission Time. Accumulated amount of time that emissions are 
visible during the observation period.
    3.3  Fugitive Emissions. Pollutant generated by an affected facility 
which is not collected by a capture system and is released to the 
atmosphere.
    3.4  Smoke Emissions. Pollutant generated by combustion in a flare 
and occurring immediately downstream of the flame. Smoke occurring 
within the flame, but not downstream of the flame, is not considered a 
smoke emission.
    3.5  Observation Period. Accumulated time period during which 
observations are conducted, not to be less than the period specified in 
the applicable regulation.

4. Equipment

    4.1  Stopwatches. Accumulative type with unit divisions of at least 
0.5 seconds; two required.
    4.2  Light Meter. Light meter capable of measuring illuminance in 
the 50- to 200-lux range; required for indoor observations only.

5. Procedure

    5.1  Position. Survey the affected facility or building or structure 
housing the process to be observed and determine the locations of 
potential emissions. If the affected facility is located inside a 
building, determine an observation location that is consistent with the 
requirements of the applicable regulation (i.e., outside observation of 
emissions escaping the building/structure or inside observation of 
emissions directly emitted from the affected facility process unit). 
Then select a position that enables a clear view of the potential 
emission point(s) of the affected facility or of the building or 
structure housing the affected facility, as appropriate for the 
applicable subpart. A position at least 15 feet, but not more than 0.25 
miles, from the emission source is recommended. For outdoor locations, 
select a position where the sun is not directly in the observer's eyes.
    5.2  Field Records.
    5.2.1  Outdoor Location. Record the following information on the 
field data sheet (Figure 22-1): company name, industry, process unit, 
observer's name, observer's affiliation, and date. Record also the 
estimated wind speed, wind direction, and sky condition. Sketch the 
process unit being observed and note the observer location relative to 
the source and the sun. Indicate the potential and actual emission 
points on the sketch.

[[Page 1028]]

    5.2.2  Indoor Location. Record the following information on the 
field data sheet (Figure 22-2): company name, industry, process unit, 
observer's name, observer's affiliation, and date. Record as appropriate 
the type, location, and intensity of lighting on the data sheet. Sketch 
the process unit being observed and note observer location relative to 
the source. Indicate the potential and actual fugitive emission points 
on the sketch.
    5.3  Indoor Lighting Requirements. For indoor locations, use a light 
meter to measure the level of illumination at a location as close to the 
emission source(s) as is feasible. An illumination of greater than 100 
lux (10 foot candles) is considered necessary for proper application of 
this method.
    5.4  Observations. Record the clock time when observations begin. 
Use one stopwatch to monitor the duration of the observation period; 
start this stopwatch when the observation period begins. If the 
observation period is divided into two or more segments by process 
shutdowns or observer rest breaks, stop the stopwatch when a break 
begins and restart it without resetting when the break ends. Stop the 
stopwatch at the end of the observation period. The accumulated time 
indicated by this stopwatch is the duration of the observation period. 
When the observation period is completed, record the clock time.
    During the observation period, continously watch the emission 
source. Upon observing an emission (condensed water vapor is not 
considered an emission), start the second accumulative stopwatch; stop 
the watch when the emission stops. Continue this procedure for the 
entire observation period. The accumulated elapsed time on this 
stopwatch is the total time emissions were visible during the 
observation period, i.e., the emission time.
    5.4.1  Observation Period. Choose an observation period of 
sufficient length to meet the requirements for determining compliance 
with the emission regulation in the applicable subpart. When the length 
of the observation period is specifically stated in the applicable 
subpart, it may not be necessary to observe the source for this entire 
period if the emission time required to indicate noncompliance (based on 
the specified observation period) is observed in a shorter time period. 
In other words, if the regulation prohibits emissions for more than 6 
minutes in any hour, then observations may (optional) be stopped after 
an emission time of 6 minutes is exceeded. Similarly, when the 
regulation is expressed as an emission frequency and the regulation 
prohibits emissions for greater than 10 percent of the time in any hour, 
then observations may (optional) be terminated after 6 minutes of 
emissions are observed since 6 minutes is 10 percent of an hour. In any 
case, the observation period shall not be less than 6 minutes in 
duration. In some cases, the process operation may be intermittent or 
cyclic. In such cases, it may be convenient for the observation period 
to coincide with the length of the process cycle.
    5.4.2  Observer Rest Breaks. Do not observe emissions continuously 
for a period of more than 15 to 20 minutes without taking a rest break. 
For sources requiring observation periods of greater than 20 minutes, 
the observer shall take a break of not less than 5 minutes and not more 
than 10 minutes after every 15 to 20 minutes of observation. If 
continuous observations are desired for extended time periods, two 
observers can alternate between making observations and taking breaks.
    5.4.3  Visual Interference. Occasionally, fugitive emissions from 
sources other than the affected facility (e.g., road dust) may prevent a 
clear view of the affected facility. This may particularly be a problem 
during periods of high wind. If the view of the potential emission 
points is obscured to such a degree that the observer questions the 
validity of continuing observations, then the observations are 
terminated, and the observer clearly notes this fact on the data form.
    5.5  Recording Observations. Record the accumulated time of the 
observation period on the data sheet as the observation period duration. 
Record the accumulated time emissions were observed on the data sheet as 
the emission time. Record the clock time the observation period began 
and ended, as well as the clock time any observer breaks began and 
ended.

6. Calculations

    If the applicable subpart requires that the emission rate be 
expressed as an emission frequency (in percent), determine this value as 
follows: Divide the accumulated emission time (in seconds) by the 
duration of the observation period (in seconds) or by any minimum 
observation period required in the applicable subpart, if the acutal 
observation period is less than the required period and multiply this 
quotient by 100.

7.  Bibliography

    1.  Missan, Robert and Arnold Stein. Guidelines for Evaluation of 
Visible Emissions Certification, Field Procedures, Legal Aspects, and 
Background Material. EPA Publication No. EPA-340/1-75-007. April 1975
    2.  Wohlschlegel, P. and D. E. Wagoner. Guideline for Development of 
a Quality Assurance Program: Volume IX--Visual Determination of Opacity 
Emissions From Stationary Sources. EPA Publication No. EPA-650/4-74-005-
i. November 1975.

[[Page 1029]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.247


[[Page 1030]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.248

   Method 23--Determination of Polychlorinated Dibenzo-p-Dioxins and 
          Polychlorinated Dibenzofurans From Stationary Sources

                     1. Applicability and Principle

    1.1  Applicability. This method is applicable to the determination 
of polychlorinated dibenzo-p-dioxins (PCDD's) and polychlorinated 
dibenzofurans (PCDF's) from stationary sources.
    1.2  Principle. A sample is withdrawn from the gas stream 
isokinetically and collected in the sample probe, on a glass fiber 
filter, and on a packed column of adsorbent material. The sample cannot 
be separated into a particle vapor fraction. The PCDD's and PCDF's are 
extracted from the sample, separated by high resolution gas 
chromatography, and measured by high resolution mass spectrometry.

                              2. Apparatus

    2.1  Sampling. A schematic of the sampling train used in this method 
is shown in Figure 23-1. Sealing greases may not be used

[[Page 1031]]

in assembling the train. The train is identical to that described in 
section 2.1 of Method 5 of this appendix with the following additions:
[GRAPHIC] [TIFF OMITTED] TC01JN92.249

    2.1.1  Nozzle. The nozzle shall be made of nickel, nickel-plated 
stainless steel, quartz, or borosilicate glass.
    2.1.2  Sample Transfer Lines. The sample transfer lines, if needed, 
shall be heat traced, heavy walled TFE (\1/2\ in. OD with \1/8\ in. 
wall) with connecting fittings that are capable of

[[Page 1032]]

forming leak-free, vacuum-tight connections without using sealing 
greases. The line shall be as short as possible and must be maintained 
at 120  deg.C.
    2.1.1  Filter Support. Teflon or Teflon-coated wire.
    2.1.2  Condenser. Glass, coil type with compatible fittings. A 
schematic diagram is shown in Figure 23-2.
    2.1.3  Water Bath. Thermostatically controlled to maintain the gas 
temperature exiting the condenser at <20  deg.C (68  deg.F).
    2.1.4  Adsorbent Module. Glass container to hold the solid 
adsorbent. A shematic diagram is shown in Figure 23-2. Other physical 
configurations of the resin trap/condenser assembly are acceptable. The 
connecting fittings shall form leak-free, vacuum tight seals. No sealant 
greases shall be used in the sampling train. A coarse glass frit is 
included to retain the adsorbent.
    2.2  Sample Recovery.
    2.2.1  Fitting Caps. Ground glass, Teflon tape, or aluminum foil 
(Section 2.2.6) to cap off the sample exposed sections of the train.
    2.2.2  Wash Bottles. Teflon, 500-ml.
    2.2.3  Probe-Liner Probe-Nozzle, and Filter-Holder Brushes. Inert 
bristle brushes with precleaned stainless steel or Teflon handles. The 
probe brush shall have extensions of stainless steel or Teflon, at least 
as long as the probe. The brushes shall be properly sized and shaped to 
brush out the nozzle, probe liner, and transfer line, if used.

[[Page 1033]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.250

    2.2.4  Filter Storage Container. Sealed filter holder, wide-mouth 
amber glass jar with Teflon-lined cap, or glass petri dish.
    2.2.5  Balance. Triple beam.
    2.2.6  Aluminum Foil. Heavy duty, hexane-rinsed.
    2.2.7  Metal Storage Container. Air tight container to store silica 
gel.

[[Page 1034]]

    2.2.8  Graduated Cylinder. Glass, 250-ml with 2-ml graduation.
    2.2.9  Glass Sample Storage Container. Amber glass bottle for sample 
glassware washes, 500- or 1000-ml, with leak free Teflon-lined caps.
    2.3  Analysis.
    2.3.1  Sample Container. 125- and 250-ml flint glass bottles with 
Teflon-lined caps.
    2.3.2  Test Tube. Glass.
    2.3.3  Soxhlet Extraction Apparatus. Capable of holding 43 x 123 mm 
extraction thimbles.
    2.3.4  Extraction Thimble. Glass, precleaned cellulosic, or glass 
fiber.
    2.3.5  Pasteur Pipettes. For preparing liquid chromatographic 
columns.
    2.3.6  Reacti-vials. Amber glass, 2-ml, silanized prior to use.
    2.3.7  Rotary Evaporator. Buchi/Brinkman RF-121 or equivalent.
    2.3.8  Nitrogen Evaporative Concentrator. N-Evap Analytical 
Evaporator Model III or equivalent.
    2.3.9  Separatory Funnels. Glass, 2-liter.
    2.3.10  Gas Chromatograph. Consisting of the following components:
    2.3.10.1  Oven. Capable of maintaining the separation column at the 
proper operating temperature   deg.C and performing 
programmed increases in temperature at rates of at least 40  deg.C/min.
    2.3.10.2  Temperature Gauge. To monitor column oven, detector, and 
exhaust temperatures 1  deg.C.
    2.3.10.3  Flow System. Gas metering system to measure sample, fuel, 
combustion gas, and carrier gas flows.
    2.3.10.4  Capillary Columns. A fused silica column, 60  x  0.25 mm 
inside diameter (ID), coated with DB-5 and a fused silica column, 30 m 
x  0.25 mm ID coated with DB-225. Other column systems may be used 
provided that the user is able to demonstrate using calibration and 
performance checks that the column system is able to meet the 
specifications of section 6.1.2.2.
    2.3.11  Mass Spectrometer. Capable of routine operation at a 
resolution of 1:10000 with a stability of 5 ppm.
    2.3.12  Data System. Compatible with the mass spectrometer and 
capable of monitoring at least five groups of 25 ions.
    2.3.13  Analytical Balance. To measure within 0.1 mg.

                               3. Reagents

    3.1  Sampling.
    3.1.1  Filters. Glass fiber filters, without organic binder, 
exhibiting at least 99.95 percent efficiency (<0.05 percent penetration) 
on 0.3-micron dioctyl phthalate smoke particles. The filter efficiency 
test shall be conducted in accordance with ASTM Standard Method D 2986-
71 (Reapproved 1978) (incorporated by reference--see Sec. 60.17).
    3.1.1.1  Precleaning. All filters shall be cleaned before their 
initial use. Place a glass extraction thimble and 1 g of silica gel and 
a plug of glass wool into a Soxhlet apparatus, charge the apparatus with 
toluene, and reflux for a minimum of 3 hours. Remove the toluene and 
discard it, but retain the silica gel. Place no more than 50 filters in 
the thimble onto the silica gel bed and top with the cleaned glass wool. 
Charge the Soxhlet with toluene and reflux for 16 hours. After 
extraction, allow the Soxhlet to cool, remove the filters, and dry them 
under a clean N2 stream. Store the filters in a glass petri 
dish sealed with Teflon tape.
    3.1.2  Adsorbent Resin. Amberlite XAD-2 resin. Thoroughly cleaned 
before initial use.
    3.1.2.1  Cleaning Procedure. This procedure may be carried out in a 
giant Soxhlet extractor. An all-glass filter thimble containing an 
extra-course frit is used for extraction of XAD-2. The frit is recessed 
10-15 mm above a crenelated ring at the bottom of the thimble to 
facilitate drainage. The resin must be carefully retained in the 
extractor cup with a glass wool plug and a stainless steel ring because 
it floats on methylene chloride. This process involves sequential 
extraction in the following order.

------------------------------------------------------------------------
                  Solvent                             Procedure
------------------------------------------------------------------------
Water.....................................  Initial rinse: Place resin
                                             in a beaker, rinse once
                                             with water, and discard.
                                             Fill with water a second
                                             time, let stand overnight,
                                             and discard.
Water.....................................  Extract with water for 8
                                             hours.
Methanol..................................  Extract for 22 hours.
Methylene Chloride........................  Extract for 22 hours.
Toluene...................................  Extract for 22 hours.
------------------------------------------------------------------------

    3.1.2.2  Drying.
    3.1.2.2.1  Drying Column. Pyrex pipe, 10.2 cm ID by 0.6 m long, with 
suitable retainers.
    3.1.2.2.2  Procedure. The adsorbent must be dried with clean inert 
gas. Liquid nitrogen from a standard commercial liquid nitrogen cylinder 
has proven to be a reliable source of large volumes of gas free from 
organic contaminants. Connect the liquid nitrogen cylinder to the column 
by a length of cleaned copper tubing, 0.95 cm ID, coiled to pass through 
a heat source. A convenient heat source is a water-bath heated from a 
steam line. The final nitrogen temperature should only be warm to the 
touch and not over 40  deg.C. Continue flowing nitrogen through the 
adsorbent until all the residual solvent is removed. The flow rate 
should be sufficient to gently agitate the particles but not so 
excessive as the cause the particles to fracture.
    3.1.2.3  Quality Control Check. The adsorbent must be checked for 
residual toluene.
    3.1.2.3.1  Extraction. Weigh 1.0 g sample of dried resin into a 
small vial, add 3 ml of toluene, cap the vial, and shake it well.

[[Page 1035]]

    3.1.2.3.2  Analysis. Inject a 2 l sample of the extract 
into a gas chromatograph operated under the following conditions:

    Column: 6 ft  x  \1/8\ in stainless steel containing 10 percent OV-
101 on 100/120 Supelcoport.
    Carrier Gas: Helium at a rate of 30 ml/min.
    Detector: Flame ionization detector operated at a sensitivity of 4 
x  10-11 A/mV.
    Injection Port Temperature: 250  deg.C.
    Detector Temperature: 305  deg.C.
    Oven Temperature: 30  deg.C for 4 min; programmed to rise at 40 
deg.C/min until it reaches 250  deg.C; return to 30  deg.C after 17 
minutes.
    Compare the results of the analysis to the results from the 
reference solution. Prepare the reference solution by injection 2.5 
l of methylene chloride into 100 ml of toluene. This 
corresponds to 100 g of methylene chloride per g of adsorbent. 
The maximum acceptable concentration is 1000 g/g of adsorbent. 
If the adsorbent exceeds this level, drying must be continued until the 
excess methylene chloride is removed.
    3.1.2.4  Storage. The adsorbent must be used within 4 weeks of 
cleaning. After cleaning, it may be stored in a wide mouth amber glass 
container with a Teflon-lined cap or placed in one of the glass 
adsorbent modules tightly sealed with glass stoppers. If precleaned 
adsorbent is purchased in sealed containers, it must be used within 4 
weeks after the seal is broken.
    3.1.3  Glass Wool. Cleaned by sequential immersion in three aliquots 
of methylene chloride, dried in a 110  deg.C oven, and stored in a 
methylene chloride-washed glass jar with a Teflon-lined screw cap.
    3.1.4  Water. Deionized distilled and stored in a methylene 
chloride-rinsed glass container with a Teflon-lined screw cap.
    3.1.5  Silica Gel. Indicating type, 6 to 16 mesh. If previously 
used, dry at 175  deg.C (350  deg.F) for two hours. New silica gel may 
be used as received. Alternately other types of desiccants (equivalent 
or better) may be used, subject to the approval of the Administrator.
    3.1.6  Chromic Acid Cleaning Solution. Dissolve 20 g of sodium 
dichromate in 15 ml of water, and then carefully add 400 ml of 
concentrated sulfuric acid.
    3.2  Sample Recovery.
    3.2.2  Acetone. Pesticide quality.
    3.2.2  Methylene Chloride. Pesticide qualtity.
    3.2.3  Toluene. Pesticide quality.
    3.3  Analysis.
    3.3.1  Potassium Hydroxide. ACS grade, 2-percent (weight/volume) in 
water.
    3.3.2  Sodium Sulfate. Granulated, reagent grade. Purify prior to 
use by rinsing with methylene chloride and oven drying. Store the 
cleaned material in a glass container with a Teflon-lined screw cap.
    3.3.3  Sulfuric Acid. Reagent grade.
    3.3.4  Sodium Hydroxide. 1.0 N. Weigh 40 g of sodium hydroxide into 
a 1-liter volumetric flask. Dilute to 1 liter with water.
    3.3.5  Hexane. Pesticide grade.
    3.3.6  Methylene Chloride. Pesticide grade.
    3.3.7  Benzene. Pesticide Grade.
    3.3.8  Ethyl Acetate.
    3.3.9  Methanol. Pesticide Grade.
    3.3.10  Toluene. Pesticide Grade.
    3.3.11  Nonane. Pesticide Grade.
    3.3.12  Cyclohexane. Pesticide Grade.
    3.3.13  Basic Alumina. Activity grade 1, 100-200 mesh. Prior to use, 
activate the alumina by heating for 16 hours at 130  deg.C before use. 
Store in a desiccator. Pre-activated alumina may be purchased from a 
supplier and may be used as received.
    3.3.14  Silica Gel. Bio-Sil A, 100-200 mesh. Prior to use, activate 
the silica gel by heating for at least 30 minutes at 180  deg.C. After 
cooling, rinse the silica gel sequentially with methanol and methylene 
chloride. Heat the rinsed silica gel at 50  deg.C for 10 minutes, then 
increase the temperature gradually to 180  deg.C over 25 minutes and 
maintain it at this temperature for 90 minutes. Cool at room temperature 
and store in a glass container with a Teflon-lined screw cap.
    3.3.15  Silica Gel Impregnated with Sulfuric Acid. Combine 100 g of 
silica gel with 44 g of concentrated sulfuric acid in a screw capped 
glass bottle and agitate thoroughly. Disperse the solids with a stirring 
rod until a uniform mixture is obtained. Store the mixture in a glass 
container with a Teflon-lined screw cap.
    3.3.16  Silica Gel Impregnated with Sodium Hydroxide. Combine 39 g 
of 1 N sodium hydroxide with 100 g of silica gel in a screw capped glass 
bottle and agitate thoroughly. Disperse solids with a stirring rod until 
a uniform mixture is obtained. Store the mixture in glass container with 
a Teflon-lined screw cap.
    3.3.17  Carbon/Celite. Combine 10.7 g of AX-21 carbon with 124 g of 
Celite 545 in a 250-ml glass bottle with a Teflon-lined screw cap. 
Agitate the mixture thoroughly until a uniform mixture is obtained. 
Store in the glass container.
    3.3.18  Nitrogen. Ultra high purity.
    3.3.19  Hydrogen. Ultra high purity.
    3.3.20  Internal Standard Solution. Prepare a stock standard 
solution containing the isotopically labelled PCDD's and PCDF's at the 
concentrations shown in Table 1 under the heading ``Internal Standards'' 
in 10 ml of nonane.
    3.3.21  Surrogate Standard Solution. Prepare a stock standard 
solution containing the isotopically labelled PCDD's and PCDF's at the 
concentrations shown in Table 1 under the heading ``Surrogate 
Standards'' in 10 ml of nonane.
    3.3.22  Recovery Standard Solution. Prepare a stock standard 
solution containing the isotopically labelled PCDD's and PCDF's

[[Page 1036]]

at the concentrations shown in Table 1 under the heading ``Recovery 
Standards'' in 10 ml of nonane.

                              4. Procedure

    4.1  Sampling. The complexity of this method is such that, in order 
to obtain reliable results, testers should be trained and experienced 
with the test procedures.
    4.1.1  Pretest Preparation.
    4.1.1.1  Cleaning Glassware. All glass components of the train 
upstream of and including the adsorbent module, shall be cleaned as 
described in section 3A of the ``Manual of Analytical Methods for the 
Analysis of Pesticides in Human and Environmental Samples.'' Special 
care shall be devoted to the removal of residual silicone grease 
sealants on ground glass connections of used glassware. Any residue 
shall be removed by soaking the glassware for several hours in a chromic 
acid cleaning solution prior to cleaning as described above.
    4.1.1.2  Adsorbent Trap. The traps must be loaded in a clean area to 
avoid contamination. They may not be loaded in the field. Fill a trap 
with 20 to 40 g of XAD-2. Follow the XAD-2 with glass wool and tightly 
cap both ends of the trap. Add 100 l of the surrogate standard 
solution (section 3.3.21) to each trap.
    4.1.1.3  Sample Train. It is suggested that all components be 
maintained according to the procedure described in APTD-0576.
    4.1.1.4  Silica Gel. Weigh several 200 to 300 g portions of silica 
gel in an air tight container to the nearest 0.5 g. Record the total 
weight of the silica gel plus container, on each container. As an 
alternative, the silica gel may be weighed directly in its impinger or 
sampling holder just prior to sampling.
    4.1.1.5  Filter. Check each filter against light for irregularities 
and flaws or pinhole leaks. Pack the filters flat in a clean glass 
container.
    4.1.2  Preliminary Determinations. Same as section 4.1.2 of Method 
5.
    4.1.3  Preparation of Collection Train.
    4.1.3.1  During preparation and assembly of the sampling train, keep 
all train openings where contamination can enter, sealed until just 
prior to assembly or until sampling is about to begin.
    Note: Do not use sealant grease in assembling the train.
    4.1.3.2  Place approximately 100 ml of water in the second and third 
impingers, leave the first and fourth impingers empty, and transfer 
approximately 200 to 300 g of preweighed silica gel from its container 
to the fifth impinger.
    4.1.3.3  Place the silica gel container in a clean place for later 
use in the sample recovery. Alternatively, the weight of the silica gel 
plus impinger may be determined to the nearest 0.5 g and recorded.
    4.1.3.4  Assemble the train as shown in Figure 23-1.
    4.1.3.5  Turn on the adsorbent module and condenser coil 
recirculating pump and begin monitoring the adsorbent module gas entry 
temperature. Ensure proper sorbent temperature gas entry temperature 
before proceeding and before sampling is initiated. It is extremely 
important that the XAD-2 adsorbent resin temperature never exceed 50 
deg.C because thermal decomposition will occur. During testing, the XAD-
2 temperature must not exceed 20  deg.C for efficient capture of the 
PCDD's and PCDF's.
    4.1.4  Leak-Check Procedure. Same as Method 5, section 4.1.4.
    4.1.5  Sample Train Operation. Same as Method 5, section 4.1.5.
    4.2  Sample Recovery. Proper cleanup procedure begins as soon as the 
probe is removed from the stack at the end of the sampling period. Seal 
the nozzle end of the sampling probe with Teflon tape or aluminum foil.
    When the probe can be safely handled, wipe off all external 
particulate matter near the tip of the probe. Remove the probe from the 
train and close off both ends with aluminum foil. Seal off the inlet to 
the train with Teflon tape, a ground glass cap, or aluminum foil.
    Transfer the probe and impinger assembly to the cleanup area. This 
area shall be clean and enclosed so that the chances of losing or 
contaminating the sample are minimized. Smoking, which could contaminate 
the sample, shall not be allowed in the cleanup area.
    Inspect the train prior to and during disassembly and note any 
abnormal conditions, e.g., broken filters, colored impinger liquid, etc. 
Treat the samples as follows:
    4.2.1  Container No. 1. Either seal the filter holder or carefully 
remove the filter from the filter holder and place it in its identified 
container. Use a pair of cleaned tweezers to handle the filter. If it is 
necessary to fold the filter, do so such that the particulate cake is 
inside the fold. Carefully transfer to the container any particulate 
matter and filter fibers which adhere to the filter holder gasket, by 
using a dry inert bristle brush and a sharp-edged blade. Seal the 
container.
    4.2.2  Adsorbent Module. Remove the module from the train, tightly 
cap both ends, label it, cover with aluminum foil, and store it on ice 
for transport to the laboratory.
    4.2.3  Container No. 2. Quantitatively recover material deposited in 
the nozzle, probe transfer lines, the front half of the filter holder, 
and the cyclone, if used, first, by brushing while rinsing three times 
each with acetone and then, by rinsing the probe three times with 
methylene chloride. Collect all the rinses in Container No. 2.

[[Page 1037]]

    Rinse the back half of the filter holder three times with acetone. 
Rinse the connecting line between the filter and the condenser three 
times with acetone. Soak the connecting line with three separate 
portions of methylene chloride for 5 minutes each. If using a separate 
condenser and adsorbent trap, rinse the condenser in the same manner as 
the connecting line. Collect all the rinses in Container No. 2 and mark 
the level of the liquid on the container.
    4.2.4  Container No. 3. Repeat the methylene chloride-rinsing 
described in Section 4.2.3 using toluene as the rinse solvent. Collect 
the rinses in Container No. 3 and mark the level of the liquid on the 
container.
    4.2.5  Impinger Water. Measure the liquid in the first three 
impingers to within 1 ml by using a graduated cylinder or by 
weighing it to within 0.5 g by using a balance. Record the 
volume or weight of liquid present. This information is required to 
calculate the moisture content of the effluent gas.
    Discard the liquid after measuring and recording the volume or 
weight.
    4.2.7  Silica Gel. Note the color of the indicating silica gel to 
determine if it has been completely spent and make a mention of its 
condition. Transfer the silica gel from the fifth impinger to its 
original container and seal.

                               5. Analysis

    All glassware shall be cleaned as described in section 3A of the 
``Manual of Analytical Methods for the Analysis of Pesticides in Human 
and Environmental Samples.'' All samples must be extracted within 30 
days of collection and analyzed within 45 days of extraction.
    5.1  Sample Extraction.
    5.1.1  Extraction System. Place an extraction thimble (section 
2.3.4), 1 g of silica gel, and a plug of glass wool into the Soxhlet 
apparatus, charge the apparatus with toluene, and reflux for a minimum 
of 3 hours. Remove the toluene and discard it, but retain the silica 
gel. Remove the extraction thimble from the extraction system and place 
it in a glass beaker to catch the solvent rinses.
    5.1.2  Container No. 1 (Filter). Transfer the contents directly to 
the glass thimble of the extraction system and extract them 
simultaneously with the XAD-2 resin.
    5.1.3  Adsorbent Cartridge. Suspend the adsorbent module directly 
over the extraction thimble in the beaker (See section 5.1.1). The glass 
frit of the module should be in the up position. Using a Teflon squeeze 
bottle containing toluene, flush the XAD-2 into the thimble onto the bed 
of cleaned silica gel. Thoroughly rinse the glass module catching the 
rinsings in the beaker containing the thimble. If the resin is wet, 
effective extraction can be accomplished by loosely packing the resin in 
the thimble. Add the XAD-2 glass wool plug into the thimble.
    5.1.4  Container No. 2 (Acetone and Methylene Chloride). Concentrate 
the sample to a volume of about 1-5 ml using the rotary evaporator 
apparatus, at a temperature of less than 37  deg.C. Rinse the sample 
container three times with small portions of methylene chloride and add 
these to the concentrated solution and concentrate further to near 
dryness. This residue contains particulate matter removed in the rinse 
of the train probe and nozzle. Add the concentrate to the filter and the 
XAD-2 resin in the Soxhlet apparatus described in section 5.1.1.
    5.1.5  Extraction. Add 100 l of the internal standard 
solution (Section 3.3.20) to the extraction thimble containing the 
contents of the adsorbent cartridge, the contents of Container No. 1, 
and the concentrate from section 5.1.4. Cover the contents of the 
extraction thimble with the cleaned glass wool plug to prevent the XAD-2 
resin from floating into the solvent reservoir of the extractor. Place 
the thimble in the extractor, and add the toluene contained in the 
beaker to the solvent reservoir. Pour additional toluene to fill the 
reservoir approximately 2/3 full. Add Teflon boiling chips and assemble 
the apparatus. Adjust the heat source to cause the extractor to cycle 
three times per hour. Extract the sample for 16 hours. After extraction, 
allow the Soxhlet to cool. Transfer the toluene extract and three 10-ml 
rinses to the rotary evaporator. Concentrate the extract to 
approximately 10 ml. At this point the analyst may choose to split the 
sample in half. If so, split the sample, store one half for future use, 
and analyze the other according to the procedures in sections 5.2 and 
5.3. In either case, use a nitrogen evaporative concentrator to reduce 
the volume of the sample being analyzed to near dryness. Dissolve the 
residue in 5 ml of hexane.
    5.1.6  Container No. 3 (Toluene Rinse). Add 100 l of the 
Internal Standard solution (section 3.3.2) to the contents of the 
container. Concentrate the sample to a volume of about 1-5 ml using the 
rotary evaporator apparatus at a temperature of less than 37  deg.C. 
Rinse the sample container apparatus at a temperature of less than 37 
deg.C. Rinse the sample container three times with small portions of 
toluene and add these to the concentrated solution and concentrate 
further to near dryness. Analyze the extract separately according to the 
procedures in sections 5.2 and 5.3, but concentrate the solution in a 
rotary evaporator apparatus rather than a nitrogen evaporative 
concentrator.
    5.2  Sample Cleanup and Fractionation.
    5.2.1  Silica Gel Column. Pack one end of a glass column, 20 mm x 
230 mm, with glass wool. Add in sequence, 1 g silica gel, 2 g of sodium 
hydroxide impregnated silica gel, 1 g silica gel, 4 g of acid-modified 
silica gel, and 1 g of silica gel. Wash the column with 30 ml

[[Page 1038]]

of hexane and discard it. Add the sample extract, dissolved in 5 ml of 
hexane to the column with two additional 5-ml rinses. Elute the column 
with an additional 90 ml of hexane and retain the entire eluate. 
Concentrate this solution to a volume of about 1 ml using the nitrogen 
evaporative concentrator (section 2.3.7).
    5.2.2  Basic Alumina Column. Shorten a 25-ml disposable Pasteur 
pipette to about 16 ml. Pack the lower section with glass wool and 12 g 
of basic alumina. Transfer the concentrated extract from the silica gel 
column to the top of the basic alumina column and elute the column 
sequentially with 120 ml of 0.5 percent methylene chloride in hexane 
followed by 120 ml of 35 percent methylene chloride in hexane. Discard 
the first 120 ml of eluate. Collect the second 120 ml of eluate and 
concentrate it to about 0.5 ml using the nitrogen evaporative 
concentrator.
    5.2.3  AX-21 Carbon/Celite 545 Column. Remove the botton 0.5 in. 
from the tip of a 9-ml disposable Pasteur pipette. Insert a glass fiber 
filter disk in the top of the pipette 2.5 cm from the constriction. Add 
sufficient carbon/celite mixture to form a 2 cm column. Top with a glass 
wool plug. In some cases AX-21 carbon fines may wash through the glass 
wool plug and enter the sample. This may be prevented by adding a celite 
plug to the exit end of the column. Rinse the column in sequence with 2 
ml of 50 percent benzene in ethyl acetate, 1 ml of 50 percent methylene 
chloride in cyclohexane, and 2 ml of hexane. Discard these rinses. 
Transfer the concentrate in 1 ml of hexane from the basic alumina column 
to the carbon/celite column along with 1 ml of hexane rinse. Elute the 
column sequentially with 2 ml of 50 percent methylene chloride in hexane 
and 2 ml of 50 percent benzene in ethyl acetate and discard these 
eluates. Invert the column and elute in the reverse direction with 13 ml 
of toluene. Collect this eluate. Concentrate the eluate in a rotary 
evaporator at 50  deg.C to about 1 ml. Transfer the concentrate to a 
Reacti-vial using a toluene rinse and concentrate to a volume of 200 
l using a stream of N2. Store extracts at room 
temperature, shielded from light, until the analysis is performed.
    5.3  Analysis. Analyze the sample with a gas chromatograph coupled 
to a mass spectrometer (GC/MS) using the instrumental parameters in 
sections 5.3.1 and 5.3.2. Immediately prior to analysis, add a 20 
l aliquot of the Recovery Standard solution from Table 1 to 
each sample. A 2 l aliquot of the extract is injected into the 
GC. Sample extracts are first analyzed using the DB-5 capillary column 
to determine the concentration of each isomer of PCDD's and PCDF's 
(tetra-through octa-). If tetra-chlorinated dibenzofurans are detected 
in this analysis, then analyze another aliquot of the sample in a 
separate run, using the DB-225 column to measure the 2,3,7,8 tetra-
chloro dibenzofuran isomer. Other column systems may be used, provided 
that the user is able to demonstrate using calibration and performance 
checks that the column system is able to meet the specifications of 
section 6.1.2.2.
    5.3.1  Gas Chromatograph Operating Conditions.
    5.3.1.1  Injector. Configured for capillary column, splitless, 250 
deg.C.
    5.3.1.2  Carrier Gas. Helium, 1-2 ml/min.
    5.3.1.3  Oven. Initially at 150  deg.C. Raise by at least 40  deg.C/
min to 190  deg.C and then at 3  deg.C/min up to 300  deg.C.
    5.3.2  High Resolution Mass Spectrometer.
    5.3.2.1  Resolution. 10000 m/e.
    5.3.2.2  Ionization Mode. Electron impact.
    5.3.2.3  Source Temperature 250  deg.C.
    5.3.2.4  Monitoring Mode. Selected ion monitoring. A list of the 
various ions to be monitored is summarized in Table 3.
    5.3.2.5  Identification Criteria. The following identification 
criteria shall be used for the characterization of polychlorinated 
dibenzodioxins and dibenzofurans.
    1. The integrated ion-abundance ratio (M/M+2 or M+2/M+4) shall be 
within 15 percent of the theoretical value. The acceptable ion-abundance 
ratio ranges for the identification of chlorine-containing compounds are 
given in Table 4.
    2. The retention time for the analytes must be within 3 seconds of 
the corresponding \1\\3\ C-labeled internal standard, surrogate or 
alternate standard.
    3. The monitored ions, shown in Table 3 for a given analyte, shall 
reach their maximum within 2 seconds of each other.
    4. The identification of specific isomers that do not have 
corresponding \1\\3\ C-labeled standards is done by comparison of the 
relative retention time (RRT) of the analyte to the nearest internal 
standard retention time with reference (i.e., within 0.005 RRT units) to 
the comparable RRT's found in the continuing calibration.
    5. The signal to noise ratio for all monitored ions must be greater 
than 2.5.
    6. The confirmation of 2, 3, 7, 8-TCDD and 2, 3, 7, 8-TCDF shall 
satisfy all of the above identification criteria.
    7. For the identification of PCDF's, no signal may be found in the 
corresponding PCDPE channels.
    5.3.2.6  Quantification. The peak areas for the two ions monitored 
for each analyte are summed to yield the total response for each 
analyte. Each internal standard is used to quantify the indigenous 
PCDD's or PCDF's in its homologous series. For example, the \1\\3\ C 
12-2,3,7,8-tetra chlorinated dibenzodioxin is used to 
calculate the concentrations of all other tetra chlorinated isomers. 
Recoveries of the tetra- and penta- internal standards are calculated 
using the \1\\3\ C 12-1,2,3,4-TCDD. Recoveries of the hexa- 
through octa- internal standards are calculated using \1\\3\ C 
12-

[[Page 1039]]

1,2,3,7,8,9-HxCDD. Recoveries of the surrogate standards are calculated 
using the corresponding homolog from the internal standard.

                             6. Calibration

    Same as Method 5 with the following additions.
    6.1  GC/MS System.
    6.1.1  Initial Calibration. Calibrate the GC/MS system using the set 
of five standards shown in Table 2. The relative standard deviation for 
the mean response factor from each of the unlabeled analytes (Table 2) 
and of the internal, surrogate, and alternate standards shall be less 
than or equal to the values in Table 5. The signal to noise ratio for 
the GC signal present in every selected ion current profile shall be 
greater than or equal to 2.5. The ion abundance ratios shall be within 
the control limits in Table 4.
    6.1.2  Daily Performance Check.
    6.1.2.1  Calibration Check. Inject on l of solution Number 
3 from Table 2. Calculate the relative response factor (RRF) for each 
compound and compare each RRF to the corresponding mean RRF obtained 
during the initial calibration. The analyzer performance is acceptable 
if the measured RRF's for the labeled and unlabeled compounds for the 
daily run are within the limits of the mean values shown in Table 5. In 
addition, the ion-abundance ratios shall be within the allowable control 
limits shown in Table 4.
    6.1.2.2  Column Separation Check. Inject a solution of a mixture of 
PCDD's and PCDF's that documents resolution between 2,3,7,8-TCDD and 
other TCDD isomers. Resolution is defined as a valley between peaks that 
is less than 25 percent of the lower of the two peaks. Identify and 
record the retention time windows for each homologous series.
    Perform a similar resolution check on the confirmation column to 
document the resolution between 2,3,7,8 TCDF and other TCDF isomers.
    6.2  Lock Channels. Set mass spectrometer lock channels as specified 
in Table 3. Monitor the quality control check channels specified in 
Table 3 to verify instrument stability during the analysis.

                           7. Quality Control

    7.1  Sampling Train Collection Efficiency Check. Add 100 l 
of the surrogate standards in Table 1 to the absorbent cartridge of each 
train before collecting the field samples.
    7.2  Internal Standard Percent Recoveries. A group of nine carbon 
labeled PCDD's and PCDF's representing, the tetra-through 
octachlorinated homologues, is added to every sample prior to 
extraction. The role of the internal standards is to quantify the native 
PCDD's and PCDF's present in the sample as well as to determine the 
overall method efficiency. Recoveries of the internal standards must be 
between 40 to 130 percent for the tetra-through hexachlorinated 
compounds while the range is 25 to 130 percent for the higher hepta- and 
octachlorinated homologues.
    7.3  Surrogate Recoveries. The five surrogate compounds in Table 2 
are added to the resin in the adsorbent sampling cartridge before the 
sample is collected. The surrogate recoveries are measured relative to 
the internal standards and are a measure of collection efficiency. They 
are not used to measure native PCDD's and PCDF's. All recoveries shall 
be between 70 and 130 percent. Poor recoveries for all the surrogates 
may be an indication of breakthrough in the sampling train. If the 
recovery of all standards is below 70 percent, the sampling runs must be 
repeated. As an alternative, the sampling runs do not have to be 
repeated if the final results are divided by the fraction of surrogate 
recovery. Poor recoveries of isolated surrogate compounds should not be 
grounds for rejecting an entire set of the samples.
    7.4  Toluene QA Rinse. Report the results of the toluene QA rinse 
separately from the total sample catch. Do not add it to the total 
sample.

                          8. Quality Assurance

    8.1  Applicability. When the method is used to analyze samples to 
demonstrate compliance with a source emission regulation, an audit 
sample must be analyzed, subject to availability.
    8.2  Audit Procedure. Analyze an audit sample with each set of 
compliance samples. The audit sample contains tetra through octa isomers 
of PCDD and PCDF. Concurrently, analyze the audit sample and a set of 
compliance samples in the same manner to evaluate the technique of the 
analyst and the standards preparation. The same analyst, analytical 
reagents, and analytical system shall be used both for the compliance 
samples and the EPA audit sample.
    8.3  Audit Sample Availability. Audit samples will be supplied only 
to enforcement agencies for compliance tests. The availability of audit 
samples may be obtained by writing: Source Test Audit Coordinator (MD-
77B), Quality Assurance Division, Atmospheric Research and Exposure 
Assessment Laboratory, U.S. Environmental Protection Agency, Research 
Triangle Park, NC 27711, or by calling the Source Test Audit Coordinator 
(STAC) at (919) 541-7834. The request for the audit sample must be made 
at least 30 days prior to the scheduled compliance sample analysis.
    8.4  Audit Results. Calculate the audit sample concentration 
according to the calculation procedure described in the audit 
instructions included with the audit sample. Fill in the audit sample 
concentration and the analyst's name on the audit response form included 
with the audit instructions.

[[Page 1040]]

Send one copy to the EPA Regional Office or the appropriate enforcement 
agency and a second copy to the STAC. The EPA Regional office or the 
appropriate enforcement agency will report the results of the audit to 
the laboratory being audited. Include this response with the results of 
the compliance samples in relevant reports to the EPA Regional Office or 
the appropriate enforcement agency.

                             9. Calculations

    Same as Method 5, section 6 with the following additions.
    9.1  Nomenclature.

    Aai=Integrated ion current of the noise at the retention 
time of the analyte.
    A*ci=Integrated ion current of the two ions 
characteristic of the internal standard i in the calibration standard.
    Acij=Integrated ion current of the two ions 
characteristic of compound i in the jth calibration standard.
    A*cij=Integrated ion current of the two ions 
characteristic of the internal standard i in the jth calibration 
standard.
    Acsi=Integrated ion current of the two ions 
characteristic of surrogate compound i in the calibration standard.
    Ai=Integrated ion current of the two ions characteristic 
of compound i in the sample.
    A*i=Integrated ion current of the two ions characteristic 
of internal standard i in the sample.
    Ars=Integrated ion current of the two ions characteristic 
of the recovery standard.
    Asi=Integrated ion current of the two ions characteristic 
of surrogate compound i in the sample.
    Ci=Concentration of PCDD or PCDF i in the sample, pg/M 
\3\.
    CT=Total concentration of PCDD's or PCDF's in the sample, 
pg/M \3\.
    mci=Mass of compound i in the calibration standard 
injected into the analyzer, pg.
    mrs=Mass of recovery standard in the calibration standard 
injected into the analyzer, pg.
    msi=Mass of surrogate compound in the calibration 
standard, pg.
    RRFi=Relative response factor.
    RRFrs=Recovery standard response factor.
    RRFs=Surrogate compound response factor.
    9.2  Average Relative Response Factor.

    [GRAPHIC] [TIFF OMITTED] TC16NO91.219
    
    9.3  Concentration of the PCDD's and PCDF's.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.220
    
    9.4  Recovery Standard Response Factor.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.221
    
    9.5  Recovery of Internal Standards (R*).
    [GRAPHIC] [TIFF OMITTED] TC16NO91.222
    
    9.6  Surrogate Compound Response Factor.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.223
    
    9.7  Recovery of Surrogate Compounds (Rs).
    [GRAPHIC] [TIFF OMITTED] TC16NO91.224
    
    9.8  Minimum Detectable Limit (MDL).
    [GRAPHIC] [TIFF OMITTED] TC16NO91.225
    
    9.9  Total Concentration of PCDD's and PCDF's in the Sample.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.226
    
    Any PCDD's or PCDF's that are reported as nondetected (below the 
MDL) shall be counted as zero for the purpose of calculating the total 
concentration of PCDD's and PCDF's in the sample.

                            10. Bibliography

    1. American Society of Mechanical Engineers. Sampling for the 
Determination of Chlorinated Organic Compounds in Stack Emissions. 
Prepared for U.S. Department of Energy and U.S. Environmental Protection 
Agency. Washington DC. December 1984. 25 p.
    2. American Society of Mechanical Engineers. Analytical Procedures 
to Assay Stack Effluent Samples and Residual Combustion Products for 
Polychlorinated Dibenzo-p-Dioxins (PCDD) and Polychlorinated 
Dibenzofurans (PCDF). Prepared for the U.S. Department of Energy and 
U.S. Environmental Protection Agency. Washington, DC. December 1984. 23 
p.
    3. Thompson, J. R. (ed.). Analysis of Pesticide Residues in Human 
and Environmental Samples. U.S. Environmental Protection Agency. 
Research Triangle Park, NC. 1974.

[[Page 1041]]

    4. Triangle Laboratories. Case Study: Analysis of Samples for the 
Presence of Tetra Through Octachloro-p-Dibenzodioxins and Dibenzofurans. 
Research Triangle Park, NC. 1988. 26 p.
    5. U.S. Environmental Protection Agency. Method 8290--The Analysis 
of Polychlorinated Dibenzo-p-dioxin and Polychlorinated Dibenzofurans by 
High-Resolution Gas Chromotography/High-Resolution Mass Spectrometry. 
In: Test Methods for Evaluating Solid Waste. Washington, DC. SW-846.

 Table 1--Composition of the Sample Fortification and Recovery Standards
                                Solutions
------------------------------------------------------------------------
                                                           Concentration
                         Analyte                            (pg/l)
------------------------------------------------------------------------
Internal Standards:
  13 C12-2,3,7,8-TCDD....................................           100
  13 C12-1,2,3,7,8-PeCDD.................................           100
  13 C12-1,2,3,6,7,8-HxCDD...............................           100
  13 C12-1,2,3,4,6,7,8-HpCDD.............................           100
  13 C12-OCDD............................................           100
  13 C12-2,3,7,8-TCDF....................................           100
  13 C12-1,2,3,7,8-PeCDF.................................           100
  13 C12-1,2,3,6,7,8-HxCDF...............................           100
  13 C12-1,2,3,4,6,7,8-HpCDF.............................           100
Surrogate Standards:
  37 Cl4-2,3,7,8-TCDD....................................           100
  13 C12-1,2,3,4,7,8-HxCDD...............................           100
  13 C12-2,3,4,7,8-PeCDF.................................           100
  13 C12-1,2,3,4,7,8-HxCDF...............................           100
  13 C12-1,2,3,4,7,8,9-HpCDF.............................           100
Recovery Standards:
  13 C12-1,2,3,4-TCDD....................................           500
  13 C12-1,2,3,7,8,9-HxCDD...............................           500
------------------------------------------------------------------------


        Table 2--Composition of the Initial Calibration Solutions
------------------------------------------------------------------------
                                         Concentrations (pg/L)
                                      ----------------------------------
               Compound                           Solution No.
                                      ----------------------------------
                                         1      2      3      4      5
------------------------------------------------------------------------
Alternate Standard:
  13 C12-1,2,3,7,8,9-HxCDF...........    2.5      5     25    250    500
Recovery Standards:
  13 C12-1,2,3,4-TCDD................    100    100    100    100    100
  13 C12-1,2,3,7,8,9-HxCDD...........    100    100    100    100    100
------------------------------------------------------------------------


 Table 3--Elemental Compositions and Exact Masses of the Ions Monitored by High Resolution Mass Spectrometry for
                                                PCDD's and PCDF's
----------------------------------------------------------------------------------------------------------------
Descriptor
    No.      Accurate mass         Ion type               Elemental composition                  Analyte
----------------------------------------------------------------------------------------------------------------
         2        292.9825  LOCK                   C7F11                                PFK
                  303.9016  M                      C12H435Cl4O                          TCDF
                  305.8987  M+2                    C12H435Cl37O                         TCDF
                  315.9419  M                      13C12H435Cl4O                        TCDF (S)
                  317.9389  M+2                    13C12H435Cl337ClO                    TCDF (S)
                  319.8965  M                      C12H435ClO2                          TCDD
                  321.8936  M+2                    C12H435Cl337ClO2                     TCDD
                  327.8847  M                      C12H437Cl4O2                         TCDD (S)
                  330.9792  QC                     C7F13                                PFK
                  331.9368  M                      13C12H435Cl4O2                       TCDD (S)
                  333.9339  M+2                    13C12H435Cl37ClO2                    TCDD (S)
                  339.8597  M+2                    C12H335Cl437ClO                      PECDF
                  341.8567  M+4                    C12H335Cl337Cl2O                     PeCDF
                  351.9000  M+2                    13C12H335Cl437ClO                    PeCDF (S)
                  353.8970  M+4                    13C12H335Cl3537Cl2O                  PeCDF (S)
                  355.8546  M+2                    C12H335Cl337ClO2                     PeCDD
                  357.8516  M+4                    C12H335Cl337Cl2O2                    PeCDD
                  367.8949  M+2                    13C12H335Cl437ClO2                   PeCDD (S)
                  369.8919  M+4                    13C12H335Cl337 Cl2O2                 PeCDD (S)
                  375.8364  M+2                    C12H435Cl537ClO                      HxCDPE
                  409.7974  M+2                    C12H335Cl637ClO                      HpCPDE
         3        373.8208  M+2                    C12H235Cl537ClO                      HxCDF
                  375.8178  M+4                    C12H235Cl437Cl2O                     HxCDF
                  383.8639  M                      13C12H235Cl6O                        HxCDF (S)
                  385.8610  M+2                    13C12H235Cl537ClO                    HxCDF (S)
                  389.8157  M+2                    C12H235Cl537ClO2                     HxCDD
                  391.8127  M+4                    C12H235Cl437Cl2O2                    HxCDD
                  392.9760  LOCK                   C9F15                                PFK
                  401.8559  M+2                    13C12H235Cl537ClO2                   HxCDD (S)
                  403.8529  M+4                    13C12H235Cl437Cl2O                   HxCDD (S)
                  445.7555  M+4                    C12H235Cl637Cl2O                     OCDPE
                  430.9729  QC                     C9F17                                PFK
         4        407.7818  M+2                    C12H35Cl637ClO                       HpCDF
                  409.7789  M+4                    C12H35Cl537Cl2O                      HpCDF

[[Page 1042]]

 
                  417.8253  M                      13C12H35Cl7O                         HpCDF (S)
                  419.8220  M+2                    13C12H35Cl637ClO                     HpCDF (S)
                  423.7766  M+2                    C12H35Cl637ClO2                      HpCDD
                  425.7737  M+4                    C12H35Cl537Cl2O2                     HpCDD
                  435.8169  M+2                    13C12H35Cl637ClO2                    HpCDD (S)
                  437.8140  M+4                    13C12H35Cl537Cl2O2                   HpCDD (S)
                  479.7165  M+4                    C12H35Cl737Cl2O                      NCPDE
                  430.9729  LOCK                   C9F17                                PFK
                  441.7428  M+2                    C1235Cl737ClO                        OCDF
                  443.7399  M+4                    C1235Cl637Cl2O                       OCDF
                  457.7377  M+2                    C1235Cl737ClO2                       OCDD
                  459.7348  M+4                    C1235Cl637Cl2O2                      OCDD
                  469.7779  M+2                    13C1235Cl737ClO2                     OCDD (S)
                  471.7750  M+4                    13C1235Cl637Cl2O2                    OCDD (S)
                  513.6775  M+4                    C1235Cl837Cl2O2                      DCDPE
                  442.9728  QC                     C10F17                               PFK
----------------------------------------------------------------------------------------------------------------
(a) The following nuclidic masses were used:
H = 1.007825
C = 12.000000
13C = 13.003355
F = 18.9984
O = 15.994915
35Cl = 34.968853
37Cl = 36.965903
S = Labeled Standard
QC = Ion selected for monitoring instrument stability during the GC/MS analysis.


Table 4--Acceptable Ranges for Ion-Abundance Ratios of PCDD's and PCDF's
------------------------------------------------------------------------
  No. of                                                 Control limits
 chlorine             Ion type             Theoretical -----------------
  atoms                                       ratio      Lower    Upper
------------------------------------------------------------------------
        4  M/M+2                                0.77       0.65     0.89
        5  M+2/M+4                              1.55       1.32     1.78
        6  M+2/M+4                              1.24       1.05     1.43
      6 a  M/M+2                                0.51       0.43     0.59
      7 b  M/M+2                                0.44       0.37     0.51
        7  M+2/M+4                              1.04       0.88     1.20
        8  M+2/M+4                              0.89       0.76     1.02
------------------------------------------------------------------------
a Used only for \13\C-HxCDF.
b Used only for \13\C-HpCDF.


Table 5--Minimum Requirements for Initial and Daily Calibration Response
                                 Factors
------------------------------------------------------------------------
                                             Relative response factors
                                         -------------------------------
                Compound                      Initial          Daily
                                            calibration    calibration %
                                                RSD         difference
------------------------------------------------------------------------
Unlabeled
    Analytes:
  2,3,7,8-TCDD..........................              25              25
  2,3,7,8-TCDF..........................              25              25
  1,2,3,7,8-PeCDD.......................              25              25
  1,2,3,7,8-PeCDF.......................              25              25
  2,3,4,7,8-PeCDF.......................              25              25
  1,2,4,5,7,8-HxCDD.....................              25              25
  1,2,3,6,7,8-HxCDD.....................              25              25
  1,2,3,7,8,9-HxCDD.....................              25              25
  1,2,3,4,7,8-HxCDF.....................              25              25
  1,2,3,6,7,8-HxCDF.....................              25              25
  1,2,3,7,8,9-HxCDF.....................              25              25
  2,3,4,6,7,8-HxCDF.....................              25              25
  1,2,3,4,6,7,8-HpCDD...................              25              25
  1,2,3,4,6,7,8-HpCDF...................              25              25
  OCDD..................................              25              25
  OCDF..................................              30              30
Internal
    Standards:
  \13\C12-2,3,7,8-TCDD..................              25              25
  \13\C12-1,2,3,7,8-PeCDD...............              30              30
  \13\C12-1,2,3,6,7,8-HxCDD.............              25              25
  \13\C12-1,2,3,4,6,7,8-HpCDD...........              30              30
  \13\C12-OCDD..........................              30              30
  \13\C12-2,3,7,8-TCDF..................              30              30
  \13\C12-1,2,3,7,8-PeCDF...............              30              30
  \13\C12-1,2,3,6,7,8-HxCDF.............              30              30
  \13\C12-1,2,3,4,6,7,8-HpCDF...........              30              30
Surrogate
    Standards:
  \37\Cl4-2,3,7,8-TCDD..................              25              25
  \13\C12-2,3,4,7,8-PeCDF...............              25              25
  \13\C12-1,2,3,4,7,8-HxCDD.............              25              25
  \13\C12-1,2,3,4,7,8-HxCDF.............              25              25
  \13\C12-1,2,3,4,7,8,9-HpCDF...........              25              25
Alternate
    Standard:
  \13\C12-1,2,3,7,8,9-HxCDF.............              25              25
------------------------------------------------------------------------

  Method 24--Determination of Volatile Matter Content, Water Content, 
      Density, Volume Solids, and Weight Solids of Surface Coatings

1. Applicability and Principle

[[Page 1043]]

    1.1  Applicability. This method applies to the determination of 
volatile matter content, water content, density, volume solids, and 
weight solids of paint, varnish, lacquer, or related surface coatings.
    1.2  Principle. Standard methods are used to determine the volatile 
matter content, water content, density, volume solids, and weight solids 
of the paint, varnish, lacquer, or related surface coatings.

2. Applicable Standard Methods

    Use the apparatus, reagents, and procedures specified in the 
standard methods below:
    2.1  ASTM D1475-60 (Reapproved 1980), Standard Test Method for 
Density of Paint, Varnish, Lacquer, and Related Products (incorporated 
by reference--see Sec. 60.17).
    2.2  ASTM D2369-81, Standard Test Method for Volatile Content of 
Coatings (incorporated by reference--see Sec. 60.17).
    2.3  ASTM D3792-79, Standard Test Method for Water Content of Water-
Reducible Paints by Direct Injection into a Gas Chromatograph 
(incorporated by reference--see Sec. 60.17).
    2.4  ASTM D4017-81, Standard Test Method for Water in Paints and 
Paint Materials by the Karl Fischer Titration Method (incorporated by 
reference--see Sec. 60.17).
    2.5  ASTM D4457-85 Standard Test Method for Determination of 
Dichloromethane and 1,1,1-Trichloroethane in Paints and Coatings by 
Direct Injection into a Gas Chromatograph (incorporated by reference--
see Sec. 60.17).
    2.6  ASTM D 5403-93 Standard Test Methods for Volatile Content of 
Radiation Curable Materials (incorporated by reference--see Sec. 60.17).

3. Procedure

    3.1  Multicomponent Coatings. Multicomponent coatings are coatings 
that are packaged in two or more parts, which are combined before 
application. Upon combination a coreactant from one part of the coating 
chemically reacts, at ambient conditions, with a coreactant from another 
part of the coating. To determine the total volatile content, water 
content, and density of multicomponent coatings, follow the procedures 
in section 3.7.
    3.2  Non Thin-film Ultraviolet Radiation-cured Coating. To determine 
volatile content of non thin-film ultraviolet radiation-cured (UV 
radiation-cured) coatings, follow the procedures in Section 3.9. 
Determine water content, density and solids content of the UV-cured 
coatings according to Sections 3.4, 3.5, and 3.6, respectively. The UV-
cured coatings are coatings which contain unreacted monomers that are 
polymerized by exposure to ultraviolet light. To determine if a coating 
or ink can be classified as a thin-film UV cured coating or ink, use the 
following equation:

C=F A D Eq. 24-1

Where:

A=Area of substrate, in \2\, cm \2\.
C=Amount of coating or ink added to the substrate, g.
D=Density of coating or ink, g/in \3\ (g/cm \3\)
F=Manufacturer's recommended film thickness, in (cm).

If C is less than 0.2 g and A is greater than or equal to 35 in \2\ (225 
cm \2\) then the coating or ink is considered a thin-film UV radiation-
cured coating for determining applicability of ASTM D 5403-93.
    Note: As noted in Section 1.4 of ASTM D 5403-93, this method may not 
be applicable to radiation curable materials wherein the volatile 
material is water. For all other coatings not covered by Sections 3.1 or 
3.2 analyze as follows:
    3.3  Volatile Matter Content. Use the procedure in ASTM D2369-81 
(incorporated by reference--see Sec. 60.17) to determine the volatile 
matter content (may include water) of the coating. Record the following 
information:

W1=Weight of dish and sample before heating, g.
W2=Weight of dish and sample after heating, g.
W3=Sample weight, g.

Run analyses in pairs (duplicate sets) for each coating until the 
criterion in Section 4.3 is met. Calculate the weight fraction of the 
volatile matter (Wv) for each analysis as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.227

Record the arithmetic average (Wv).
    3.4  Water Content. For waterborne (water reducible) coatings only, 
determine the weight fraction of water (WW) using either 
``Standard Content Method Test for Water of Water-Reducible Paints by 
Direct Injection into a Gas Chromatograph'' or ``Standard Test Method 
for Water in Paint and Paint Materials by Karl Fischer Method.'' (These 
two methods are incorporated by reference--see Sec. 60.17.) A waterborne 
coating is any coating which contains more than 5 percent water by 
weight in its volatile fraction. Run duplicate sets of determinations 
until the criterion in Section 4.3 is met. Record the arithmetic average 
(Ww).
    3.5  Coating Density. Determine the density (Dc, kg/
liter) of the surface coating using the procedure in ASTM D1475-60 
(Reapproved 1980) (incorporated by reference--see Sec. 60.17).
    Run duplicate sets of determinations for each coating until the 
criterion in Section 4.3 is met. Record the arithmetic average 
(Dc).

[[Page 1044]]

    3.6  Solids Content. Determine the volume fraction (Vs) 
solids of the coating by calculation using the manufacturer's 
formulation.
    3.7  Exempt Solvent Content. Determine the weight fraction of exempt 
solvents (WE) by using ASTM Method D4457-85 (incorporated by 
reference--see Sec. 60.17). Run a duplicate set of determinations and 
record the arithmetic average (WE)
    Note: Exempt solvents are defined as those solvents listed in 57 FR 
3941, February 3, 1992. Dichloromethane and 1,1,1-trichloroethane are 
listed exempt solvents and may be used in coatings.
    3.8  To determine the total volatile content, water content, and 
density of multicomponent coatings, use the following procedures:
    3.8.1  Prepare about 100 ml of sample by mixing the components in a 
storage container, such as a glass jar with a screw top or a metal can 
with a cap. The storage container should be just large enough to hold 
the mixture. Combine the components (by weight or volume) in the ratio 
recommended by the manufacturer. Tightly close the container between 
additions and during mixing to prevent loss of volatile materials. 
However, most manufacturers mixing instructions are by volume. Because 
of possible error caused by expansion of the liquid when measuring the 
volume, it is recommended that the components be combined by weight. 
When weight is used to combine the components and the manufacturer's 
recommended ratio is by volume, the density must be determined by 
section 3.5.
    3.8.2  Immediately after mixing, take aliquots from this 100 ml 
sample for determination of the total volatile content, water content, 
and density. To determine water content, follow section 3.4. To 
determine density, follow section 3.5. To determine total volatile 
content, use the apparatus and reagents described in ASTM D2369-81, 
sections 3 and 4, respectively (incorporated by reference, and see 
Sec. 60.17) the following procedures:
    3.8.2.1  Weigh and record the weight of an aluminum foil weighing 
dish. Add 31l of suitable solvent as specified in ASTM 
D2369-81 to the weighing dish. Using a syringe as specified in ASTM 
D2369-81, weigh to 1 mg, by difference, a sample of coating into the 
weighing dish. For coatings believed to have a volatile content less 
than 40 weight percent, a suitable size is 0.30.10 g, but 
for coatings believed to have a volatile content greater than 40 weight 
percent, a suitable size is 0.50.10 g.
    Note: If the volatile content determined pursuant to section 5 is 
not in the range corresponding to the sample size chosen repeat the test 
with the appropriate sample size. Add the specimen dropwise, shaking 
(swirling) the dish to disperse the specimen completely in the solvent. 
If the material forms a lump that cannot be dispersed, discard the 
specimen and prepare a new one. Similarly, prepare a duplicate. The 
sample shall stand for a minimum of 1 hour, but no more than 24 hours 
prior to being oven dried at 110  deg.C5  deg.C. for 1 hour.
    3.8.2.2  Heat the aluminum foil dishes containing the dispersed 
specimens in the forced draft oven for 60 min at 1105 
deg.C. Caution--provide adequate ventilation, consistent with accepted 
laboratory practice, to prevent solvent vapors from accumulating to a 
dangerous level.
    3.8.2.3  Remove the dishes from the oven, place immediately in a 
desiccator, cool to ambient temperature, and weigh to within 1 mg.
    3.8.2.4  Run analyses in pairs (duplicate sets) for each coating 
mixture until the criterion in section 4.3 is met. Calculate 
Wv following Equation 24-2 and record the arithmetic average.
    3.9  UV-cured Coating's Volatile Matter Content. Use the procedure 
in ASTM D 5403-93 (incorporated by reference--see Sec. 60.17) to 
determine the volatile matter content of the coating except the curing 
test described in NOTE 2 of ASTM D 5403-93 is required.

4. Data Validation Procedure

    4.1  Summary. The variety of coatings that may be subject to 
analysis makes it necessary to verify the ability of the analyst and the 
analytical procedures to obtain reproducible results for the coatings 
tested. This is done by running duplicate analyses on each sample tested 
and comparing results with the within-laboratory precision statements 
for each parameter. Because of the inherent increased imprecision in the 
determination of the VOC content of waterborne coatings as the weight 
percent water increases, measured parameters for waterborne coatings are 
modified by the appropriate confidence limits based on between-
laboratory precision statements.
    4.2  Analytical Precision Statements. The within-laboratory and 
between-laboratory precision statements are given below:

------------------------------------------------------------------------
                                   Within-laboratory  Between-laboratory
------------------------------------------------------------------------
Volatile matter content, Wv.....  1.5 pct Wv........  4.7 pct Wv.
Water content, Ww...............  2.9 pct Ww........  7.5 pct Ww.
Density, Dc.....................  0.001 kg/liter....  0.002 kg/liter.
------------------------------------------------------------------------

    4.3  Sample Analysis Criteria. For Wv and Ww, 
run duplicate analyses until the difference between the two values in a 
set is less than or equal to the within-laboratory precision statement 
for that parameter. For Dc run duplicate analyses until each 
value in a set deviates from the mean of the set by no more than the 
within-laboratory precision

[[Page 1045]]

statement. If after several attempts it is concluded that the ASTM 
procedures cannot be used for the specific coating with the established 
within-laboratory precision, the Administrator will assume 
responsibility for providing the necessary procedures for revising the 
method or precision statements upon written request to: Director, 
Emission Standards and Engineering Division, (MD-13) Office of Air 
Quality Planning and Standards, U.S. Environmental Protection Agency, 
Research Triangle Park, NC 27711.
    4.4  Confidence Limit Calculations for Waterborne Coatings. Based on 
the between-laboratory precision statements, calculate the confidence 
limits for waterborne coatings as follows:
    To calculate the lower confidence limit, subtract the appropriate 
between-laboratory precision value from the measured mean value for that 
parameter. To calculate the upper confidence limit, add the appropriate 
between-laboratory precision value to the measured mean value for that 
parameter. For Wv and Dc, use the lower confidence 
limits, and for Ww, use the upper confidence limit. Because 
Vs is calculated, there is no adjustment for the parameter.

5. Calculations

    5.1  Nonaqueous Volatile Matter.
    5.1.1  Solvent-borne Coatings.

                       Wo=Wv              Eq. 24-3

Where:

Wo=Weight fraction nonaqueous volatile matter, g/g.
    5.1.2  Waterborne Coatings.

           Wo=Wv-Ww            Eq. 24-4
    5.1.3  Coatings Containing Exempt Solvents.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.228
    
where:
    WE=weight fraction of exempt solvents, g/g.
    5.2  Weight Fraction Solids.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.229
    
where:
    Ws=weight fraction of solids, g/g.

  Method 24A--Determination of Volatile Matter Content and Density of 
                   Printing Inks and Related Coatings

1. Applicability and Principle

    1.1  Applicability. This method applies to the determination of the 
volatile organic compound (VOC) content and density of solvent-borne 
(solvent reducible) printing inks or related coatings.
    1.2  Principle. Separate procedures are used to determine the VOC 
weight fraction and density of the coating and the density of the 
solvent in the coating. The VOC weight fraction is determined by 
measuring the weight loss of a known sample quantity which has been 
heated for a specified length of time at a specified temperature. The 
density of both the coating and solvent are measured by a standard 
procedure. From this information, the VOC volume fraction is calculated.

2. Procedure

    2.1  Weight Fraction VOC.
    2.1.1  Apparatus.
    2.1.1.1  Weighing Dishes. Aluminum foil, 58 mm in diameter by 18 mm 
high, with a flat bottom. There must be at least three weighing dishes 
per sample.
    2.1.1.2  Disposable Syringe. 5 ml.
    2.1.1.3  Analytical Balance. To measure to within 0.1 mg.
    2.1.1.4  Oven. Vacuum oven capable of maintaining a temperature of 
1202  deg.C and an absolute pressure of 510 51 
mm Hg for 4 hours. Alternatively, a forced draft oven capable of 
maintaining a temperature of 1202  deg.C for 24 hours.
    2.1.2  Analysis. Shake or mix the sample thoroughly to assure that 
all the solids are completely suspended. Label and weigh to the nearest 
0.1 mg a weighing dish and record this weight (Mxl).
    Using a 5-ml syringe without a needle remove a sample of the 
coating. Weigh the syringe and sample to the nearest 0.1 mg and record 
this weight (McYl). Transfer 1 to 3 g of the sample to the 
tared weighing dish. Reweigh the syringe and sample to the nearest 0.1 
mg and record this weight (McY2). Heat the weighing dish and 
sample in a vacuum oven at an absolute pressure of 51051 mm 
Hg and a temperature of 1202  deg.C for 4 hours. 
Alternatively, heat the weighing dish and sample in a forced draft oven 
at a temperature of 1202  deg.C for 24 hours. After the 
weighing dish has cooled, reweigh it to the nearest 0.1 mg and record 
the weight (Mx2). Repeat this procedure for a total of three 
determinations for each sample.
    2.2  Coating Density. Determine the density of the ink or related 
coating according to the procedure outlined in ASTM D 1475-60 
(Reapproved 1980), (incorporated by reference--see Sec.  60.17).
    2.3  Solvent Density. Determine the density of the solvent according 
to the procedure outlined in ASTM D 1475-60 (reapproved 1980). Make a 
total of three determinations for each coating. Report the density 
Do as the arithmetic average of the three determinations.

3. Calculations

    3.1  Weight Fraction VOC. Calculate the weight fraction volatile 
organic content Wo using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.230



[[Page 1046]]


Report the weight fraction VOC Wo as the arithmetic average 
of the three determinations.
    3.2  Volume Fraction VOC. Calculate the volume fraction volatile 
organic content Vo using the following equation:

        Vo = (WoDc/Do

                                                               Eq. 24A-2

4. Bibliography

    1.  Standard Test Method for Density of Paint, Varnish, Lacquer, and 
Related Products. ASTM Designation D 1475-60 (Reapproved 1980).
    2.  Teleconversation. Wright, Chuck, Inmont Corporation with Reich, 
R. A., Radian Corporation. September 25, 1979. Gravure Ink Analysis.
    3.  Teleconversation. Oppenheimer, Robert, Gravure Research 
Institute with Burt, Rick, Radian Corporation, November 5, 1979. Gravure 
Ink Analysis.

 Method 25--Determination of Total Gaseous Nonmethane Organic Emissions 
                                as Carbon

                     1. Applicability and Principle

    1.1  Applicability. This method applies to the measurement of 
volatile organic compounds (VOC) as total gaseous nonmethane organics 
(TGNMO) as carbon in source emissions. Organic particulate matter will 
interfere with the analysis and, therefore, a particulate filter is 
required. The minimum detectable for the method is 50 ppm as carbon.
    When carbon dioxide (CO2) and water vapor are present 
together in the stack, they can produce a positive bias in the sample. 
The magnitude of the bias depends on the concentrations of 
CO2 and water vapor. As a guideline, multiply the 
CO2 concentration, expressed as volume percent, times the 
water vapor concentration. If this product does not exceed 100, the bias 
can be considered insignificant. For example, the bias is not 
significant for a source having 10 percent CO2 and 10 percent 
water vapor, but it would be significant for a source near the detection 
limit having 10 percent CO2 and 20 percent water vapor.
    This method is not the only method that applies to the measurement 
of TGNMO. Costs, logistics, and other practicalities of source testing 
may make other test methods more desirable for measuring VOC contents of 
certain effluent streams. Proper judgment is required in determining the 
most applicable VOC test method. For example, depending upon the 
molecular weight of the organics in the effluent stream, a totally 
automated semicontinuous nonmethane organics (NMO) analyzer interfaced 
directly to the source may yield accurate results. This approach has the 
advantage of providing emission data semicontinuously over an extended 
time period.
    Direct measurement of an effluent with a flame ionization detector 
(FID) analyzer may be appropriate with prior characterization of the gas 
stream and knowledge that the detector responds predictably to the 
organic compounds in the stream. If present, methane (CH4) 
will, of course, also be measured. The FID can be applied to the 
determination of the mass concentration of the total molecular structure 
of the organic emissions under any of the following limited conditions: 
(1) Where only one compound is known to exist; (2) when the organic 
compounds consist of only hydrogen and carbon; (3) where the relative 
percentages of the compounds are known or can be determined, and the FID 
responses to the compounds are known; (4) where a consistent mixture of 
the compounds exists before and after emission control and only the 
relative concentrations are to be assessed; or (5) where the FID can be 
calibrated against mass standards of the compounds emitted (solvent 
emissions, for example).
    Another example of the use of a direct FID is as a screening method. 
If there is enough information available to provide a rough estimate of 
the analyzer accuracy, the FID analyzer can be used to determine the VOC 
content of an uncharacterized gas stream. With a sufficient buffer to 
account for possible inaccuracies, the direct FID can be a useful tool 
to obtain the desired results without costly exact determination.
    In situations where a qualitative/quantitative analysis of an 
effluent stream is desired or required, a gas chromatographic FID system 
may apply. However, for sources emitting numerous organics, the time and 
expense of this approach will be formidable.
    1.2  Principle. An emission sample is withdrawn from the stack at a 
constant rate through a heated filter and a chilled condensate trap by 
means of an evacuated sample tank. After sampling is completed, the 
TGNMO are determined by independently analyzing the condensate trap and 
sample tank fractions and combining the analytical results. The organic 
content of the condensate trap fraction is determined by oxidizing the 
NMO to CO2 and quantitatively collecting the effluent in an 
evacuated vessel; then a portion of the CO2 is reduced to 
CH4 and measured by an FID. The organic content of the sample 
tank fraction is measured by injecting a portion of the sample into a 
gas chromatographic column to separate the NMO from carbon monoxide 
(CO), CO2, and CH4; the NMO are oxidized to 
CO2, reduced to CH4, and measured by an FID. In 
this manner, the variable response of the FID associated with different 
types of organics is eliminated.

[[Page 1047]]

                              2. Apparatus

    2.1  Sampling. The sampling system consists of a heated probe, 
heated filter, condensate trap, flow control system, and sample tank 
(Figure 25-1). The TGNMO sampling equipment can be constructed from 
commercially available components and components fabricated in a machine 
shop. The following equipment is required:
    2.1.1  Heated Probe. 6.4-mm (\1/4\-in.) OD stainless steel tubing 
with a heating system capable of maintaining a gas temperature at the 
exit end of at least 129  deg.C (265  deg.F). The probe shall be 
equipped with a thermocouple at the exit end to monitor the gas 
temperature.
    A suitable probe is shown in Figure 25-1. The nozzle is an elbow 
fitting attached to the front end of the probe while the thermocouple is 
inserted in the side arm of a tee fitting attached to the rear of the 
probe. The probe is wrapped with a suitable length of high temperature 
heating tape, and then covered with two layers of glass cloth insulation 
and one layer of aluminum foil.
    Note. If it is not possible to use a heating system for safety 
reasons, an unheated system with an in-stack filter is a suitable 
alternative.
    2.1.2  Filter Holder. 25-mm (\15/16\-in.) ID Gelman filter holder 
with stainless steel body and stainless steel support screen with the 
Viton O-ring replaced by a Teflon O-ring.
    Note. Mention of trade names or specific products does not 
constitute endorsement by the Environmental Protection Agency.
    2.1.3  Filter Heating System. A metal box consisting of an inner and 
an outer shell separated by insulating material with a heating element 
in the inner shell capable of maintaining a gas temperature at the 
filter of 1213  deg.C (2505  deg.F).
    A suitable heating box is shown in Figure 25-2. The outer shell is a 
metal box that measures 102 mm x 280 mm x 292 mm (4 in. x 11 in. x 11\1/
2\ in.), while the inner shell is a metal box measuring 76 mm x 229 
mm x 241 mm (3 in. x 9 in. x 9\1/2\ in.). The inner box is supported by 
13-mm (\1/2\-in.) phenolic rods. The void space between the boxes is 
filled with fiberfrax insulation which is sealed in place by means of a 
silicon rubber bead around the upper sides of the box. A removable lid 
made in a similar manner, with a 25-mm (1-in.) gap between the parts, is 
used to cover the heating chamber.
    The inner box is heated witn a 250-watt cartridge heater, shielded 
by a stainless steel shroud. The heater is regulated by a thermostatic 
temperature controller which is set to maintain a temperature of 121 
deg.C as measured by a thermocouple in the gas line just before the 
filter. An additional thermocouple is used to monitor the temperature of 
the gas behind the filter.
    2.1.4  Condensate Trap. 9.5-mm (\3/8\-in.) OD 316 stainless steel 
tubing bent into a U-shape. Exact dimensions are shown in Figure 25-3. 
The tubing shall be packed with coarse quartz wool, to a density of 
approximately 0.11 g/cc before bending. While the condensate trap is 
packed with dry ice in the Dewar, an ice bridge may form between the 
arms of the condensate trap making it difficult to remove the condensate 
trap. This problem can be prevented by attaching a steel plate between 
the arms of the condensate trap in the same plane as the arms to 
completely fill the intervening space.
    2.1.5  Valve. Stainless steel shut-off valve for starting and 
stopping sample flow.
    2.1.6  Metering Valve. Stainless steel control valve for regulating 
the sample flow rate through the sample train.
    2.1.7  Rotameter. Glass tube with stainless steel fittings, capable 
of measuring sample flow in the range of 60 to 100 cc/min.
    2.1.8  Sample Tank. Stainless steel or aluminum tank with a minimum 
volume of 4 liters.
    2.1.9  Mercury Manometer or Absolute Pressure Gauge. Capable of 
measuring pressure to within 1 mm Hg in the range of 0 to 900 mm.
    2.1.10  Vacuum Pump. Capable of evacuating to an absolute pressure 
of 10 mm Hg.
    2.2 Condensate Recovery Apparatus. The system for the recovery of 
the organics captured in the condensate trap consists of a heat source, 
oxidation catalyst, nondispersive infrared (NDIR) analyzer and an 
intermediate collection vessel (ICV). Figure 25-4 is a schematic of a 
typical system. The system shall be capable of proper oxidation and 
recovery, as specified in Section 5.1. The following major components 
are required:
    2.2.1 Heat Source. Sufficient to heat the condensate trap (including 
connecting tubing) to a temperature of 200  deg.C. A system using both a 
heat gun and an electric tube furnace is recommended.
    2.2.2 Heat Tape. Sufficient to heat the connecting tubing between 
the water trap and the oxidation catalyst to 100  deg.C.
    2.2.3 Oxidation Catalyst. A suitable length of 9.5-mm (\3/8\-in.) OD 
Inconel 600 tubing packed with 15 cm (6 in.) of 3.2-mm (\1/8\-1n.) 
diameter 19 percent chromia on alumina pellets. The catalyst material is 
packed in the center of the catalyst tube with quartz wool packed on 
either end to hold it in place. The catalyst tube shall be mounted 
vertically in a 650  deg.C tube furnace.
    2.2.4  Water Trap. Leak proof, capable of removing moisture from the 
gas stream
    2.2.5  Syringe Port. A 6.4-mm (\1/4\-in.) OD stainless steel tee 
fitting with a rubber septum placed in the side arm.
    2.2.6  NDIR Detector. Capable of indicating CO2 
concentration in the range of zero to 5

[[Page 1048]]

percent, to monitor the progress of combustion of the organic compounds 
from the condensate trap.
    2.2.7  Flow-Control Valve. Stainless steel, to maintain the trap 
conditioning system near atmospheric pressure.
    2.2.8  Intermediate Collection Vessel. Stainless steel or aluminum, 
equipped with a female quick connect. Tanks with nominal volumes of at 
least 6 liters are recommended.
    2.2.9  Mercury Manometer or Absolute Pressure Gauge. Capable of 
measuring pressure to within 1 mm Hg in the range of 0 to 900 mm.
    2.2.10  Syringe. 10-ml gas-tight, glass syringe equipped with an 
appropriate needle.
    2.3  NMO Analyzer. The NMO analyzer is a gas chromatograph (GC) with 
backflush capability for NMO analysis and is equipped with an oxidation 
catalyst, reduction catalyst, and FID. Figures 25-5 and 25-6 are 
schematics of a typical NMO analyzer. This semicontinuous GC/FID 
analyzer shall be capable of: (1) Separating CO, CO2, and 
CH4 from NMO, (2) reducing the CO2 to 
CH4 and quantifying as CH4, and (3) oxidizing the 
NMO to CO2, reducing the CO2 to CH4 and 
quantifying as CH4, according to Section 5.2. The analyzer 
consists of the following major components:
    2.3.1  Oxidation Catalyst. A suitable length of 9.5-mm (\3/8\-in.) 
OD Inconel 600 tubing packed with 5.1 cm (2 in.) of 19 percent chromia 
on 3.2-mm (\1/8\-in.) alumina pellets. The catalyst material is packed 
in the center of the tube supported on either side by quartz wool. The 
catalyst tube must be mounted vertically in a 650  deg.C furnace.
    2.3.2  Reduction Catalyst. A 7.6-cm (3-in.) length of 6.4-mm (\1/4\-
in.) OD Inconel tubing fully packed with 100-mesh pure nickel powder. 
The catalyst tube must be mounted vertically in a 400  deg.C furnace.
    2.3.3  Separation Column(s). A 30-cm (1-ft) length of 3.2-mm (\1/8\-
in.) OD stainless steel tubing packed with 60/80 mesh Unibeads 1S 
followed by a 61-cm (2-ft) length of 3.2-mm (\1/8\-in.) OD stainless 
steel tubing packed with 60/80 mesh Carbosieve G. The Carbosieve and 
Unibeads columns must be baked separately at 200  deg.C with carrier gas 
flowing through them for 24 hours before initial use.
    2.3.4  Sample Injection System. A 10-port GC sample injection valve 
fitted with a sample loop properly sized to interface with the NMO 
analyzer (1-cc loop recommended).
    2.3.5  FID. An FID meeting the following specifications is required:
    2.3.5.1  Linearity. A linear response (5 percent) over 
the operating range as demonstrated by the procedures established in 
Section 5.2.3.
    2.3.5.2  Range. A full scale range of 10 to 50,000 ppm 
CH4. Signal attenuators shall be available to produce a 
minimum signal response of 10 percent of full scale.
    2.3.6  Data Recording System. Analog strip chart recorder or digital 
integration system compatible with the FID for permanently recording the 
analytical results.
    2.4  Other Analysis Apparatus.
    2.4.1  Barometer. Mercury, aneroid, or other barometer capable of 
measuring atmospheric pressure to within 1 mm Hg.
    2.4.2  Thermometer. Capable of measuring the laboratory temperature 
to within 1  deg.C.
    2.4.3  Vacuum Pump. Capable of evacuating to an absolute pressure of 
10 mm Hg.
    2.4.4  Syringes. 10-l and 50-l liquid injection 
syringes.
    2.4.5  Liquid Sample Injection Unit. 316 SS U-tube fitted with an 
injection septum, see Figure 25-7.

                               3. Reagents

    3.1  Sampling. The following are required for sampling:
    3.1.1  Crushed Dry Ice.
    3.1.2  Coarse Quartz Wool. 8 to 15 m.
    3.1.3  Filters. Glass fiber filters, without organic binder.
    3.2  NMO Analysis. The following gases are needed:
    3.2.1  Carrier Gases. Zero grade helium (He) and oxygen 
(O2 containing less than 1 ppm CO2 and less than 
0.1 ppm C as hydrocarbon.
    3.2.2  Fuel Gas. Zero grade hydrogen (H2), 99.999 percent 
pure.
    3.2.3  Combustion Gas. Zero grade air or O2 as required 
by the detector.
    3.3  Condensate Analysis. The following gases are needed:
    3.3.1  Carrier Gas. Zero grade air, containing less than 1 ppm C.
    3.3.2  Auxiliary O2. Zero grade O2, containing 
less than 1 ppm C.
    3.3.3  Hexane. ACS grade, for liquid injection.
    3.3.4  Decane. ACS grade, for liquid injection.
    3.4  Calibration. For all calibration gases, the manufacturer must 
recommend a maximum shelf life for each cylinder (i.e., the length of 
time the gas concentration is not expected to change more than 
5 percent from its certified value). The date of gas 
cylinder preparation, certified organic concentration, and recommended 
maximum shelf life must be affixed to each cylinder before shipment from 
the gas manufacturer to the buyer. The following calibration gases are 
required:
    3.4.1  Oxidation Catalyst Efficiency Check Calibration Gas. Gas 
mixture standard with nominal concentration of 1 percent methane in air.
    3.4.2  FID Linearity and NMO Calibration Gases. Three gas mixture 
standards with nominal propane concentrations of 20 ppm, 200 ppm, and 
3000 ppm, in air.

[[Page 1049]]

    3.4.3  CO2 Calibration Gases. Three gas mixture standards 
with nominal CO2 concentrations of 50 ppm, 500 ppm, and 1 
percent, in air.
    Note.-- Total NMO of less than 1 ppm required for 1 percent mixture.
    3.4.4  NMO Analyzer System Check Calibration Gases. Four calibration 
gases are needed as follows:
    3.4.4.1  Propane Mixture. Gas mixture standard containing (nominal) 
50 ppm CO, 50 ppm CH4, 2 percent CO2, and 20 ppm 
C3H8, prepared in air.
    3.4.4.2  Hexane. Gas mixture standard containing (nominal) 50 ppm 
hexane in air.
    3.4.4.3  Toluene. Gas mixture standard containing (nominal) 20 ppm 
toluene in air.
    3.4.4.4  Methanol. Gas mixture standard containing (nominal) 100 ppm 
methanol in air.

                              4. Procedure

    4.1   Sampling.
    4.1.1  Cleaning Sampling Equipment. Before its initial use and after 
each subsequent use, a condensate trap should be thoroughly cleaned and 
checked to ensure that it is not contaminated. Both cleaning and 
checking can be accomplished by installing the trap in the condensate 
recovery system and treating it as if it were a sample. The trap should 
be heated as described in the final paragraph of Section 4.3.3. A trap 
may be considered clean when the CO2 concentration in its 
effluent gas drops below 10 ppm. This check is optional for traps that 
have been used to collect samples which were then recovered according to 
the procedure in Section 4.3.3.
    4.1.2  Sample Tank Evacuation and Leak Check. Evacuate the sample 
tank to 10 mm Hg absolute pressure or less. Then close the sample tank 
valve, and allow the tank to sit for 60 minutes. The tank is acceptable 
if no change in tank vacuum is noted. The evacuation and leak check may 
be conducted either in the laboratory or the field. The results of the 
leak check should be included in the test report.
    4.1.3  Sample Train Assembly. Just before assembly, measure the tank 
vacuum using a mercury U-tube manometer or absolute pressure gauge. 
Record this vacuum, the ambient temperature, and the barometric pressure 
at this time. Close the sample tank valve and assemble the sampling 
system as shown in Figure 25-1. Immerse the condensate trap body in dry 
ice. The point where the inlet tube joins the trap body should be 2.5 to 
5 cm above the top of the dry ice.
    4.1.4  Pretest Leak Check. A pretest leak check is required. 
Calculate or measure the approximate volume of the sampling train from 
the probe trip to the sample tank valve. After assembling the sampling 
train, plug the probe tip, and make certain that the sample tank valve 
is closed. Turn on the vacuum pump, and evacuate the sampling system 
from the probe tip to the sample tank valve to an absolute pressure of 
10 ppm Hg or less. Close the purge valve, turn off the pump, wait a 
minimum period of 5 minutes, and recheck the indicated vacuum. Calculate 
the maximum allowable pressure change based on a leak rate of 1 percent 
of the sampling rate using Equation 25-1, Section 6.2. If the measured 
pressure change exceeds the calculated limit, correct the problem before 
beginning sampling. The results of the leak check should be included in 
the test report.
    4.1.5  Sample Train Operation. Unplug the probe tip, and place the 
probe into the stack such that the probe is perpendicular to the duct or 
stack axis; locate the probe tip at a single preselected point of 
average velocity facing away from the direction of gas flow. For stacks 
having a negative static pressure, seal the sample port sufficiently to 
prevent air in-leakage around the probe. Set the probe temperature 
controller to 129  deg.C (265  deg.F) and the filter temperature 
controller to 121  deg.C (250  deg.F). Allow the probe and filter to 
heat for about 30 minutes before purging the sample train.
    Close the sample valve, open the purge valve, and start the vacuum 
pump. Set the flow rate between 60 and 100 cc/min, and purge the train 
with stack gas for at least 10 minutes. When the temperatures at the 
exit ends of the probe and filter are within their specified range, 
sampling may begin.
    Check the dry ice level around the condensate trap, and add dry ice 
if necessary. Record the clock time. To begin sampling, close the purge 
valve and stop the pump. Open the sample valve and the sample tank 
valve. Using the flow control valve, set the flow through the sample 
train to the proper rate. Adjust the flow rate as necessary to maintain 
a constant rate (10 percent) throughout the duration of the 
sampling period. Record the sample tank vacuum and flowmeter setting at 
5-minute intervals. (See Figure 25-8.) Select a total sample time 
greater than or equal to the minimum sampling time specified in the 
applicable subpart of the regulation; end the sampling when this time 
period is reached or when a constant flow rate can no longer be 
maintained because of reduced sample tank vacuum.
    Note: If sampling had to be stopped before obtaining the minimum 
sampling time (specified in the applicable subpart) because a constant 
flow rate could not be maintained, proceed as follows: After closing the 
sample tank valve, remove the used sample tank from the sampling train 
(without disconnecting other portions of the sampling train). Take 
another evacuated and leak-checked sample tank, measure and record the 
tank vacuum, and attach the new tank to the sampling train. After the 
new tank is attached to the sample train, proceed with the sampling 
until the required minimum sampling time has been exceeded.

[[Page 1050]]

    4.2  Sample Recovery. After sampling is completed, close the flow 
control valve, and record the final tank vacuum; then record the tank 
temperature and barometric pressure. Close the sample tank valve, and 
disconnect the sample tank from the sample system. Disconnect the 
condensate trap at the flowmetering system, and tightly seal both ends 
of the condensate trap. Do not include the probe from the stack to the 
filter as part of the condensate sample. Keep the trap packed in dry ice 
until the samples are returned to the laboratory for analysis. Ensure 
that the test run number is properly identified on the condensate trap 
and the sample tank(s).
    4.3  Condensate Recovery. See Figure 25-9. Set the carrier gas flow 
rate, and heat the catalyst to its operating temperature to condition 
the apparatus.
    4.3.1  Daily Performance Checks. Each day before analyzing any 
samples, perform the following tests:
    4.3.1.1  Leak Check. With the carrier gas inlets and the flow 
control valve closed, install a clean condensate trap in the system, and 
evacuate the system to 10 mm Hg absolute pressure or less. Close the 
vacuum pump valve and turn off the vacuum pump. Monitor the system 
pressure for 10 minutes. The system is acceptable if the pressure change 
is less than 2 mm Hg.
    4.3.1.2   System Background Test. Adjust the carrier gas and 
auxiliary oxygen flow rate to their normal values of 100 cc/min and 150 
cc/min, respectively, with the sample recovery valve in vent position. 
Using a 10-ml syringe withdraw a sample from the system effluent through 
the syringe port. Inject this sample into the NMO analyzer, and measure 
the CO2 content. The system background is acceptable if the 
CO2 concentration is less than 10 ppm.
    4.3.1.3   Oxidation Catalyst Efficiency Check. Conduct a catalyst 
efficiency test as specified in Section 5.1.2 of this method. If the 
criterion of this test cannot be met, make the necessary repairs to the 
system before proceeding.
    4.3.2  Condensate Trap CO2 Purge and Sample Tank 
Pressurization. After sampling is completed, the condensate trap will 
contain condensed water and organics and a small volume of sampled gas. 
This gas from the stack may contain a significant amount of 
CO2 which must be removed from the condensate trap before the 
sample is recovered. This is accomplished by purging the condensate trap 
with zero air and collecting the purged gas in the original sample tank.
    Begin with the sample tank and condensate trap from the test run to 
be analyzed. Set the four-port valve of the condensate recovery system 
in the CO2 purge position as shown in Figure 25-9. With the 
sample tank valve closed, attach the sample tank to the sample recovery 
system. With the sample recovery valve in the vent position and the flow 
control valve fully open, evacuate the manometer or pressure gauge to 
the vacuum of the sample tank. Next, close the vacuum pump valve, open 
the sample tank valve, and record the tank pressure.
    Attach the dry-ice-cooled condensate trap to the recovery system, 
and initiate the purge by switching the sample recovery valve from vent 
to collect position. Adjust the flow control valve to maintain 
atmospheric pressure in the recovery system. Continue the purge until 
the CO2 concentration of the trap effluent is less than 5 
ppm. CO2 concentration in the trap effluent should be 
measured by extracting syringe samples from the recovery system and 
analyzing the samples with the NMO analyzer. This procedure should be 
used only after the NDIR response has reached a minimum level. Using a 
10-ml syringe, extract a sample from the syringe port prior to the NDIR, 
and inject this sample into the NMO analyzer.
    After the completion of the CO2 purge, use the carrier 
gas bypass valve to pressurize the sample tank to approximately 1060 mm 
Hg absolute pressure with zero air.
    4.3.3  Recovery of the Condensate Trap Sample. See Figure 25-10. 
Attach the ICV to the sample recovery system. With the sample recovery 
valve in a closed position, between vent and collect, and the flow 
control and ICV valves fully open, evacuate the manometer or gauge, the 
connecting tubing, and the ICV to 10 mm Hg absolute pressure. Close the 
flow-control and vacuum pump valves.
    Begin auxiliary oxygen flow to the oxidation catalyst at a rate of 
150 cc/min, then switch the four-way valve to the trap recovery position 
and the sample recovery valve to collect position. The system should now 
be set up to operate as indicated in Figure 25-10. After the manometer 
or pressure gauge begins to register a slight positive pressure, open 
the flow control valve. Adjust the flow-control valve to maintain 
atmospheric pressure in the system within 10 percent.
    Now, remove the condensate trap from the dry ice, and allow it to 
warm to ambient temperature while monitoring the NDIR response. If after 
5 minutes, the CO2 concentration of the catalyst effluent is 
below 10,000 ppm, discontinue the auxiliary oxygen flow to the oxidation 
catalyst. Begin heating the trap by placing it in a furnace preheated to 
200  deg.C. Once heating has begun, carefully monitor the NDIR response 
to ensure that the catalyst effluent concentration does not exceed 
50,000 ppm. Whenever the CO2 concentration exceeds 50,000 
ppm, supply auxiliary oxygen to the catalyst at the rate of 150 cc/min. 
Begin heating the tubing that connected the heated sample box to the 
condensate trap only after the CO2 concentration falls below 
10,000 ppm. This tubing may be heated in the same oven as the condensate

[[Page 1051]]

trap or with an auxiliary heat source such as a heat gun. Heating 
temperature must not exceed 200  deg.C. If a heat gun is used, heat the 
tubing slowly along its entire length from the upstream end to the 
downstream end, and repeat the pattern for a total of three times. 
Continue the recovery until the CO2 concentration drops to 
less than 10 ppm as determined by syringe injection as described under 
the condensate trap CO2 purge Procedure, Section 4.3.2.
    After the sample recovery is completed, use the carrier gas bypass 
valve to pressurize the ICV to approximately 1060 mm Hg absolute 
pressure with zero air.
    4.4  Analysis. Before putting the NMO analyzer into routine 
operation, conduct an initial performance test. Start the analyzer, and 
perform all the necessary functions in order to put the analyzer into 
proper working order; then conduct the performance test according to the 
procedures established in Section 5.2. Once the performance test has 
been successfully completed and the CO2 and NMO calibration 
response factors have been determined, proceed with sample analysis as 
follows:
    4.4.1  Daily Operations and Calibration Checks. Before and 
immediately after the analysis of each set of samples or on a daily 
basis (whichever occurs first), conduct a calibration test according to 
the procedures established in Section 5.3. If the criteria of the daily 
calibration test cannot be met, repeat the NMO analyzer performance test 
(Section 5.2) before proceeding.
    4.4.2  Operating Conditions. The carrier gas flow rate is 29.5 cc/
min He and 2.2 cc/min O2. The column oven is heated to 85 
deg.C. The order of elution for the sample from the column is CO, 
CH4, CO2, and NMO.
    4.4.3   Analysis of Recovered Condensate Sample. Purge the sample 
loop with sample, and then inject the sample. Under the specified 
operating conditions, the CO2 in the sample will elute in 
approximately 100 seconds. As soon as the detector response returns to 
baseline following the CO2 peak, switch the carrier gas flow 
to backflush, and raise the column oven temperature to 195  deg.C as 
rapidly as possible. A rate of 30  deg.C/min has been shown to be 
adequate. Record the value obtained for the condensible organic material 
(Ccm) measured as CO2 and any measured NMO. Return 
the column oven temperature to 85  deg.C in preparation for the next 
analysis. Analyze each sample in triplicate, and report the average 
Ccm.
    4.4.4  Analysis of Sample Tank. Perform the analysis as described in 
Section 4.4.3, but record only the value measured for NMO 
(Ctm).
    4.5  Audit Samples. Analyze a set of two audit samples concurrently 
with any compliance samples and in exactly the same manner to evaluate 
the analyst's technique and the instrument calibration. The same 
analysts, analytical reagents, and analytical system shall be used for 
the compliance samples and the EPA audit samples; if this condition is 
met, auditing of subsequent compliance analyses for the same enforcement 
agency within 30 days is not required. An audit sample set may not be 
used to validate different sets of compliance samples under the 
jurisdiction of different enforcement agencies, unless prior 
arrangements are made with both enforcement agencies.
    Calculate the concentrations of the audit samples in ppm using the 
specified sample volume in the audit instructions. (Note.-- Indication 
of acceptable results may be obtained immediately by reporting the audit 
results in ppm and compliance results in ppm by telephone to the 
responsible enforcement agency.) Include the results of both audit 
samples, their identification numbers, and the analyst's name with the 
results of the compliance determination samples in appropriate reports 
to the EPA regional office or the appropriate enforcement agency during 
the 30-day period.
    The concentration of the audit samples obtained by the analyst shall 
agree within 20 percent of the actual concentrations. Failure to meet 
the 20-percent specification may require retests until the audit 
problems are resolved. However, if the audit results do not affect the 
compliance or noncompliance status of the affected facility, the 
Administrator may waive the reanalysis requirement, further audits, or 
retests and accept the results of the compliance test. While steps are 
being taken to resolve audit analysis problems, the Administrator may 
also choose to use the data to determine the compliance or noncompliance 
of the affected facility.

                  5. Calibration and Operational Checks

    Maintain a record of performance of each item.
    5.1  Initial Performance Check of Condensate Recovery Apparatus. 
Perform these tests before the system is first placed in operation, 
after any shutdown of 6 months or more, and after any major modification 
of the system, or at the specified frequency.
    5.1.1  Carrier Gas and Auxiliary O2 Blank Check. Analyze 
each new tank of carrier gas or auxiliary O2 with the NMO 
analyzer to check for contamination. Treat the gas cylinders as 
noncondensible gas samples, and analyze according to the procedure in 
Section 4.4.3. Add together any measured CH4, CO, 
CO2, or NMO. The total concentration must be less than 5 ppm.
    5.1.2  Catalyst Efficiency Check. With a clean condensate trap 
installed in the recovery system, replace the carrier gas cylinder with 
the high level methane standard gas cylinder (Section 3.4.1). Set the 
four-port valve to the recovery position, and attach an ICV to the 
recovery system. With the sample

[[Page 1052]]

recovery valve in vent position and the flow-control and ICV valves 
fully open, evacuate the manometer or gauge, the connecting tubing, and 
the ICV to 10 mm Hg absolute pressure. Close the flow-control and vacuum 
pump valves.
    After the NDIR response has stabilized, switch the sample recovery 
valve from vent to collect. When the manometer or pressure gauge begins 
to register a slight positive pressure, open the flow-control valve. 
Keep the flow adjusted so that atmospheric pressure is maintained in the 
system within 10 percent. Continue collecting the sample in a normal 
manner until the ICV is filled to a nominal gauge pressure of 300 mm Hg. 
Close the ICV valve, and remove the ICV from the system. Place the 
sample recovery valve in the vent position, and return the recovery 
system to its normal carrier gas and normal operating conditions. 
Analyze the ICV for CO2 using the NMO analyzer; the catalyst 
efficiency is acceptable if the CO2 concentration is within 2 
percent of the methane standard concentration.
    5.1.3  System Performance Check. Construct a liquid sample injection 
unit similar in design to the unit shown in Figure 25-7. Insert this 
unit into the condensate recovery and conditioning system in place of a 
condensate trap, and set the carrier gas and auxiliary O2 
flow rates to normal operating levels. Attach an evacuated ICV to the 
system, and switch from system vent to collect. With the carrier gas 
routed through the injection unit and the oxidation catalyst, inject a 
liquid sample (See Sections 5.1.3.1 to 5.1.3.4) into the injection port. 
Operate the trap recovery system as described in Section 4.3.3. Measure 
the final ICV pressure, and then analyze the vessel to determine the 
CO2 concentration. For each injection, calculate the percent 
recovery using the equation in Section 6.6.
    The performance test is acceptable if the average percent recovery 
is 10010 percent with a relative standard deviation (Section 
6.9) of less than 5 percent for each set of triplicate injections as 
follows:
    5.1.3.1  50 l Hexane.
    5.1.3.2  10 l Hexane.
    5.1.3.3  50 l Decane.
    5.1.3.4  10 l Decane.
    5.2  Initial NMO Analyzer Performance Test. Perform these tests 
before the system is first placed in operation, after any shutdown 
longer than 6 months, and after any major modification of the system.
    5.2.1  Oxidation Catalyst Efficiency Check. Turn off or bypass the 
NMO analyzer reduction catalyst. Make triplicate injections of the high 
level methane standard (Section 3.4.1). The oxidation catalyst operation 
is acceptable if the FID response is less than 1 percent of the injected 
methane concentration.
    5.2.2  Reduction Catalyst Efficiency Check. With the oxidation 
catalyst unheated or bypassed and the heated reduction catalyst 
bypassed, make triplicate injections of the high level methane standard 
(Section 3.4.1). Repeat this procedure with both catalysts operative. 
The reduction catalyst operation is acceptable if the response under 
both conditions agree within 5 percent.
    5.2.3  Analyzer Linearity Check and NMO Calibration. While operating 
both the oxidation and reduction catalysts, conduct a linearity check of 
the analyzer using the propane standards specified in Section 3.4.2. 
Make triplicate injections of each calibration gas, and then calculate 
the average response factor (area/ppm C) for each gas, as well as the 
overall mean of the response factor values. The instrument linearity is 
acceptable if the average response factor of each calibration gas is 
within 2.5 percent of the overall mean value and if the relative 
standard deviation (Section 6.9) for each set of triplicate injections 
is less than 2 percent. Record the overall mean of the propane response 
factor values as the NMO calibration response factor (RFNMO).
    Repeat the linearity check using the CO2 standards 
specified in Section 3.4.3. Make triplicate injections of each gas, and 
then calculate the average response factor (area/ppm C) for each gas, as 
well as the overall mean of the response factor values. Record the 
overall mean of the response factor values as the CO2 
calibration response factor (RFCO2). Linearity is acceptable 
if the average response factor of each calibration gas is within 2.5 
percent of the overall mean value and if the relative standard deviation 
for each set of triplicate injections is less than 2 percent. The 
RFCO2 must be witnin 10 percent of the RFNMO.
    5.2.4  System Peformance Check. Check the column separation and 
overall performance of the analyzer by making triplicate injections of 
the calibration gases listed in Section 3.4.4. The analyzer performance 
is acceptable if the measured NMO value for each gas (average of 
triplicate injections) is within 5 percent of the expected value.
    5.3  NMO Analyzer Daily Calibration.
    5.3.1  CO2 Response Factor. Inject triplicate samples of 
the high level CO2 calibration gas (Section 3.4.3), and 
calculate the average response factor. The system operation is adequate 
if the calculated response factor is within 5 percent of the 
RFCO2 calculated during the initial performance test (Section 
5.2.3). Use the daily response factor (DRFCO2) for analyzer 
calibration and the calculation of measured CO2 
concentrations in the ICV samples.
    5.3.2  NMO Response Factors. Inject triplicate samples of the mixed 
propane calibration cylinder (Section 3.4.4.1), and calculate the 
average NMO response factor. The system operation is adequate if the 
calculated

[[Page 1053]]

response factor is within 5 percent of the RFNMO calculated 
during the initial performance test (Section 5.2.4). Use the daily 
response factor (DRFNMO) for analyzer calibration and 
calculation of NMO concentrations in the sample tanks.
    5.4  Sample Tank and ICV Volume. The volume of the gas sampling 
tanks used must be determined. Determine the tank and ICV volumes by 
weighing them empty and then filled with deionized distilled water; 
weigh to the nearest 5 g, and record the results. Alternatively, measure 
the volume of water used to fill them to the nearest 5 ml.

                             6. Calculations

    All equations are written using absolute pressure; absolute 
pressures are determined by adding the measured barometric pressure to 
the measured gauge or manometer pressure.
    6.1  Nomenclature.

C=TGNMO concentration of the effluent, ppm C equivalent.
Cc=Calculated condensible organic (condensate trap) 
          concentration of the effluent, ppm C equivalent.
Ccm=Measured concentration (NMO analyzer) for the condensate 
          trap ICV, ppm CO2.
Ct=Calculated noncondensible organic concentration (sample 
          tank) of the effluent, ppm C equivalent.
Ctm=Measured concentration (NMO analyzer) for the sample 
          tank, ppm NMO.
F=Sampling flow rate, cc/min.
L=Volume of liquid injected, l.
M=Molecular weight of the liquid injected, g/g-mole.
mC =TGNMO mass concentration of the effluent, mg C/dsm\3\.
N=Carbon number of the liquid compound injected (N=12 for decane, N=6 
          for hexane).
Pf =Final pressure of the intermediate collection vessel, mm 
          Hg absolute.
Pb =Barometric pressure, cm Hg.
Pti =Gas sample tank pressure before sampling, mm Hg 
          absolute.
Pt =Gas sample tank pressure after sampling, but before 
          pressurizing, mm Hg absolute.
Ptf =Final gas sample tank pressure after pressurizing, mm Hg 
          absolute.
Tf =Final temperature of intermediate collection vessel, 
          +K.
Tti =Sample tank temperature before sampling, +K.
Tt =Sample tank temperature at completion of sampling, 
          +K.
Ttf =Sample tank temperature after pressurizing, 
          +K.
V=Sample tank volume, m\3\.
Vt =Sample train volume, cc.
Vv =Intermediate collection vessel volume, m\3\.
Vs =Gas volume sampled, dsm\3\.
n=Number of data points.
q=Total number of analyzer injections of intermediate collection vessel 
          during analysis (where k=injection number, 1 . . . q).
r=Total number of analyzer injections of sample tank during analysis 
          (where j=injection number, 1 . . . r).
xi =Individual measurements.
x=Mean value.
=Density of liquid injected, g/cc.
=Leak check period, min.
=Allowable pressure change, cm Hg.
    6.2  Allowable Pressure Change. For the pretest leak check, 
calculate the allowable pressure change:
[GRAPHIC] [TIFF OMITTED] TC01JN92.251

    6.3  Sample Volume. For each test run, calculate the gas volume 
sampled:
[GRAPHIC] [TIFF OMITTED] TC01JN92.252

    6.4  Noncondensible Organics. For each sample tank, determine the 
concentration of nonmethane organics (ppm C):
[GRAPHIC] [TIFF OMITTED] TC01JN92.305


[[Page 1054]]


    6.5  Condensible Organics. For each condensate trap determine the 
concentration of organics (ppm C):
[GRAPHIC] [TIFF OMITTED] TC01JN92.253

    6.6  TGNMO. To determine the TGNMO concentration for each test run, 
use the following equation:

C=Ct+Cc
   Eq. 25-5
    6.7  TGNMO Mass Concentration. To determine the TGNMO mass 
concentration as carbon for each test run, use the following equation:

mc=0.4993 C
   Eq. 25-6
    6.8  Percent Recovery. To calculate the percent recovery for the 
liquid injections to the condensate recovery and conditioning system use 
the following equation.
[GRAPHIC] [TIFF OMITTED] TC16NO91.231

    6.9  Relative Standard Deviation.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.254
    
                             7. Bibliography

    1. Salo, Albert E., Samuel Witz, and Robert D. MacPhee. 
Determination of Solvent Vapor Concentrations by Total Combustion 
Analysis: A Comparison of Infrared with Flame Ionization Detectors. 
Paper No. 75-33.2. (Presented at the 68th Annual Meeting of the Air 
Pollution Control Association. Boston, Massachusetts. June 15-20, 1975.) 
14 p.
    2. Salo, Albert E., William L. Oaks, and Robert D. MacPhee. 
Measuring the Organic Carbon Content of Source Emissions for Air 
Pollution Control. Paper No. 74-190. (Presented at the 67th Annual 
Meeting of the Air Pollution Control Association. Denver, Colorado. June 
9-13, 1974.) 25 p.

[[Page 1055]]

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[[Page 1056]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.256


[[Page 1057]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.257


[[Page 1058]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.258


[[Page 1059]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.259


[[Page 1060]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.260


[[Page 1061]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.261


[[Page 1062]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.262


[[Page 1063]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.263


[[Page 1064]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.264

Method 25A--Determination of Total Gaseous Organic Concentration Using a 
                        Flame Ionization Analyzer

1. Applicability and Principle
    1.1  Applicability. This method applies to the measurement of total 
gaseous organic concentration of vapors consisting primarily of alkanes, 
alkenes, and/or arenes (aromatic hydrocarbons). The concentration is 
expressed in terms of propane (or other appropriate organic calibration 
gas) or in terms of carbon.
    1.2  Principle. A gas sample is extracted from the source through a 
heated sample line, if necessary, and glass fiber filter to a flame 
ionization analyzer (FIA). Results are reported as volume concentration 
equivalents of the calibration gas or as carbon equivalents.

2. Definitions

    2.1  Measurement System. The total equipment required for the 
determination of the gas concentration. The system consists of the 
following major subsystems:
    2.1.1  Sample Interface. That portion of the system that is used for 
one or more of the following: sample acquisition, sample transportation, 
sample conditioning, or protection of the analyzer from the effects of 
the stack effluent.
    2.1.2  Organic Analyzer. That portion of the system that senses 
organic concentration and generates an output proportional to the gas 
concentration.
    2.2  Span Value. The upper limit of a gas concentration measurement 
range that is specified for affected source categories in the applicable 
part of the regulations. The span

[[Page 1065]]

value is established in the applicable regulation and is usually 1.5 to 
2.5 times the applicable emission limit. If no span value is provided, 
use a span value equivalent to 1.5 to 2.5 times the expected 
concentration. For convenience, the span value should correspond to 100 
percent of the recorder scale.
    2.3  Calibration Gas. A known concentration of a gas in an 
appropriate diluent gas.
    2.4  Zero Drift. The difference in the measurement system response 
to a zero level calibration gas before and after a stated period of 
operation during which no unscheduled maintenance, repair, or adjustment 
took place.
    2.5  Calibration Drift. The difference in the measurement system 
response to a mid-level calibration gas before and after a stated period 
of operation during which no unscheduled maintenance, repair or 
adjustment took place.
    2.6  Response Time. The time interval from a step change in 
pollutant concentration at the inlet to the emission measurement system 
to the time at which 95 percent of the corresponding final value is 
reached as displayed on the recorder.
    2.7  Calibration Error. The difference between the gas concentration 
indicated by the measurement system and the known concentration of the 
calibration gas.

3. Apparatus

    A schematic of an acceptable measurement system is shown in Figure 
25A-1. The essential components of the measurement system are described 
below:
[GRAPHIC] [TIFF OMITTED] TC01JN92.265

    3.1  Organic Concentration Analyzer. A flame ionization analyzer 
(FIA) capable of meeting or exceeding the specifications in this method.
    3.2  Sample Probe. Stainless steel, or equivalent, three-hole rake 
type. Sample holes shall be 4 mm in diameter or smaller and located at 
16.7, 50, and 83.3 percent of the equivalent stack diameter. 
Alternatively, a single opening probe may be used so that a gas sample 
is collected from the centrally located 10 percent area of the stack 
cross-section.
    3.3  Sample Line. Stainless steel or Teflon* tubing to transport the 
sample gas to the analyzer. The sample line should be heated, if 
necessary, to prevent condensation in the line.
---------------------------------------------------------------------------

    * Mention of trade names or specific products does not 
constitute endorsement by the Environmental Protection Agency.
---------------------------------------------------------------------------

    3.4  Calibration Valve Assembly. A three-way valve assembly to 
direct the zero and calibration gases to the analyzers is recommended. 
Other methods, such as quick-connect lines, to route calibration gas to 
the analyzers are applicable.

[[Page 1066]]

    3.5  Particulate Filter. An in-stack or an out-of-stack glass fiber 
filter is recommended if exhaust gas particulate loading is significant. 
An out-of-stack filter should be heated to prevent any condensation.
    3.6  Recorder. A strip-chart recorder, analog computer, or digital 
recorder for recording measurement data. The minimum data recording 
requirement is one measurement value per minute. Note: This method is 
often applied in highly explosive areas. Caution and care should be 
exercised in choice of equipment and installation.

4. Calibration and Other Gases

    Gases used for calibrations, fuel, and combustion air (if required) 
are contained in compressed gas cylinders. Preparation of calibration 
gases shall be done according to the procedure in Protocol No. 1, listed 
in Citation 2 of Bibliography. Additionally, the manufacturer of the 
cylinder should provide a recommended shelf life for each calibration 
gas cylinder over which the concentration does not change more than 
plus-minus2 percent from the certified value. For calibration 
gas values not generally available (i.e., organics between 1 and 10 
percent by volume), alternative methods for preparing calibration gas 
mixtures, such as dilution systems, may be used with prior approval of 
the Administrator.
    Calibration gases usually consist of propane in air or nitrogen and 
are determined in terms of the span value. Organic compounds other than 
propane can be used following the above guidelines and making the 
appropriate corrections for response factor.
    4.1  Fuel. A 40 percent H2/60 percent He or 40 percent 
H2/60 percent N2 gas mixture is recommended to 
avoid an oxygen synergism effect that reportedly occurs when oxygen 
concentration varies significantly from a mean value.
    4.2  Zero Gas. High purity air with less than 0.1 parts per million 
by volume (ppmv) of organic material (propane or carbon equivalent) or 
less than 0.1 percent of the span value, whichever is greater.
    4.3  Low-level Calibration Gas. An organic calibration gas with a 
concentration equivalent to 25 to 35 percent of the applicable span 
value.
    4.4  Mid-level Calibration Gas. An organic calibration gas with a 
concentration equivalent to 45 to 55 percent of the applicable span 
value.
    4.5  High-level Calibration Gas. An organic calibration gas with a 
concentration equivalent to 80 to 90 percent of the applicable span 
value.

5. Measurement System Performance Specifications

    5.1  Zero Drift. Less than plus-minus3 percent of the 
span value.
    5.2  Calibration Drift. Less than plus-minus3 percent of 
span value.
    5.3  Calibration Error. Less than plus-minus5 percent of 
the calibration gas value.

6. Pretest Preparations

    6.1  Selection of Sampling Site. The location of the sampling site 
is generally specified by the applicable regulation or purpose of the 
test; i.e., exhaust stack, inlet line, etc. The sample port shall be 
located at least 1.5 meters or 2 equivalent diameters upstream of the 
gas discharge to the atmosphere.
    6.2  Location of Sample Probe. Install the sample probe so that the 
probe is centrally located in the stack, pipe, or duct and is sealed 
tightly at the stack port connection.
    6.3  Measurement System Preparation. Prior to the emission test, 
assemble the measurement system following the manufacturer's written 
instructions in preparing the sample interface and the organic analyzer. 
Make the system operable.
    FIA equipment can be calibrated for almost any range of total 
organics concentrations. For high concentrations of organics (>1.0 
percent by volume as propane) modifications to most commonly available 
analyzers are necessary. One accepted method of equipment modification 
is to decrease the size of the sample to the analyzer through the use of 
a smaller diameter sample capillary. Direct and continuous measurement 
of organic concentration is a necessary consideration when determining 
any modification design.
    6.4  Calibration Error Test. Immediately prior to the test series, 
(within 2 hours of the start of the test) introduce zero gas and high-
level calibration gas at the calibration valve assembly. Adjust the 
analyzer output to the appropriate levels, if necessary. Calculate the 
predicted response for the low-level and mid-level gases based on a 
linear response line between the zero and high-level responses. Then 
introduce low-level and mid-level calibration gases successively to the 
measurement system. Record the analyzer responses for low-level and mid-
level calibration gases and determine the differences between the 
measurement system responses and the predicted responses. These 
differences must be less than 5 percent of the respective calibration 
gas value. If not, the measurement system is not acceptable and must be 
replaced or repaired prior to testing. No adjustments to the measurement 
system shall be conducted after the calibration and before the drift 
check (Section 7.3). If adjustments are necessary before the completion 
of the test series, perform the drift checks prior to the required 
adjustments and repeat the calibration following the adjustments. If 
multiple electronic ranges are to be used, each additional range must be 
checked with a mid-level calibration gas to verify the multiplication 
factor.
    6.5  Response Time Test. Introduce zero gas into the measurement 
system at the

[[Page 1067]]

calibration valve assembly. When the system output has stabilized, 
switch quickly to the high-level calibration gas. Record the time from 
the concentration change to the measurement system response equivalent 
to 95 percent of the step change. Repeat the test three times and 
average the results.

7. Emission Measurement Test Procedure

    7.1  Organic Measurement. Begin sampling at the start of the test 
period, recording time and any required process information as 
appropriate. In particular, note on the recording chart periods of 
process interruption or cyclic operation.
    7.2  Drift Determination. Immediately following the completion of 
the test period and hourly during the test period, reintroduce the zero 
and mid-level calibration gases, one at a time, to the measurement 
system at the calibration valve assembly. (Make no adjustments to the 
measurement system until after both the zero and calibration drift 
checks are made.) Record the analyzer response. If the drift values 
exceed the specified limits, invalidate the test results preceding the 
check and repeat the test following corrections to the measurement 
system. Alternatively, recalibrate the test measurement system as in 
Section 6.4 and report the results using both sets of calibration data 
(i.e., data determined prior to the test period and data determined 
following the test period).

8. Organic Concentration Calculations

    Determine the average organic concentration in terms of ppmv as 
propane or other calibration gas. The average shall be determined by the 
integration of the output recording over the period specified in the 
applicable regulation.
    If results are required in terms of ppmv as carbon, adjust measured 
concentrations using Equation 25A-1.

           Cc=K Cmeas                    Eq. 25A-1

Where:
Cc=Organic concentration as carbon, ppmv.
Cmeas=Organic concentration as measured, ppmv.
K=Carbon equivalent correction factor,
    K=2 for ethane.
    K=3 for propane.
    K=4 for butane.
    K=Appropriate response factor for other organic calibration gases.

9. Bibliography

    1.  Measurement of Volatile Organic Compounds--Guideline Series. 
U.S. Environmental Protection Agency. Research Triangle Park, NC. 
Publication No. EPA-450/2-78-041. June 1978. p. 46-54.
    2.  Traceability Protocol for Establishing True Concentrations of 
Gases Used for Calibration and Audits of Continuous Source Emission 
Monitors (Protocol No. 1). U.S. Environmental Protection Agency, 
Environmental Monitoring and Support Laboratory. Research Triangle Park, 
NC. June 1978.
    3.  Gasoline Vapor Emission Laboratory Evaluation--Part 2. U.S. 
Environmental Protection Agency, Office of Air Quality Planning and 
Standards. Research Triangle Park, NC. EMB Report No. 75-GAS-6. August 
1975.

Method 25B--Determination of Total Gaseous Organic Concentration Using a 
                     Nondispersive Infrared Analyzer

1. Applicability and Principle

    1.1  Applicability. This method applies to the measurement of total 
gaseous organic concentration of vapors consisting primarily of alkanes. 
(Other organic materials may be measured using the general procedure in 
this method, the appropriate calibration gas, and an analyzer set to the 
appropriate absorption band.) The concentration is expressed in terms of 
propane (or other appropriate organic calibration gas) or in terms of 
carbon.
    1.2  Principle. A gas sample is extracted from the source through a 
heated sample line, if necessary, and glass fiber filter to a 
nondispersive infrared analyzer (NDIR). Results are reported as volume 
concentration equivalents of the calibration gas or as carbon 
equivalents.

2. Definitions

    The terms and definitions are the same as for Method 25A.

3. Apparatus

    The apparatus is the same as for Method 25A with the exception of 
the following:
    3.1  Organic Concentration Analyzer. A nondispersive infrared 
analyzer designed to measure alkane organics and capable of meeting or 
exceeding the specifications in this method.

4. Calibration Gases

    The calibration gases are the same as required for Method 25A, 
Section 4. No fuel gas is required for an NDIR.

5. Measurement System Performance Specifications

    5.1  Zero Drift. Less than 3 percent of the span value.
    5.2  Calibration Drift. Less than 3 percent of the span 
value.
    5.3  Calibration Error. Less than 5 percent of the 
calibration gas value.

6. Pretest Preparations

    6.1  Selection of Sampling Site. Same as in Method 25A, Section 6.1.
    6.2  Location of Sample Probe. Same as in Method 25A, Section 6.2.
    6.3  Measurement System Preparation. Prior to the emission test, 
assemble the measurement system following the manufacturer's written 
instructions in preparing the sample interface and the organic analyzer. 
Make the system operable.

[[Page 1068]]

    6.4  Calibration Error Test. Same as in Method 25A, Section 6.4.
    6.5  Response Time Test Procedure. Same as in Method 25A, Section 
6.5.

7. Emission Measurement Test Procedure

    Proceed with the emission measurement immediately upon satisfactory 
completion of the calibration.
    7.1  Organic Measurement. Same as in Method 25A, Section 7.1.
    7.2  Drift Determination. Same as in Method 25A, Section 7.2.

8. Organic Concentration Calculations

    The calculations are the same as in Method 25A, Section 8.

9. Bibliography

    The bibliography is the same as in Method 25A.

Method 25C--Determination of Nonmethane Organic Compounds (NMOC) in MSW 
                             Landfill Gases

                     1. Applicability and Principle

    1.1  Applicability. This method is applicable to the sampling and 
measurement of nonmethane organic compounds (NMOC) as carbon in MSW 
landfill gases.
    1.2  Principle. A sample probe that has been perforated at one end 
is driven or augered to a depth of 1.0 meter below the bottom of the 
landfill cover. A sample of the landfill gas is extracted with an 
evacuated cylinder. The NMOC content of the gas is determined by 
injecting a portion of the gas into a gas chromatographic column to 
separate the NMOC from carbon monoxide (CO), carbon dioxide 
(CO2), and methane (CH4); the NMOC are oxidized to 
CO2, reduced to CH4, and measured by a flame 
ionization detector (FID). In this manner, the variable response of the 
FID associated with different types of organics is eliminated.

                              2. Apparatus

    2.1  Sample Probe. Stainless steel, with the bottom third 
perforated. The sample probe shall be capped at the bottom and shall 
have a threaded cap with a sampling attachment at the top. The sample 
probe shall be long enough to go through and extend no less than 1.0 
meter below the landfill cover. If the sample probe is to be driven into 
the landfill, the bottom cap should be designed to facilitate driving 
the probe into the landfill.
    2.2  Sampling Train.
    2.2.1  Rotameter with Flow Control Valve. Capable of measuring a 
sample flow rate of 500 ml/min or less (30.53.1 m\3\/min). 
The control valve shall be made of stainless steel.
    2.2.2  Sampling Valve. Stainless steel.
    2.2.3  Pressure Gauge. U-tube mercury manometer, or equivalent, 
capable of measuring pressure to within 1 mm Hg in the range of 0 to 
1,100 mm Hg.
    2.2.4  Sample Tank. Stainless steel or aluminum cylinder, with a 
minimum volume of 4 liters and equipped with a stainless steel sample 
tank valve.
    2.3  Vacuum Pump. Capable of evacuating to an absolute pressure of 
10 mm Hg.
    2.4  Purging Pump. Portable, explosion proof, and suitable for 
sampling NMOC.
    2.5  Pilot Probe Procedure. The following are needed only if the 
tester chooses to use the procedure described in section 4.2.1.
    2.5.1  Pilot Probe. Tubing of sufficient strength to withstand being 
driven into the landfill by a post driver and an outside diameter of at 
least 6.0 millimeters smaller than the sample probe. The pilot probe 
shall be capped on both ends and long enough to go through the landfill 
cover and extend no less than 1.0 meter into the landfill.
    2.5.2  Post Driver and Compressor. Capable of driving the pilot 
probe and the sampling probe into the landfill.
    2.6  Auger Procedure. The following are needed only if the tester 
chooses to use the procedure described in section 4.2.2.
    2.6.1  Auger. Capable of drilling through the landfill cover and to 
a depth of no less than 0.9 meters into the landfill.
    2.6.2  Pea Gravel.
    2.6.3  Bentonite.
    2.7  NMOC Analyzer, Barometer, Thermometer, and Syringes. Same as in 
sections 2.3, 2.4.1, 2.4.2, 2.4.4, respectively, of Method 25.

                               3. Reagents

    3.1  NMOC Analysis. Same as in Method 25, section 3.2.
    3.2  Calibration. Same as in Method 25, section 3.4, except omit 
section 3.4.3.

                              4. Procedure

    4.1  Sample Tank Evacuation and Leak Check. Conduct the sample tank 
evacuation and leak check either in the laboratory or the field. Connect 
the pressure gauge and sampling valve to the sample tank. Evacuate the 
sample tank to 10 mm Hg absolute pressure or less. Close the sampling 
valve, and allow the tank to sit for 60 minutes. The tank is acceptable 
if no change is noted. Include the results of the leak check in the test 
report.
    4.2  Sample Probe Installation. The tester may use the procedure in 
sections 4.2.1 or 4.2.2. CAUTION: Since this method is complex, only 
experienced personnel should perform this test. LFG contains methane, 
therefore explosive mixtures may exist on or near the landfill. It is 
advisable to take appropriate safety precautions when testing landfills, 
such as refraining from smoking and installing explosion-proof 
equipment.

[[Page 1069]]

    4.2.1  Pilot Probe Procedure. Use the post driver to drive the pilot 
probe at least 1.0 meter below the landfill cover. Alternative 
procedures to drive the probe into the landfill may be used subject to 
the approval of the Administrator.
    Remove the pilot probe and drive the sample probe into the hole left 
by the pilot probe. The sample probe shall extend not less than 1.0 
meter below the landfill cover and shall protrude about 0.3 meters above 
the landfill cover. Seal around the sampling probe with bentonite and 
cap the sampling probe with the sampling probe cap.
    4.2.2  Auger Procedure. Use an auger to drill a hole through the 
landfill cover and to at least 1.0 meter below the landfill cover. Place 
the sample probe in the hole and backfill with pea gravel to a level 0.6 
meters from the surface. The sample probe shall protrude at least 0.3 
meters above the landfill cover. Seal the remaining area around the 
probe with bentonite. Allow 24 hours for the landfill gases to 
equilibrate inside the augered probe before sampling.
    4.3  Sample Train Assembly. Prepare the sample by evacuating and 
filling the sample tank with helium three times. After the third 
evacuation, charge the sample tank with helium to a pressure of 
approximately 325 mm Hg. Record the pressure, the ambient temperature, 
and the barometric pressure. Assemble the sampling probe purging system 
as shown in figure 1.
[GRAPHIC] [TIFF OMITTED] TR12MR96.023


    4.4  Sampling Procedure. Open the sampling valve and use the purge 
pump and the flow control valve to evacuate at least two sample probe 
volumes from the system at a flow rate of 500 ml/min or less 
(30.53.1 m\3\/min). Close the sampling valve and replace the 
purge pump with the sample tank apparatus as shown in figure 2. Open the 
sampling valve and the sample tank valves and, using the flow control 
valve, sample at a flow rate of 500 ml/min or less (30.53.1 
m\3\/min) until the sample tank gauge pressure is zero. Disconnect the 
sampling tank apparatus and use the carrier gas bypass valve to 
pressurize the sample cylinder to approximately 1,060 mm Hg absolute 
pressure with helium and record the final pressure. Alternatively, the 
sample tank may be pressurized in the lab. If not analyzing for 
N2, the sample cylinder may be pressurized with zero air. Use 
Method 3C to determine the percent N2 in the sample. Presence 
of N2 indicates infiltration of ambient air into the gas 
sample. The landfill sample is acceptable if the concentration of 
N2 is less than 20 percent.

[[Page 1070]]

[GRAPHIC] [TIFF OMITTED] TR12MR96.024

    4.5  Analysis. The oxidation, reduction, and measurement of NMOC is 
similar to Method 25. Before putting the NMOC analyzer into routine 
operation, conduct an initial performance test. Start the analyzer, and 
perform all the necessary functions to put the analyzer into proper 
working order. Conduct the performance test according to the procedures 
established in section 5.1. Once the performance test has been 
successfully completed and the NMOC calibration response factor has been 
determined, proceed with sample analysis as follows:
    4.5.1  Daily Operations and Calibration Checks. Before and 
immediately after the analysis of each set of samples or on a daily 
basis (whichever occurs first), conduct a calibration test according to 
the procedures established in section 5.2. If the criteria of the daily 
calibration test cannot be met, repeat the NMOC analyzer performance 
test (section 5.1) before proceeding.
    4.5.2  Operating Conditions. Same as in Method 25, section 4.4.2.
    4.5.3  Analysis of Sample Tank. Purge the sample loop with sample, 
and then inject the sample. Under the specified operating conditions, 
the CO2 in the sample will elute in approximately 100 
seconds. As soon as the detector response returns to baseline following 
the CO2 peak, switch the carrier gas flow to backflush, and 
raise the column oven temperature to 195  deg.C as rapidly as possible. 
A rate of 30  deg.C/min has been shown to be adequate. Record the value 
obtained for any measured NMOC. Return the column oven temperature to 85 
 deg.C in preparation for the next analysis. Analyze each sample in 
triplicate, and report the average as Ctm.
    4.6  Audit Samples. Same as in Method 25, section 4.5.
    4.7  Deactivation of Sample Probe Holes. Once sampling has taken 
place, either plug the sampling probes with a cap or remove the probes 
and refill the hole with cover material.

                  5. Calibration and Operational Checks

    Maintain a record of performance of each item.
    5.1  Initial NMOC Analyzer Performance Test. Same as in Method 25, 
section 5.2, except omit the linearity checks for CO2 
standards.
    5.2  NMOC Analyzer Daily Calibration. NMOC response factors, same as 
in Method 25, section 5.3.2.

                             6. Calculations

    All equations are written using absolute pressure; absolute 
pressures are determined by adding the measured barometric pressure to 
the measured gauge of manometer pressure.
    6.1  Nomenclature.

Bw=moisture content in the sample, fraction
CN2=measured N2 concentration, fraction

[[Page 1071]]

Ct=calculated NMOC concentration, ppmv C equivalent
Ctm=measured NMOC concentration, ppmv C equivalent
Pb=barometric pressure, mm Hg
Pti=gas sample tank pressure before sampling, mm Hg absolute
Pt=gas sample tank pressure at completion of sampling, but 
          before pressurizing, mm Hg absolute
Ptf=final gas sample tank pressure after pressurizing, mm Hg 
          absolute
Pw=vapor pressure of H2O (from table 25C-1), mm Hg
Tti=sample tank temperature before sampling,  deg.K
Tt=sample tank temperature at completion of sampling, but 
          before pressuring,  deg.K
Ttf=sample tank temperature after pressurizing,  deg.K
r=total number of analyzer injections of sample tank during analysis 
          (where j=injection number, 1. . .r)
    6.2  Water Correction. Use table 25C-1, the LFG temperature, and 
barometric pressure at the sampling site to calculate Bw.
[GRAPHIC] [TIFF OMITTED] TR12MR96.032


                    Table 25C-1.--Moisture Correction
------------------------------------------------------------------------
                                                                Vapor
                    Temperature,  deg.C                      Pressure of
                                                              H2O, mm Hg
------------------------------------------------------------------------
4..........................................................          6.1
6..........................................................          7.0
8..........................................................          8.0
1..........................................................          9.2
12.........................................................         10.5
14.........................................................         12.0
16.........................................................         13.6
18.........................................................         15.5
20.........................................................         17.5
22.........................................................         19.8
24.........................................................         22.4
26.........................................................         25.2
28.........................................................         28.3
30.........................................................         31.8
------------------------------------------------------------------------

    6.3  NMOC Concentration. Use the following equation to calculate the 
concentration of NMOC for each sample tank.
[GRAPHIC] [TIFF OMITTED] TR12MR96.033

                             7. Bibliography

    1. Salon, Albert E., Samuel Witz, and Robert D. MacPhee. 
Determination of Solvent Vapor Concentrations by Total Combustion 
Analysis: A Comparison of Infrared with Flame Ionization Detectors. 
Paper No. 75-33.2. (Presented at the 68th Annual Meeting of the Air 
Pollution Control Association. Boston, Massachusetts. June 15-20, 1975.) 
p. 14.
    2. Salon, Albert E., William L. Oaks, and Robert D. MacPhee. 
Measuring the Organic Carbon Content of Source Emissions for Air 
Pollution Control. Paper No. 74-190. (Presented at the 67th Annual 
Meeting of the Air Pollution Control Association. Denver, Colorado. June 
9-13, 1974.) p. 25.

Method 25D--Determination of the Volatile Organic Concentration of Waste 
                                 Samples

                              Introduction

    Performance of this method should not be attempted by persons 
unfamiliar with the operation of a flame ionization detector (FID) or an 
electrolytic conductivity detector (ELCD) because knowledge beyond the 
scope of this presentation is required.

                     1. Applicability and Principle

    1.1  Applicability. This method is applicable for determining the 
volatile organic (VO) concentration of a waste sample.
    1.2  Principle. A sample of waste is obtained at a point which is 
most representative of the unexposed waste (where the waste has had 
minimum opportunity to volatilize to the atmosphere). The sample is 
suspended in an organic/aqueous matrix, then heated and purged with 
nitrogen for 30 min in order to separate certain organic compounds. Part 
of the sample is analyzed for carbon concentration, as methane, with an 
FID, and part of the sample is analyzed for chlorine concentration, as 
chloride, with an ELCD. The VO concentration is the sum of the carbon 
and chlorine content of the sample.

                              2. Apparatus

    2.1  Sampling. The following equipment is required:
    2.1.1  Sampling Tube. Flexible Teflon, 0.25 in. ID.
    Note: Mention of trade names or specific products does not 
constitute endorsement by the Environmental Protection Agency.
    2.1.2  Sample Container. Borosilicate glass, 40 mL, and a Teflon 
lined screw cap capable of forming an air tight seal.
    2.1.3  Cooling Coil. Fabricated from 0.25 in. ID 304 stainless steel 
tubing with a thermocouple at the coil outlet.
    2.2  Analysis. The following equipment is required:
    2.2.1  Purging Apparatus. For separating the VO from the waste 
sample. A schematic of the system is shown in Figure 25D-1. The purging 
apparatus consists of the following major components.

[[Page 1072]]

[GRAPHIC] [TIFF OMITTED] TR22AP94.012

    2.2.1.1  Purging Flask. A glass container to hold the sample while 
it is heated and purged with dry nitrogen. The cap of the purging flask 
is equipped with three fittings: one for a purging lance (fitting with 
the #7 Ace-thread), one for the Teflon exit tubing (side fitting, also a 
#7 Ace-thread), and a third (a 50-mm Ace-thread) to attach the base of 
the purging flask as shown in Figure 25D-2. The base of the purging 
flask is a 50-mm ID cylindrical glass tube. One end of the tube is open 
while the other end is sealed. Exact dimensions are shown in Figure 25D-
2.
    2.2.1.2  Purging Lance. Glass tube, 6-mm OD by 30 cm long. The 
purging end of the tube is fitted with a four-arm bubbler with each tip 
drawn to an opening 1 mm in diameter.

    Details and exact dimensions are shown in Figure 25D-2.


[[Page 1073]]


[GRAPHIC] [TIFF OMITTED] TR22AP94.013


[[Page 1074]]


    2.2.1.3  Coalescing Filter. Porous fritted disc incorporated into a 
container with the same dimensions as the purging flask. The details of 
the design are shown in Figure 25D-3.
[GRAPHIC] [TIFF OMITTED] TR22AP94.014

    2.2.1.4  Constant Temperature Chamber. A forced draft oven capable 
of maintaining a uniform temperature around the purging flask and 
coalescing filter of 752  deg.C.
    2.2.1.5  Three-way Valve. Manually operated, stainless steel. To 
introduce calibration gas into system.
    2.2.1.6  Flow Controllers. Two, adjustable. One capable of 
maintaining a purge gas flow

[[Page 1075]]

rate of 6.06 L/min. The other capable of maintaining a 
calibration gas flow rate of 1-100 mL/min.
    2.2.1.7  Rotameter. For monitoring the air flow through the purging 
system (0-10 L/min).
    2.2.1.8  Sample Splitters. Two heated flow restrictors (placed 
inside oven or heated to 12010  deg.C). At a purge rate of 6 
L/min, one will supply a constant flow to the first detector (the rest 
of the flow will be directed to the second sample splitter). The second 
splitter will split the analytical flow between the second detector and 
the flow restrictor. The approximate flow to the FID will be 40 mL/min 
and to the ELCD will be 15 mL/min, but the exact flow must be adjusted 
to be compatible with the individual detector and to meet its linearity 
requirement. The two sample splitters will be connected to each other by 
\1/8\" OD stainless steel tubing.
    2.2.1.9  Flow Restrictor. Stainless steel tubing, \1/8\" OD, 
connecting the second sample splitter to the ice bath. Length is 
determined by the resulting pressure in the purging flask (as measured 
by the pressure gauge). The resulting pressure from the use of the flow 
restrictor shall be 6-7 psiG.
    2.2.1.10  Filter Flask. With one-hole stopper. Used to hold ice 
bath. Excess purge gas is vented through the flask to prevent 
condensation in the flowmeter and to trap volatile organic compounds.
    2.2.1.11  Four-way Valve. Manually operated, stainless steel. Placed 
inside oven, used to bypass purging flask.
    2.2.1.12  On/Off Valves. Two, stainless steel. One heat resistant up 
to 130  deg.C and placed between oven and ELCD. The other a toggle valve 
used to control purge gas flow.
    2.2.1.13  Pressure Gauge. Range 0-40 psi. To monitor pressure in 
purging flask and coalescing filter.
    2.2.1.14  Sample Lines. Teflon, 1/4" OD, used 
inside the oven to carry purge gas to and from purging chamber and to 
and from coalescing filter to four-way valve. Also used to carry sample 
from four-way valve to first sample splitter.
    2.2.1.15  Detector Tubing. Stainless steel, \1/8\" OD, heated to 
12010  deg.C. Used to carry sample gas from each sample 
splitter to a detector. Each piece of tubing must be wrapped with heat 
tape and insulating tape in order to insure that no cold spots exist. 
The tubing leading to the ELCD will also contain a heat-resistant on-off 
valve (Section 2.2.1.12) which shall also be wrapped with heat-tape and 
insulation.
    2.2.2  Volatile Organic Measurement System. Consisting of an FID to 
measure the carbon concentration of the sample and an ELCD to measure 
the chlorine concentration.
    2.2.2.1  FID. A heated FID meeting the following specifications is 
required.
    2.2.2.1.1  Linearity. A linear response (+ 5 percent) over the 
operating range as demonstrated by the procedures established in Section 
5.1.1.
    2.2.2.1.2   Range. A full scale range of 50 pg carbon/sec to 50 
Kg carbon/sec. Signal attenuators shall be available to produce 
a minimum signal response of 10 percent of full scale.
    2.2.2.1.3  Data Recording System. A digital integration system 
compatible with the FID for permanently recording the output of the 
detector. The recorder shall have the capability to start and stop 
integration at points selected by the operator or it shall be capable of 
the ``integration by slices'' technique (this technique involves 
breaking down the chromatogram into smaller increments, integrating the 
area under the curve for each portion, subtracting the background for 
each portion, and then adding all of the areas together for the final 
area count).
    2.2.2.2  ELCD. An ELCD meeting the following specifications is 
required. The ELCD components shall consist of quartz reactor tubing and 
1-propanol as electrolyte. The electrolyte flow through the conductivity 
cell shall be 1 to 2 mL/min.
    Note: A \1/4\-in. ID quartz reactor tube is recommended to reduce 
carbon buildup and the resulting detector maintenance.
    2.2.2.2.1  Linearity. A linear response ( 10 percent) 
over the response range as demonstrated by the procedures in Section 
5.1.2.
    2.2.2.2.2  Range. A full scale range of 5.0 pg/sec to 500 ng/sec 
chloride. Signal attenuators shall be available to produce a minimum 
signal response of 10 percent of full scale.
    2.2.2.2.3  Data Recording System. A digital integration system 
compatible with the output voltage range of the ELCD. The recorder must 
have the capability to start and stop integration at points selected by 
the operator or it shall be capable of performing the ``integration by 
slices'' technique.

                               3. Reagents

    3.1  Sampling.
    3.1.1  Polyethylene Glycol (PEG). Ninety-eight percent pure with an 
average molecular weight of 400. Before using the PEG, remove any 
organic compounds that might be detected as volatile organics by heating 
it to 120  deg.C and purging it with nitrogen at a flow rate of 1 to 2 
L/min for 2 hours. The cleaned PEG must be stored under a 1 to 2 L/min 
nitrogen purge until use. The purge apparatus is shown in Figure 25D-4.


[[Page 1076]]


[GRAPHIC] [TIFF OMITTED] TR22AP94.015

    3.2  Analysis.
    3.2.1  Sample Separation. The following are required for the sample 
purging step.
    3.2.1.1  PEG. Same as Section 3.1.1.
    3.2.1.2  Purge Gas. Zero grade nitrogen (N2), containing 
less than 1 ppm carbon.
    3.2.2  Volatile Organics Measurement. The following are required for 
measuring the VO concentration.
    3.2.2.1  Hydrogen (H2). Zero grade H2, 99.999 
percent pure.
    3.2.2.2  Combustion Gas. Zero grade air or oxygen as required by the 
FID.
    3.2.2.3  Calibration Gas. Pressurized gas cylinder containing 10 
percent propane and 1 percent 1,1-dichloroethylene by volume in 
nitrogen.
    3.2.2.4  Water. Deionized distilled water that conforms to American 
Society for Testing and Materials Specification D 1193-77, Type 3 
(incorporated by reference as specified in Sec. 60.17), is required for 
analysis. At the option of the analyst, the KMnO4 test for 
oxidizable organic matter may be omitted when high concentrations are 
not expected to be present.
    3.2.2.5  1-Propanol. ACS grade or better. Electrolyte Solution. For 
use in the ELCD.

[[Page 1077]]

                              4. Procedure

    4.1  Sampling.
    4.1.1  Sampling Plan Design and Development. Use the procedures in 
chapter nine of the Office of Solid Waste's publication, Test Methods 
for Evaluating Solid Waste, third edition (SW-846), as guidance in 
developing a sampling plan.
    4.1.2  Single Phase or Well-mixed Waste. Well-mixed in the context 
of this method refers to turbulent flow which results in multiple-phase 
waste in effect behaving as single-phase waste due to good mixing.
    4.1.2.1  Install a sampling tap to obtain the sample at a point 
which is most representative of the unexposed waste (where the waste has 
had minimum opportunity to volatilize to the atmosphere). Assemble the 
sampling apparatus as shown in Figure 25D-5.
[GRAPHIC] [TIFF OMITTED] TR22AP94.016

    4.1.2.2  Prepare the sampling containers as follows: Pour 30 mL of 
clean PEG into the container. PEG will reduce but not eliminate the loss 
of organics during sample collection. Weigh the sample container with 
the screw cap, the PEG, and any labels to the nearest 0.01 g and record 
the weight (mst). Store the containers in an ice bath until 1 
h before sampling (PEG will solidify at ice bath temperatures; allow the 
containers to reach room temperature before sampling).
    4.1.2.3  Begin sampling by purging the sample lines and cooling coil 
with at least four volumes of waste. Collect the purged material in a 
separate container and dispose of it properly.
    4.1.2.4  After purging, stop the sample flow and direct the sampling 
tube to a preweighed sample container, prepared as described in Section 
4.1.2.2. Keep the tip of the tube below the surface of the PEG during 
sampling to minimize contact with the atmosphere. Sample at a flow rate 
such that the temperature of the waste is less than 10  deg.C. Fill the 
sample container and immediately cap it (within 5 seconds) so that a 
minimum headspace exists in the container. Store immediately in a cooler 
and cover with ice.
    4.1.3  Multiple-phase Waste. Collect a 10 g sample of each phase of 
waste generated using the procedures described in Section 4.1.2 or 
4.1.5. Each phase of the waste shall be analyzed as a separate sample. 
Calculate the weighted average VO concentration of the waste using 
Equation 13 (Section 6.14).
    4.1.4  Solid waste. Add approximately 10 g of the solid waste to a 
container prepared in the manner described in Section 4.1.2.2, 
minimizing headspace. Cap and chill immediately.
    4.1.5  Alternative to Tap Installation. If tap installation is 
impractical or impossible, fill a large, clean, empty container by 
submerging the container into the waste below the surface of the waste. 
Immediately fill a container prepared in the manner described in Section 
4.1.2.2 with approximately 10 g of the waste collected in the large 
container. Minimize headspace, cap and chill immediately.
    4.1.6  Alternative sampling techniques may be used upon the approval 
of the Administrator.
    4.2  Sample Recovery.
    4.2.1  Assemble the purging apparatus as shown in Figures 25D-1 and 
25D-2. The oven

[[Page 1078]]

shall be heated to 75  2  deg.C. The sampling lines leading 
from the oven to the detectors shall be heated to 120  10 
deg.C with no cold spots. The flame ionization detector shall be 
operated with a heated block. Adjust the purging lance so that it 
reaches the bottom of the chamber.
    4.2.2  Remove the sample container from the cooler, and wipe the 
exterior of the container to remove any extraneous ice, water, or other 
debris. Reweigh the sample container to the nearest 0.01 g, and record 
the weight (msf). Pour the contents of the sample container 
into the purging flask, rinse the sample container three times with a 
total of 20 mL of PEG (since the sample container originally held 30 mL 
of PEG, the total volume of PEG added to the purging flask will be 50 
mL), transferring the rinsings to the purging flask after each rinse. 
Cap purging flask between rinses. The total volume of PEG in the purging 
flask shall be 50 mL. Add 50 mL of water to the purging flask.
    4.3  Sample Analysis.
    4.3.1  Turn on the constant temperature chamber and allow the 
temperature to equilibrate at 75  2  deg.C. Turn the four-
way valve so that the purge gas bypasses the purging flask, the purge 
gas flowing through the coalescing filter and to the detectors (standby 
mode). Turn on the purge gas. Allow both the FID and the ELCD to warm up 
until a stable baseline is achieved on each detector. Pack the filter 
flask with ice. Replace ice after each run and dispose of the waste 
water properly. When the temperature of the oven reaches 752 
 deg.C, start both integrators and record baseline. After 1 min, turn 
the four-way valve so that the purge gas flows through the purging 
flask, to the coalescing filter and to the sample splitters (purge 
mode). Continue recording the response of the FID and the ELCD. Monitor 
the readings of the pressure gauge and the rotameter. If the readings 
fall below established setpoints, stop the purging, determine the source 
of the leak, and resolve the problem before resuming. Leaks detected 
during a sampling period invalidate that sample.
    4.3.2  As the purging continues, monitor the output of the detectors 
to make certain that the analysis is proceeding correctly and that the 
results are being properly recorded. Every 10 minutes read and record 
the purge flow rate, the pressure and the chamber temperature. Continue 
the purging for 30 minutes.
    4.3.3  For each detector output, integrate over the entire area of 
the peak starting at 1 minute and continuing until the end of the run. 
Subtract the established baseline area from the peak area. Record the 
corrected area of the peak. See Figure 25D-6 for an example integration.
    4.4  Water Blank. A water blank shall be analyzed for each batch of 
cleaned PEG prepared. Transfer about 60 mL of water into the purging 
flask. Add 50 mL of the cleaned PEG to the purging flask. Treat the 
blank as described in Sections 4.2 and 4.3, excluding Section 4.2.2. 
Calculate the concentration of carbon and chlorine in the blank sample 
(assume 10 g of waste as the mass). A VO concentration equivalent to 
10 percent of the applicable standard may be subtracted from 
the measured VO concentration of the waste samples. Include all blank 
results and documentation in the test report.

                 5. Operational Checks and Calibration.

    Maintain a record of performance of each item.
    5.1  Initial Performance Check of Purging System.

[[Page 1079]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.266

Before placing the system in operation, after a shutdown of greater than 
six months, after any major modifications, and at least once per month 
during continuous operation, conduct the linearity checks described in 
Sections 5.1.1 and 5.1.2. Install calibration gas at the three-way 
calibration gas valve. See Figure 25D-1.
    5.1.1  Linearity Check Procedure. Using the calibration standard 
described in Section 3.2.2.3 and by varying the injection time, it is 
possible to calibrate at multiple concentration levels. Use Equation 3 
to calculate three sets of calibration gas flow rates and run times 
needed to introduce a total methane mass (mco) of 1, 5, and 
10 mg into the system (low, medium and high FID calibration, 
respectively). Use Equation 4 to calculate three sets of calibration gas 
flow rates and run times needed to introduce a total chloride mass 
(mch) of 1, 5, and 10 mg into the system (low, medium and 
high ELCD calibration, respectively). With the system operating in 
standby mode, allow the FID and the ELCD to establish a stable baseline. 
Set the secondary pressure regulator of the calibration gas cylinder to 
the same pressure as the purge gas cylinder and set the proper flow rate 
with the calibration flow controller (see Figure 25D-1). The calibration 
gas flow rate can be measured with a flowmeter attached to the vent 
position of the calibration gas valve. Set the four-way bypass valve to 
standby position so that the calibration gas flows through the 
coalescing filter only. Inject the calibration gas by turning the 
calibration gas valve from vent position to inject position. Continue 
the calibration gas flow for the appropriate period of time before 
switching the calibration valve to vent position. Continue recording the 
response of the FID and the ELCD for 5 min after switching off 
calibration gas flow. Make triplicate injections of all six levels of 
calibration.
    5.1.2  Linearity Criteria. Calculate the average response factor 
(Equations 5 and 6) and the relative standard deviation (RSD) (Equation 
10) at each level of the calibration curve for both detectors. Calculate 
the overall mean of the three response factor averages for each 
detector. The FID linearity is acceptable if each response factor is 
within 5 percent of the overall mean and if the RSD for each set of 
triplicate injections is less than 5 percent. The ELCD linearity is 
acceptable if each response factor is within 10 percent of the overall 
mean and if the RSD for each set of triplicate injections is less than 
10 percent. Record the overall mean value of the response factors for 
the FID and the ELCD. If the calibration for either the FID or the ELCD 
does not meet the criteria, correct the detector/system problem and 
repeat Sections 5.1.1 and 5.1.2.

[[Page 1080]]

    5.2  Daily Calibrations.
    5.2.1  Daily Linearity Check. Follow the procedures outlined in 
Section 5.1.1 to analyze the medium level calibration for both the FID 
and the ELCD in duplicate at the start of the day. Calculate the 
response factors and the RSDs for each detector. For the FID, the 
calibration is acceptable if the average response factor is within 5 
percent of the overall mean response factor (Section 5.1.2) and if the 
RSD for the duplicate injection is less than 5 percent. For the ELCD, 
the calibration is acceptable if the average response factor is within 
10 percent of the overall mean response factor (Section 5.1.2) and if 
the RSD for the duplicate injection is less than 10 percent. If the 
calibration for either the FID or the ELCD does not meet the criteria, 
correct the detector/system problem and repeat Sections 5.1.1 and 5.1.2.
    5.2.2  Calibration Range Check.
    5.2.2.1  If the waste concentration for either detector falls below 
the range of calibration for that detector, use the procedure outlined 
in Section 5.1.1 to choose 2 calibration points that bracket the new 
target concentration. Analyze each of these points in triplicate (as 
outlined in Section 5.1.1) and use the criteria in Section 5.1.2 to 
determine the linearity of the detector in this ``mini-calibration'' 
range.
    5.2.2.2  After the initial linearity check of the minicalibration 
curve, it is only necessary to test one of the points in duplicate for 
the daily calibration check (in addition to the points specified in 
Section 5.2.1). The average daily mini-calibration point should fit the 
linearity criteria specified in Section 5.2.1. If the calibration for 
either the FID or the ELCD does not meet the criteria, correct the 
detector/system problem and repeat the calibration procedure mentioned 
in the first paragraph of Section 5.2.2. A mini-calibration curve for 
waste concentrations above the calibration curve for either detector is 
optional.
    5.3  Analytical Balance. Calibrate against standard weights.
    5.4  Audit Procedure. Concurrently analyze the audit sample and a 
set of compliance samples in the same manner to evaluate the technique 
of the analyst and the standards preparation. The same analyst, 
analytical reagents, and analytical system shall be used both for 
compliance samples and the EPA audit sample. If this condition is met, 
auditing of subsequent compliance analyses for the same enforcement 
agency within 30 days is not required. An audit sample set may not be 
used to validate different sets of compliance samples under the 
jurisdiction of different enforcement agencies, unless prior 
arrangements are made with both enforcement agencies.
    5.5  Audit Samples. Audit Sample Availability. Audit samples will be 
supplied only to enforcement agencies for compliance tests. The 
availability of audit samples may be determined by writing: Source Test 
Audit Coordinator (MD-77B), Quality Assurance Division, Atmospheric 
Research and Exposure Assessment Laboratory, U.S. Environmental 
Protection Agency, Research Triangle Park, NC 27711 or by calling the 
Source Test Audit Coordinator (STAC) at (919) 541-7834. The request for 
the audit sample must be made at least 30 days prior to the scheduled 
compliance sample analysis. If audit samples are not available, follow 
the quality control sample procedures in Section 5.7.
    5.6  Audit Results. Calculate the audit sample concentration 
according to the calculation procedure described in the audit 
instructions included with the audit sample. Fill in the audit sample 
concentration and the analyst's name on the audit response form included 
with the audit instructions. Send one copy to the EPA Regional Office or 
the appropriate enforcement agency and a second copy to the STAC. The 
EPA Regional office or the appropriate enforcement agency will report 
the results of the audit to the laboratory being audited. Include this 
response with the results of the compliance samples in relevant reports 
to the EPA Regional Office or the appropriate enforcement agency.
    5.7  Quality Control Samples. If audit samples are not available, 
prepare and analyze the two types of quality control samples (QCS) 
listed in Sections 5.7.1 and 5.7.2. Before placing the system in 
operation, after a shutdown of greater than six months, and after any 
major modifications, analyze each QCS in triplicate. For each detector, 
calculate the percent recovery by dividing measured concentration by 
theoretical concentration and multiplying by 100. Determine the mean 
percent recovery for each detector for each QCS triplicate analysis. The 
RSD for any triplicate analysis shall be 10 percent. For QCS 
1 (methylene chloride), the percent recovery shall be 90 
percent for carbon as methane, and 55 percent for chlorine as 
chloride. For QCS 2 (1,3-dichloro-2-propanol), the percent recovery 
shall be 15 percent for carbon as methane, and 6 
percent for chlorine as chloride. If the analytical system does not meet 
the above-mentioned criteria for both detectors, check the system 
parameters (temperature, system pressure, purge rate, etc.), correct the 
problem, and repeat the triplicate analysis of each QCS.
    5.7.1  QCS 1, Methylene Chloride. Prepare a stock solution by 
weighing, to the nearest 0.1 mg, 55 L of HPLC grade methylene 
chloride in a tared 5 mL volumetric flask. Record the weight in 
milligrams, dilute to 5 mL with cleaned PEG, and inject 100 L 
of the stock solution into a sample prepared as a water blank (50 mL of 
cleaned PEG and 60 mL of water in the purging flask). Analyze

[[Page 1081]]

the QCS according to the procedures described in Sections 4.2 and 4.3, 
excluding Section 4.2.2. To calculate the theoretical carbon 
concentration (in mg) in QCS 1, multiply mg of methylene chloride in the 
stock solution by 3.777  x  10 -3. To calculate the 
theoretical chlorine concentration (in mg) in QCS 1, multiply mg of 
methylene chloride in the stock solution by 1.670  x  10 -2.
    5.7.2  QCS 2, 1,3-dichloro-2-propanol. Prepare a stock solution by 
weighing, to the nearest 0.1 mg, 60 L of high purity grade 1,3-
dichloro-2-propanol in a tared 5 mL volumetric flask. Record the weight 
in milligrams, dilute to 5 mL with cleaned PEG, and inject 100 
L of the stock solution into a sample prepared as a water blank 
(50 mL of cleaned PEG and 60 mL of water in the purging flask).
    Analyze the QCS according to the procedures described in Sections 
4.2 and 4.3, excluding Section 4.2.2. To calculate the theoretical 
carbon concentration (in mg) in QCS 2, multiply mg of 1,3-dichloro-2-
propanol in the stock solution by 7.461  x  10 -3. To 
calculate the theoretical chlorine concentration (in mg) in QCS 2, 
multiply mg of 1,3-dichloro-2-propanol in the stock solution by 1.099 
x  10 -2.
    5.7.3  Routine QCS Analysis. For each set of compliance samples (in 
this context, set is per facility, per compliance test), analyze one QCS 
1 and one QCS 2 sample. The percent recovery for each sample for each 
detector shall be  13 percent of the mean recovery 
established for the most recent set of QCS triplicate analysis (Section 
5.7). If the sample does not meet this criteria, check the system 
components and analyze another QCS 1 and 2 until a single set of QCS 
meet the  13 percent criteria.

                             6. Calculations

    6.1  Nomenclature.

Ab=Area under the water blank response curve, counts.
Ac=Area under the calibration response curve, counts.
As=Area under the sample response curve, counts.
C=Concentration of volatile organics in the sample, ppmw.
Cc=Concentration of carbon, as methane, in the calibration 
          gas, mg/L.
Chh=Concentration of chloride in the calibration gas, mg/L.
Cj=VO concentration of phase j, ppmw.
DRt=Average daily response factor of the FID, mg 
          CH4 counts.
DRth=Average daily response factor of the ELCD, mg 
          Cl- counts.
Fj= Weight fraction of phase j present in the waste.
mco=Mass of carbon, as methane, in a calibration run, mg.
mch=Mass of chloride in a calibration run, mg.
ms=Mass of the waste sample, g.
msc=Mass of carbon, as methane, in the sample, mg.
msf=Mass of sample container and waste sample, g.
msh=Mass of chloride in the sample, mg.
mst=Mass of sample container prior to sampling, g.
mvo=Mass of volatile organics in the sample, mg.
n=Total number of phases present in the waste.
Pp=Percent propane in calibration gas (L/L).
Pvc=Percent 1,1-dichloroethylene in calibration gas (L/L).
Qc=Flow rate of calibration gas, L/min.
tc=Length of time standard gas is delivered to the analyzer, 
          min.
W=Weighted average VO concentration, ppmw.
    6.2  Concentration of Carbon, as Methane, in the Calibration Gas.

Cc=(19.681  x  Pp) + (13.121  x  Pvc)    
          Eq. 1
    6.3  Concentration of Chloride in the Calibration Gas.

Ch=28.998  x  Pvc    Eq. 2
    6.4  Mass of Carbon, as Methane, in a Calibration Run.

mco=Cc  x  Qc  x  tc    Eq. 
          3
    6.5  Mass of Chloride in a Calibration Run.

mch=Cch  x  Qc  x  tc    Eq. 
          4
    6.6  FID Response Factor, mg/counts.

Rt=mco/Ac    Eq. 5
    6.7  ELCD Response Factor, mg/counts.

Rth=mch/Ac    Eq. 6
    6.8  Mass of Carbon in the Sample.

msc=DRt (As-Ab)    Eq. 7
    6.9  Mass of Chloride in the Sample.

msh=DRth (As-Ab)    Eq. 8
    6.10  Mass of Volatile Organics in the Sample.

mvo=msc + msh    Eq. 9
    6.11  Relative Standard Deviation.
    [GRAPHIC] [TIFF OMITTED] TR22AP94.019
    

[[Page 1082]]


    6.12  Mass of Sample.

ms=msf-mst    Eq. 11
    6.13  Concentration of Volatile Organics in Waste.

C=(mvo x 1000)/ms    Eq. 12
    6.14  Weighted Average VO Concentration of Multi-phase Waste.
    [GRAPHIC] [TIFF OMITTED] TR22AP94.020
    
Method 25E--Determination of Vapor Phase Organic Concentration in Waste 
                                 Samples

                              Introduction

    Performance of this method should not be attempted by persons 
unfamiliar with the operation of a flame ionization detector (FID) nor 
by those who are unfamiliar with source sampling because knowledge 
beyond the scope of this presentation is required.

                     1. Applicability and Principle

    1.1  Applicability. This method is applicable for determining the 
vapor pressure of waste samples which represent waste which is or will 
be managed in tanks.
    1.2  Principle. The headspace vapor of the sample is analyzed for 
carbon content by a headspace analyzer, which uses an FID.

                            2. Interferences

    2.1  The analyst shall select the operating parameters best suited 
to the requirements for a particular analysis. The analyst shall produce 
confirming data through an adequate supplemental analytical technique 
and have the data available for review by the Administrator.

                              3. Apparatus

    3.1  Sampling. The following equipment is required:
    3.1.1  Sample Containers. Vials, glass, with butyl rubber septa, 
Perkin-Elmer Corporation Numbers 0105-0129 (glass vials), B001-0728 
(gray butyl rubber septum, plug style), 0105-0131 (butyl rubber septa), 
or equivalent. The seal must be made from butyl rubber. Silicone rubber 
seals are not acceptable.
    3.1.2  Vial Sealer. Perkin-Elmer Number 105-0106, or equivalent.
    3.1.3  Gas-Tight Syringe. Perkin-Elmer Number 00230117, or 
equivalent.
    3.1.4  The following equipment is required for sampling.
    3.1.4.1  Tap.
    3.1.4.2  Tubing. Telfon, 0.25-in. ID. Note: Mention of trade names 
or specific products does not constitute endorsement by the 
Environmental Protection Agency.
    3.1.4.3  Cooling Coil. Stainless steel (304), 0.25 in.-ID, equipped 
with a thermocouple at the coil outlet.
    3.2  Analysis. The following equipment is required:
    3.2.1  Balanced Pressure Headspace Sampler. Perkin-Elmer HS-6, HS-
100, or equivalent, equipped with a glass bead column instead of a 
chromatographic column.
    3.2.2  FID. An FID meeting the following specifications is required:
    3.2.2.1  Linearity. A linear response (5 percent) over 
the operating range as demonstrated by the procedures established in 
Section 6.1.2.
    3.2.2.2  Range. A full scale range of 1 to 10,000 ppm 
CH4. Signal attenuators shall be available to produce a 
minimum signal response of 10 percent of full scale.
    3.2.3  Data Recording System. Analog strip chart recorder or digital 
integration system compatible with the FID for permanently recording the 
output of the detector.
    3.2.4  Thermometer. Capable of reading temperatures in the range of 
30 deg. to 60  deg.C with an accuracy of 0.1  deg.C.

                               4. Reagents

    4.1  Analysis. The following items are required for analysis:
    4.1.1  Hydrogen (H2). Zero grade.
    4.1.2  Carrier Gas. Zero grade nitrogen, containing less than 1 ppm 
carbon (C) and less than 1 ppm carbon dioxide.
    4.1.3  Combustion Gas. Zero grade air or oxygen as required by the 
FID.
    4.2  Calibration and Linearity Check.
    4.2.1  Stock Cylinder Gas Standard. 100 percent propane. The 
manufacturer shall:
    (a) Certify the gas composition to be accurate to 3 
percent or better (see Section 4.2.1.1);
    (b) Recommend a maximum shelf life over which the gas concentration 
does not change by greater than 5 percent from the certified 
value; and
    (c) Affix the date of gas cylinder preparation, certified propane 
concentration, and recommended maximum shelf life to the cylinder before 
shipment to the buyer.

[[Page 1083]]

    4.2.1.1 Cylinder Standards Certification. The manufacturer shall 
certify the concentration of the calibration gas in the cylinder by (a) 
directly analyzing the cylinder and (b) calibrating his analytical 
procedure on the day of cylinder analysis. To calibrate his analytical 
procedure, the manufacturer shall use, as a minimum, a three-point 
calibration curve.
    4.2.1.2  Verification of Manufacturer's Calibration Standards. 
Before using, the manufacturer shall verify each calibration standard by 
(a) comparing it to gas mixtures prepared in accordance with the 
procedure described in Section 7.1 of Method 106 of part 61, appendix B, 
or by (b) calibrating it against Standard Reference Materials (SRM's) 
prepared by the National Bureau of Standards, if such SRM's are 
available. The agreement between the initially determined concentration 
value and the verification concentration value shall be within 
5 percent. The manufacturer must reverify all calibration 
standards on a time interval consistent with the shelf life of the 
cylinder standards sold.

                              5. Procedure

    5.1  Sampling.
    5.1.1  Install a sampling tap to obtain the sample at a point which 
is most representative of the unexposed waste (where the waste has had 
minimum opportunity to volatilize to the atmosphere). Assemble the 
sampling apparatus as shown in Figure 25E-1.
[GRAPHIC] [TIFF OMITTED] TR06DE94.000

    5.1.2  Begin sampling by purging the sample lines and cooling coil 
with at least four volumes of waste. Collect the purged material in a 
separate container and dispose of it properly.
    5.1.3  After purging, stop the sample flow and transfer the Teflon 
sampling tube to a sample container. Sample at a flow rate such that the 
temperature of the waste is 10  deg.C (50  deg.F). Fill the sample 
container halfway (5 percent) and cap it within 5 seconds. 
Store immediately in a cooler and cover with ice.
    5.1.4  Alternative sampling techniques may be used upon the approval 
of the Administrator.
    5.2  Analysis.
    5.2.1  Allow one hour for the headspace vials to equilibrate at the 
temperature specified in the regulation. Allow the FID to warm up until 
a stable baseline is achieved on the detector.
    5.2.2  Check the calibration of the FID daily using the procedures 
in Section 6.1.2.
    5.2.3  Follow the manufacturer's recommended procedures for the 
normal operation of the headspace sampler and FID.
    5.2.4  Use the procedures in Sections 7.4 and 7.5 to calculate the 
vapor phase organic vapor pressure in the samples.
    5.2.5  Monitor the output of the detector to make certain that the 
results are being properly recorded.

[[Page 1084]]

                  6. Operational Checks and Calibration

    Maintain a record of performance of each item.
    6.1  Use the procedures in Section 6.1.1 to calibrate the headspace 
analyzer and FID and check for linearity before the system is first 
placed in operation, after any shutdown longer than 6 months, and after 
any modification of the system.
    6.1.1  Calibration and Linearity. Use the procedures in Section 
6.2.1 of Method 18 of Part 60, Appendix A, to prepare the standards and 
calibrate the flowmeters, using propane as the standard gas. Fill the 
calibration standard vials halfway (5 percent) with 
deionized water. Purge and fill the airspace with calibration standard. 
Prepare a minimum of three calibration standards in triplicate at 
concentrations that will bracket the applicable cutoff. For a cutoff of 
5.2 kPa, prepare nominal concentrations of 30,000, 50,000, and 70,000 
ppm as propane. For a cutoff of 27.6 kPa, prepare nominal concentrations 
of 200,000, 300,000, and 400,000 ppm as propane.
    6.1.1.1  Use the procedures in Section 5.2.3 to measure the FID 
response of each standard. Use a linear regression analysis to calculate 
the values for the slope (k) and the y-intercept (b). Use the procedures 
in Sections 7.2 and 7.3 to test the calibration and the linearity.
    6.1.2  Daily FID Calibration Check. Check the calibration at the 
beginning and at the end of the daily runs by using the following 
procedures. Prepare two calibration standards at the nominal cutoff 
concentration using the procedures in Section 6.1.1. Place one at the 
beginning and one at the end of the daily run. Measure the FID response 
of the daily calibration standard and use the values for k and b from 
the most recent calibration to calculate the concentration of the daily 
standard. Use an equation similar to 25E-2 to calculate the percent 
difference between the daily standard and Cs. If the 
difference is within 5 percent, then the previous values for k and b may 
be used. Otherwise, use the procedures in Section 6.1.1 to recalibrate 
the FID.

                             7. Calculations

    7.1  Nomenclature.

A = Measurement of the area under the response curve, counts.
b = y-intercept of the linear regression line.
Ca = Measured vapor phase organic concentration of sample, 
          ppm as propane.
Cma = Average measured vapor phase organic concentration of 
          standard, ppm as propane.
Cm = Measured vapor phase organic concentration of standard, 
          ppm as propane.
Cs = Calculated standard concentration, ppm as propane.
k = Slope of the linear regression line.
Pbar = Atmospheric pressure at analysis conditions, mm Hg 
          (in. Hg).
P* = Organic vapor pressure in the sample, kPa (psi).
 = 1.333 X 10-7 kPa/[(mm Hg)(ppm)], (4.91 X 
          10-7 psi/[(in. Hg)(ppm)])
    7.2  Linearity. Use the following equation to calculate the measured 
standard concentration for each standard vial.

Cm = k A + b    Eq. 25E-1
    7.2.1  Calculate the average measured standard concentration 
(Cma) for each set of triplicate standards and use the 
following equation to calculate the percent difference (PD) between 
Cma and Cs.
[GRAPHIC] [TIFF OMITTED] TR06DE94.001

    The instrument linearity is acceptable if the percent difference is 
within five for each standard.
    7.3  Relative Standard Deviation (RSD). Use the following equation 
to calculate the RSD for each triplicate set of standards.
[GRAPHIC] [TIFF OMITTED] TR06DE94.002

    The calibration is acceptable if the RSD is within five for each 
standard concentration.
    7.4  Concentration of organics in the headspace. Use the following 
equation to calculate the concentration of vapor phase organics in each 
sample.

Ca = k A + b    Eq. 25E-4
    7.5  Vapor Pressure of Organics in the Headspace Sample. Use the 
following equation to calculate the vapor pressure of organics in the 
sample.

P* =  Pbar Ca    Eq. 25E-5

Method 26--Determination of Hydrogen Chloride Emissions From Stationary 
                                 Sources

    1. Applicability, Principle, Interferences, Precision, Bias, and 
                                Stability

    1.1  Applicability. This method is applicable for determining 
emissions of hydrogen halides (HX) [hydrogen chloride (HCl), hydrogen 
bromide (HBr), and hydrogen fluoride (HF)] and halogens (X2) 
[chlorine (Cl2) and bromine (Br2)] from stationary 
sources. Sources, such as those controlled by wet scrubbers, that emit 
acid particulate matter must be sampled using Method 26A.
    Note: Mention of trade names or specific products does not 
constitute endorsement by the Environmental Protection Agency.]
    1.2  Principle. An integrated sample is extracted from the source 
and passed through

[[Page 1085]]

a prepurged heated probe and filter into dilute sulfuric acid and dilute 
sodium hydroxide solutions which collect the gaseous hydrogen halides 
and halogens, respectively. The filter collects other particulate matter 
including halide salts. The hydrogen halides are solubilized in the 
acidic solution and form chloride (Cl-), bromide 
(Br-), and fluoride (F-) ions. The halogens have a 
very low solubility in the acidic solution and pass through to the 
alkaline solution where they are hydrolyzed to form a proton 
(H=), the halide ion, and the hypohalous acid (HClO or HBrO). 
Sodium thiosulfate is added in excess to the alkaline solution to assure 
reaction with the hypohalous acid to form a second halide ion such that 
2 halide ions are formed for each molecule of halogen gas. The halide 
ions in the separate solutions are measured by ion chromatography (IC).
    1.3  Interferences. Volatile materials, such as chlorine dioxide 
(ClO2) and ammonium chloride (NH4Cl), which 
produce halide ions upon dissolution during sampling are potential 
interferents. Interferents for the halide measurements are the halogen 
gases which disproportionate to a hydrogen halide and a hydrohalous acid 
upon dissolution in water. However, the use of acidic rather than 
neutral or basic solutions for collection of the hydrogen halides 
greatly reduces the dissolution of any halogens passing through this 
solution. The simultaneous presence of HBr and CL2 may cause 
a positive bias in the HCL result with a corresponding negative bias in 
the Cl2 result as well as affecting the HBr/Br2 
split. High concentrations of nitrogen oxides (NOX) may 
produce sufficient nitrate (NO3-) to interfere with 
measurements of very low Br- levels.
    1.4  Precision and Bias. The within-laboratory relative standard 
deviations are 6.2 and 3.2 percent at HCl concentrations of 3.9 and 15.3 
ppm, respectively. The method does not exhibit a bias to Cl2 
when sampling at concentrations less than 50 ppm.
    1.5  Sample Stability. The collected Cl- samples can be 
stored for up to 4 weeks.
    1.6  Detection Limit. The analytical detection limit for 
Cl- is 0.1 g/ml. Detection limits for the other 
analyses should be similar.

                              2. Apparatus

    2.1  Sampling. The sampling train is shown in Figure 26-1, and 
component parts are discussed below.
    2.1.1  Probe. Borsilicate glass, approximately 3/8-in. (9-mm) I.D. 
with a heating system to prevent moisture condensation. A Teflon-glass 
filter in a mat configuration shall be installed behind the probe to 
remove particulate matter from the gas stream (see section 2.1.5). A 
glass wool plug should not be used to remove particulate matter since a 
negative bias in the data could result.
    2.1.2  Three-Way Stopcock. A borosilicate glass three-way stopcock 
with a heating system to prevent moisturecondensation. The heated 
stopcock should connect to the outlet of the heated filter and the inlet 
of the first impinger. The heating system shall be capable of preventing 
condensation up to the inlet of the first impinger. Silicone grease may 
be used, if necessary, to prevent leakage.

[[Page 1086]]

[GRAPHIC] [TIFF OMITTED] TR22AP94.011

    2.1.3  Impingers. Four 30-ml midget impingers with leak-free glass 
connectors. Silicone grease may be used, if necessary, to prevent 
leakage. For sampling at high moisture sources or for sampling times 
greater than 1 hour, a midget impinger with a shortened stem (such that 
the gas sample does not bubble through the collected condensate) should 
be used in front of the first impinger.
    2.1.4  Drying Tube or Impinger. Tube or impinger, of Mae West 
design, filled with 6- to 16-mesh indicating type silica gel, or 
equivalent, to dry the gas sample and to protect the dry gas meter and 
pump. If the silica gel has been used previously, dry at 175  deg.C (350 
 deg.F) for 2 hours. New silica gel may be used as received. 
Alternatively, other types of desiccants (equivalent or better) may be 
used.
    2.1.5  Filter. When the stack gas temperature exceeds 210  deg.C 
(410  deg.F) and the HCl concentration is greater than 20 ppm, a quartz-
fiber filter may be used.
    2.1.6  Filter Holder and Support. The filter holder should be made 
of Teflon or quartz. The filter support shall be made of Teflon. All-
Teflon filter holders and supports are available from Savillex Corp., 
5325 Hwy 101, Minnetonka, MN 55345.
    2.1.7  Sample Line. Leak-free, with compatible fittings to connect 
the last impinger to the needle valve.
    2.1.8  Rate Meter. Rotameter, or equivalent, capable of measuring 
flow rate to within 2 percent of the selected flow rate of 2 liters/min.
    2.1.9  Purge Pump, Purge Line, Drying Tube, Needle Valve, and Rate 
Meter. Pump capable of purging the sampling probe at 2 liters/min, with 
drying tube, filled with silica gel or equivalent, to protect pump, and 
a rate meter capable of measuring 0 to 5 liters/min.
    2.1.10  Stopcock Grease, Valve, Pump, Volume Meter, Barometer, and 
Vacuum Gauge. Same as in Method 6, Sections 2.1.4, 2.1.7, 2.1.8, 2.1.10, 
2.1.11, and 2.1.12.
    2.1.11  Temperature Measuring Devices. Temperature measuring device 
to monitor the temperature of the probe and a thermometer or other 
temperature measuring device to monitor the temperature of the sampling 
system from the outlet of the probe to the inlet of the first impinger.
    2.1.12  Ice Water Bath. To minimize loss of absorbing solution.
    2.2  Sample Recovery.
    2.2.1  Wash Bottles. Polyethylene or glass, 500-ml or larger, two.
    2.2.2   Storage Bottles. 100- or 250-ml, high-density polyethylene 
bottles with Teflon screw cap liners to store impinger 
samples.
    2.3  Sample Preparation and Analysis. The materials required for 
volumetric dilution and chromatographic analysis of samples are 
described below.
    2.3.1  Volumetric Flasks. Class A, 100-ml size.
    2.3.2  Volumetric Pipets. Class A, assortment. To dilute samples 
into the calibration range of the instrument.

[[Page 1087]]

    2.3.3  Ion Chromatograph. Suppressed or nonsuppressed, with a 
conductivity detector and electronic integrator operating in the peak 
area mode. Other detectors, strip chart recorders, and peak height 
measurements may be used.

                               3. Reagents

    Unless otherwise indicated, all reagents must conform to the 
specifications established by the Committee on Analytical Reagents of 
the American Chemical Society (ACS reagent grade). When such 
specifications are not available, the best available grade shall be 
used.
    3.1  Sampling.
    3.1.1  Water. Deionized, distilled water that conforms to ASTM 
Specification D 1193-77, Type 3.
    3.1.2  Acidic Absorbing solution, 0.1 N Sulfuric Acid 
(H2SO4). To prepare 100 ml of the absorbing 
solution for the front impinger pair, slowly add 0.28 ml of concentrated 
H2SO4 to about 90 ml of water while stirring, and 
adjust the final volume to 100 ml using additional water. Shake well to 
mix the solution.
    3.1.3  Alkaline Absorbing Solution, 0.1 N Sodium Hydroxide (NaOH). 
To prepare 100 ml of the scrubber solution for the back pair of 
impingers, dissolve 0.40 g of solid NaOH in about 90 ml of water, and 
adjust the final solution volume to 100 ml using additional water. Shake 
well to mix the solution.
    3.1.4  Sodium Thiosulfate 
(Na2S2O3.5H2O)
    3.2  Sample Preparation and Analysis.
    3.2.1  Water. Same as in Section 3.1.1.
    3.2.2  Absorbing Solution Blanks. A separate blank solution of each 
absorbing reagent should be prepared for analysis with the field 
samples. Dilute 30 ml of each absorbing solution to approximately the 
same final volume as the field samples using the blank sample of rinse 
water.
    3.2.3  Halide Salt Stock Standard Solutions. Prepare concentrated 
stock solutions from reagent grade sodium chloride (NaCl), sodium 
bromide (NaBr), and sodium fluoride (NaF). Each must be dried at 110 
deg.C for two or more hours and then cooled to room temperature in a 
desiccator immediately before weighing. Accurately weigh 1.6 to 1.7 g of 
the dried NaCl to within 0.1 mg, dissolve in water, and dilute to 1 
liter. Calculate the exact Cl- concentration using Equation 
26-1.

  g Cl-/ml = g of NaCl  x  10\3\  x  35.453/58.44

      Eq. 26-1
    In a similar manner, accurately weigh and solubilize 1.2 to 1.3 g of 
dried NaBr and 2.2 to 2.3 g of NaF to make 1-liter solutions. Use 
Equations 26-2 and 26-3 to calculate the Br- and 
F- concentrations.

  g Br-/ml = g of NaBr  x  10\3\  x  79.904/102.90
      Eq. 26-2

  g F-/ml = g of NaF  x  10\3\  x  18.998/41.99
      Eq. 26-3

Alternately, solutions containing a nominal certified concentration of 
1000 mg/l NaCl are commercially available as convenient stock solutions 
from which standards can be made by appropriate volumetric dilution. 
Refrigerate the stock standard solutions and store no longer than one 
month.
    3.2.4  Chromatographic Eluent. Effective eluents for nonsuppressed 
IC using a resin- or silica-based weak ion exchange column are a 4 mM 
potassium hydrogen phthalate solution, adjusted to pH 4.0 using a 
saturated sodium borate solution, and a 4 mM 4-hydroxy benzoate 
solution, adjusted to pH 8.6 using 1 N NaOH. An effective eluent for 
suppressed ion chromatography is a solution containing 3 mM sodium 
bicarbonate and 2.4 mM sodium carbonate. Other dilute solutions buffered 
to a similar pH and containing no interfering ions may be used. When 
using suppressed ion chromatography, if the ``water dip'' resulting from 
sample injection interferes with the chloride peak, use a 2 mM NaOH/2.4 
mM sodium bicarbonate eluent.

                              4. Procedure

    4.1  Sampling.
    4.1.1  Preparation of Collection Train. Prepare the sampling train 
as follows: Pour 15 ml of the acidic absorbing solution into each one of 
the first pair of impingers, and 15 ml of the alkaline absorbing 
solution into each one of the second pair of impingers. Connect the 
impingers in series with the knockout impinger first, if used, followed 
by the two impingers containing the acidic absorbing solution and the 
two impingers containing the alkaline absorbing solution. Place a fresh 
charge of silica gel, or equivalent, in the drying tube or impinger at 
the end of the impinger train.
    4.1.2  Adjust the probe temperature and the temperature of the 
filter and the stopcock, i.e., the heated area in Figure 26-1 to a 
temperature sufficient to prevent water condensation. This temperature 
should be at least 20 deg.C above the source temperature, but not 
greater than 120  deg.C. The temperature should be monitored throughout 
a sampling run to ensure that the desired temperature is maintained.
    4.1.3  Leak-Check Procedure. A leak-check prior to the sampling run 
is optional; however, a leak-check after the sampling run is mandatory. 
The leak-check procedure is as follows: Temporarily attach a suitable 
(e.g., 0-40 cc/min) rotameter to the outlet of the dry gas meter and 
place a vacuum gauge at or near the probe inlet. Plug the probe inlet, 
pull a vacuum of at least 250 mm Hg (10 in. Hg), and note the flow rate 
as indicated by the rotameter. A leakage rate not in excess of 2 percent 
of the average sampling rate is acceptable. (NOTE: Carefully release the 
probe inlet plug before turning off the

[[Page 1088]]

pump.) It is suggested (not mandatory) that the pump be leak-checked 
separately, either prior to or after the sampling run. If done prior to 
the sampling run, the pump leak-check shall precede the leak-check of 
the sampling train described immediately above; if done after the 
sampling run, the pump leak-check shall follow the train leak-check. To 
leak-check the pump, proceed as follows: Disconnect the drying tube from 
the probe-impinger assembly. Place a vacuum gauge at the inlet to either 
the drying tube or pump, pull a vacuum of 250 mm (10 in.) Hg, plug or 
pinch off the outlet of the flowmeter, and then turn off the pump. The 
vacuum should remain stable for at least 30 sec. Other leak-check 
procedures may be used, subject to the approval of the Administrator, 
U.S. Environmental Protection Agency.
    4.1.4  Purge Procedure. Immediately before sampling, connect the 
purge line to the stopcock, and turn the stopcock to permit the purge 
pump to purge the probe (see Figure 1A of Figure 26-1). Turn on the 
purge pump, and adjust the purge rate to 2 liters/min. Purge for at 
least 5 minutes before sampling.
    4.1.5  Sample Collection. Turn on the sampling pump, pull a slight 
vacuum of approximately 25 mm Hg (1 in. Hg) on the impinger train, and 
turn the stopcock to permit stack gas to be pulled through the impinger 
train (see Figure 1C of Figure 26-1). Adjust the sampling rate to 2 
liters/min, as indicated by the rate meter, and maintain this rate to 
within 10 percent during the entire sampling run. Take readings of the 
dry gas meter volume and temperature, rate meter, and vacuum gauge at 
least once every 5 minutes during the run. A sampling time of 1 hour is 
recommended. Shorter sampling times may introduce a significant negative 
bias in the HCl concentration. At the conclusion of the sampling run, 
remove the train from the stack, cool, and perform a leak-check as 
described in section 4.1.2.
    4.2  Sample Recovery. Disconnect the impingers after sampling. 
Quantitatively transfer the contents of the acid impingers and the 
knockout impinger, if used, to a leak-free storage bottle. Add the water 
rinses of each of these impingers and connecting glassware to the 
storage bottle. Repeat this procedure for the alkaline impingers and 
connecting glassware using a separate storage bottle. Add 25 mg sodium 
thiosulfate per the product of ppm of halogen anticipated to be in the 
stack gas times the dscm stack gas sampled. [Note: This amount of sodium 
thiosulfate includes a safety factor of approximately 5 to assure 
complete reaction with the hypohalous acid to form a second 
Cl- ion in the alkaline solution.] Save portions of the 
absorbing reagents (0.1 N H2SO4 and 0.1 N NaOH) 
equivalent to the amount used in the sampling train (these are the 
absorbing solution blanks described in Section 3.2.2); dilute to the 
approximate volume of the corresponding samples using rinse water 
directly from the wash bottle being used. Add the same amount of sodium 
thiosulfate solution to the 0.1 N NaOH absorbing solution blank. Also, 
save a portion of the rinse water used to rinse the sampling train. 
Place each in a separate, prelabeled storage bottle. The sample storage 
bottles should be sealed, shaken to mix, and labeled. Mark the fluid 
level.
    4.3  Sample Preparation for Analysis. Note the liquid levels in the 
storage bottles and confirm on the analysis sheet whether or not leakage 
occurred during transport. If a noticeable leakage has occurred, either 
void the sample or use methods, subject to the approval of the 
Administrator, to correct the final results. Quantitatively transfer the 
sample solutions to 100-ml volumetric flasks, and dilute to 100 ml with 
water.
    4.4  Sample Analysis.
    4.4.1  The IC conditions will depend upon analytical column type and 
whether suppressed or nonsuppressed IC is used. An example chromatogram 
from a nonsuppressed system using a 150-mm Hamilton PRP-X100 anion 
column, a 2 ml/min flow rate of 4 mM 4-hydroxy benzoate solution 
adjusted to a pH of 8.6 using 1 N NaOH, a 50-l sample loop, and 
a conductivity detector set on 1.0 S full scale is shown in 
Figure 26-2.
    4.4.2  Before sample analysis, establish a stable baseline. Next, 
inject a sample of water, and determine if any Cl-, 
Br-, or F- appears in the chromatogram. If any of 
these ions are present, repeat the load/injection procedure until they 
are no longer present. Analysis of the acid and alkaline absorbing 
solution samples requires separate standard calibration curves; prepare 
each according to Section 5.2. Ensure adequate baseline separation of 
the analyses.
    4.4.3  Between injections of the appropriate series of calibration 
standards, inject in duplicate the reagent blanks, quality control 
sample, and the field samples. Measure the areas or heights of the 
Cl-, Br-, and F- peaks. Use the mean 
response of the duplicate injections to determine the concentrations of 
the field samples and reagent blanks using the linear calibration curve. 
The values from duplicate injections should agree within 5 percent of 
their mean for the analysis to be valid. Dilute any sample and the blank 
with equal volumes of water if the concentration exceeds that of the 
highest standard.
    4.5  Audit Analysis. An audit sample must be analyzed, subject to 
availability.

[[Page 1089]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.267

                             5. Calibration

    5.1  Dry Gas Metering System. Thermometers, Rate Meter, and 
Barometer. Same as in Method 6, sections 5.1, 5.2, 5.3, and 5.4.
    5.2  Ion Chromatograph. To prepare the calibration standards, dilute 
given amounts (1.0 ml or greater) of the stock standard solutions to 
convenient volumes, using 0.1 N H2SO2 or 0.1 N 
NaOH, as appropriate. Prepare at least four calibration standards for 
each absorbing reagent containing the appropriate stock solutions such 
that they are within the linear range of the field samples. Using one of 
the standards in each series, ensure adequate baseline separation for 
the peaks of interest. Inject the appropriate series of calibration 
standards, starting with the lowest concentration standard first both 
before and after injection of the quality control check sample, reagent 
blanks, and field samples. This allows compensation for any instrument 
drift occurring during sample analysis.
    Determine the peak areas, or heights, for the standards and plot 
individual values versus halide ion concentrations in g/ml. 
Draw a smooth curve through the points. Use linear regression to 
calculate a formula describing the resulting linear curve.

                          6. Quality Assurance

    6.1  Applicability. When the method is used to analyze samples to 
demonstrate compliance with a source emission regulation, a set of two 
audit samples must be analyzed.
    6.2  Audit Procedure. The audit sample are chloride solutions. 
Concurrently analyze the two audit samples and a set of compliance 
samples in the same manner to evaluate the technique of the analyst and 
the standards preparation. The same analyst, analytical reagents, and 
analytical system shall be used both for compliance samples and the EPA 
audit samples. If this condition is met, auditing the subsequent 
compliance analyses for the same enforcement agency within 30 days is 
not required. An audit sample set may not be used to validate different 
sets of compliance samples under the jurisdiction of different 
enforcement agencies, unless prior arrangements are made with both 
enforcement agencies.
    6.3  Audit Sample Availability. The audit samples may be obtained by 
writing or calling the EPA Regional Office or the appropriate 
enforcement agency. The request for the audit samples must be made at 
least 30 days prior to the scheduled compliance sample analyses.
    6.4  Audit Results.
    6.4.1  Calculate the concentrations in mg/dscm using the specified 
sample volume in the audit instructions.
    Note: Indication of acceptable results may be obtained immediately 
by reporting the audit results in mg/dscm and compliance results in 
total g HCl/sample to the responsible enforcement agency. 
Include the results of both audit samples, their identification numbers, 
and the analyst's name with the results of the compliance determination 
samples in appropriate reports to the EPA Regional Office or the 
appropriate enforcement agency. Include this information with subsequent 
analyses for the same enforcement agency during the 30-day period.

[[Page 1090]]

    6.4.2  The concentrations of the audit samples obtained by the 
analyst shall agree within 10 percent of the actual concentrations. If 
the 10 percent specification is not met, reanalyze the compliance 
samples and audit samples, and include initial and reanalysis values in 
the test report.
    6.4.3  Failure to meet the 10 percent specification may require 
retests until the audit problems are resolved. However, if the audit 
results do not affect the compliance or noncompliance status of the 
affected facility, the Administrator may waive the reanalysis 
requirement, further audits, or retests and accept the results of the 
compliance test. While steps are being taken to resolve audit analysis 
problems, the Administrator may also choose to use the data to determine 
the compliance or noncompliance status of the affected facility.

                             7. Calculations

    Retain at least one extra decimal figure beyond those contained in 
the available data in intermediate calculations, and round off only the 
final answer appropriately.
    7.1  Sample Volume, Dry Basis, Corrected to Standard Conditions. 
Calculate the sample volume using Eq. 6-1 of Method 6.
    7.2  Total g HCl, HBr, or HF Per Sample.
    mHX=K Vs 
(SX--BX-)    Eq. 26-4

where:

    BX-=Mass concentration of applicable absorbing 
solution blank, g halide ion (Cl-, Br-, 
F-)/ml, not to exceed 1 g/ml which is 10 times the 
published analytical detection limit of 0.1 g/ml.
    mHX=Mass of HCl, HBr, or HF in sample, g.
    SX-=Analysis of sample, g halide ion 
(Cl-, Br-, F-)/ml.
    Vs=Volume of filtered and diluted sample, ml.
    KHCl=1.028 (g HCl/g-mole)/(g 
Cl-/g-mole).
    KHBr=1.013 (g HBr/g-mole)/(g 
Br-/g-mole).
    KHF=1.053 (g HF/g-mole)/(g 
F-/g-mole).
    7.3  Total g Cl2 or Br2 Per Sample.

    mX2=Vs 
(SX--BX-)    Eq. 26-5

where:

    mX2=Mass of Cl2 or Br2 in sample, 
g.

    7.4  Concentration of Hydrogen Halide or Halogen in Flue Gas.
    C=K mHX,X2/Vm(std)    Eq. 26-6

where:

    C=Concentration of hydrogen halide (HX) or halogen (X2), 
dry basis, mg/dscm.
    Vm(std)= Dry gas volume measured by the dry gas meter, 
corrected to standard conditions, dscm.
    K=10-3 mg/g.

                             8. Bibliography

    1. Steinsberger, S.C. and J.H. Margeson, ``Laboratory and Field 
Evaluation of a Methodology for Determination of Hydrogen Chloride 
Emissions form Municipal and Hazardous Waste Incinerators,'' U.S. 
Environmental Protection Agency, Office of Research and Development, 
Report No. 600/3-89/064, April 1989. Available from the National 
Technical Information Service, Springfield, VA 22161 as PB89220586/AS.
    2. State of California, Air Resources Board. Method 421. 
``Determination of Hydrochloric Acid Emissions from Stationary 
Sources.'' March 18, 1987.
    3. Cheney, J.L. and C.R. Fortune. Improvements in the Methodology 
for Measuring Hydrochloric Acid in Combustion Source Emissions. J. 
Environ. Sci. Health. A19(3): 337-350. 1984.
    4. Stern, D. A., B. M. Myatt, J. F. Lachowski, and K. T. McGregor. 
Speciation of Halogen and Hydrogen Halide Compounds in Gaseous 
Emissions. In: Incineration and Treatment of Hazardous Waste: 
Proceedings of the 9th Annual Research Symposium, Cincinnati, Ohio, May 
2-4, 1983. Publication No. 600/9-84-015. July 1984. Available from 
National Technical Information Service, Springfield, VA 22161 as PB84-
234525.
    5. Holm, R. D. and S. A. Barksdale. Analysis of Anions in Combustion 
Products. In: Ion Chromatographic Analysis of Environmental Pollutants. 
E. Sawicki, J. D. Mulik, and E. Wittgenstein (eds.). Ann Arbor, 
Michigan, Ann Arbor Science Publishers. 1978. pp. 99-110.

Method 26A--Determination of Hydrogen Halide and Halogen Emissions from 
                  Stationary Sources--Isokinetic Method

    1. Applicability, Principle, Interferences, Precision, Bias, and 
                                Stability

    1.1  Applicability. This method is applicable for determining 
emissions of hydrogen halides (HX) [hydrogen chloride (HCl), hydrogen 
bromide (HBr), and hydrogen fluoride (HF)] and halogens (X2) 
[chlorine (Cl2) and bromine (Br2)] from stationary 
sources. This method collects the emission sample isokinetically and is 
therefore particularly suited for sampling at sources, such as those 
controlled by wet scrubbers, emitting acid particulate matter (e.g., 
hydrogen halides dissolved in water droplets). [Note: Mention of trade 
names or specific products does not constitute endorsement by the 
Environmental Protection Agency.]
    1.2  Principle. Gaseous and particulate pollutants are withdrawn 
isokinetically from the source and collected in an optional cyclone, on 
a filter, and in absorbing solutions. The cyclone collects any liquid 
droplets and is not necessary if the source emissions do not contain 
them; however, it is preferable

[[Page 1091]]

to include the cyclone in the sampling train to protect the filter from 
any moisture present. The filter collects other particulate matter 
including halide salts. Acidic and alkaline absorbing solutions collect 
the gaseous hydrogen halides and halogens, respectively. Following 
sampling of emissions containing liquid droplets, any halides/halogens 
dissolved in the liquid in the cyclone and on the filter are vaporized 
to gas and collected in the impingers by pulling conditioned ambient air 
through the sampling train. The hydrogen halides are solubilized in the 
acidic solution and form chloride (Cl-), bromide 
(Br-), and fluoride (F-) ions. The halogens have a 
very low solubility in the acidic solution and pass through to the 
alkaline solution where they are hydrolyzed to form a proton 
(H=), the halide ion, and the hypohalous acid (HClO or HBrO). 
Sodium thiosulfate is added to the alkaline solution to assure reaction 
with the hypohalous acid to form a second halide ion such that 2 halide 
ions are formed for each molecule of halogen gas. The halide ions in the 
separate solutions are measured by ion chromatography (IC). If desired, 
the particulate matter recovered from the filter and the probe is 
analyzed following the procedures in Method 5. [Note: If the tester 
intends to use this sampling arrangement to sample concurrently for 
particulate matter, the alternative TeflonR probe liner, 
cyclone, and filter holder should not be used. The TeflonR 
filter support must be used. The tester must also meet the probe and 
filter temperature requirements of both sampling trains.]
    1.3  Interferences. Volatile materials, such as chlorine dioxide 
(ClO2) and ammonium chloride (NH4Cl), which 
produce halide ions upon dissolution during sampling are potential 
interferents. Interferents for the halide measurements are the halogen 
gases which disproportionate to a hydrogen halide and an hypohalous acid 
upon dissolution in water. The use of acidic rather than neutral or 
basic solutions for collection of the hydrogen halides greatly reduces 
the dissolution of any halogens passing through this solution. The 
simultaneous presence of both HBr and C12 may cause a 
positive bias in the HCl result with a corresponding negative bias in 
the C12 result as well as affecting the HBr/Br2 
split. High concentrations of nitrogen oxides (NOx) may 
produce sufficient nitrate (NO3-) to interfere with 
measurements of very low Br- levels.
    1.4  Precision and Bias. The method has a possible measurable 
negative bias below 20 ppm HCl perhaps due to reaction with small 
amounts of moisture in the probe and filter. Similar bias for the other 
hydrogen halides is possible.
    1.5  Sample Stability. The collected Cl- samples can be 
stored for up to 4 weeks for analysis for HCl and C12.
    1.6  Detection Limit. The in-stack detection limit for HCl is 
approximately 0.02g per liter of stack gas; the analytical 
detection limit for HCl is 0.1 1g/ml. Detection limits for the 
other analyses should be similar.

                              2. Apparatus

    2.1  Sampling. The sampling train is shown in Figure 26A-1; the 
apparatus is similar to the Method 5 train where noted as follows:

[[Page 1092]]

[GRAPHIC] [TIFF OMITTED] TR22AP94.018

    2.1.1  Probe Nozzle. Borosilicate or quartz glass; constructed and 
calibrated according to Method 5, Sections 2.1.1 and 5.1, and coupled to 
the probe liner using a Teflon  union; a stainless steel nut 
is recommended for this union. When the stack temperature exceeds 210 
deg.C (410  deg.F), a one-piece glass nozzle/liner assembly must be 
used.
    2.1.2  Probe Liner. Same as Method 5, Section 2.1.2, except metal 
liners shall not be used. Water-cooling of the stainless steel sheath is 
recommended at temperatures exceeding 500  deg.C. Teflon  
may be used in limited applications where the minimum stack temperature 
exceeds 120  deg.C (250  deg.F) but never exceeds the temperature where 
Teflon is estimated to become unstable (approximately 210 
deg.C).
    2.1.3  Pitot Tube, Differential Pressure Gauge, Filter Heating 
System, Metering System, Barometer, Gas Density Determination Equipment. 
Same as Method 5, Sections 2.1.3, 2.1.4, 2.1.6, 2.1.8, 2.1.9, and 
2.1.10.
    2.1.4  Cyclone (Optional). Glass or Teflon . Use of the 
cyclone is required only when the sample gas stream is saturated with 
moisture; however, the cyclone is recommended to protect the filter from 
any moisture droplets present.
    2.1.5  Filter Holder. Borosilicate or quartz glass, or 
Teflon filter holder, with a Teflon filter 
support and a sealing gasket. The sealing gasket shall be constructed of 
Teflon or equivalent materials. The holder design shall 
provide a positive seal against leakage at any point along the filter 
circumference. The holder shall be attached immediately to the outlet of 
the cyclone.
    2.1.6  Impinger Train. The following system shall be used to 
determine the stack gas moisture content and to collect the hydrogen 
halides and halogens: five or six impingers connected in series with 
leak-free ground glass fittings or any similar leak-free 
noncontaminating fittings. The first impinger shown in Figure 26A-1 
(knockout or condensate impinger) is optional and is recommended as a 
water knockout trap for use under high moisture conditions. If used, 
this impinger should be constructed as described below for the alkaline 
impingers, but with a shortened stem, and should contain 50 ml of 0.1 N 
H2SO4. The following two impingers (acid impingers 
which each contain 100 ml of 0.1 N H2SO4) shall be 
of the Greenburg-Smith design with the standard tip (Method 5, Section 
2.1.7). The next two impingers (alkaline impingers which each contain 
100 ml of 0.1 N

[[Page 1093]]

NaOH) and the last impinger (containing silica gel) shall be of the 
modified Greenburg-Smith design (Method 5, Section 2.1.7). The 
condensate, acid, and alkaline impingers shall contain known quantities 
of the appropriate absorbing reagents. The last impinger shall contain a 
known weight of silica gel or equivalent desiccant. Teflon 
impingers are an acceptable alternative.
    2.1.7  Ambient Air Conditioning Tube (Optional). Tube tightly packed 
with approximately 150 g of fresh 8 to 20 mesh sodium hydroxide-coated 
silica, or equivalent, (Ascarite II has been found suitable) 
to dry and remove acid gases from the ambient air used to remove 
moisture from the filter and cyclone, when the cyclone is used. The 
inlet and outlet ends of the tube should be packed with at least 1-cm 
thickness of glass wool or filter material suitable to prevent escape of 
fines. Fit one end with flexible tubing, etc. to allow connection to 
probe nozzle following the test run.
    2.2  Sample Recovery. The following items are needed:
    2.2.1  Probe-Liner and Probe-Nozzle Brushes, Wash Bottles,
    Glass Sample Storage Containers, Petri Dishes, Graduated Cylinder or 
Balance, and Rubber Policeman. Same as Method 5, Sections 2.2.1, 2.2.2, 
2.2.3, 2.2.4, 2.2.5, and 2.2.7.
    2.2.2  Plastic Storage Containers. Screw-cap polypropylene or 
polyethylene containers to store silica gel. High-density polyethylene 
bottles with Teflon screw cap liners to store impinger reagents, 1-
liter.
    2.2.3  Funnels. Glass or high-density polyethylene, to aid in sample 
recovery.
    2.3  Analysis. For analysis, the following equipment is needed:
    2.3.1  Volumetric Flasks. Class A, various sizes.
    2.3.2  Volumetric Pipettes. Class A, assortment, to dilute samples 
to calibration range of the ion chromatograph (IC).
    2.3.3  Ion Chromatograph. Suppressed or nonsuppressed, with a 
conductivity detector and electronic integrator operating in the peak 
area mode. Other detectors, a strip chart recorder, and peak heights may 
be used.

                               3. Reagents

    Unless otherwise indicated, all reagents must conform to the 
specifications of the Committee on Analytical Reagents of the American 
Chemical Society (ACS reagent grade). When such specifications are not 
available, the best available grade shall be used.
    3.1  Sampling.
    3.1.1  Water. Deionized, distilled water that conforms to American 
Society of Testing and Materials (ASTM) Specification D 1193-77, Type 3 
(incorporated by reference as specified in Sec. 60.17).
    3.1.2  Acidic Absorbing Solution, 0.1 N Sulfuric Acid 
(H2SO4). To prepare 1 L, slowly add 2.80 ml of 
concentrated H2SO4 to about 900 ml of water while 
stirring, and adjust the final volume to 1 L using additional water. 
Shake well to mix the solution.
    3.1.3  Alkaline Absorbing Solution, 0.1 N Sodium Hydroxide (NaOH). 
To prepare 1 L, dissolve 4.00 g of solid NaOH in about 900 ml of water 
and adjust the final volume to 1 L using additional water. Shake well to 
mix the solution.
    3.1.4  Filter. Teflon  mat (e.g., Pallflex  
TX40H145) filter. When the stack gas temperature exceeds 210  deg.C (410 
 deg.F) a quartz fiber filter may be used.
    3.1.5  Silica Gel, Crushed Ice, and Stopcock Grease. Same as Method 
5, Sections 3.1.2, 3.1.4, and 3.1.5, respectively.
    3.1.6  Sodium Thiosulfate, 
(Na2S2O33.5H2O).

                          3.2  Sample Recovery

    3.2.1  Water. Same as Section 3.1.1.
    3.2.2  Acetone. Same as Method 5, Section 3.2.
    3.3  Sample Analysis.
    3.3.1  Water. Same as Section 3.1.1.
    3.3.2  Reagent Blanks. A separate blank solution of each absorbing 
reagent should be prepared for analysis with the field samples. Dilute 
200 ml of each absorbing solution (250 ml of the acidic absorbing 
solution, if a condensate impinger is used) to the same final volume as 
the field samples using the blank sample of rinse water. If a 
particulate determination is conducted, collect a blank sample of 
acetone.
    3.3.3  Halide Salt Stock Standard Solutions. Prepare concentrated 
stock solutions from reagent grade sodium chloride (NaCl), sodium 
bromide (NaBr), and sodium fluoride (NaF). Each must be dried at 110 
deg.C for 2 or more hours and then cooled to room temperature in a 
desiccator immediately before weighing. Accurately weigh 1.6 to 1.7 g of 
the dried NaCl to within 0.1 mg, dissolve in water, and dilute to 1 
liter. Calculate the exact Cl- concentration using Equation 
26A-1.

  g Cl-/ml = g of NaCl  x  10\3\  x  35.453/58.44

      Eq. 26A-1
    In a similar manner, accurately weigh and solubilize 1.2 to 1.3 g of 
dried NaBr and 2.2 to 2.3 g of NaF to make 1-liter solutions. Use 
Equations 26A-2 and 26A-3 to calculate the Br- and 
F- concentrations.

  g Br-/ml = g of NaBr  x  10\3\  x  79.904/102.90

      Eq. 26A-2

g F-/ml = g of NaF  x  10\3\  x  18.998/41.99

      Eq. 26A-3
    Alternately, solutions containing a nominal certified concentration 
of 1000 mg/L NaCl are commercially available as convenient stock 
solutions from which standards can be made by appropriate volumetric 
dilution.

[[Page 1094]]

Refrigerate the stock standard solutions and store no longer than 1 
month.
    3.3.4  Chromatographic Eluent. Same as Method 26, Section 3.2.4.

                              4. Procedure

    Because of the complexity of this method, testers and analysts 
should be trained and experienced with the procedures to ensure reliable 
results.
    4.1  Sampling.
    4.1.1  Pretest Preparation. Follow the general procedure given in 
Method 5, Section 4.1.1, except the filter need only be desiccated and 
weighed if a particulate determination will be conducted.
    4.1.2  Preliminary Determinations. Same as Method 5, Section 4.1.2.
    4.1.3  Preparation of Sampling Train. Follow the general procedure 
given in Method 5, Section 4.1.3, except for the following variations:
    Add 50 ml of 0.1 N H2SO4 to the condensate 
impinger, if used. Place 100 ml of 0.1 N H2SO4 in 
each of the next two impingers. Place 100 ml of 0.1 N NaOH in each of 
the following two impingers. Finally, transfer approximately 200-300 g 
of preweighed silica gel from its container to the last impinger. Set up 
the train as in Figure 26A-1. When used, the optional cyclone is 
inserted between the probe liner and filter holder and located in the 
heated filter box.
    4.1.4  Leak-Check Procedures. Follow the leak-check procedures given 
in Method 5, Sections 4.4.1 (Pretest Leak-Check), 4.1.4.2 (Leak-Checks 
During the Sample Run), and 4.1.4.3 (Post-Test Leak-Check).
    4.1.5  Train Operation. Follow the general procedure given in Method 
5, Section 4.1.5. Maintain a temperature around the filter and (cyclone, 
if used) of greater than 120  deg.C (248  deg.F).
    For each run, record the data required on a data sheet such as the 
one shown in Method 5, Figure 5-2. If the condensate impinger becomes 
too full, it may be emptied, recharged with 50 ml of 0.1 N 
H2SO4, and replaced during the sample run. The 
condensate emptied must be saved and included in the measurement of the 
volume of moisture collected and included in the sample for analysis. 
The additional 50 ml of absorbing reagent must also be considered in 
calculating the moisture. After the impinger is reinstalled in the 
train, conduct a leak-check as described in Method 5, Section 4.1.4.2.
    4.1.6  Post-Test Moisture Removal (Optional). When the optional 
cyclone is included in the sampling train or when moisture is visible on 
the filter at the end of a sample run even in the absence of a cyclone, 
perform the following procedure. Upon completion of the test run, 
connect the ambient air conditioning tube at the probe inlet and operate 
the train with the filter heating system at least 120  deg.C (248 
deg.F) at a low flow rate (e.g.,  H=1 in. H2O) to 
vaporize any liquid and hydrogen halides in the cyclone or on the filter 
and pull them through the train into the impingers. After 30 minutes, 
turn off the flow, remove the conditioning tube, and examine the cyclone 
and filter for any visible moisture. If moisture is visible, repeat this 
step for 15 minutes and observe again. Keep repeating until the cyclone 
is dry. [Note: It is critical that this is repeated until the cyclone is 
completely dry.]
    4.2  Sample Recovery. Allow the probe to cool. When the probe can be 
handled safely, wipe off all the external surfaces of the tip of the 
probe nozzle and place a cap loosely over the tip. Do not cap the probe 
tip tightly while the sampling train is cooling down because this will 
create a vacuum in the filter holder, drawing water from the impingers 
into the holder. Before moving the sampling train to the cleanup site, 
remove the probe, wipe off any silicone grease, and cap the open outlet 
of the impinger train, being careful not to lose any condensate that 
might be present. Wipe off any silicone grease and cap the filter or 
cyclone inlet. Remove the umbilical cord from the last impinger and cap 
the impinger. If a flexible line is used between the first impinger and 
the filter holder, disconnect it at the filter holder and let any 
condensed water drain into the firsd impinger. Wipe off any silicone 
grease and cap the filter holder outlet and the impinger inlet. Ground 
glass stoppers, plastic caps, serum caps, Teflon tape, 
Parafilm, or aluminum foil may be used to close these 
openings. Transfer the probe and filter/impinger assembly to the cleanup 
area. This area should be clean and protected from the weather to 
minimize sample contamination or loss. Inspect the train prior to and 
during disassembly and note any abnormal conditions. Treat samples as 
follows:
    4.2.1  Container No. 1 (Optional; Filter Catch for Particulate 
Determination). Same as Method 5, Section 4.2, Container No. 1.
    4.2.2  Container No. 2 (Optional; Front-Half Rinse for Particulate 
Determination). Same as Method 5, Section 4.2, Container No. 2.
    4.2.3  Container No. 3 (Knockout and Acid Impinger Catch for 
Moisture and Hydrogen Halide Determination). Disconnect the impingers. 
Measure the liquid in the acid and knockout impingers to 1 
ml by using a graduated cylinder or by weighing it to 0.5 g 
by using a balance. Record the volume or weight of liquid present. This 
information is required to calculate the moisture content of the 
effluent gas. Quantitatively transfer this liquid to a leak-free sample 
storage container. Rinse these impingers and connecting glassware 
including the back portion of the filter holder (and flexible tubing, if 
used) with water and add these rinses to the storage container. Seal the 
container, shake to mix, and label. The fluid level should be

[[Page 1095]]

marked so that if any sample is lost during transport, a correction 
proportional to the lost volume can be applied. Retain rinse water and 
acidic absorbing solution blanks and analyze with the samples.
    4.2.4  Container No. 4 (Alkaline Impinger Catch for Halogen and 
Moisture Determination). Measure and record the liquid in the alkaline 
impingers as described in Section 4.2.3. Quantitatively transfer this 
liquid to a leak-free sample storage container. Rinse these two 
impingers and connecting glassware with water and add these rinses to 
the container. Add 25 mg of sodium thiosulfate per ppm halogen-dscm of 
stack gas sampled. [Note: This amount of sodium thiosulfate includes a 
safety factor of approximately 5 to assure complete reaction with the 
hypohalous acid to form a second Cl- ion in the alkaline 
solution.] Seal the container, shake to mix, and label; mark the fluid 
level. Retain alkaline absorbing solution blank and analyze with the 
samples.
    4.2.5  Container No. 5 (Silica Gel for Moisture Determination). Same 
as Method 5, Section 4.2, Container No. 3.
    4.2.6  Container Nos. 6 through 9 (Reagent Blanks). Save portions of 
the absorbing reagents (0.1 N H2SO4 and 0.1 N 
NaOH) equivalent to the amount used in the sampling train; dilute to the 
approximate volume of the corresponding samples using rinse water 
directly from the wash bottle being used. Add the same ratio of sodium 
thiosulfate solution used in container No. 4 to the 0.1 N NaOH absorbing 
reagent blank. Also, save a portion of the rinse water alone and a 
portion of the acetone equivalent to the amount used to rinse the front 
half of the sampling train. Place each in a separate, prelabeled sample 
container.
    4.2.7  Prior to shipment, recheck all sample containers to ensure 
that the caps are well-secured. Seal the lids of all containers around 
the circumference with Teflon tape. Ship all liquid samples 
upright and all particulate filters with the particulate catch facing 
upward.
    4.3  Sample Preparation and Analysis. Note the liquid levels in the 
sample containers and confirm on the analysis sheet whether or not 
leakage occurred during transport. If a noticeable leakage has occurred, 
either void the sample or use methods, subject to the approval of the 
Administrator, to correct the final results.
    4.3.1  Container Nos. 1 and 2 and Acetone Blank (Optional; 
Particulate Determination). Same as Method 5, Section 4.3.
    4.3.2  Container No. 5. Same as Method 5, Section 4.3 for silica 
gel.
    4.3.3  Container Nos. 3 and 4 and Absorbing Solution and Water 
Blanks. Quantitatively transfer each sample to a volumetric flask or 
graduated cylinder and dilute with water to a final volume within 50 ml 
of the largest sample.
    4.3.3.1  The IC conditions will depend upon analytical column type 
and whether suppressed or nonsuppressed IC is used. Prior to calibration 
and sample analysis, establish a stable baseline. Next, inject a sample 
of water, and determine if any Cl-, Br-, or 
F- appears in the chromatogram. If any of these ions are 
present, repeat the load/injection procedure until they are no longer 
present. Analysis of the acid and alkaline absorbing solution samples 
requires separate standard calibration curves; prepare each according to 
Section 5.2. Ensure adequate baseline separation of the analyses.
    4.3.3.2  Between injections of the appropriate series of calibration 
standards, inject in duplicate the reagent blanks and the field samples. 
Measure the areas or heights of the Cl-, Br-, and 
F- peaks. Use the average response to determine the 
concentrations of the field samples and reagent blanks using the linear 
calibration curve. If the values from duplicate injections are not 
within 5 percent of their mean, the duplicate injection shall be 
repeated and all four values used to determine the average response. 
Dilute any sample and the blank with equal volumes of water if the 
concentration exceeds that of the highest standard.
    4.4  Audit Sample Analysis. Audit samples must be analyzed subject 
to availability.

                             5. Calibration

    Maintain a laboratory log of all calibrations.
    5.1  Probe Nozzle, Pitot Tube, Dry Gas Metering System, Probe 
Heater, Temperature Gauges, Leak-Check of Metering System, and 
Barometer. Same as Method 5, Sections 5.1, 5.2, 5.3, 5.4, 5.5, 5.6, and 
5.7, respectively.
    5.2  Ion Chromatograph. To prepare the calibration standards, dilute 
given amounts (1.0 ml or greater) of the stock standard solutions to 
convenient volumes, using 0.1 N H2SO4 or 0.1 N 
NaOH, as appropriate. Prepare at least four calibration standards for 
each absorbing reagent containing the three stock solutions such that 
they are within the linear range of the field samples. Using one of the 
standards in each series, ensure adequate baseline separation for the 
peaks of interest. Inject the appropriate series of calibration 
standards, starting with the lowest concentration standard first both 
before and after injection of the quality control check sample, reagent 
blanks, and field samples. This allows compensation for any instrument 
drift occurring during sample analysis. Determine the peak areas, or 
height, of the standards and plot individual values versus halide ion 
concentrations in g/ml. Draw a smooth curve through the points. 
Use linear regression to calculate a formula describing the resulting 
linear curve.

[[Page 1096]]

                           6. Quality Control

    Same as Method 5, Section 4.4.

                          7. Quality Assurance

    7.1  Applicability. When the method is used to demonstrate 
compliance with a regulation, a set of two audit samples shall be 
analyzed.
    7.2  Audit Procedure. The currently available audit samples are 
chloride solutions. Concurrently analyze the two audit samples and a set 
of compliance samples in the same manner to evaluate the technique of 
the analyst and the standards preparation. The same analyst, analytical 
reagents, and analytical system shall be used both for compliance 
samples and the Environmental Protection Agency (EPA) audit samples.
    7.3  Audit Sample Availability. Audit samples will be supplied only 
to enforcement agencies for compliance tests. Audit samples may be 
obtained by writing the Source Test Audit Coordinator (MD-77B), Quality 
Assurance Division, Atmospheric Research and Exposure Assessment 
Laboratory, U.S. Environmental Protection Laboratory, Research Triangle 
Park, NC 27711 or by calling the Source Test Audit Coordinator (STAC) at 
(919) 541-7834. The request for the audit samples should be made at 
least 30 days prior to the scheduled compliance sample analysis.
    7.4  Audit Results. Calculate the concentrations in mg/dscm using 
the specified sample volume in the audit instructions. Include the 
results of both audit samples, their identification numbers, and the 
analyst's name with the results of the compliance determination samples 
in appropriate reports to the EPA regional office or the appropriate 
enforcement agency. (NOTE: Acceptability of results may be obtained 
immediately by reporting the audit results in mg/dscm and compliance 
results in total g HCl/sample to the responsible enforcement 
agency.) The concentrations of the audit samples obtained by the analyst 
shall agree within 10 percent of the actual concentrations. If the 10 
percent specification is not met, reanalyze the compliance samples and 
audit samples, and include initial and reanalysis values in the test 
report. Failure to meet the 10 percent specification may require retests 
until the audit problems are resolved.

                             8. Calculations

    Retain at least one extra decimal figure beyond those contained in 
the available data in intermediate calculations, and round off only the 
final answer appropriately.
    8.1  Nomenclature. Same as Method 5, Section 6.1. In addition:

1 BX-=Mass concentration of applicable absorbing solution 
          blank, g halide ion (Cl-, Br-, 
          F-)/ml, not to exceed 1 g/ml which is 10 
          times the published analytical detection limit of 0.1 
          g/ml. (It is also approximately 5 percent of the mass 
          concentration anticipated to result from a one hour sample at 
          10 ppmv HCl.)
C=Concentration of hydrogen halide (HX) or halogen (X2), dry 
          basis, mg/dscm.
mHX=Mass of HCl, HBr, or HF in sample, g.
mX2=Mass of Cl2 or Br2 in sample, 
          g.
SX--=Analysis of sample, g halide ion 
          (Cl-, Br-, F-)/ml.
VS=Volume of filtered and diluted sample, ml.
    8.2  Average Dry Gas Meter Temperature and Average Orifice Pressure 
Drop. See data sheet (Figure 5-2 of Method 5).
    8.3  Dry Gas Volume. Calculate Vm(std) and adjust for 
leakage, if necessary, using the equation in Section 6.3 of Method 5.
    8.4  Volume of Water Vapor and Moisture Content. Calculate the 
volume of water vapor Vw(std) and moisture content 
Bws from the data obtained in this method (Figure 5-2 of 
Method 5); use Equations 5-2 and 5-3 of Method 5.
    8.5  Isokinetic Variation and Acceptable Results. Use Method 5, 
Sections 6.11 and 6.12.
    8.6  Acetone Blank Concentration, Acetone Wash Blank Residue Weight, 
Particulate Weight, and Particulate Concentration. For particulate 
determination.
    8.7  Total g HCl, HBr, or HF Per Sample.

    mHX=K Vs (SX--BX-)    
Eq. 26A-4
where:
    KHC1 = 1.028 (g HCl/g-mole)/(g 
Cl-/g-mole).
    KHBr=1.013 (g HBr/g-mole)/(g 
Br-/g-mole).
    KHF=1.053 (g HF/g-mole)/(g 
F-/g-mole).
    8.8  Total g Cl2 or Br2 Per Sample.

mX2= Vs (SX--BX-)    Eq. 
          26A-5
    8.9  Concentration of Hydrogen Halide or Halogen in Flue Gas.

C=K mHX,X2/Vm(std)    Eq. 26A-6
where: K=1010- mg/g
    8.10  Stack Gas Velocity and Volumetric Flow Rate. Calculate the 
average stack gas velocity and volumetric flow rate, if needed, using 
data obtained in this method and the equations in Sections 5.2 and 5.3 
of Method 2.

                             9. Bibliography

    1. Steinsberger, S. C. and J. H. Margeson. Laboratory and Field 
Evaluation of a Methodology for Determination of Hydrogen Chloride 
Emissions from Municipal and Hazardous Waste Incinerators. U.S. 
Environmental Protection Agency, Office of Research and Development. 
Publication No. 600/3-89/064. April 1989. Available from National 
Technical Information Service, Springfield, VA 22161 as PB89220586/AS.
    2. State of California Air Resources Board. Method 421--
Determination of Hydrochloric Acid Emissions from Stationary Sources. 
March 18, 1987.

[[Page 1097]]

    3. Cheney, J.L. and C.R. Fortune. Improvements in the Methodology 
for Measuring Hydrochloric Acid in Combustion Source Emissions. J. 
Environ. Sci. Health. A19(3): 337-350. 1984.
    4. Stern, D.A., B.M. Myatt, J.F. Lachowski, and K.T. McGregor. 
Speciation of Halogen and Hydrogen Halide Compounds in Gaseous 
Emissions. In: Incineration and Treatment of Hazardous Waste: 
Proceedings of the 9th Annual Research Symposium, Cincinnati, Ohio, May 
2-4, 1983. Publication No. 600/9-84-015. July 1984. Available from 
National Technical Information Service, Springfield, VA 22161 as PB84-
234525.
    5. Holm, R.D. and S.A. Barksdale. Analysis of Anions in Combustion 
Products. In: Ion Chromatographic Analysis of Environmental Pollutants, 
E. Sawicki, J.D. Mulik, and E. Wittgenstein (eds.). Ann Arbor, Michigan, 
Ann Arbor Science Publishers. 1978. pp. 99-110.

 Method 27--Determination of Vapor Tightness of Gasoline Delivery Tank 
                       Using Pressure-Vacuum Test

1. Applicability and Principle

    1.1  Applicability. This method is applicable for the determination 
of vapor tightness of a gasoline delivery tank which is equipped with 
vapor collection equipment.
    1.2  Principle. Pressure and vacuum are applied alternately to the 
compartments of a gasoline delivery tank and the change in pressure or 
vacuum is recorded after a specified period of time.

2. Definitions and Nomenclature

    2.1  Gasoline. Any petroleum distillate or petroleum distillate/
alcohol blend having a Reid vapor pressure of 27.6 kilopascals or 
greater which is used as a fuel for internal combustion engines.
    2.2  Delivery Tank. Any container, including associated pipes and 
fittings, that is attached to or forms a part of any truck, trailer, or 
railcar used for the transport of gasoline.
    2.3  Compartment. A liquid-tight division of a delivery tank.
    2.4  Delivery Tank Vapor Collection Equipment. Any piping, hoses, 
and devices on the delivery tank used to collect and route gasoline 
vapors either from the tank to a bulk terminal vapor control system or 
from a bulk plant or service station into the tank.
    2.5  Time Period of the Pressure or Vacuum Test (t). The time period 
of the test, as specified in the appropriate regulation, during which 
the change in pressure or vacuum is monitored, in minutes.
    2.6  Initial Pressure (Pi). The pressure applied to the 
delivery tank at the beginning of the static pressure test, as specified 
in the appropriate regulation, in mm H2O.
    2.7  Initial Vacuum (Vi). The vacuum applied to the 
delivery tank at the beginning of the static vacuum test, as specified 
in the appropriate regulation, in mm H2O.
    2.8  Allowable Pressure Change (p). The allowable amount of 
decrease in pressure during the static pressure test, within the time 
period t, as specified in the appropriate regulation, in mm 
H2O.
    2.9  Allowable Vacuum Change (v). The allowable amount of 
decrease in vacuum during the static vacuum test, within the time period 
t, as specified in the appropriate regulation, in mm H2O.

3. Apparatus

    3.1  Pressure Source. Pump or compressed gas cylinder of air or 
inert gas sufficient to pressurize the delivery tank to 500 mm 
H2O above atmospheric pressure.
    3.2  Regulator. Low pressure regulator for controlling 
pressurization of the delivery tank.
    3.3  Vacuum Source. Vacuum pump capable of evacuating the delivery 
tank to 250 mm H2O below atmospheric pressure.
    3.4  Pressure-Vacuum Supply Hose.
    3.5  Manometer. Liquid manometer, or equivalent instrument, capable 
of measuring up to 500 mm H2O gauge pressure with 
plus-minus2.5 mm H2O precision.
    3.6  Pressure-Vacuum Relief Valves. The test apparatus shall be 
equipped with an in-line pressure-vacuum relief valve set to activate at 
675 mm H2O above atmospheric pressure or 250 mm 
H2O below atmospheric pressure, with a capacity equal to the 
pressurizing or evacuating pumps.
    3.7  Test Cap for Vapor Recovery Hose. This cap shall have a tap for 
manometer connection and a fitting with shut-off valve for connection to 
the pressure-vacuum supply hose.
    3.8  Caps for Liquid Delivery Hoses.

4. Pretest Preparations

    4.1  Summary. Testing problems may occur due to the presence of 
volatile vapors and/or temperature fluctuations inside the delivery 
tank. Under these conditions, it is often difficult to obtain a stable 
initial pressure at the beginning of a test, and erroneous test results 
may occur. To help prevent this, it is recommended that, prior to 
testing, volatile vapors be removed from the tank and the temperature 
inside the tank be allowed to stabilize. Because it is not always 
possible to attain completely these pretest conditions a provision to 
ensure reproducible results is included. The difference in results for 
two consecutive runs must meet the criterion in Sections 5.2.5 and 
5.3.5.
    4.2  Emptying of Tank. The delivery tank shall be emptied of all 
liquid.
    4.3  Purging of Vapor. As much as possible, the delivery tank shall 
be purged of all volatile vapors by any safe, acceptable method. One 
method is to carry a load of non-volatile

[[Page 1098]]

liquid fuel, such as diesel or heating oil, immediately prior to the 
test, thus flushing out all the volatile gasoline vapors. A second 
method is to remove the volatile vapors by blowing ambient air into each 
tank compartment for at least 20 minutes. This second method is usually 
not as effective and often causes stabilization problems, requiring a 
much longer time for stabilization during the testing.
    4.4  Temperature Stabilization. As much as possible, the test shall 
be conducted under isothermal conditions. The temperature of the 
delivery tank should be allowed to equilibrate in the test environment. 
During the test, the tank should be protected from extreme environmental 
and temperature variability, such as direct sunlight.

5. Test Procedure

    5.1  Preparations.
    5.1.1  Open and close each dome cover.
    5.1.2  Connect static electrical ground connections to tank. Attach 
the liquid delivery and vapor return hoses, remove the liquid delivery 
elbows, and plug the liquid delivery fittings.
    Note: The purpose of testing the liquid delivery hoses is to detect 
tears or holes that would allow liquid leakage during a delivery. Liquid 
delivery hoses are not considered to be possible sources of vapor 
leakage, and thus, do not have to be attached for a vapor leakage test. 
Instead, a liquid delivery hose could be either visually inspected, or 
filled with water to detect any liquid leakage.)
    5.1.3  Attach the test cap to the end of the vapor recovery hose.
    5.1.4  Connect the pressure-vacuum supply hose and the pressure-
vacuum relief valve to the shut-off valve. Attach a manometer to the 
pressure tap.
    5.1.5  Connect compartments of the tank internally to each other if 
possible. If not possible, each compartment must be tested separately, 
as if it were an individual delivery tank.
    5.2  Pressure Test.
    5.2.1  Connect the pressure source to the pressure-vacuum supply 
hose.
    5.2.2  Open the shut-off valve in the vapor recovery hose cap. 
Applying air pressure slowly, pressurize the tank to Pi, the 
initial pressure specified in the regulation.
    5.2.3  Close the shut-off valve and allow the pressure in the tank 
to stabilize, adjusting the pressure if necessary to maintain pressure 
of Pi. When the pressure stabilizes, record the time and 
initial pressure.
    5.2.4  At the end of t minutes, record the time and final pressure.
    5.2.5  Repeat steps 5.2.2 through 5.2.4 until the change in pressure 
for two consecutive runs agrees within plus-minus12.5 mm 
H2O. Calculate the arithmetic average of the two results.
    5.2.6  Compare the average measured change in pressure to the 
allowable pressure change,  p, as specified in the regulation. 
If the delivery tank does not satisfy the vapor tightness criterion 
specified in the regulation, repair the sources of leakage, and repeat 
the pressure test until the criterion is met.
    5.2.7  Disconnect the pressure source from the pressure-vacuum 
supply hose, and slowly open the shut-off valve to bring the tank to 
atmospheric pressure.
    5.3  Vacuum Test.
    5.3.1  Connect the vacuum source to the pressure-vacuum supply hose.
    5.3.2  Open the shut-off valve in the vapor recovery hose cap. 
Slowly evacuate the tank to Vi, the initial vacuum specified 
in the regulation.
    5.3.3  Close the shut-off valve and allow the pressure in the tank 
to stabilize, adjusting the pressure if necessary to maintain a vacuum 
of Vi. When the pressure stabilizes, record the time and 
initial vacuum.
    5.3.4  At the end of t minutes, record the time and final vacuum.
    5.3.5  Repeat steps 5.3.2 through 5.3.4 until the change in vacuum 
for two consecutive runs agrees within plus-minus12.5 mm 
H2O. Calculate the arithmetic average of the two results.
    5.3.6  Compare the average measured change in vacuum to the 
allowable vacuum change,  v, as specified in the regulation. 
If the delivery tank does not satisfy the vapor tightness criterion 
specified in the regulation, repair the sources of leakage, and repeat 
the vacuum test until the criterion is met.
    5.3.7  Disconnect the vacuum source from the pressure-vacuum supply 
hose, and slowly open the shut-off valve to bring the tank to 
atmospheric pressure.
    5.4  Post-Test Clean-Up. Disconnect all test equipment and return 
the delivery tank to its pretest condition.

6. Alternative Procedures

    6.1  The pumping of water into the bottom of a delivery tank is an 
acceptable alternative to the pressure source described above. Likewise, 
the draining of water out of the bottom of a delivery tank may be 
substituted for the vacuum source. Note that some of the specific step-
by-step procedures in the method must be altered slightly to accommodate 
these different pressure and vacuum sources.
    6.2  Techniques other than specified above may be used for purging 
and pressurizing a delivery tank, if prior approval is obtained from the 
Administrator. Such approval will be based upon demonstrated equivalency 
with the above method.

[[Page 1099]]

          Method 28--Certification and Auditing of Wood Heaters

                     1. Applicability and Principle

    1.1  Applicability. This method is applicable for the certification 
and auditing of wood heaters. This method describes the test facility, 
test fuel charge, and wood heater operation as well as procedures for 
determining burn rates and particulate emission rates and for reducing 
data.
    1.2  Principle. Particulate matter emissions are measured from a 
wood heater burning a prepared test fuel crib in a test facility 
maintained at a set of prescribed conditions.

                             2. Definitions

    2.1  Burn Rate. The rate at which test fuel is consumed in a wood 
heater. Measured in kilograms of wood (dry basis) per hour (kg/hr).
    2.2  Certification or Audit Test. A series of at least four test 
runs conducted for certification or audit purposes that meets the burn 
rate specifications in Section 5.
    2.3  Firebox. The chamber in the wood heater in which the test fuel 
charge is placed and combusted.
    2.4  Secondary Air Supply. An air supply that introduces air to the 
wood heater such that the burn rate is not altered by more than 25 
percent when the secondary air supply is adjusted during the test run. 
The wood heater manufacturer can document this through design drawings 
that show the secondary air is introduced only into a mixing chamber or 
secondary chamber outside the firebox.
    2.5  Test Facility. The area in which the wood heater is installed, 
operated, and sampled for emissions.
    2.6  Test Fuel Charge. The collection of test fuel pieces placed in 
the wood heater at the start of the emission test run.
    2.7  Test Fuel Crib. The arrangement of the test fuel charge with 
the proper spacing requirements between adjacent fuel pieces.
    2.8  Test Fuel Loading Density. The weight of the as-fired test fuel 
charge per unit volume of usable firebox.
    2.9  Test Fuel Piece. The 2 x 4 or 4 x 4 wood piece cut to the 
length required for the test fuel charge and used to construct the test 
fuel crib.
    2.10  Test Run. An individual emission test which encompasses the 
time required to consume the mass of the test fuel charge.
    2.11  Usable Firebox Volume. The volume of the firebox determined 
using the following definitions:
    2.11.1  Height. The vertical distance extending above the loading 
door, if fuel could reasonably occupy that space, but not more than 2 
inches above the top (peak height) of the loading door, to the floor of 
the firebox (i.e., below a permanent grate) if the grate allows a 1-inch 
diameter piece of wood to pass through the grate, or, if not, to the top 
of the grate. Firebox height is not necessarily uniform but must account 
for variations caused by internal baffles, air channels, or other 
permanent obstructions.
    2.11.2  Length. The longest horizontal fire chamber dimension that 
is parallel to a wall of the chamber.
    2.11.3  Width. The shortest horizontal fire chamber dimension that 
is parallel to a wall of the chamber.
    2.12  Wood Heater. An enclosed, woodburning appliance capable of and 
intended for space heating or domestic water heating, as defined in the 
applicable regulation.
    2.13  Pellet Burning Wood Heater. A wood heater which meets the 
following criteria: (1) The manufacturer makes no reference to burning 
cord wood in advertising or other literature, (2) the unit is safety 
listed for pellet fuel only, (3) the unit operating and instruction 
manual must state that the use of cordwood is prohibited by law, and (4) 
the unit must be manufactured and sold including the hopper and auger 
combination as integral parts.

                              3. Apparatus

    3.1  Insulated Solid Pack Chimney. For installation of wood heaters. 
Solid pack insulated chimneys shall have a minimum of 2.5 cm (1 in.) 
solid pack insulating material surrounding the entire flue and possess a 
label demonstrating conformance to U.L. Standard 103 (incorporated by 
reference. See Sec. 60.17).
    3.2  Platform Scale and Monitor. For monitoring of fuel load weight 
change. The scale shall be capable of measuring weight to within 0.05 kg 
(0.1 lb) or 1 percent of the initial test fuel charge weight, whichever 
is greater.
    3.3  Wood Heater Temperature Monitors. Seven, each capable of 
measuring temperature to within 1.5 percent of expected absolute 
temperatures.
    3.4  Test Facility Temperature Monitor. A thermocouple located 
centrally in a vertically oriented 150 mm (6 in.) long, 50 mm (2 in.) 
diameter pipe shield that is open at both ends, capable of measuring 
temperature to within 1.5 percent of expected temperatures.
    3.5  Balance (optional). Balance capable of weighing the test fuel 
charge to within 0.05 kg (0.1 1b).
    3.6  Moisture Meter. Calibrated electrical resistance meter for 
measuring test fuel moisture to within 1 percent moisture content.
    3.7  Anemometer. Device capable of detecting air velocities less 
than 0.10 m/sec (20 ft/min), for measuring air velocities near the test 
appliance.

[[Page 1100]]

    3.8  Barometer. Mercury, aneroid or other barometer capable of 
measuring atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg).
    3.9  Draft Gauge. Electromanometer or other device for the 
determination of flue draft or static pressure readable to within 0.50 
Pa (0.002 in. H2O).
    3.10  Humidity Gauge. Psychrometer or hygrometer for measuring room 
humidity.
    3.11  Sampling Methods. Use particulate emission measurement Method 
5G or Method 5H to determine particulate concentrations, gas flow rates, 
and particulate emission rates.

      4. Test Facility. Test Fuel Properties, and Test Fuel Charge 
                             Specifications

    4.1  Test Facility.
    4.1.1  Wood Heater Flue. Steel flue pipe extending to 
2.60.15 m (8.50.5 ft) above the top of the 
platform scale, and above this level, insulated solid pack type chimney 
extending to 4.6+0.3 m (151 ft) above the platform scale, 
and of the size specified by the wood heater manufacturer. This applies 
to both freestanding and insert type wood heaters.
    Other chimney types (e.g., solid pack insulated pipe) may be used in 
place of the steel flue pipe if the wood heater manufacturer's written 
appliance specifications require such chimney for home installation 
(e.g., zero clearance wood heater inserts). Such alternative chimney or 
flue pipe must remain and be sealed with the wood heater following the 
certification test.
    4.1.2  Test Facility Conditions. The test facility temperature shall 
be maintained between 18 and 32  deg.C (65 and 90  deg.F) during each 
test run.
    Air velocities within 0.6 m (2 ft) of the test appliance and exhaust 
system shall be less than 0.25 m/sec (50 ft/min) without fire in the 
unit.
    The flue shall discharge into the same space or into a space freely 
communicating with the test facility. Any hood or similar device used to 
vent combustion products shall not induce a draft greater than 1.25 Pa 
(0.005 in. H2O) on the wood heater measured when the wood 
heater is not operating.
    For test facilities with artificially induced barometric pressures 
(e.g., pressurized chambers), the barometric pressure in the test 
facility shall not exceed 1,033 mb (30.5 in. Hg) during any test run.
    4.2  Test Fuel Properties. The test fuel shall conform to the 
following requirements:
    4.2.1  Fuel Species. Untreated, air-dried, Douglas fir lumber. Kiln-
dried lumber is not permitted. The lumber shall be certified C grade 
(standard) or better Douglas fir by a lumber grader at the mill of 
origin as specified in the West Coast Lumber Inspection Bureau standard 
No. 16 (incorporated by reference. See Sec. 60.17).
    4.2.2  Fuel Moisture. The test fuel shall have a moisture content 
range between 16 to 20 percent on a wet basis (19 to 25 percent dry 
basis).
    Addition of moisture to previously dried wood is not allowed. It is 
recommended that the test fuel be stored in a temperature and humidity-
controlled room.
    4.2.3  Fuel Temperature. The test fuel shall be at the test facility 
temperature 18 to 32  deg.C (65 to 90  deg.F).
    4.3  Test Fuel Charge Specifications.
    4.3.1  Fuel Dimensions. The dimensions of each test fuel piece shall 
conform to the nominal measurements of 2 x 4 and 4 x 4 lumber. Each 
piece of test fuel (not including spacers) shall be of equal length, 
except as necessary to meet requirements in Section 6.2.5, and shall 
closely approximate \5/6\ the dimensions of the length of the usable 
firebox. The fuel piece dimensions shall be determined in relation to 
the appliance's firebox volume according to guidelines listed below:
    4.3.1.1  If the usable firebox volume is less than or equal to 0.043 
m\3\ (1.5 ft\3\), use 2 x 4 lumber.
    4.3.1.2  If the usable firebox volume is greater than 0.043 m\3\ 
(1.5 ft\3\) and less than or equal to 0.085 m\3\ (3.0 ft\3\), use 2 x 4 
and 4 x 4 lumber. About half the weight of the test fuel charge shall be 
2 x 4 lumber, and the remainder shall be 4 x 4 lumber.
    4.3.1.3  If the usable firebox volume is greater than 0.085 m\3\ 
(3.0 ft\3\), use 4 x 4 lumber.
    4.3.2  Test Fuel Spacers. Air-dried, Douglas fir lumber meeting the 
fuel properties in Section 4.2. The spacers shall be 130 x 40 x 20 mm (5 
x 1.5 x 0.75 in.).
    4.3.3  Test Fuel Charge Density. The test fuel charge density shall 
be 112  11.2 kg/m\3\ (7  0.7 lb/ft\3\) of usable 
firebox volume on a wet basis.
    4.4  Wood Heater Thermal Equilibrium. The average of the wood heater 
surface temperatures at the end of the test run shall agree with the 
average surface temperature at the start of the test run to within 70 
deg.C (125  deg.F).

                          5. Burn Rate Criteria

    5.1  Burn Rate Categories. One emission test run is required in each 
of the following burn rate categories:

                          Burn Rate Categories
                       (Average kg/hr, dry basis)
------------------------------------------------------------------------
    Category 1         Category 2         Category 3       Category 4
------------------------------------------------------------------------
        <0.80       0.80 to 1.25       1.25 to 1.90      Maximum burn
                                                                rate.
------------------------------------------------------------------------

    5.1.1  Maximum Burn Rate. For Category 4, the wood heater shall be 
operated with the primary air supply inlet controls fully open

[[Page 1101]]

(or, if thermostatically controlled, the thermostat shall be set at 
maximum heat output) during the entire test run, or the maximum burn 
rate setting specified by the manufacturer's written instructions.
    5.1.2  Other Burn Rate Categories. For burn rates in Categories 1 
through 3, the wood heater shall be operated with the primary air supply 
inlet control, or other mechanical control device, set at a 
predetermined position necessary to obtain the average burn rate 
required for the category.
    5.2  Alternative Burn Rates for Burn Rate Categories 1 and 2. If a 
wood heater cannot be operated at a burn rate below 0.80 kg/hr, two test 
runs shall be conducted with burn rates within Category 2. If a wood 
heater cannot be operated at a burn rate below 1.25 kg/hr, the flue 
shall be dampered or the air supply otherwise controlled in order to 
achieve two test runs within Category 2.
    Evidence that a wood heater cannot be operated at a burn rate less 
than 0.80 kg/hr shall include documentation of two or more attempts to 
operate the wood heater in burn rate Category 1 and fuel combustion has 
stopped, or results of two or more test runs demonstrating that the burn 
rates were greater than 0.80 kg/hr when the air supply controls were 
adjusted to the lowest possible position or settings. Stopped fuel 
combustion is evidenced when an elapsed time of 30 minutes or more has 
occurred without a measurable (< 0.05 kg (0.1 lb) or 1.0 percent, 
whichever is greater) weight change in the test fuel charge. See also 
Section 6.4.3. Report the evidence and the reasoning used to determine 
that a test in burn rate Category 1 cannot be achieved; for example, two 
attempts to operate at a burn rate of 0.4 kg/hr are not sufficient 
evidence that burn rate Category 1 cannot be achieved.
    Note: After July 1, 1990, if a wood heater cannot be operated at a 
burn rate less than 0.80 kg/hr, at least one test run with an average 
burn rate of 1.00 kg/hr or less shall be conducted. Additionally, if 
flue dampering must be used to achieve burn rates below 1.25 kg/hr (or 
1.0 kg/hr), results from a test run conducted at burn rates below 0.90 
kg/hr need not be reported or included in the test run average provided 
that such results are replaced with results from a test run meeting the 
criteria above.

                              6. Procedures

    6.1  Catalytic Combustor and Wood Heater Aging. The catalyst-
equipped wood heater or a wood heater of any type shall be aged before 
the certification test begins. The aging procedure shall be conducted 
and documented by a testing laboratory accredited according to 
procedures in Sec. 60.535 of 40 CFR Part 60.
    6.1.1  Catalyst-equipped Wood Heater. Operate the catalyst-equipped 
wood heater using fuel described in Section 4.2 or cordwood with a 
moisture content between 15 and 25 percent on a wet basis. Operate the 
wood heater at a medium burn rate (Category 2 or 3) with a new catalytic 
combustor in place and in operation for at least 50 hours. Record and 
report hourly catalyst exit temperature data (Section 6.2.2) and the 
hours of operation.
    6.1.2  Non-Catalyst Wood Heater. Operate the wood heater using the 
fuel described in Section 6.1.1 at a medium burn rade for at least 10 
hours. Record and report the hours of operation.
    6.2  Pretest Preparation. Record the test fuel charge dimensions and 
weights, and wood heater and catalyst descriptions as shown in the 
example in Figure 28-3.
    6.2.1  Wood Heater Installation. Assemble the wood heater appliance 
and parts in conformance with the manufacturer's written installation 
instructions. Place the wood heater centrally on the platform scale and 
connect the wood heater to the flue described in Section 4.1.1. Clean 
the flue with an appropriately sized, wire chimney brush before each 
certification test.
    6.2.2  Wood Heater Temperature Monitors. For catalyst-equipped wood 
heaters, locate a temperature monitor (optional) about 25 mm (1 in.) 
upstream of the catalyst at the centroid of the catalyst face area, and 
locate a temperature monitor (mandatory) that will indicate the catalyst 
exhaust temperature. This temperature monitor is centrally located 
within 25 mm (1 in.) downstream at the centroid of catalyst face area. 
Record these locations.
    Locate wood heater surface temperature monitors at five locations on 
the wood heater firebox exterior surface. Position the temperature 
monitors centrally on the top surface, on two sidewall surfaces, and on 
the bottom and back surfaces. Position the monitor sensing tip on the 
firebox exterior surface inside of any heat shield, air circulation 
walls, or other wall or shield separated from the firebox exterior 
surface. Surface temperature locations for unusual design shapes (e.g., 
spherical, etc.) shall be positioned so that there are four surface 
temperature monitors in both the vertical and horizontal planes passing 
at right angles through the centroid of the firebox, not including the 
fuel loading door (total of five temperature monitors).
    6.2.3  Test Facility Conditions. Locate the test facility 
temperature monitor on the horizontal plane that includes the primary 
air intake opening for the wood heater. Locate the temperature monitor 1 
to 2 m (3 to 6 ft) from the front of the wood heater in the 90 deg. 
sector in front of the wood heater.
    Use an anemometer to measure the air velocity. Measure and record 
the room air velocity before the pretest ignition period (Section 6.3) 
and once immediately following the test run completion.

[[Page 1102]]

    Measure and record the test facility's ambient relative humidity, 
barometric pressure, and temperature before and after each test run.
    Measure and record the flue draft or static pressure in the flue at 
a location no greater than 0.3 m (1 ft) above the flue connector at the 
wood heater exhaust during the test run at the recording intervals 
(Section 6.4.2).
    6.2.4  Wood Heater Firebox Volume. Determine the firebox volume 
using the definitions for height, width, and length in Section 2. Volume 
adjustments due to presence of firebrick and other permanent fixtures 
may be necessary. Adjust width and length dimensions to extend to the 
metal wall of the wood heater above the firebrick or permanent 
obstruction if the firebrick or obstruction extending the length of the 
side(s) or back wall extends less than one-third of the usable firebox 
height. Use the width or length dimensions inside the firebrick if the 
firebrick extends more than one-third of the usable firebox height. If a 
log retainer or grate is a permanent fixture and the manufacturer 
recommends that no fuel be placed outside the retainer, the area outside 
of the retainer is excluded from the firebox volume calculations.
    In general, exclude the area above the ash lip if that area is less 
than 10 percent of the usable firebox volume. Otherwise, take into 
account consumer loading practices. For instance, if fuel is to be 
loaded front-to-back, an ash lip may be considered usable firebox 
volume.
    Include areas adjacent to and above a baffle (up to two inches above 
the fuel loading opening) if four inches or more horizontal space exist 
between the edge of the baffle and a vertical obstruction (e.g., 
sidewalls or air channels).
    6.2.5  Test Fuel Charge. Prepare the test fuel pieces in accordance 
with the specifications in Section 4.3. Determine the test fuel moisture 
content with a calibrated electrical resistance meter or other 
equivalent performance meter. (To convert moisture meter readings from 
the dry basis to the wet basis: (100)(percent dry reading)  (100 
+ percent dry reading) = percent moisture wet basis.) Determine fuel 
moisture for each fuel piece (not including spacers) by averaging at 
least three moisture meter readings, one from each of three sides, 
measured parallel to the wood grain. Average all the readings for all 
the fuel pieces in the test fuel charge. If an electrical resistance 
type meter is used, penetration of insulated electrodes shall be one-
fourth the thickness of the test fuel piece or 19 mm (0.75 in.), 
whichever is greater. Measure the moisture content within a 4-hour 
period prior to the test run. Determine the fuel temperature by 
measuring the temperature of the room where the wood has been stored for 
at least 24 hours prior to the moisture determination.
    Attach the spacers to the test fuel pieces with uncoated, 
ungalvanized nails or staples as illustrated in Figure 28-1. Attachment 
of spacers to the top of the test fuel piece(s) on top of the test fuel 
charge is optional.
    To avoid stacking difficulties, or when a whole number of test fuel 
pieces does not result, all piece lengths shall be adjusted uniformly to 
remain within the specified loading density. The shape of the test fuel 
crib shall be geometrically similar to the shape of the firebox volume 
without resorting to special angular or round cuts on the individual 
fuel pieces.
    6.2.6  Sampling Method. Prepare the sampling equipment as defined by 
the selected method. Collect one particulate emission sample for each 
test run.
    6.2.7  Secondary Air Adjustment Validation. If design drawings do 
not show the introductions of secondary air into a chamber outside the 
firebox (Section 2.4), conduct a separate test of the wood heater's 
secondary air supply. Operate the wood heater at a burn rate in Category 
1 (Sections 5.1 or 5.2) with the secondary air supply operated following 
the manufacturer's written instructions. Start the secondary air 
validation test run as described in Section 6.4.1, except no emission 
sampling is necessary and burn rate data shall be recorded at 5-minute 
intervals.
    After the start of the test run, operate the wood heater with the 
secondary air supply set as per the manufacturer's instructions, but 
with no adjustments to this setting. After 25 percent of the test fuel 
has been consumed, adjust the secondary air supply controls to another 
setting, as per the manufacturer's instructions. Record the burn rate 
data (5-minute intervals) for 20 minutes following the air supply 
adjustment.
    Adjust the air supply control(s) to the original position(s), 
operate at this condition for at least 20 minutes, and repeat the air 
supply adjustment procedure above. Repeat the procedure three times at 
equal intervals over the entire burn period as defined in Section 6.4. 
If the secondary air adjustment results in a burn rate change of more 
than an average of 25 percent between the 20-minute periods before and 
after the secondary adjustments, the secondary air supply shall be 
considered a primary air supply, and no adjustment to this air supply is 
allowed during the test run.
    6.3  Pretest Ignition. Build a fire in the wood heater in accordance 
with the manufacturer's written instructions.
    6.3.1  Pretest Fuel Charge. Crumpled newspaper loaded with kindling 
may be used to help ignite the pretest fuel. The pretest fuel, used to 
sustain the fire, shall meet the same fuel requirements prescribed in 
Section 4.2. The pretest fuel charge shall consist of whole 2 x 4's that 
are no less than 1/3 the length of the test fuel pieces. Pieces of 4 x 4 
lumber in approximately the same weight ratio as for

[[Page 1103]]

the test fuel charge may be added to the pretest fuel charge.
    6.3.2  Wood Heater Operation and Adjustments. Set the air inlet 
supply controls at any position that will maintain combustion of the 
pretest fuel load. At least one hour before the start of the test run, 
set the air supply controls at the approximate positions necessary to 
achieve the burn rate desired for the test run. Adjustment of the air 
supply controls, fuel addition or subtractions, and coalbed raking shall 
be kept to a minimum but are allowed up to 15 minutes prior to the start 
of the test run. For the purposes of this method, coalbed raking is the 
use of a metal tool (poker) to stir coals, break burning fuel into 
smaller pieces, dislodge fuel pieces from positions of poor combustion, 
and check for the condition of uniform charcoalization. Record all 
adjustments made to the air supply controls, adjustments to and 
additions or subtractions of fuel, and any other changes to wood heater 
operations that occur during pretest ignition period. Record fuel weight 
data and wood heater temperature measurements at 10-minute intervals 
during the hour of the pretest ignition period preceding the start of 
the test run. During the 15-minute period prior to the start of the test 
run, the wood heater loading door shall not be open more than a total of 
1 minute. Coalbed raking is the only adjustment allowed during this 
period.
    Note: One purpose of the pretest ignition period is to achieve 
uniform charcoalization of the test fuel bed prior to loading the test 
fuel charge. Uniform charcoalization is a general condition of the test 
fuel bed evidenced by an absence of large pieces of burning wood in the 
coal bed and the remaining fuel pieces being brittle enough to be broken 
into smaller charcoal pieces with a metal poker. Manipulations to the 
fuel bed prior to the start of the test run should be done to achieve 
uniform charcoalization while maintaining the desired burn rate. In 
addition, some wood heaters (e.g., high mass units) may require extended 
pretest burn time and fuel additions to reach an initial average surface 
temperature sufficient to meet the thermal equilibrium criteria in 
Section 4.4.
    The weight of pretest fuel remaining at the start of the test run is 
determined as the difference between the weight of the wood heater with 
the remaining pretest fuel and the tare weight of the cleaned, dry wood 
heater with or without dry ash or sand added consistent with the 
manufacturer's instructions and the owner's manual. The tare weight of 
the wood heater must be determined with the wood heater (and ash, if 
added) in a dry condition.
    6.4  Test Run. Complete a test run in each burn rate category, as 
follows:
    6.4.1  Test Run Start. When the kindling and pretest fuel have been 
consumed to leave a fuel weight between 20 and 25 percent of the weight 
of the test fuel charge, record the weight of the fuel remaining and 
start the test run. Record and report any other criteria, in addition to 
those specified in this section, used to determine the moment of the 
test run start (e.g., firebox or catalyst temperature), whether such 
criteria are specified by the wood heater manufacturer or the testing 
laboratory. Record all wood heater individual surface temperatures, 
catalyst temperatures, any initial sampling method measurement values, 
and begin the particulate emission sampling. Within 1 minute following 
the start of the test run, open the wood heater door, load the test fuel 
charge, and record the test fuel charge weight. Recording of average, 
rather than individual, surface temperatures is acceptable for tests 
conducted in accordance with Sec. 60.533(o)(3)(i) of 40 CFR Part 60.
    Position the fuel charge so that the spacers are parallel to the 
floor of the firebox, with the spacer edges abutting each other. If 
loading difficulties result, some fuel pieces may be placed on edge. If 
the usable firebox volume is between 0.043 and 0.085 m\3\ (1.5 and 3.0 
ft\3\), alternate the piece sizes in vertical stacking layers to the 
extent possible. For example, place 2 x 4's on the bottom layer in 
direct contact with the coal bed and 4 x 4's on the next layer, etc. 
(See Figure 28-2). Position the fuel pieces parallel to each other and 
parallel to the longest wall of the firebox to the extent possible 
within the specifications in Section 6.2.5.
    Load the test fuel in appliances having unusual or unconventional 
firebox design maintaining air space intervals between the test fuel 
pieces and in conformance with the manufacturer's written instructions. 
For any appliance that will not accommodate the loading arrangement 
specified in the paragraph above, the test facility personnel shall 
contact the Administrator for an alternative loading arrangement.
    The wood heater door may remain open and the air supply controls 
adjusted up to five minutes after the start of the test run in order to 
make adjustments to the test fuel charge and to ensure ignition of the 
test fuel charge has occurred. Within the five minutes after the start 
of the test run, close the wood heater door and adjust the air supply 
controls to the position determined to produce the desired burn rate. No 
other adjustments to the air supply controls or the test fuel charge are 
allowed (except as specified in Sections 6.4.3 and 6.4.4) after the 
first five minutes of the test run. Record the length of time the wood 
heater door remains open, the adjustments to the air supply controls, 
and any other operational adjustments.
    6.4.2  Data Recording. Record fuel weight data, wood heater 
individual surface and catalyst temperature measurements, other wood 
heater operational data (e.g., draft), test facility temperature and 
sampling

[[Page 1104]]

method data at 10-minute intervals (or more frequently at the option of 
the tester) as shown on example data sheet, Figure 28-4.
    6.4.3  Test Fuel Charge Adjustment. The test fuel charge may be 
adjusted (i.e., re-positioned) once during a test run if more than 60 
percent of the initial test fuel charge weight has been consumed and 
more than 10 minutes have elapsed without a measurable (< 0.05 kg (0.1 
lb) or 1.0 percent, whichever is greater) weight change. The time used 
to make this adjustment shall be less than 15 seconds.
    6.4.4  Air Supply Adjustment. Secondary air supply controls may be 
adjusted once during the test run following the manufacturer's written 
instructions (see Section 6.2.7). No other air supply adjustments are 
allowed during the test run.
    Recording of wood heater flue draft during the test run is optional 
for tests conducted in accordance with Sec. 60.533(o)(3)(i) of 40 CFR 
Part 60.
    6.4.5  Auxiliary Wood Heater Equipment Operation. Heat exchange 
blowers sold with the wood heater shall be operated during the test run 
following the manufacturer's written instructions. If no manufacturer's 
written instructions are available, operate the heat exchange blower in 
the ``high'' position. (Automatically operated blowers shall be operated 
as designed.) Shaker grates, by-pass controls, or other auxiliary 
equipment may be adjusted only one time during the test run following 
the manufacturer's written instructions.
    Record all adjustments on a wood heater operational written record.
    Note: If the wood heater is sold with a heat exchange blower as an 
option, test the wood heater with the heat exchange blower operating as 
described in Sections 5 and 6 and report the results. As an alternative 
to repeating all test runs without the heat exchange blower operating, 
the tester may conduct one test run without the blower operating as 
described in Section 6.4.5 at a burn rate in Category 2 (Section 5.1). 
If the emission rate resulting from this test run without the blower 
operating is equal to or less than the emission rate plus 1.0 g/hr for 
the test run in burn rate Category 2 with the blower operating, the wood 
heater may be considered to have the same average emission rate with or 
without the blower operating. Additional test runs without the blower 
operating are unnecessary.
    6.5  Consecutive Test Runs. Test runs on a wood heater may be 
conducted consecutively provided that a minimum one-hour interval occurs 
between test runs.
    6.6  Additional Test Runs. The testing laboratory may conduct more 
than one test run in each of the burn rate categories specified in 
Section 5.1. If more than one test run is conducted at a specified burn 
rate, the results from at least two-thirds of the test runs in that burn 
rate category shall be used in calculating the weighted average emission 
rate (see Section 8.1). The measurement data and results of all test 
runs shall be reported regardless of which values are used in 
calculating the weighted average emission rate (see Note: in Section 
5.2).
    6.7  Pellet Burning Heaters. Certification testing procedures for 
pellet burning wood heaters are based on the procedures in this method. 
The differences in the procedures from the sections in Method 28 are as 
follows:
    6.7.1  Test Fuel Properties. The test fuel shall be all wood pellets 
with a moisture content no greater than 20 percent on a wet basis (25 
percent on a dry basis). Determine the wood moisture content with either 
ASTM-D2016-74(82)(Method A) or ASTM D4442-84. (incorporated by 
reference. See Section 60.17).
    6.7.2  Test Fuel Charge Specifications. The test fuel charge size 
shall be as per the manufacturer s written instructions for maintaining 
the desired burn rate.
    6.7.3  Wood Heater Firebox Volume. The firebox volume need not be 
measured or determined for establishing the test fuel charge size. The 
firebox dimensions and other heater specifications needed to identify 
the heater for certification purposes shall be reported.
    6.7.4  Heater Installation. Arrange the heater with the fuel supply 
hopper on the platform scale as described in Section 6.2.1.
    6.7.5  Pretest Ignition. Start a fire in the heater as directed by 
the manufacturer's written instructions, and adjust the heater controls 
to achieve the desired burn rate. Operate the heater at the desired burn 
rate for at least 1 hour before the start of the test run.
    6.7.6 Sampling Method. Method 5G or 5H shall be used for the 
certification testing of pellet burners. Prepare the sampling equipment 
as described in Method 5G or 5H. Collect one particulate emission sample 
for each test run.
    6.7.7  Test Run. Complete a test run in each burn rate category as 
follows:
    6.7.7.1  Test Run Start. When the wood heater has operated for at 
least 1 hour at the desired burn rate, add fuel to the supply hopper as 
necessary to complete the test run, record the weight of the fuel in the 
supply hopper (the wood heater weight), and start the test run. Add no 
additional fuel to the hopper during the test run.
    Record all the wood heater surface temperatures, the initial 
sampling method measurement values, the time at the start of the test, 
and begin the emission sampling. Make no adjustments to the wood heater 
air supply or wood supply rate during the test run.

[[Page 1105]]

    6.7.7.2  Data Recording. Record the fuel (wood heater) weight data, 
wood heater temperature and operational data, and emission sampling data 
as described in Section 6.4.2.
    6.7.7.3  Test Run Completion. Continue emission sampling and wood 
heater operation for 2 hours. At the end of the test run, stop the 
particulate sampling, and record the final fuel weight, the run time, 
and all final measurement values.
    6.7.8  Calculations. Determine the burn rate using the difference 
between the initial and final fuel (wood heater) weights and the 
procedures described in Section 8.3. Complete the other calculations as 
described in Section 8.

                             7. Calibrations

    7.1  Platform Scale. Perform a multipoint calibration (at least five 
points spanning the operational range) of the platform scale before its 
initial use. The scale manufacturer's calibration results are sufficient 
for this purpose. Before each certification test, audit the scale with 
the wood heater in place by weighing at least one calibration weight 
(Class F) that corresponds to 20 percent to 80 percent of the expected 
test fuel charge weight. If the scale cannot reproduce the value of the 
calibration weight within 0.05 kg (0.1 lbs) or 1 percent of the expected 
test fuel charge weight, whichever is greater, recalibrate the scale 
before use with at least five calibration weights spanning the 
operational range of the scale.
    7.2  Balance (optional). Calibrate as described in Section 7.1.
    7.3  Temperature Monitor. Calibrate as in Method 2, Section 4.3, 
before the first certification test and semiannually thereafter.
    7.4  Moisture Meter. Calibrate as per the manufacturer's 
instructions before each certification test.
    7.5  Anemometer. Calibrate the anemometer as specified by the 
manufacturer's instructions before the first certification test and 
semiannually thereafter.
    7.6  Barometer. Calibrate against a mercury barometer before the 
first certification test and semiannually thereafter.
    7.7  Draft Gauge. Calibrate as per the manufacturer's instructions; 
a liquid manometer does not require calibration.
    7.8  Humidity Gauge. Calibrate as per the manufacturer's 
instructions before the first certification test and semiannually 
thereafter.

                      8. Calculations and Reportinq

    Carry out calculations retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figures after the final 
calculation.
    8.1  Weighted Average Emission Rate.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.232
    
where:

Ew = Weighted average emission rate, g/hr;
Ei = Emission rate for test run, i, from Method 5G or 5H, g/
          hr;
ki = Test run weighting factor = Pi=1--
          Pi-1;
n = Total number of test runs;
Pi = Probability for burn rate during test run, i, obtained 
          from Table 28-1. Use linear interpolation to determine 
          probability values for burn rates between those listed on the 
          table.
    Note: Po always equals 0, P(n=1) always equals 
1, P1 corresponds to the probability of the lowest recorded 
burn rate, P2 corresponds to the probability of the next 
lowest burn rate, etc. An example calculation is shown on Figure 28-5.
    8.2  Average Wood Heater Surface Temperatures. Calculate the average 
of the wood heater surface temperatures for the start of the test run 
(Section 6.3.1) and for the test run completion (Section 6.3.6). If the 
two average temperatures do not agree within 70  deg.C (125  deg.F), 
report the test run results, but do not include the test run results in 
the test average. Replace such test run results with results from 
another test run in the same burn rate category.
    8.3  Burn Rate.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.233
    
Where:

BR = Dry wood burn rate, kg/hr (lb/hr)
Wwd = Total mass of wood burned during the test run, kg (lb)
 - Total time of test run, min.
%Mw = Average moisture in test fuel charge, wet basis, 
          percent.
    8.4  Reporting Criteria. Submit both raw and reduced test data for 
wood heater tests. Specific reporting requirements are as follows:
    8.4.1  Wood Heater Identification. Report wood heater identification 
information. An example data form is shown on Figure 28-4.
    8.4.2  Test Facility Information. Report test facility temperature, 
air velocity, and humidity information. An example data form is shown on 
Figure 28-4.
    8.4.3  Test Equipment Calibration and Audit Information. Report 
calibration and audit results for the platform scale, test fuel balance, 
test fuel moisture meter, and sampling equipment including volume 
metering systems and gaseous analyzers.

[[Page 1106]]

    8.4.4  Pretest Procedure Description. Report all pretest procedures 
including pretest fuel weight, burn rates, wood heater temperatures, and 
air supply settings. An example data form is shown on Figure 28-4.
    8.4.5  Particulate Emission Data. Report a summary of test results 
for all test runs and the weighted average emission rate. Submit copies 
of all data sheets and other records collected during the testing. 
Submit examples of all calculations.
    8.4.6  Suggested Test Report Format.

                             a. Introduction

    1. Purpose of test--certification, audit, efficiency, research and 
development.
    2. Wood heater identification--manufacturer, model number, 
catalytic/ noncatalytic, options.
    3. Laboratory--name, location (altitude), participants.
    4. Test information--date wood heater received, date of tests, 
sampling methods used, number of test runs.

                  b. Summary and Discussion of Results

    1. Table of results (in order of increasing burn rate)--test run 
number, burn rate, particulate emission rate, efficiency (if 
determined), averages (indicate which test runs are used).
    2. Summary of other data--test facility conditions, surface 
temperature averages, catalyst temperature averages, pretest fuel 
weights, test fuel charge weights, run times.
    3. Discussion--Burn rate categories achieved, test run result 
selection, specific test run problems and solutions.

                         c. Process Description

    1. Wood heater dimensions--volume, height, width, lengths (or other 
linear dimensions), weight, volume adjustments.
    2. Firebox configuration--air supply locations and operation, air 
supply introduction location, refractory location and dimensions, 
catalyst location, baffle and by-pass location and operation (include 
line drawings or photographs).
    3. Process operation during test--air supply settings and 
adjustments, fuel bed adjustments, draft.
    4. Test fuel--test fuel properties (moisture and temperature), test 
fuel crib description (include line drawing or photograph), test fuel 
charge density.

                          d. Sampling Locations

    Describe sampling location relative to wood heater. Include drawing 
or photograph.

                  e. Sampling and Analytical Procedures

    1. Sampling methods--brief reference to operational and sampling 
procedures and optional and alternative procedures used.
    2. Analytical methods--brief description of sample recovery and 
analysis procedures.

         f. Quality Control and Assurance Procedures and Results

    1. Calibration procedures and results--certification procedures, 
sampling and analysis procedures.
    2. Test method quality control procedures--leak-checks, volume meter 
checks, stratification (velocity) checks, proportionality results.

                               Appendices

    1. Results and Example Calculations. Complete summary tables and 
accompanying examples of all calculations.
    2. Raw Data. Copies of all uncorrected data sheets for sampling 
measurements, temperature records and sample recovery data. Copies of 
all pretest burn rate and wood heater temperature data.
    3. Sampling and Analytical Procedures. Detailed description of 
procedures followed by laboratory personnel in conducting the 
certification test, emphasizing particularly parts of the procedures 
differing from the methods (e.g., approved alternatives).
    4. Calibration Results. Summary of all calibrations, checks, and 
audits pertinent to certification test results with dates.
    5. Participants. Test personnel, manufacturer representatives, and 
regulatory observers.
    6. Sampling And Operation Records. Copies of uncorrected records of 
activities not included on raw data sheets (e.g., wood heater door open 
times and durations).
    7. Additional Information. Wood heater manufacturer's written 
instructions for operation during the certification test.

                             9. Bibliography

    1. Oregon Department of Environmental Quality Standard Method for 
Measuring the Emissions and Efficiencies of Woodstoves, June 8, 1984. 
Pursuant to Oregon Administrative Rules Chapter 340, Division 21.
    2. American Society for Testing Materials. Proposed Test Methods for 
Heating Performance and Emissions of Residential Wood-Fired Closed 
Combustion-Chamber Heating Appliances. E-6 Proposal P 180. August, 1986.
    3. Radian Corporation, OMNI Environmental Services, Inc., Cumulative 
Probability for a Given Burn Rate Based on Data Generated in the CONEG 
and BPA Studies. Package of materials submitted to the Fifth Session of 
the Regulatory Negotiation Committee, July 16-17, 1986.

[[Page 1107]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.268


[[Page 1108]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.269


[[Page 1109]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.270


[[Page 1110]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.271


[[Page 1111]]



   Figure 28-5--Example Calculation of Weighted Average Emission Rate
------------------------------------------------------------------------
                                                         Burn
                                                         rate
              Burn rate category                 Test   (Dry-  Emissions
                                                number   kg/     (g/hr)
                                                         hr)
------------------------------------------------------------------------
1.............................................       1   0.65      5.0
2\1\..........................................       2   0.85      6.7
2.............................................       3   0.90      4.7
2.............................................       4   1.00      5.3
3.............................................       5   1.45      3.8
4.............................................       6   2.00      5.1
------------------------------------------------------------------------
\1\ As permitted in Section 6.6, this test run may be omitted from the
  calculation of the weighted average emission rate because three runs
  were conducted for this burn rate category.


------------------------------------------------------------------------
                                               Burn
                 Test number                   rate    Pi     Ei    Ki
------------------------------------------------------------------------
1...........................................   0.65   0.121  5.0   0.300
2...........................................   0.90   0.300  4.7   0.259
3...........................................   1.00   0.380  5.3   0.422
4...........................................   1.45   0.722  3.8   0.532
5...........................................   2.00   0.912  5.1   0.278
------------------------------------------------------------------------

K1=P2-Po=0.300-0=0.300
K2=P3-P1=0.380-0.121=0.259
K3=P4-P2=0.722-0.300=0.422
K4=P5-P3=0.912-0.380=0.532
K5=P6-P4=1-0.722=0.278
[GRAPHIC] [TIFF OMITTED] TC01JN92.272

Ew equals (0.3)(5.0) + (0.259)(4.7) + (0.422)(5.3) + 
          (0.532)(3.8) + (0.278)(5.1) divided by 1.791
Ew=4.69 g/hr.

  Table 28-1--Burn Rate Weighted Probabilities for Calculating Weighted
                         Average Emission Rates
------------------------------------------------------------------------
                                                           Cumulative
                 Burn rate (kg/hr-dry)                   Probability (P)
------------------------------------------------------------------------
0.00..................................................         0.000
0.05..................................................         0.002
0.10..................................................         0.007
0.15..................................................         0.012
0.20..................................................         0.016
0.25..................................................         0.021
0.30..................................................         0.028
0.35..................................................         0.033
0.40..................................................         0.041
0.45..................................................         0.054
0.50..................................................         0.065
0.55..................................................         0.086
0.60..................................................         0.100
0.65..................................................         0.121
0.70..................................................         0.150
0.75..................................................         0.185
0.80..................................................         0.220
0.85..................................................         0.254
0.90..................................................         0.300
0.95..................................................         0.328
1.00..................................................         0.380
1.05..................................................         0.407
1.10..................................................         0.460
1.15..................................................         0.490
1.20..................................................         0.550
1.25..................................................         0.572
1.30..................................................         0.620
1.35..................................................         0.654
1.40..................................................         0.695
1.45..................................................         0.722
1.50..................................................         0.750
1.55..................................................         0.779
1.60..................................................         0.800
1.65..................................................         0.825
1.70..................................................         0.840
1.75..................................................         0.857
1.80..................................................         0.875
1.85..................................................         0.882
1.90..................................................         0.895
1.95..................................................         0.906
2.00..................................................         0.912
2.05..................................................         0.920
2.10..................................................         0.925
2.15..................................................         0.932

[[Page 1112]]

 
2.20..................................................         0.936
2.25..................................................         0.940
2.30..................................................         0.945
2.35..................................................         0.951
2.40..................................................         0.956
2.45..................................................         0.959
2.50..................................................         0.964
2.55..................................................         0.968
2.60..................................................         0.972
2.65..................................................         0.975
2.70..................................................         0.977
2.75..................................................         0.979
2.80..................................................         0.980
2.85..................................................         0.981
2.90..................................................         0.982
2.95..................................................         0.984
3.00..................................................         0.984
3.05..................................................         0.985
3.10..................................................         0.986
3.15..................................................         0.987
3.20..................................................         0.987
3.25..................................................         0.988
3.30..................................................         0.988
3.35..................................................         0.989
3.40..................................................         0.989
3.45..................................................         0.989
3.50..................................................         0.990
3.55..................................................         0.991
3.60..................................................         0.991
3.65..................................................         0.992
3.70..................................................         0.992
3.75..................................................         0.992
3.80..................................................         0.993
3.85..................................................         0.994
3.90..................................................         0.994
3.95..................................................         0.994
4.00..................................................         0.994
4.05..................................................         0.995
4.10..................................................         0.995
4.15..................................................         0.995
4.20..................................................         0.995
4.25..................................................         0.995
4.30..................................................         0.996
4.35..................................................         0.996
4.40..................................................         0.996
4.45..................................................         0.996
4.50..................................................         0.996
4.55..................................................         0.996
4.60..................................................         0.996
4.65..................................................         0.996
4.70..................................................         0.996
4.75..................................................         0.997
4.80..................................................         0.997
4.85..................................................         0.997
4.90..................................................         0.997
4.95..................................................         0.997
5.00..................................................         1.000
------------------------------------------------------------------------

Method 28A--Measurement of Air To Fuel Ratio and Minimum Achievable Burn 
                     Rates for Wood-Fired Appliances

                     1. Applicability and Principle

    1.1 Applicability. This method is applicable for the measurement of 
air to fuel ratios and minimum achievable burn rates, for determining 
whether a wood-fired appliance is an affected facility, as specified in 
40 CFR 60.530.
    1.2 Principle. A gas sample is extracted from a location in the 
stack of a wood-fired appliance while the appliance is operating at a 
prescribed set of conditions. The gas sample is analyzed for percent 
carbon dioxide (CO2), percent oxygen (O2), and 
percent carbon monoxide (CO). These stack gas components are measured 
for determining dry molecular weight of exhaust gas. Total moles of 
exhaust gas are determined stoichiometrically. Air to fuel ratio is 
determined by relating the mass of dry combustion air to the mass of dry 
fuel consumed.

                             2. Definitions

    2.1 Burn Rate, Firebox, Secondary Air Supply, Test Facility, Test 
Fuel Charge, Test Fuel Crib, Test Fuel Loading Density, Test Fuel Piece, 
Test Run, Usable Firebox Volume, and Wood Heater. Same as Method 28, 
Sections 2.1 and 2.3 to 2.12.
    2.2 Air to Fuel Ratio. Ratio of the mass of dry combustion air 
introduced into the firebox, to the mass of dry fuel consumed (grams of 
dry air per gram of dry wood burned).

                              3. Apparatus

    3.1 Test Facility. Insulated Solid Pack Chimney, Platform Scale and 
Monitor, Room Temperature Monitor, Balance, Moisture Meter, Anemometer, 
Barometer, Draft Gauge, and Humidity Gauge. Same as Method 28, Sections 
3.1, 3.2, and 3.4 to 3.10, respectively.
    3.2 Sampling System. Probe, Condenser, Valve, Pump, Rate Meter, 
Flexible Bag, Pressure Gauge, and Vacuum Gauge. Same as Method 3, 
Sections 2.2.1 to 2.2.8, respectively. The sampling systems described in 
Method 5H, Sections 2.2.1, 2.2.2, and 2.2.3, may be used.
    3.3 Analysis. Orsat analyzer, same as Method 3, Section 2.3; or 
instrumental analyzers, same as Method 5H, Sections 2.2.4 and 2.2.5, for 
CO2 and CO analyzers, except use a CO analyzer with a range 
of 0 to 5 percent and use a CO2 analyzer with a range of 0 to 
5 percent. Use an O2 analyzer capable of providing a measure 
of O2 in the range of 0 to 25 percent by volume at least once 
every 10 minutes. Prepare cylinder gases for the three analyzers as 
described in Method 5H, Section 3.3.

                           4. Test Preparation

    4.1 Test Facility, Wood Heater Appliance Installation, and Test 
Facility Conditions. Same as Method 28, Sections 4.1.1 and 4.1.2, 
respectively, with the exception that barometric dampers or other 
devices designed to introduce dilution air downstream of the firebox 
shall be sealed.
    4.2 Wood Heater Air Supply Adjustments. This section describes how 
dampers are to be

[[Page 1113]]

set or adjusted and air inlet ports closed or sealed during Method 28A 
tests. The specifications in this section are intended to ensure that 
affected facility determinations are made on the facility configurations 
that could reasonably be expected to be employed by the user. They are 
also intended to prevent circumvention of the standard through the 
addition of an air port that would often be blocked off in actual use. 
These specifications are based on the assumption that consumers will 
remove such items as dampers or other closure mechanism stops if this 
can be done readily with household tools; that consumers will block air 
inlet passages not visible during normal operation of the appliance 
using aluminum tape or parts generally available at retail stores; and 
that consumers will cap off any threaded or flanged air inlets. They 
also assume that air leakage around glass doors, sheet metal joints or 
through inlet grilles visible during normal operation of the appliance 
would not be further blocked or taped off by a consumer.
    It is not the intention of this section to cause an appliance that 
is clearly designed, intended, and, in most normal installations, used 
as a fireplace to be converted into a wood heater for purposes of 
applicability testing. Such a fireplace would be identifiable by such 
features as large or multiple glass doors or panels that are not 
gasketed, relatively unrestricted air inlets intended, in large part, to 
limit smoking and fogging of glass surfaces, and other aesthetic 
features not normally included in wood heaters.
    4.2.1 Adjustable Air Supply Mechanisms. Any commercially available 
flue damper, other adjustment mechanism or other air inlet port that is 
designed, intended or otherwise reasonably expected to be adjusted or 
closed by consumers, installers, or dealers and which could restrict air 
into the firebox shall be set so as to achieve minimum air into the 
firebox, i.e., closed off or set in the most closed position.
    Flue dampers, mechanisms and air inlet ports which could reasonably 
be expected to be adjusted or closed would include:
    (a) All internal or externally adjustable mechanisms (including 
adjustments that affect the tightness of door fittings) that are 
accessible either before and/or after installation.
    (b) All mechanisms, other inlet ports, or inlet port stops that are 
identified in the owner's manual or in any dealer literature as being 
adjustable or alterable. For example, an inlet port that could be used 
to provide access to an outside air duct but which is identified as 
being closable through use of additional materials whether or not they 
are supplied with the facility.
    (c) Any combustion air inlet port or commercially available flue 
damper or mechanism stop, which would readily lend itself to closure by 
consumers who are handy with household tools by the removal of parts or 
the addition of parts generally available at retail stores (e.g., 
addition of a pipe cap or plug, addition of a small metal plate to an 
inlet hole on a nondecorative sheet metal surface, or removal of riveted 
or screwed damper stops).
    (d) Any flue damper, other adjustment mechanisms or other air inlet 
ports that are found and documented in several (e.g., a number 
sufficient to reasonably conclude that the practice is not unique or 
uncommon) actual installations as having been adjusted to a more closed 
position, or closed by consumers, installers, or dealers.
    4.2.2 Air Supply Adjustments During Test. The test shall be 
performed with all air inlets identified under this section in the 
closed or most closed position or in the configuration which otherwise 
achieves the lowest air inlet (e.g., greatest blockage).
    For the purposes of this section, air flow shall not be minimized 
beyond the point necessary to maintain combustion or beyond the point 
that forces smoke into the room.
    Notwithstanding Section 4.2.1, any flue damper, adjustment mechanism 
or air inlet port (whether or not equipped with flue dampers or 
adjusting mechanisms) that is visible during normal operation of the 
appliance and which could not reasonably be closed further or blocked 
except through means that would significantly degrade the aesthetics of 
the facility (e.g., through use of duct tape) will not be closed further 
or blocked.
    4.3 Test Fuel Properties and Test Fuel Charge Specifications. Same 
as Method 28, Sections 4.2 to 4.3, respectively.
    4.4 Sampling System.
    4.4.1 Sampling Location. Same as Method 5H, Section 5.1.2.
    4.4.2 Sampling System Set Up. Set up the sampling equipment as 
described in Method 3, Section 3.2, or as in Method 3A, Section 7.

                              5. Procedures

    5.1 Pretest Preparation. Same as Method 28, Sections 6.2.1 and 6.2.3 
to 6.2.5.
    5.2 Pretest Ignition. Same as Method 28, Section 6.3. Set the wood 
heater air supply settings to achieve a burn rate in Category 1 or the 
lowest achievable burn rate (see Section 4.2).
    5.3 Test Run. Same as Method 28, Section 6.4. Begin sample 
collection at the start of the test run as defined in Method 28, Section 
6.4.1. If Method 3 is used, collect a minimum of two bag samples 
simultaneously at a constant sampling rate for the duration of the test 
run. A minimum sample volume of 30 1 per bag is recommended. If 
instrumental gas concentration measurement procedures are used, conduct 
the gas measurement system performance specifications checks as 
described in Method 5H, Sections 6.7, 6.8, and 6.9. The zero drift and 
calibration drift limits

[[Page 1114]]

for all three analyzers shall be 0.2 percent O2, 
CO2, or CO, as applicable, or less. Other measurement system 
performance specifications are as defined in Method 5H, Section 4. 
Sample at a constant rate for the duration of the test run.
    5.3.1 Data Recording. Record wood heater operational data, test 
facility temperature, sample train flow rate, and fuel weight data at 
10-minute intervals.
    5.3.2 Test Run Completion. Same as Method 28, Section 6.4.6.
    5.4 Analysis Procedure.
    5.4.1 Method 3 Integrated Bag Samples. Within 4 hours after the 
sample collection, analyze each bag sample for percent CO2, 
O2, and CO using an Orsat analyzer as described in Method 3, 
Sections 4.2.5 through 4.2.7.
    5.4.2 Instrumental Analyzers. Average the percent CO2, 
CO, and O2 values for the test run.
    5.5 Quality Control Procedures.
    5.5.1 Data Validation. The following quality control procedure is 
suggested to provide a check on the quality of the data.
    5.5.1.1 Calculate a fuel factor, F0, using the following 
equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.234

where:

%O2 Percent O2 by volume (dry basis).
%CO2 Percent CO2 by volume (dry basis).
20.9 Percent O2 by volume in ambient air.

If CO is present in quantities measurable by this method, adjust the 
O2 and CO2 values before performing the 
calculation for F0 as follows:

%CO2 (adj) = %CO2 + %CO
%O2 (adj) = %O2 - 0.5 %CO

where:

%CO = Percent CO by volume (dry basis).
    5.5.1.2  Compare the calculated F0 factor with the 
expected F0 range for wood (1.000 - 1.120). Calculated 
F0 values beyond this acceptable range should be investigated 
before accepting the test results. For example, the strength of the 
solutions in the gas analyzer and the analyzing technique should be 
checked by sampling and analyzing a known concentration, such as air. If 
no detectable or correctable measurement error can be identified, the 
test should be repeated. Alternatively, determine a range of air to fuel 
ratio results that could include the correct value by using an 
F0 value of 1.05 and calculating a potential range of 
CO2 and O2 values. Acceptance of such results will 
be based on whether the calculated range includes the exemption limit 
and the judgment of the administrator.
    5.5.1.3  Method 3 Analyses. Compare the results of the analyses of 
the two bag samples. If all the gas components (O2, CO, and 
CO2) values for the two analyses agree within 0.5 percent 
(e.g., 6.0 percent O2 for bag 1 and 6.5 percent O2 
for bag 2, agree within 0.5 percent), the results of the bag analyses 
may be averaged for the calculations in Section 6. If the analysis 
results do not agree within 0.5 percent for each component, calculate 
the air-to-fuel ratio using both sets of analyses and report the 
results.

                             6. Calculations

    Carry out calculations, retaining at least one extra decimal figure 
beyond that of the acquired data. Round off figure after the final 
calculation. Other forms of the equations may be used as long as they 
give equivalent results.
    6.1  Nomenclature.
Md=Dry molecular weight, g/g-mole(lb/lb-mole).
%CO2=Percent CO2 by volume (dry basis).
%O2=Percent O2 by volume (dry basis).
%CO=Percent CO by volume (dry basis).
%N2=Percent N2 by volume (dry basis).
NT=Total gram-moles of dry exhaust gas per kg of wood burned 
          (lb-moles/lb).
YCO2=Measured mole fraction of CO2 (e.g., 10 
          percent CO2=.10 mole fraction), g/g-mole (lb/lb-
          mole).
YCO=Measured mole fraction of CO (e.g., 1 percent CO=.01 mole 
          fraction), g/g-mole (lb/lb-mole).
YHC=Assumed mole fraction of HC (dry as CH4)
    =0.0088 for catalytic wood heaters;
    =0.0132 for noncatalytic wood heaters.
    =0.0080 for pellet-fired wood heaters.
0.280=Molecular weight of N2 or CO, divided by 100.
0.320=Molecular weight of O2 divided by 100.
0.440=Molecular weight of CO2 divided by 100.
42.5=Gram-moles of carbon in 1 kg of dry wood assuming 51 percent carbon 
          by weight dry basis (.0425 lb/lb).
510=Grams of carbon in exhaust gas per kg of wood burned.
1,000=Grams in 1 kg.
    6.2  Dry Molecular Weight. Use Equation 28a-1 to calculate the dry 
molecular weight of the stack gas.
Md=0.440(%CO2)+0.320(%O)2)+0.280(%N2
          +%CO)      Eq. 28a-1
    Note: The above equation does not consider argon in air (about 0.9 
percent, molecular weight of 37.7). A negative error of about 0.4 
percent is introduced. The tester may opt to include argon in the 
analysis using procedures subject to approval of the Administrator.
    6.3  Dry Moles of Exhaust Gas. Use Equation 28a-2 to calculate the 
total moles of dry exhaust gas produced per kilogram of dry wood burned.

[[Page 1115]]

[GRAPHIC] [TIFF OMITTED] TC16NO91.235

    6.4  Air to Fuel Ratio. Use Equation 28a-3 to calculate the air to 
fuel ratio on a dry mass basis.
[GRAPHIC] [TIFF OMITTED] TC16NO91.236

    6.5  Burn Rate. Calculate the fuel burn rate as in Method 28, 
Section 8.3.

                             7. Bibliography

    Same as Method 3, Section 7, and Method 5H, Section 7.

  Method 29--Determination of Metals Emissions from Stationary Sources

                     1. Applicability and Principle

    1.1  Applicability. This method is applicable to the determination 
of antimony (Sb), arsenic (As), barium (Ba), beryllium (Be), cadmium 
(Cd), chromium (Cr), cobalt (Co), copper (Cu), lead (Pb), manganese 
(Mn), mercury (Hg), nickel (Ni), phosphorus (P), selenium (Se), silver 
(Ag), thallium (T1), and zinc (Zn) emissions from stationary sources. 
This method may be used to determine particulate emissions in addition 
to the metals emissions if the prescribed procedures and precautions are 
followed.
    1.1.1  Hg emissions can be measured, alternatively, using EPA Method 
101A of Appendix B, 40 CFR Part 61. Method 101-A measures only Hg but it 
can be of special interest to sources which need to measure both Hg and 
Mn emissions.
    1.2  Principle. A stack sample is withdrawn isokinetically from the 
source, particulate emissions are collected in the probe and on a heated 
filter, and gaseous emissions are then collected in an aqueous acidic 
solution of hydrogen peroxide (analyzed for all metals including Hg) and 
an aqueous acidic solution of potassium permanganate (analyzed only for 
Hg). The recovered samples are digested, and appropriate fractions are 
analyzed for Hg by cold vapor atomic absorption spectroscopy (CVAAS) and 
for Sb, As, Ba, Be, Cd, Cr, Co, Cu, Pb, Mn, Ni, P, Se, Ag, Tl, and Zn by 
inductively coupled argon plasma emission spectroscopy (ICAP) or atomic 
absorption spectroscopy (AAS). Graphite furnace atomic absorption 
spectroscopy (GFAAS) is used for analysis of Sb, As, Cd, Co, Pb, Se, and 
Tl if these elements require greater analytical sensitivity than can be 
obtained by ICAP. If one so chooses, AAS may be used for analysis of all 
listed metals if the resulting in-stack method detection limits meet the 
goal of the testing program. Similarly, inductively coupled plasma-mass 
spectroscopy (ICP-MS) may be used for analysis of Sb, As, Ba, Be, Cd, 
Cr, Co, Cu, Pb, Mn, Ni, As, Tl and Zn.

        2. Range, Detection Limits, Precision, and Interferences

    2.1  Range. For the analysis described and for similar analyses, the 
ICAP response is linear over several orders of magnitude. Samples 
containing metal concentrations in the nanograms per ml (ng/ml) to 
micrograms per ml (g/ml) range in the final analytical solution 
can be analyzed using this method. Samples containing greater than 
approximately 50 g/ml As, Cr, or Pb should be diluted to that 
level or lower for final analysis. Samples containing greater than 
approximately 20 g/ml of Cd should be diluted to that level 
before analysis.
    2.2  Analytical Detection Limits. (Note: See section 2.3 for the 
description of in-stack detection limits.)
    2.2.1  ICAP analytical detection limits for the sample solutions 
(based on Method 6010 in EPA Publication SW-846, Third Edition (November 
1986) including updates I, II, IIA, and IIB, as incorporated by 
reference in Sec. 60.17(i)) are approximately as follows: Sb (32 ng/ml), 
As (53 ng/ml), Ba (2 ng/ml), Be (0.3 ng/ml), Cd (4 ng/ml), Cr (7 ng/ml), 
Co (7 ng/ml), Cu (6 ng/ml), Pb (42 ng/ml), Mn (2 ng/ml), Ni (15 ng/ml), 
P (75 ng/ml), Se (75 ng/ml), Ag (7 ng/ml), Tl (40 ng/ml), and Zn (2 ng/
ml). ICP-MS analytical detection limits (based on based on Method 6020 
in EPA Publication SW-846, Third Edition (November 1986) as incorporated 
by reference in Sec. 60.17(i)) are lower generally by a factor of ten or 
more. Be is lower by a factor of three. The actual sample analytical 
detection limits are sample dependent and may vary due to the sample 
matrix.
    2.2.2  The analytical detection limits for analysis by direct 
aspiration AAS are approximately as follow: Sb (200 ng/ml), As (2 ng/
ml), Ba (100 ng/ml), Be (5 ng/ml), Cd (5 ng/ml), Cr (50 ng/ml), Co (50 
ng/ml), Cu (20 ng/ml), Pb (100 ng/ml), Mn (10 ng/ml), Ni (40 ng/ml), Se 
(2 ng/ml), Ag (10 ng/ml), Tl (100 ng/ml), and Zn (5 ng/ml).
    2.2.3  The detection limit for Hg by CVAAS (on the resultant volume 
of the disgestion of the aliquots taken for Hg analyses) can be 
approximately 0.02 to 0.2ng/ml, depending upon the type of CVAAS 
analytical instrument used.
    2.2.4  The use of GFAAS can enhance the detection limits compared to 
direct aspiration AAS as follows: Sb (3 ng/ml), As (1 ng/ml), Be (0.2 
ng/ml), Cd (0.1 ng/ml), Cr (1 ng/ml), Co (1 ng/ml), Pb (1 ng/ml), Se (2 
ng/ml), and T1 (ng/ml).
    2.3  In-stack Detection Limits.
    2.3.1  For test planning purposes in-stack detection limits can be 
developed by using the following information (1) the procedures

[[Page 1116]]

described in this method, (2) the analytical detection limits described 
in Section 2.2 and in EPA Publication SW-846, Third Edition (November 
1986) including updates I, II, IIA and IIB, as incorporated by reference 
in Sec. 60.17(i), (3) the normal volumes of 300 ml (Analytical Fraction 
1) for the front-half and 150 ml (Analytical Fraction 2A) for the back-
half samples, and (4) a stack gas sample volume of 1.25 m\3\. The 
resultant in-stack method detection limits for the above set of 
conditions are presented in Table 29-1 and were calculated by using Eq. 
29-1.

A x B/C=D      Eq. 29-1

Where:

A=Analytical detectin limit, g/ml.
B=Liquid volume of digested sample prior to aliquotting for analysis, 
          Ml.
C=Stack sample gas volume, dsm\3\.
D=In-stack detection limit, g/m\3\.

   Table 29-1.--In-Stack Method Detection Limits (g/m \3\) for the Front-Half, the Back-Half, and the Total Sampling Train Using ICAP and AAS
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                         Front-half: Probe and                                   Back-half: Impingers (4-6)
                Metal                            filter              Back-half: Impingers 1-3                a                       Total train:
--------------------------------------------------------------------------------------------------------------------------------------------------------
Antimony............................  \1\ 7.7 (0.7)                \1\ 3.8 (0.4)                ...........................  \1\ 11.5 (1.1)
Arsenic.............................  \1\ 12.7 (0.3)               \1\ 6.4 (0.1)                ...........................  \1\ 19.1 (0.4)
Barium..............................  0.5                          0.3                          ...........................  0.8
Beryllium...........................  \1\ 0.07 (0.05)              \1\ 0.04 (0.03)              ...........................  \1\ 0.11 (0.08)
Cadmium.............................  \1\ 1.0 (0.02)               \1\ 0.5 (0.01)               ...........................  \1\ 1.5 (0.03)
Chromium............................  \1\ 1.7 (0.2)                \1\ 0.8 (0.1)                ...........................  \1\ 2.5 (0.3)
Cobalt..............................  \1\ 1.7 (0.2)                \1\ 0.8 (0.1)                ...........................  \1\ 2.5 (0.3)
Copper..............................  1.4                          0.7                          ...........................  2.1
Lead................................  \1\ 10.1 (0.2)               \1\ 5.0 (0.1)                ...........................  \1\ 15.1 (0.3)
Manganese...........................  \1\ 0.5 (0.2)                \1\ 0.2 (0.1)                ...........................  \1\ 0.7 (0.3)
Mercury.............................  \2\ 0.06                     \2\ 0.3                      \2\ 0.2                      \2\ 0.56
Nickel..............................  3.6                          1.8                          ...........................  5.4
Phosphorus..........................  18                           9                            ...........................  27
Selenium............................  \1\ 18 (0.5)                 \1\ 9 (0.3)                  ...........................  \1\ 27 (0.8)
Silver..............................  1.7                          0.9                          ...........................  2.6
Thallium............................  \1\ 9.6 (0.2)                \1\ 4.8 (0.1)                ...........................  \1\ 14.4 (0.3)
Zinc................................  0.5                          0.3                          ...........................  0.8
--------------------------------------------------------------------------------------------------------------------------------------------------------
a Mercury analysis only.
\1\ Detection limit when analyzed by GFAAS.
\2\ Detection limit when analyzed by CVAAS, estimated for Back-Half and Total Train. See Sections 2.2 and 5.4.3.
 
Note: Actual method in-stack detection limits may vary from these values, as described in Section 2.3.3.

    2.3.2  To ensure optimum precision/resolution in the analyses, the 
target concentrations of metals in the analytical solutions should be at 
least ten times their respective analytical detection limits. Under 
certain conditions, and with greater care in the analytical procedure, 
these concentrations can be as low as approximately three times the 
respective analytical detection limits without seriously impairing the 
precision of the analyses. On at least one sample run in the source 
test, and for each metal analyzed, perform either repetitive analyses, 
Method of Standard Additions, serial dilution, or matrix spike addition, 
etc., to document the quality of the data.
    2.3.3  Actual in-stack method detection limits are based on actual 
source sampling parameters and analytical results as described above. If 
required, the method in-stack detection limits can be improved over 
those shown in Table 29-1 for a specific test by either increasing the 
sampled stack gas volume, reducing the total volume of the digested 
samples, improving the analytical detection limits, or any combination 
of the three. For extremely low levels of Hg only, the aliquot size 
selected for digestion and analysis can be increased to as much as 10 
ml, thus improving the in-stack detection limit by a factor of ten 
compared to a 1 ml aliquot size.
    2.3.3.1  A nominal one hour sampling run will collect a stack gas 
sampling volume of about 1.25 m3. If the sampling time is 
increased to four hours and 5 m3 are collected, the in-stack 
method detection limits would be improved by a factor of four compared 
to the values shown in Table 29-1.
    2.3.3.2  The in-stack detection limits assume that all of the sample 
is digested and the final liquid volumes for analysis are the normal 
values of 300 ml for Analytical Fraction 1, and 150 ml for Analytical 
Fraction 2A. If the volume of Analytical Fraction 1 is reduced from 300 
to 30 ml, the in-stack detection limits for that fraction of the sample 
would be improved by a factor of ten. If the volume of Analytical 
Fraction 2A is reduced from 150 to 25 ml, the in-stack detection limits 
for that fraction of the sample would be improved by a factor of six. 
Matrix effect checks are necessary on sample analyses and typically are 
of much greater significance for samples that have been concentrated to

[[Page 1117]]

less than the normal original sample volume. Reduction of Analytical 
Fractions 1 and 2A to volumes of less than 30 and 25 ml, respectively, 
could interfere with the redissolving of the residue and could increase 
interference by other compounds to an intolerable level.
    2.3.3.3  When both of the modifications described in Sections 
2.3.3.1 and 2.3.3.2 are used simultaneously on one sample, the resultant 
improvements are multiplicative. For example, an increase in stack gas 
volume by a factor of four and a reduction in the total liquid sample 
digested volume of both Analytical Fractions 1 and 2A by a factor of six 
would result in an improvement by a factor of twenty-four of the in-
stack method detection limit.
    2.4  Precision. The precision (relative standard deviation) for each 
metal detected in a method development test performed at a sewage sludge 
incinerator were found to be as follows: Sb (12.7 percent), As (13.5 
percent), Ba (20.6 percent), Cd (11.5 percent), Cr (11.2 percent), Cu 
(11.5 percent), Pb (11.6 percent), P (14.6 percent), Se (15.3 percent), 
Tl (12.3 percent), and Zn (11.8 percent). The precision for Ni was 7.7 
percent for another test conducted at a source simulator. Be, Mn, and Ag 
were not detected in the tests. However, based on the analytical 
detection limits of the ICAP for these metals, their precisions could be 
similar to those for the other metals when detected at similar levels.
    2.5  Interferences. Iron (Fe) can be a spectral interference during 
the analysis of As, Cr, and Cd by ICAP. Aluminum (Al) can be a spectral 
interference during the analysis of As and Pb by ICAP. Generally, these 
interferences can be reduced by diluting the analytical sample, but such 
dilution raises the in-stack detection limits. Background and overlap 
corrections may be used to adjust for spectral interferences. Refer to 
Method 6010 in EPA Publication SW-846 Third Edition (November 1986) 
including updates I, II, IIA and IIB, as incorporated by reference in 
Sec. 60.17(i) the other analytical methods used for details on potential 
interferences to this method. For all GFAAS analyses, use matrix 
modifiers to limit interferences, and matrix match all standards.

                              3. Apparatus

    3.1  Sampling. A schematic of the sampling train is shown in Figure 
29-1. It has general similarities to the Method 5 train.

[[Page 1118]]

[GRAPHIC] [TIFF OMITTED] TR25AP96.000

    3.1.1  Probe Nozzle (Probe Tip) and Borosilicate or Quartz Glass 
Probe Liner. Same as Method 5, Sections 2.1.1 and 2.1.2, except that 
glass nozzles are required unless alternate tips are constructed of 
materials that are free from contamination and will not interfere with 
the sample. If a probe tip other than glass is used, no correction to 
the

[[Page 1119]]

sample test results to compensate for the nozzle's effect on the sample 
is allowed. Probe fittings of plastic such as Teflon, polypropylene, 
etc. are recommended instead of metal fittings to prevent contamination. 
If one chooses to do so, a single glass piece consisting of a combined 
probe tip and probe liner may be used.
    3.1.2  Pitot Tube and Differential Pressure Gauge. Same as Method 2, 
Sections 2.1 and 2.2, respectively.
    3.1.3  Filter Holder. Glass, same as Method 5, Section 2.1.5, except 
use a Teflon filter support or other non-metallic, non-contaminating 
support in place of the glass frit.
    3.1.4  Filter Heating System. Same as Method 5, Section 2.1.6.
    3.1.5  Condenser. Use the following system for condensing and 
collecting gaseous metals and determining the moisture content of the 
stack gas. The condensing system shall consist of four to seven 
impingers connected in series with leak-free ground glass fittings or 
other leak-free, non-contaminating fittings. Use the first impinger as a 
moisture trap. The second impinger (which is the first HNO3/
H2O2 impinger) shall be identical to the first 
impinger in Method 5. The third impinger (which is the second 
HNO3/H2O2 impinger) shall be a 
Greenburg Smith impinger with the standard tip as described for the 
second impinger in Method 5, Section 2.1.7. The fourth (empty) impinger 
and the fifth and sixth (both acidified KMnO4) impingers are 
the same as the first impinger in Method 5. Place a thermometer capable 
of measuring to within 1  deg.C (2  deg.F) at the outlet of the last 
impinger. If no Hg analysis is planned, then the fourth, fifth, and 
sixth impingers are not used.
    3.1.6  Metering System, Barometer, and Gas Density Determination 
Equipment. Same as Method 5, Sections 2.1.8 through 2.1.10, 
respectively.
    3.1.7  Teflon Tape. For capping openings and sealing connections, if 
necessary, on the sampling train.
    3.2.  Sample Recovery. Same as Method 5, Sections 2.2.1 through 
2.2.8 (Probe-Liner and Probe-Nozzle Brushes or Swabs, Wash Bottles, 
Sample Storage Containers, Petri Dishes, Glass Graduated Cylinder, 
Plastic Storage Containers, Funnel and Rubber Policeman, and Glass 
Funnel), respectively, with the following exceptions and additions:
    3.2.1  Non-metallic Probe-Liner and Probe-Nozzle Brushes or Swabs. 
Use non-metallic probe-liner and probe-nozzle brushes or swabs for 
quantitative recovery of materials collected in the front-half of the 
sampling train.
    3.2.2  Sample Storage Containers. Use glass bottles (see the 
Precaution: in Section 4.3.2 of this Method) with Teflon-lined caps that 
are non-reactive to the oxidizing solutions, with capacities of 1000- 
and 500-ml, for storage of acidified KMnO4- containing 
samples and blanks. Glass or polyethylene bottles may be used for other 
sample types.
    3.2.3  Graduated Cylinder. Glass or equivalent.
    3.2.4  Funnel. Glass or equivalent.
    3.2.5  Labels. For identifying samples.
    3.2.6  Polypropylene Tweezers and/or Plastic Gloves. For recovery of 
the filter from the sampling train filter holder.
    3.3  Sample Preparation and Analysis.
    3.3.1  Volumetric Flasks, 100-ml, 250-ml, and 100-ml. For 
preparation of standards and sample dilutions.
    3.3.2  Graduated Cylinders. For preparation of reagents.
    3.3.3  ParrR Bombs or Microwave Pressure Relief Vessels 
with Capping Station (CEM Corporation model or equivalent). For sample 
digestion.
    3.3.4  Beakers and Watch Glasses. 250-ml beakers, with watch glass 
covers, for sample digestion.
    3.3.5  Ring Stands and Clamps. For securing equipment such as 
filtration apparatus.
    3.3.6  Filter Funnels. For holding filter paper.
    3.3.7  Disposable Pasteur Pipets and Bulbs.
    3.3.8  Volumetric Pipets.
    3.3.9  Analytical Balance. Accurate to within .01 mg.
    3.3.10  Microwave or Conventional Oven. For heating samples at fixed 
power levels or temperatures, respectively.
    3.3.11  Hot Plates.
    3.3.12  Atomic Absorption Spectrometer (AAS). Equipped with a 
background corrector.
    3.3.12.1  Graphite Furnace Attachment. With Sb, As, Cd, Co, Pb, Se, 
and Tl hollow cathode lamps (HCLs) or electrodeless discharge lamps 
(EDLs). Same as Methods 7041 (Sb), 7060 (As), 7131 (Cd), 7201 (Co), 7421 
(Pb), 7740 (Se), and 7841 (Tl) in EPA publication SW-846 Third Edition 
(November 1986) including updates I, II, IIA and IIB, as incorporated by 
reference in Sec. 60.17(i).
    3.3.12.2  Cold Vapor Mercury Attachment. With a mercury HCL or EDL, 
an air recirculation pump, a quartz cell, an aerator apparatus, and a 
heat lamp or desiccator tube. The heat lamp shall be capable of raising 
the temperature at the quartz cell by 10  deg.C above ambient, so that 
no condensation forms on the wall of the quartz cell. Same as Method 
6020 in EPA publication SW-846 Third Edition (November 1986) including 
updates I, II, IIA and IIB, as incorporated by reference in 
Sec. 60.17(i). See Note No. 2: Section 5.4.3 for other acceptable 
approaches for analysis of Hg in which analytical detection limits of 
0.002 ng/ml were obtained.
    3.3.13  Inductively Coupled Argon Plasma Spectrometer. With either a 
direct or sequential reader and an alumina torch. Same as EPA Method 
6010 in EPA publication SW-846 Third Edition (November 1986) including

[[Page 1120]]

updates I, II, IIA and IIB, as incorporated by reference in 
Sec. 60.17(i).
    3.3.14  Inductively Coupled Plasma-Mass Spectrometer. Same as EPA 
Method 6020 in EPA publication SW-846 Third Edition (November 1986) 
including updates I, II, IIA and IIB, as incorporated by reference in 
Sec. 60.17(i).

                               4. Reagents

    4.1  Unless otherwise indicated, it is intended that all reagents 
conform to the specifications established by the Committee on Analytical 
Reagents of the American Chemical Society, where such specifications are 
available. Otherwise, use the best available grade.
    4.2  Sampling Reagents.
    4.2.1  Sample Filters. Without organic binders. The filters shall 
contain less than 1.3 g/in.2 of each of the metals 
to be measured. Analytical results provided by filter manufacturers 
stating metals content of the filters are acceptable. However, if no 
such results are available, analyze filter blanks for each target metal 
prior to emission testing. Quartz fiber filters meeting these 
requirements are recommended. However, if glass fiber filters become 
available which meet these requirements, they may be used. Filter 
efficiencies and unreactiveness to sulfur dioxide (SO2) or 
sulfur trioxide (SO3) shall be as described in Section 3.1.1 
of Method 5.
    4.2.2  Water. To conform to ASTM Specification D1193-77, Type II 
(incorporated by reference--See Sec. 60.17). If necessary, analyze the 
water for all target metals prior to field use. All target metals should 
be less than 1 ng/ml.
    4.2.3  Nitric Acid (HNO3). Concentrated. Baker Instra-
analyzed or equivalent.
    4.2.4  Hydrochloric Acid (HCL). Concentrated. Baker Instra-analyzed 
or equivalent.
    4.2.5  Hydrogen Peroxide (H2O2), 30 Percent 
(V/V).
    4.2.6  Potassium Permanganate (KMnO4).
    4.2.7  Sulfuric Acid (H2SO4). Concentrated.
    4.2.8  Silica Gel and Crushed Ice. Same as Method 5, Sections 3.1.2 
and 3.1.4, respectively.
    4.3  Pretest Preparation of Sampling Reagents.
    4.3.1  HNO3/H2O2 Absorbing 
Solution, 5 Percent HNO3/10 Percent 
H2O2. Add carefully with stirring 50 ml of 
concentrated HNO3 to a 1000-ml volumeric flask containing 
approximately 500 ml of water, and then add carefully with stirring 333 
ml of 30 percent H2O2. Dilute to volume with 
water. Mix well. This reagent shall contain less than 2 ng/ml of each 
target metal.
    4.3.2  Acidic KMnO4 Absorbing Solution, 4 Percent 
KMnO4 (W/V), 10 Percent H2SO4 (V/V). 
Prepare fresh daily. Mix carefully, with stirring, 100 ml of 
concentrated H2SO4 into approximately 800 ml of 
water, and add water with stirring to make a volume of 1 liter: this 
solution is 10 percent H2SO4 (V/V). Dissolve, with 
stirring, 40 g of KMnO4 into 10 percent 
H2SO4 (V/V) and add 10 percent 
H2SO4 (V/V) with stirring to make a volume of 1 
liter. Prepare and store in glass bottles to prevent degradation. This 
reagent shall contain less than 2 ng/ml of Hg.
Precaution: To prevent autocatalytic decomposition of the permanganate 
solution, filter the solution through Whatman 541 filter paper. Also, 
due to the potential reaction of the potassium permanganate with the 
acid, there could be pressure buildup in the solution storage bottle. 
Therefore these bottles shall not be fully filled and shall be vented to 
relieve excess pressure and prevent explosion potentials. Venting is 
required, but not in a manner that will allow contamination of the 
solution. A No. 70-72 hole drilled in the container cap and Teflon liner 
has been used.
    4.3.3  HNO3, 0.1 N. Add with stirring 6.3 ml of 
concentrated HNO3 (70 percent) to a flask containing 
approximately 900 ml of water. Dilute to 1000 ml with water. Mix well. 
This reagent shall contain less than 2 ng/ml of each target metal.
    4.3.4  HCl, 8 N. Carefully add with stirring 690 ml of concentrated 
HCl to a flask containing 250 ml of water. Dilute to 1000 ml with water. 
Mix well. This reagent shall contain less than 2 ng/ml of Hg.
    4.4  Glassware Cleaning Reagents.
    4.4.1  HNO3, Concentrated. Fisher ACS grade or 
equivalent.
    4.4.2  Water. To conform to ASTM Specification D1193-77, Type II 
(incorporated by reference--See Sec. 60.17).
    4.4.3  HNO3, 10 Percent (V/V). Add with stirring 500 ml 
of concentrated HNO3 to a flask containing approximately 4000 
ml of water. Dilute to 5000 ml with water. Mix well. This reagent shall 
contain less than 2 ng/ml of each target metal.
    4.5  Sample Digestion and Analysis Reagents.
    The metals standards, except Hg, may also be made from solid 
chemicals as described in Citation 3 of the Bibliography. Refer to 
Citations 1, 2, or 5 of the Bibliography for additional information on 
Hg standards. The 1000 g/ml Hg stock solution standard may be 
made according to Section 6.2.5 of Method 101A.
    4.5.1  HCL, Concentrated.
    4.5.2  Hydrofluoric Acid (HF), Concentrated.
    4.5.3  HNO3, Concentrated. Baker Instra-analyzed or 
equivalent.
    4.5.4  HNO3, 50 Percent (V/V). Add with stirring 125 ml 
of concentrated HNO3 to 100 ml of water. Dilute to 250 ml 
with water. Mix well. This reagent shall contain less than 2 ng/ml of 
each target metal.
    4.5.5  HNO3, 5 Percent (V/V). Add with stirring 50 ml of 
concentrated HNO3 to 800 ml of water. Dilute to 1000 ml with 
water. Mix

[[Page 1121]]

well. This reagent shall contain less than 2 ng/ml of each target metal.
    4.5.6  Water. To conform to ASTM Specification D1193-77, Type II 
(incorporated by reference--See Sec. 60.17).
    4.5.7  Hydroxylamine Hydrochloride and Sodium Chloride Solution. See 
Citation 2 of the Bibliography for preparation.
    4.5.8  Stannous Chloride. See Citation 2 of the Bibliography for 
preparation.
    4.5.9  KMnO4, 5 Percent (W/V). See Citation 2 of the 
Bibliography for preparation.
    4.5.10  H2SO4, Concentrated.
    4.5.11  Potassium Persulfate, 5 Percent (W/V). See Citation 2 of the 
Bibliography for preparation.
    4.5.12  Nickel Nitrate, Ni (NO3)2 
6H2O.
    4.5.13  Lanthanum Oxide, La2 O3.
    4.5.14  Hg Standard (AAS Grade), 1000 g/ml.
    4.5.15  Pb Standard (AAS Grade), 1000 g/ml.
    4.5.16  As Standard (AAS Grade), 1000 g/ml.
    4.5.17  Cd Standard (AAS Grade), 1000 g/ml.
    4.5.18  Cr Standard (AAS Grade), 1000 g/ml.
    4.5.19  Sb Standard (AAS Grade), 1000 g/ml.
    4.5.20  Ba Standard (AAS Grade), 1000 g/ml.
    4.5.21  Be Standard (AAS Grade), 1000 g/ml.
    4.5.22  Co Standard (AAS Grade), 1000 g/ml.
    4.5.23  Cu Standard (AAS Grade), 1000 g/ml.
    4.5.24  Mn Standard (AAS Grade), 1000 g/ml.
    4.5.25  Ni Standard (AAS Grade), 1000 g/ml.
    4.5.26  P Standard (AAS Grade), 1000 g/ml.
    4.5.27  Se Standard (AAS Grade), 1000 g/ml.
    4.5.28  Ag Standard (AAS Grade), 1000 g/ml.
    4.5.29  Tl Standard (AAS Grade), 1000 g/ml.
    4.5.30  Zn Standard (AAS Grade), 1000 g/ml.
    4.5.31  Al Standard (AAS Grade), 1000 g/ml.
    4.5.32  Fe Standard (AAS Grade), 1000 g/ml.
    4.5.33  Hg Standards and Quality Control Samples. Prepare fresh 
weekly a 10 g/ml intermediate Hg standard by adding 5 ml of 
1000 g/ml Hg stock solution prepared according to Method 101A 
to a 500-ml volumetric flask; dilute with stirring to 500 ml by first 
carefully adding 20 ml of 15 percent HNO3 and then adding 
water to the 500-ml volume. Mix well. Prepare a 200 ng/ml working Hg 
standard solution fresh daily: add 5 ml of the 10 g/ml 
intermediate standard to a 250-ml volumetric flask, and dilute to 250 ml 
with 5 ml of 4 percent KMnO4, 5 ml of 15 percent 
HNO3, and then water. Mix well. Use at least five separate 
aliquots of the working Hg standard solution and a blank to prepare the 
standard curve. These aliquots and blank shall contain 0.0, 1.0, 2.0, 
3.0, 4.0, and 5.0 ml of the working standard solution containing 0, 200, 
400, 600, 800, and 1000 ng Hg, respectively. Prepare quality control 
samples by making a separate 10 g/ml standard and diluting 
until in the calibration range.
    4.5.34  ICAP Standards and Quality Control Samples. Calibration 
standards for ICAP analysis can be combined into four different mixed 
standard solutions as follows:

               Mixed Standard Solutions for ICAP Analysis
------------------------------------------------------------------------
                Solution                             Elements
------------------------------------------------------------------------
I......................................  As, Be, Cd, Mn, Pb, Se, Zn.
II.....................................  Ba, Co, Cu, Fe.
III....................................  Al, Cr, Ni.
IV.....................................  Ag, P, Sb, Tl.
------------------------------------------------------------------------

Prepare these standards by combining and diluting the appropriate 
volumes of the 1000 g/ml solutions with 5 percent 
HNO3. A minimum of one standard and a blank can be used to 
form each calibration curve. However, prepare a separate quality control 
sample spiked with known amounts of the target metals in quantities in 
the mid-range of the calibration curve. Suggested standard levels are 25 
g/ml for Al, Cr and Pb, 15 g/ml for Fe, and 10 
g/ml for the remaining elements. Prepare any standards 
containing less than 1 g/ml of metal on a daily basis. 
Standards containing greater than 1 g/ml of metal should be 
stable for a minimum of 1 to 2 weeks. For ICP-MS, follow Method 6020 in 
EPA Publication SW-846 Third Edition (November 1986) including updates 
I, II, IIA and IIB, as incorporated by reference in Sec. 60.17(i).
    4.5.35  GFAAS Standards. Sb, As, Cd, Co, Pb, Se, and Tl. Prepare a 
10 g/ml standard by adding 1 ml of 1000 g/ml standard 
to a 100-ml volumetric flask. Dilute with stirring to 100 ml with 10 
percent HNO3. For GFAAS, matrix match the standards. Prepare 
a 100 ng/ml standard by adding 1 ml of the 10 g/ml standard to 
a 100-ml volumetric flask, and dilute to 100 ml with the appropriate 
matrix solution. Prepare other standards by diluting the 100 ng/ml 
standards. Use at least five standards to make up the standard curve. 
Suggested levels are 0, 10, 50, 75, and 100 ng/ml. Prepare quality 
control samples by making a separate 10 g/ml standard and 
diluting until it is in the range of the samples. Prepare any standards 
containing less than 1 g/ml of metal on a daily basis. 
Standards containing greater than 1 g/ml of metal should be 
stable for a minimum of 1 to 2 weeks.
    4.5.36  Matrix Modifiers.
    4.5.36.1  Nickel Nitrate, 1 Percent (V/V). Dissolve 4.956 g of Ni 
(NO3)2&
6H2O or

[[Page 1122]]

other nickel compound suitable for preparation of this matrix modifier 
in approximately 50 ml of water in a 100-ml volumetric flask. Dilute to 
100 ml with water.
    4.5.36.2  Nickel Nitrate, 0.1 Percent (V/V). Dilute 10 ml of 1 
percent nickel nitrate solution to 100 ml with water. Inject an equal 
amount of sample and this modifier into the graphite furnace during 
GFAAS analysis for As.
    4.5.36.3  Lanthanum. Carefully dissolve 0.5864 g of La2 
O3 in 10 ml of concentrated HNO3, and dilute the 
solution by adding it with stirring to approximately 50 ml of water. 
Dilute to 100 ml with water, and mix well. Inject an equal amount of 
sample and this modifier into the graphite furnace during GFAAS analysis 
for Pb.
    4.5.37  Whatman 40 and 541 Filter Papers (or equivalent). For 
filtration of digested samples.

                              5. Procedure

    5.1  Sampling. The complexity of this method is such that, to obtain 
reliable results, both testers and analysts must be trained and 
experienced with the test procedures, including source sampling; reagent 
preparation and handling; sample handling; safety equipment and 
procedures; analytical calculations; reporting; and the specific 
procedural descriptions throughout this method.
    5.1.1  Pretest Preparation. Follow the same general procedure given 
in Method 5, Section 4.1.1, except that, unless particulate emissions 
are to be determined, the filter need not be desiccated or weighed. 
First, rinse all sampling train glassware with hot tap water and then 
wash in hot soapy water. Next, rinse glassware three times with tap 
water, followed by three additional rinses with water. Then soak all 
glassware in a 10 percent (V/V) nitric acid solution for a minimum of 4 
hours, rinse three times with water, rinse a final time with acetone, 
and allow to air dry. Cover all glassware openings where contamination 
can occur until the sampling train is assembled for sampling.
    5.1.2  Preliminary Determinations. Same as Method 5, Section 4.1.2.
    5.1.3  Preparation of Sampling Train.
    5.1.3.1  Set up the sampling train as shown in Figure 29-1. Follow 
the same general procedures given in Method 5, Section 4.1.3, except 
place 100 ml of the HNO3/H2O2 solution 
(Section 4.3.1. of this method) in each of the second and third 
impingers as shown in Figure 29-1. Placee 100 ml of the acidic 
KMnO4 absorbing solution (Section 4.3.2 of this method) in 
each of the fifth and sixth impingers as shown in Figure 29-1, and 
transfer approximately 200 to 300 g of pre-weighed silica gel from its 
container to the last impinger. Alternatively, the silica gel may be 
weighed directly in the impinger just prior to final train assembly.
    5.1.3.2  Based on the specific source sampling conditions, the use 
of an empty first impinger can be eliminated if the moisture to be 
collected in the impingers will be less than approximately 100 ml.
    5.1.3.3  If Hg analysis will not be performed, the fourth, fifth, 
and sixth impingers as shown in Figure 29-1 are not required.
    5.1.3.4  To insure leak-free sampling train connections and to 
prevent possible sample contamination problems, use Teflon tape or other 
non-contaminating material instead of silicone grease.
    Precaution: Exercise extreme care to prevent contamination within 
the train. Prevent the acidic KMnO4 from contacting any 
glassware that contains sample material to be analyzed for Mn. Prevent 
acidic H2O2 from mixing with the acidic 
KMnO4.
    5.1.4  Leak-Check Procedures. Follow the leak-check procedures given 
in Method 5, Section 4.1.4.1 (Pretest Leak-Check), Section 4.1.4.2 
(Leak-Checks During the Sample Run), and Section 4.1.4.3 (Post-Test 
Leak-Checks).
    5.1.5  Sampling Train Operation. Follow the procedures given in 
Method 5, Section 4.1.5. When sampling for Hg, use a procedure analagous 
to that described in Section 7.1.1 of Method 101A, 40 CFR Part 61, 
Appendix B, if necessary to maintain the desired color in the last 
acidified permanganate impinger. For each run, record the data required 
on a data sheet such as the one shown in Figure 5-2 of Method 5.
    5.1.6  Calculation of Percent Isokinetic. Same as Method 5, Section 
4.1.6.
    5.2  Sample Recovery.
    5.2.1  Begin cleanup procedures as soon as the probe is removed from 
the stack at the end of a sampling period. The probe should be allowed 
to cool prior to sample recovery. When it can be safely handled, wipe 
off all external particulate matter near the tip of the probe nozzle and 
place a rinsed, non-contaminating cap over the probe nozzle to prevent 
losing or gaining particulate matter. Do not cap the probe tip tightly 
while the sampling train is cooling; a vacuum can form in the filter 
holder with the undesired result of drawing liquid from the impingers 
onto the filter.
    5.2.2  Before moving the sampling train to the cleanup site, remove 
the probe from the sampling train and cap the open outlet. Be careful 
not to lose any condensate that might be present. Cap the filter inlet 
where the probe was fastened. Remove the umbilical cord from the last 
impinger and cap the impinger. Cap the filter holder outlet and impinger 
inlet. Use non-contaminating caps, whether ground-glass stoppers, 
plastic caps, serum caps, or Teflon tape to close these openings.

[[Page 1123]]

    5.2.3  Alternatively, the following procedure may be used to 
disassemble the train before the probe and filter holder/oven are 
completely cooled: Initially disconnect the filter holder outlet/
impinger inlet and loosely cap the open ends. Then disconnect the probe 
from the filter holder or cyclone inlet and loosely cap the open ends. 
Cap the probe tip and remove the umbilical cord as previously described.
    5.2.4  Transfer the probe and filter-impinger assembly to a cleanup 
area that is clean and protected from the wind and other potential 
causes of contamination or loss of sample. Inspect the train before and 
during disassembly and note any abnormal conditions. Take special 
precautions to assure that all the items necessary for recovery do not 
contaminate the samples. The sample is recovered and treated as follows 
(see schematic in Figures 29-2a and 29-2b):

[[Page 1124]]

[GRAPHIC] [TIFF OMITTED] TR25AP96.001


[[Page 1125]]


[GRAPHIC] [TIFF OMITTED] TR25AP96.002

    5.2.5  Container No. 1 (Sample Filter). Carefully remove the filter 
from the filter holder and place it in its labeled petri dish container. 
To handle the filter, use either acid-washed polypropylene or Teflon 
coated tweezers or clean, disposable surgical gloves rinsed with water 
and dried. If it is necessary

[[Page 1126]]

to fold the filter, make certain the particulate cake is inside the 
fold. Carefully transfer the filter and any particulate matter or filter 
fibers that adhere to the filter holder gasket to the petri dish by 
using a dry (acid-cleaned) nylon bristle brush. Do not use any metal-
containing materials when recovering this train. Seal the labeled petri 
dish.
    5.2.6  Container No. 2. (Acetone Rinse). Perform this procedure only 
if a determination of particulate emissions is to be made. 
Quantitatively recover particulate matter and any condensate from the 
probe nozzle, probe fitting, probe liner, and front half of the filter 
holder by washing these components with a total of 100 ml of acetone, 
while simultaneously taking great care to see that no dust on the 
outside of the probe or other surfaces gets in the sample. The use of 
exactly 100 ml is necessary for the subsequent blank correction 
procedures. Distilled water may be used instead of acetone when approved 
by the Administrator and shall be used when specified by the 
Administrator; in these cases, save a water blank and follow the 
Administrator's directions on analysis.
    5.2.6.1  Carefully remove the probe nozzle, and clean the inside 
surface by rinsing with acetone from a wash bottle while brushing with a 
non-metallic brush. Brush until the acetone rinse shows no visible 
particles, then make a final rinse of the inside surface with acetone.
    5.2.6.2  Brush and rinse the sample exposed inside parts of the 
probe fitting with acetone in a similar way until no visible particles 
remain. Rinse the probe liner with acetone by tilting and rotating the 
probe while squirting acetone into its upper end so that all inside 
surfaces will be wetted with acetone. Allow the acetone to drain from 
the lower end into the sample container. A funnel may be used to aid in 
transferring liquid washings to the container. Follow the acetone rinse 
with a non-metallic probe brush. Hold the probe in an inclined position, 
squirt acetone into the upper end as the probe brush is being pushed 
with a twisting action three times through the probe. Hold a sample 
container underneath the lower end of the probe, and catch any acetone 
and particulate matter which is brushed through the probe until no 
visible particulate matter is carried out with the acetone or until none 
remains in the probe liner on visual inspection. Rinse the brush with 
acetone, and quantitatively collect these washings in the sample 
container. After the brushing, make a final acetone rinse of the probe 
as described above.
    5.2.6.3  It is recommended that two people clean the probe to 
minimize sample losses. Between sampling runs, keep brushes clean and 
protected from contamination. Clean the inside of the front-half of the 
filter holder by rubbing the surfaces with a non-metallic brush and 
rinsing with acetone. Rinse each surface three times or more if needed 
to remove visible particulate. Make a final rinse of the brush and 
filter holder. After all acetone washings and particulate matter have 
been collected in the sample container, tighten the lid so that acetone 
will not leak out when shipped to the laboratory. Mark the height of the 
fluid level to determine whether or not leakage occurred during 
transport. Clearly label the container to identify its contents.
    5.2.7  Container No. 3 (Probe Rinse). Keep the probe assembly clean 
and free from contamination during the probe rinse. Rinse the probe 
nozzle and fitting, probe liner, and front-half of the filter holder 
thoroughly with a total of 100 ml of 0.1 N HNO3, and place 
the wash into a sample storage container.
    (Note: The use of a total of exactly 100 ml is necessary for the 
subsequent blank correction procedures.)
    Perform the rinses as applicable and generally as described in 
Method 12, Section 5.2.2. Record the volume of the rinses. Mark the 
height of the fluid level on the outside of the storage container and 
use this mark to determine if leakage occurs during transport. Seal the 
container, and clearly label the contents. Finally, rinse the nozzle, 
probe liner, and front-half of the filter holder with water followed by 
acetone, and discard these rinses.
    5.2.8  Container No. 4 (Impingers 1 through 3, Moisture Knockout 
Impinger, when used, HNO3/H2O2 
Impingers Contents and Rinses). Due to the potentially large quantity of 
liquid involved, the tester may place the impinger solutions from 
impingers 1 through 3 in more than one container, if necessary. Measure 
the liquid in the first three impingers to within 0.5 ml using a 
graduated cylinder. Record the volume. This information is required to 
calculate the moisture content of the sampled flue gas. Clean each of 
the first three impingers, the filter support, the back half of the 
filter housing, and connecting glassware by thoroughly rinsing with 100 
ml of 0.1 N HNO3 using the procedure as applicable in Method 
12, Section 5.2.4.
    (Note: The use of exactly 100 ml of 0.1 N HNO3 rinse is 
necessary for the subsequent blank correction procedures. Combine the 
rinses and impinger solutions, measure and record the final total 
volume. Mark the height of the fluid level, seal the container, and 
clearly label the contents.)
    5.2.9  Container Nos. 5A (0.1 N HNO3), 5B 
(KMnO4/H2SO4 absorbing solution), and 
5C (8 N HCl rinse and dilution).
    5.2.9.1  When sampling for Hg, pour all the liquid from the impinger 
(normally impinger No. 4) that immediately preceded the two permanganate 
impingers into a graduated cylinder and measure the volume to within 0.5 
ml. This information is required to calculate the moisture content of 
the sampled

[[Page 1127]]

flue gas. Place the liquid in Container No. 5A. Rinse the impinger with 
exactly 100 ml of 0.1 N HNO3 and place this rinse in 
Container No. 5A.
    5.2.9.2 Pour all the liquid from the two permanganate impingers into 
a graduated cylinder and measure the volume to within 0.5 ml. This 
information is required to calculate the moisture content of the sampled 
flue gas. Place this acidic KMnO4 solution into Container No. 
5B. Using a total of exactly 100 ml of fresh acidified KMnO4 
solution for all rinses (approximately 33 ml per rinse), rinse the two 
permanganate impingers and connecting glassware a minimum of three 
times. Pour the rinses into Container No. 5B, carefully assuring 
transfer of all loose precipitated materials from the two impingers. 
Similarly, using 100 ml total of water, rinse the permanganate impingers 
and connecting glass a minimum of three times, and pour the rinses into 
Container 5B, carefully assuring transfer of any loose precipitated 
material. Mark the height of the fluid level, and clearly label the 
contents. Read the Precaution: in Section 4.3.2. NOTE: Due to the 
potential reaction of KMnO4 with acid, pressure buildup can 
occur in the sample storage bottles. Do not fill these bottles 
completely and take precautions to relieve excess pressure. A No. 70-72 
hole drilled in the container cap and Teflon liner has been used 
successfully.
    5.2.9.3 If no visible deposits remain after the water rinse, no 
further rinse is necessary. However, if deposits remain on the impinger 
surfaces, wash them with 25 ml of 8 N HCl, and place the wash in a 
separate sample container labeled No. 5C containing 200 ml of water. 
First, place 200 ml of water in the container. Then wash the impinger 
walls and stem with the HCl by turning the impinger on its side and 
rotating it so that the HC1 contacts all inside surfaces. Use a total of 
only 25 ml of 8 N HCl for rinsing both permanganate impingers combined. 
Rinse the first impinger, then pour the actual rinse used for the first 
impinger into the second impinger for its rinse. Finally, pour the 25 ml 
of 8 N HCl rinse carefully into the container. Mark the height of the 
fluid level on the outside of the container to determine if leakage 
occurs during transport.
    5.2.10  Container No. 6 (Silica Gel). Note the color of the 
indicating silica gel to determine whether it has been completely spent 
and make a notation of its condition. Transfer the silica gel from its 
impinger to its original container and seal it. The tester may use a 
funnel to pour the silica gel and a rubber policeman to remove the 
silica gel from the impinger. The small amount of particles that might 
adhere to the impinger wall need not be removed. Do not use water or 
other liquids to transfer the silica gel since weight gained in the 
silica gel impinger is used for moisture calculations. Alternatively, if 
a balance is available in the field, record the weight of the spent 
silica gel (or silica gel plus impinger) to the nearest 0.5 g.
    5.2.11  Container No. 7 (Acetone Blank). If particulate emissions 
are to be determined, at least once during each field test, place a 100-
ml portion of the acetone used in the sample recovery process into a 
container labeled No. 7. Seal the container.
    5.2.12  Container No. 8A (0.1 N HNO3 Blank). At least 
once during each field test, place 300 ml of the 0.1 N HNO3 
solution used in the sample recovery process into a container labeled 
No. 8A. Seal the container.
    5.2.13  Container No. 8B (Water Blank). At least once during each 
field test, place 100 ml of the water used in the sample recovery 
process into a container labeled No. 8B. Seal the container.
    5.2.14  Container No. 9 (5 Percent HNO3/10 Percent 
H2O2 Blank). At least once during each field test, 
place 200 ml of the 5 Percent HNO3/10 Percent 
H2O2 solution used as the nitric acid impinger 
reagent into a container labeled No. 9. Seal the container.
    5.2.15  Container No. 10 (Acidified KMnO4 Blank). At 
least once during each field test, place 100 ml of the acidified 
KMnO4 solution used as the impinger solution and in the 
sample recovery process into a container labeled No. 10. Prepare the 
container as described in Section 5.2.9.2. Read the Precaution: in 
Section 4.3.2. and read the Note in Section 5.2.9.2.
    5.2.16  Container No. 11 (8 N HCl Blank). At least once during each 
field test, place 200 ml of water into a sample container labeled No. 
11. Then carefully add with stirring 25 ml of 8 N HCl. Mix well and seal 
the container.
    5.2.17  Container No. 12 (Sample Filter Blank). Once during each 
field test, place into a petri dish labeled No. 12 three unused blank 
filters from the same lot as the sampling filters. Seal the petri dish.
    5.3  Sample Preparation. Note the level of the liquid in each of the 
containers and determine if any sample was lost during shipment. If a 
noticeable amount of leakage has occurred, either void the sample or use 
methods, subject to the approval of the Administrator, to correct the 
final results. A diagram illustrating sample preparation and analysis 
procedures for each of the sample train components is shown in Figure 
29-3.
    5.3.1  Container No. 1 (Sample Filter).
    5.3.1.1  If particulate emissions are being determined, first 
desiccate the filter and filter catch without added heat (do not heat 
the filters to speed the drying) and weigh to a constant weight as 
described in Section 4.3 of Method 5.
    5.3.1.2  Following this procedure, or initially, if particulate 
emissions are not being determined in addition to metals analysis, 
divide the filter with its filter catch into portions containing 
approximately 0.5 g

[[Page 1128]]

each. Place the pieces in the analyst's choice of either individual 
microwave pressure relief vessels or ParrR Bombs. Add 6 ml of 
concentrated HNO3 and 4 ml of concentrated HF to each vessel. 
For microwave heating, microwave the samples for approximately 12 to 15 
minutes total heating time as follows: heat for 2 to 3 minutes, then 
turn off the microwave for 2 to 3 minutes, then heat for 2 to 3 minutes, 
etc., continue this alternation until the 12 to 15 minutes total heating 
time are completed (this procedure should comprise approximately 24 to 
30 minutes at 600 watts). Microwave heating times are approximate and 
are dependent upon the number of samples being digested simultaneously. 
Sufficient heating is evidenced by sorbent reflux within the vessel. For 
conventional heating, heat the ParrR Bombs at 140  deg.C (285 
 deg.F) for 6 hours. Then cool the samples to room temperature, and 
combine with the acid digested probe rinse as required in Section 5.3.3.
    5.3.1.3  If the sampling train includes an optional glass cyclone in 
front of the filter, prepare and digest the cyclone catch by the 
procedures described in section 5.3.1.2 and then combine the digestate 
with the digested filter sample.
    5.3.2  Container No. 2 (Acetone Rinse). Note the level of liquid in 
the container and confirm on the analysis sheet whether or not leakage 
occurred during transport. If a noticeable amount of leakage has 
occurred, either void the sample or use methods, subject to the approval 
of the Administrator, to correct the final results. Measure the liquid 
in this container either volumetrically within 1 ml or gravimetrically 
within 0.5 g. Transfer the contents to an acid-cleaned, tared 250-ml 
beaker and evaporate to dryness at ambient temperature and pressure. If 
particulate emissions are being determined, desiccate for 24 hours 
without added heat, weigh to a constant weight according to the 
procedures described in Section 4.3 of Method 5, and report the results 
to the nearest 0.1 mg. Redissolve the residue with 10 ml of concentrated 
HNO3.

[[Page 1129]]

[GRAPHIC] [TIFF OMITTED] TR25AP96.003

Quantitatively combine the resultant sample, including all liquid and 
any particulate matter, with Container No. 3 before beginning Section 
5.3.3.
    5.3.3  Container No. 3 (Probe Rinse). Verify that the pH of this 
sample is 2 or lower. If it is not, acidify the sample by careful 
addition with stirring of concentrated HNO3 to pH 2.

[[Page 1130]]

Use water to rinse the sample into a beaker, and cover the beaker with a 
ribbed watch glass. Reduce the sample volume to approximately 20 ml by 
heating on a hot plate at a temperature just below boiling. Digest the 
sample in microwave vessels or ParrR Bombs by quantitatively 
transferring the sample to the vessel or bomb, carefully adding the 6 ml 
of concentrated HNO3, 4 ml of concentrated HF, and then 
continuing to follow the procedures described in Section 5.3.1.2. Then 
combine the resultant sample directly with the acid digested portions of 
the filter prepared previously in Section 5.3.1.2. The resultant 
combined sample is referred to as ``Sample Fraction 1''. Filter the 
combined sample using Whatman 541 filter paper. Dilute to 300 ml (or the 
appropriate volume for the expected metals concentration) with water. 
This diluted sample is ``Analytical Fraction 1''. Measure and record the 
volume of Analytical Fraction 1 to within 0.1 ml. Quantitatively remove 
a 50-ml aliquot and label as ``Analytical Fraction 1B''. Label the 
remaining 250-ml portion as ``Analytical Fraction 1A''. Analytical 
Fraction 1A is used for ICAP or AAS analysis for all desired metals 
except Hg. Analytical Fraction 1B is used for the determination of 
front-half Hg.
    5.3.4  Container No. 4 (Impingers 1-3). Measure and record the total 
volume of this sample to within 0.5 ml and label it ``Sample Fraction 
2''. Remove a 75- to 100-ml aliquot for Hg analysis and label the 
aliquot ``Analytical Fraction 2B''. Label the remaining portion of 
Container No. 4 as ``Sample Fraction 2A''. Sample Fraction 2A defines 
the volume of Analytical Fraction 2A prior to digestion. All of Sample 
Fraction 2A is digested to produce ``Analytical Fraction 2A''. 
Analytical Fraction 2A defines the volume of Sample Fraction 2A after 
its digestion and the volume of Analytical Fraction 2A is normally 150 
ml. Analytical Fraction 2A is analyzed for all metals except Hg. Verify 
that the pH of Sample Fraction 2A is 2 or lower. If necessary, use 
concentrated HNO3 by careful addition and stirring to lower 
Sample Fraction 2A to pH 2. Use water to rinse Sample Fraction 2A into a 
beaker and then cover the beaker with a ribbed watch glass. Reduce 
Sample Fraction 2A to approximately 20 ml by heating on a hot plate at a 
temperature just below boiling. Then follow either of the digestion 
procedures described in Sections 5.3.4.1 or 5.3.4.2.
    5.3.4.1  Conventional Digestion Procedure. Add 30 ml of 50 percent 
HNO3, and heat for 30 minutes on a hot plate to just below 
boiling. Add 10 ml of 3 percent H2O2 and heat for 
10 more minutes. Add 50 ml of hot water, and heat the sample for an 
additional 20 minutes. Cool, filter the sample, and dilute to 150 ml (or 
the appropriate volume for the expected metals concentrations) with 
water. This dilution produces Analytical Fraction 2A. Measure and record 
the volume to within 0.1 ml.
    5.3.4.2  Microwave Digestion Procedure. Add 10 ml of 50 percent 
HNO3 and heat for 6 minutes total heating time in 
alternations of 1 to 2 minutes at 600 Watts followed by 1 to 2 minutes 
with no power, etc., similar to the procedure described in Section 
5.3.1. Allow the sample to cool. Add 10 ml of 3 percent 
H2O2 and heat for 2 more minutes. Add 50 ml of hot 
water, and heat for an additional 5 minutes. Cool, filter the sample, 
and dilute to 150 ml (or the appropriate volume for the expected metals 
concentrations) with water. This dilution produces Analytical Fraction 
2A. Measure and record the volume to within 0.1 ml.
    (Note: All microwave heating times given are approximate and are 
dependent upon the number of samples being digested at a time. Heating 
times as given above have been found acceptable for simultaneous 
digestion of up to 12 individual samples. Sufficient heating is 
evidenced by solvent reflux within the vessel.)
    5.3.5  Container No. 5A (Impinger 4), Container Nos. 5B and 5C 
(Impingers 5 and 6). Keep the samples in Containers Nos. 5A, 5B, and 5C 
separate from each other. Measure and record the volume of 5A to within 
0.5 ml. Label the contents of Container No. 5A to be Analytical Fraction 
3A. To remove any brown MnO2 precipitate from the contents of 
Container No. 5B, filter its contents through Whatman 40 filter paper 
into a 500 ml volumetric flask and dilute to volume with water. Save the 
filter for digestion of the brown MnO2 precipitate. Label the 
500 ml filtrate from Container No. 5B to be Analytical Fraction 3B. 
Analyze Analytical Fraction 3B for Hg within 48 hours of the filtration 
step. Place the saved filter, which was used to remove the brown 
MnO2 precipitate, into an appropriately sized vented 
container, which will allow release of any gases including chlorine 
formed when the filter is digested. In a laboratory hood which will 
remove any gas produced by the digestion of the MnO2, add 25 
ml of 8 N HCl to the filter and allow to digest for a minimum of 24 
hours at room temperature. Filter the contents of Container No. 5C 
through a Whatman 40 filter into a 500-ml volumetric flask. Then filter 
the result of the digestion of the brown MnO2 from Container 
No. 5B through a Whatman 40 filter into the same 500-ml volumetric 
flask, and dilute and mix well to volume with water. Discard the Whatman 
40 filter. Mark this combined 500-ml dilute HCl solution as Analytical 
Fraction 3C.
    5.3.6  Container No. 6 (Silica Gel). Weigh the spent silica gel (or 
silica gel plus impinger) to the nearest 0.5 g using a balance.
    5.4  Sample Analysis. For each sampling train sample run, seven 
individual analytical samples are generated; two for all desired

[[Page 1131]]

metals except Hg, and five for Hg. A schematic identifying each sample 
container and the prescribed analytical preparation and analysis scheme 
is shown in Figure 29-3. The first two analytical samples, labeled 
Analytical Fractions 1A and 1B, consist of the digested samples from the 
front-half of the train. Analytical Fraction 1A is for ICAP, ICP-MS or 
AAS analysis as described in Sections 5.4.1 and 5.4.2, respectively. 
Analytical Fraction 1B is for front-half Hg analysis as described in 
Section 5.4.3. The contents of the back-half of the train are used to 
prepare the third through seventh analytical samples. The third and 
fourth analytical samples, labeled Analytical Fractions 2A and 2B, 
contain the samples from the moisture removal impinger No. 1, if used, 
and HNO3 H2O2 impingers Nos. 2 and 3. 
Analytical Fraction 2A is for ICAP, ICP-MS or AAS analysis for target 
metals, except Hg. Analytical Fraction 2B is for analysis for Hg. The 
fifth through seventh analytical samples, labeled Analytical Fractions 
3A, 3B, and 3C, consist of the impinger contents and rinses from the 
empty impinger No. 4 and the H2SO4/
KMnO4 Impingers Nos. 5 and 6. These analytical samples are 
for analysis for Hg as described in Section 5.4.3. The total back-half 
Hg catch is determined from the sum of Analytical Fractions 2B, 3A, 3B, 
and 3C. Analytical Fractions 1A and 2A can be combined proportionally 
prior to analysis.
    5.4.1  ICAP and ICP-MS Analysis. Analyze Analytical Fractions 1A and 
2A by ICAP using Method 6010 or Method 200.7 (40 CFR part 136, appendix 
C). Calibrate the ICAP, and set up an analysis program as described in 
Method 6010 or Method 200.7. Follow the quality control procedures 
described in Section 7.3.1. Recommended wavelengths for analysis are as 
follows:

------------------------------------------------------------------------
                                                              Wavelength
                           Element                               (nm)
------------------------------------------------------------------------
Aluminum....................................................     308.215
Antimony....................................................     206.833
Arsenic.....................................................     193.696
Barium......................................................     455.403
Beryllium...................................................     313.042
Cadmium.....................................................     226.502
Chromium....................................................     267.716
Cobalt......................................................     228.616
Copper......................................................     324.754
Iron........................................................     259.940
Lead........................................................     220.353
Manganese...................................................     257.610
Nickel......................................................     231.604
Phosphorous.................................................     214.914
Selenium....................................................     196.026
Silver......................................................     328.068
Thallium....................................................     190.864
Zinc........................................................     213.856
------------------------------------------------------------------------

    These wavelengths represent the best combination of specificity and 
potential detection limit. Other wavelengths may be substituted if they 
can provide the needed specificity and detection limit, and are treated 
with the same corrective techniques for spectral interference. 
Initially, analyze all samples for the target metals (except Hg) plus Fe 
and Al. If Fe and Al are present, the sample might have to be diluted so 
that each of these elements is at a concentration of less than 50 ppm so 
as to reduce their spectral interferences on As, Cd, Cr, and Pb. Perform 
ICP-MS analysis by following Method 6020 in EPA Publication SW-846 Third 
Edition (November 1986) including updates I, II, IIA, and IIB, as 
incorporated by reference in Sec. 60.17(i).
    (Note: When analyzing samples in a HF matrix, an alumina torch 
should be used; since all front-half samples will contain HF, use an 
alumina torch.)
    5.4.2.  AAS by Direct Aspiration and/or GFAAS. If analysis of metals 
in Analytical Fractions 1A and 2A by using GFAAS or direct aspiration 
AAS is needed, use Table 29-2 to determine which techniques and 
procedures to apply for each target metal. Use Table 29-2, if necessary, 
to determine techniques for minimization of interferences. Calibrate the 
instrument according to Section 6.3 and follow the quality control 
procedures specified in Section 7.3.2.

          Table 29-2.--Applicable Techniques, Methods and Minimization of Interference for AAS Analysis
----------------------------------------------------------------------------------------------------------------
                                                                                    Interferences
      Metal              Technique         SW-846 \1\   Wavelength ---------------------------------------------
                                           method No.      (nm)             Cause               Minimization
----------------------------------------------------------------------------------------------------------------
Fe...............  Aspiration...........         7380        248.3  Contamination........  Great care taken to
                                                                                            avoid contamination.
Pb...............  Aspiration...........         7420        283.3  217.0 nm alternate...  Background correction
                                                                                            required.
Pb...............  Furnace..............         7421        283.3  Poor recoveries......  Matrix modifier, add
                                                                                            10 ul of phosphorus
                                                                                            acid to 1 ml of
                                                                                            prepared sample in
                                                                                            sampler cup.
Mn...............  Aspiration...........         7460        279.5  403.1 nm alternate...  Background correction
                                                                                            required.

[[Page 1132]]

 
Ni...............  Aspiration...........         7520        232.0  352.4 nm alternate     Background correction
                                                                     Fe, Co, and Cr.        required.
                                                                                           Matrix matching or
                                                                                            nitrous-oxide/
                                                                                            acetylene flame.
                                                                    Nonlinear response...  sample dilution or
                                                                                            use 352.3 nm line.
Se...............  Furnace..............         7740        196.0  Volatility...........  Spike samples and
                                                                                            reference materials
                                                                                            and add nickel
                                                                                            nitrate to minimize
                                                                                            volatilization.
                                                                    Adsorption & scatter.  Background correction
                                                                                            is required and
                                                                                            Zeeman background
                                                                                            correction can be
                                                                                            useful.
Ag...............  Aspiration...........         7760        328.1  Adsorption & Scatter   Background correction
                                                                     AgCl insoluble.        is required. Avoid
                                                                                            Hydrochloric acid
                                                                                            unless silver is in
                                                                                            solution as a
                                                                                            chloride complex
                                                                                            Sample and standards
                                                                                            monitored for
                                                                                            aspiration rate.
Tl...............  Aspiration...........         7840        276.8  .....................  Background correction
                                                                                            is required.
                                                                                            Hydrochloric acid
                                                                                            should not be used.
Tl...............  Furnace..............         7841        276.8  Hydrochloric acid or   Background correction
                                                                     chloride.              is required.
                                                                                           Verify that losses
                                                                                            are not occurring
                                                                                            for volatization by
                                                                                            spiked samples or
                                                                                            standard addition;
                                                                                            Palladium is a
                                                                                            suitable matrix
                                                                                            modifier.
Zn...............  Aspiration...........         7950        213.9  High Si, Cu, & P       Strontium removes Cu
                                                                     Contamination.         and phosphate, Great
                                                                                            care taken to avoid
                                                                                            contamination.
Sb...............  Aspiration...........         7040        217.6  1000 mg/ml Pb Ni, Cu,  Use secondary
                                                                     or acid.               wavelengths of
                                                                                            231.1.nm; match
                                                                                            sample & standards
                                                                                            acid concentration
                                                                                            or use nitrous
                                                                                            oxidefacetylene
                                                                                            flame.
Sb...............  Furnace..............         7041        217.6  High Pb..............  Secondary Wavelength
                                                                                            or Zeeman
                                                                                            correction.
As...............  Furnace..............         7060        193.7  Arsenic                Spiked samples and
                                                                     volatilization.        add nickel nitrate
                                                                    Aluminum.............   solution to
                                                                                            digestates prior to
                                                                                            analysis.
                                                                                           Use Zeeman background
                                                                                            correction.
Ba...............  Aspiration 7080......         7080        553.6  Calcium..............  High hollow cathode
                                                                    Barium ionization....   current and narrow
                                                                                            band set.
                                                                                           2 ml of KCl per 100
                                                                                            ml of sample.
Be...............  Aspiration...........         7090        234.9  500 ppm Al High Mg     Add 0.1% fluoride.
                                                                     and Si.               Use method of
                                                                                            standard additions.
Be...............  Furnace..............         7091        234.9  Be in optical path...  Optimize parameters
                                                                                            to minimize effects.
Cd...............  Aspiration...........         7130        228.8  Absorption and light   Background correction
                                                                     scattering.            is required.
Cd...............  Furnace..............         7131        228.8  As above.............  As above.
                                                                    Excess Chloride......  Ammonium phosphate
                                                                    Pipet tips...........   used as a matrix
                                                                                            modifier.
                                                                                           Use cadmiun-free
                                                                                            tips.

[[Page 1133]]

 
Cr...............  Aspiration...........         7190        357.9  Akali metal..........  KCl ionization
                                                                                            suppressant in
                                                                                            samples and
                                                                                            standards--Consult
                                                                                            mfgs literature.
Co...............  Furnace..............         7201        240.7  Excess chloride......  Use Method of
                                                                                            Standard Additions.
Cr...............  Furnace..............         7191        357.9  200 mg/L Ca and P....  All calcium nitrate
                                                                                            for a known constant
                                                                                            effect and to
                                                                                            eliminate effect of
                                                                                            phosphate.
Cu...............  Aspiration...........         7210        324.7  Absorption & scatter.  Consult
                                                                                            manufacturer's
                                                                                            manual.
----------------------------------------------------------------------------------------------------------------
\1\ Refer to EPA publication SW-846 Third Edition (November 1986) including updates I, II, IIA, and IIB, as
  incorporated by reference in Sec.  60.17(i).

    5.4.3  CVAAS Hg analysis. Analyze Analytical Fractions 1B, 2B, 3A, 
3B, and 3C separately for Hg using CVAAS following the method outlined 
in Method 7470 in EPA Publication SW-846 Third Edition (November 1986) 
including updates I, II, IIA and IIB, as incorporated by reference in 
Sec. 60.17(i) or in Standard Methods for the Examination of Water and 
Wastewater, 16th Edition, (1985), Method 303F, as incorporated by 
reference in Sec. 60.17, or, optionally using NOTE No. 2 in this 
section. Set up the calibration curve (zero to 1000 ng) as described in 
Method 7470 or similar to Method 303F using 300-ml BOD bottles instead 
of Erlenmeyers. Perform the following for each Hg analysis. From each 
original sample, select and record an aliquot in the size range from 1 
ml to 10 ml. If no prior knowledge of the expected amount of Hg in the 
sample exists, a 5 ml aliquot is suggested for the first dilution to 100 
ml (see NOTE No. 1 in this Section). The total amount of Hg in the 
aliquot shall be less than 1  g and within the range (zero to 
1000 ng) of the calibration curve. Place the sample aliquot into a 
separate 300-ml BOD bottle, and add enough water to make a total volume 
of 100 ml. Next add to it sequentially the sample digestion solutions 
and perform the sample preparation described in the procedures of Method 
7470 or Method 303F. (See NOTE No. 2 in this Section). If the maximum 
readings are off-scale (because Hg in the aliquot exceeded the 
calibration range; including the situation where only a 1-ml aliquot of 
the original sample was digested), then dilute the original sample (or a 
portion of it) with 0.15 percent HNO3 (1.5 ml concentrated 
HNO3 per liter aqueous solution) so that when a 1- to 10-ml 
aliquot of the ``0.15 HNO3 percent dilution of the original 
sample'' is digested and analyzed by the procedures described above, it 
will yield an analysis within the range of the calibration curve.
    Note No. 1 to Section 5.4.3. When Hg levels in the sample fractions 
are below the in-stack detection limit given in Table 29-1, select a 10 
ml aliquot for digestion and analysis as described.
    Note No. 2 to Section 5.4.3. Optionally, Hg can be analyzed by using 
the CVAAS analytical procedures given by some instrument manufacturer's 
directions. These include calibration and quality control procedures for 
the Leeman Model PS200, the Perkin Elmer FIAS systems, and similar 
models, if available, of other instrument manufacturers. For digestion 
and analyses by these instruments, perform the following two steps:
    (1) Digest the sample aliquot through the addition of the aqueous 
hydroxylamine hydrochloride/sodium chloride solution the same as 
described in this Section 5.4.3.: (The Leeman, Perkin Elmer, and similar 
instruments described in this note add automatically the necessary 
stannous chloride solution during the automated analysis of Hg.) and
    (2) Upon completion of the digestion described in paragraph (1), of 
this note, analyze the sample according to the instrument manufacturer's 
directions. This approach allows multiple (including duplicate) 
automated analyses of a digested sample aliquot.

                             6. Calibration

    Maintain a laboratory log of all calibrations.
    6.1  Sampling Train Calibration. Calibrate the sampling train 
components according to the indicated sections of Method 5: Probe Nozzle 
(Section 5.1); Pitot Tube (Section 5.2); Metering System (Section 5.3); 
Probe Heater (Section 5.4); Temperature Gauges (Section 5.5); Leake-
Check of the Metering System (Section 5.6); and Barometer (Section 5.7).
    6.2  Industively Coupled Argon Plasma Spectrometer Calibration. 
Prepare standards

[[Page 1134]]

as outlined in Section 4.5. Profile and calibrate the instrument 
according to the manufacturer's recommended procedures using those 
standards. Check the calibration once per hour. If the instrument does 
not reproduce the standard concentrations within 10 percent, perform the 
complete calibration procedures. Perform ICP-MS analysis by following 
Method 6020 in EPA Publication SW-846 Third Edition (November 1986) 
including updates I, II, IIA and IIB, as incorporated by reference in 
Sec. 60.17(i).
    6.3  Atomic Absorption Spectrometer--Direct Aspiration AAS, GFAAS, 
and CVAAS analyses. Prepare the standards as outlined in Section 4.5 and 
use them to calibrate the spectrometer. Calibration procedures are also 
outlined in the EPA methods referred to in Table 29-2 and in Method 7470 
in EPA Publication SW-846 Third Edition (November 1986) including 
updates I, II, IIA and IIB, as incorporated by reference in 
Sec. 60.17(i) or in Standard Methods for the Examination of Water and 
Wastewater, 16th Edition, (1985), Method 303F (for Hg) as incorporated 
by reference in Sec. 60.17. Run each standard curve in duplicate and use 
the mean values to calculate the calibration line. Recalibrate the 
instrument approximately once every 10 to 12 samples.

                           7. Quality Control

    7.1  Field Reagent Blanks, if analyzed. Perform the digestion and 
analysis of the blanks in Container Nos. 7 through 12 that were produced 
in Sections 5.2.11 through 5.2.17, respectively. For Hg field reagent 
blanks, use a 10 ml aliquot for digestion and analysis.
    7.1.1   Digest and analyze one of the filters from Container No. 12 
per Section 5.3.1, 100 ml from Container No. 7 per Section 5.3.2, and 
100 ml from Container No. 8A per Section 5.3.3. This step produces 
blanks for Analytical Fractions 1A and 1B.
    7.1.2  Combine 100 ml of Container No. 8A with 200 ml from Container 
No. 9, and digest and analyze the resultant volume per Section 5.3.4. 
This step produces blanks for Analytical Fractions 2A and 2B.
    7.1.3  Digest and analyze a 100-ml portion of Container No. 8A to 
produce a blank for Analytical Fraction 3A.
    7.1.4  Combine 100 ml from Container No. 10 with 33 ml from 
Container No. 8B to produce a blank for Analytical Fraction 3B. Filter 
the resultant 133 ml as described for Container No. 5B in Section 5.3.5, 
except do not dilute the 133ml. Analyze this blank for Hg within 48 hrs. 
of the filtration step, and use 400 ml as the blank volume when 
calculating the blank mass value. Use the actual volumes of the other 
analytical blanks when calculating their mass values.
    7.1.5  Digest the filter that was used to remove any brown 
MnO2 precipitate from the blank for Analytical Fraction 3B by 
the same procedure as described in Section 5.3.5 for the similar sample 
filter. Filter the digestate and the contents of Container No. 11 
through Whatman 40 paper into a 500-ml volumetric flask, and dilute to 
volume with water. These steps produce a blank for Analytical Fraction 
3C.
    7.1.6  Analyze the blanks for Analytical Fraction Blanks 1A and 2A 
per Section 5.4.1 and/or Section 5.4.2. Analyze the blanks for 
Analytical Fractions 1B, 2B, 3A, 3B, and 3C per Section 5.4.3. Analysis 
of the blank for Analytical Fraction 1A produces the front-half reagent 
blank correction values for the desired metals except for Hg; Analysis 
of the blank for Analytical Fraction 1B produces the front-half reagent 
blank correction value for Hg. Analysis of the blank for Analytical 
Fraction 2A produces the back-half reagent blank correction values for 
all of the desired metals except for Hg, while separate analyses of the 
blanks for Analytical Fractions 2B, 3A, 3B, and 3C produce the back-half 
reagent blank correction value for Hg.
    7.2  Quality Control Samples. Analyze the following quality control 
samples.
    7.2.1  ICAP and ICP-MS Analysis. Follow the respective quality 
control descriptions in Section 8 of Methods 6010 and 6020 of EPA 
Publication SW-846 Third Edition (November 1986) including updates I, 
II, IIA and IIB, as incorporated by reference in Sec. 60.17(i). For the 
purposes of a source test that consists of three sample runs, modify 
those requirements to include the following: two instrument check 
standard runs, two calibration blank runs, one interference check sample 
at the beginning of the analysis (analyze by Method of Standard 
Additions unless within 25 percent), one quality control sample to check 
the accuracy of the calibration standards (required to be within 25 
percent of calibration), and one duplicate analysis (required to be 
within 20 percent of average or repeat all analyses).
    7.2.2.  Direct Aspiration AAS and/or GFAAS Analysis for Sb, As, Ba, 
Be, Cd, Cu, Cr, Co, Pb, Ni, Mn, Hg, P, Se, Ag, Tl, and Zn. Analyze all 
samples in duplicate. Perform a matrix spike on at least one front-half 
sample and one back-half sample, or one combined sample. If recoveries 
of less than 75 percent or greater than 125 percent are obtained for the 
matrix spike, analyze each sample by the Method of Standard Additions. 
Analyze a quality control sample to check the accuracy of the 
calibration standards. If the results are not within 20 percent, repeat 
the calibration.
    7.2.3  CVAAS Analysis for Hg. Analyze all samples in duplicate. 
Analyze a quality control sample to check the accuracy of the 
calibration standards (if not within 15 percent, repeat calibration). 
Perform a matrix spike on one sample (if not within 25 percent, analyze 
all samples by the Method of Standard Additions). Additional information 
on quality control can be obtained from Method

[[Page 1135]]

7470 of EPA Publication SW-846 Third Edition (November 1986) including 
updates I, II, IIA and IIB, as incorporated by reference in 
Sec. 60.17(i) or in Standard Methods for the Examination of Water and 
Wastewater, 16th Edition, (1985), Method 303F as incorporated by 
reference in Sec. 60.17.

                             8. Calculations

    8.1  Dry Gas Volume. Using the data from this test, calculate 
Vm(std), the dry gas sample volume at standard conditions as 
outlined in Section 6.3 of Method 5.
    8.2  Volume of Water Vapor and Moisture Content. Using the total 
volume of condensate collected during the source sampling, calculate the 
volume of water vapor Vw(std) and the moisture content 
Bws of the stack gas. Use Equations 5-2 and 5-3 of Method 5.
    8.3  Stack Gas Velocity. Using the data from this test and Equation 
2-9 of Method 2, calculate the average stack gas velocity.
    8.4  Metals (Except Hg) in Source Sample.
    8.4.1   Analytical Fraction 1A, Front-Half, Metals (except Hg). 
Calculate separately the amount of each metal collected in Sample 
Fraction 1 of the sampling train using the following equation:

Mfh=Ca1 Fd Vsoln,1      Eq. 
          29-1

where:
Mfh=Total mass of each metal (except Hg) collected in the 
          front half of the sampling train (Sample Fraction 1), 
          g.
Ca1=Concentration of metal in Analytical Fraction 1A as read 
          from the standard curve, g/ml.
Fd=Dilution factor (Fd = the inverse of the 
          fractional portion of the concentrated sample in the solution 
          actually used in the instrument to produce the reading 
          Ca1. For example, if a 2 ml aliquot of Analytical 
          Fraction 1A is diluted to 10 ml to place it in the calibration 
          range, Fd = 5).
Vsoln,1=Total volume of digested sample solution (Analytical 
          Fraction 1), ml.
    8.4.1.1  If Analytical Fractions 1A and 2A are combined, use 
proportional aliquots. Then make appropriate changes in Equations 29-1 
through 29-3 to reflect this approach.
    8.4.2  Analytical Fraction 2A, Back-Half, Metals (except Hg). 
Calculate separately the amount of each metal collected in Fraction 2 of 
the sampling train using the following equation.

Mbh=Ca2 Fa Va      Eq. 29-2

where:
Mbh=Total mass of each metal (except Hg) collected in the 
          back-half of the sampling train (Sample Fraction 2), 
          g.
Ca2=Concentration of metal in Analytical Fraction 2A as read 
          from the standard curve, (g/ml).
Fa=Aliquot factor, volume of Sample Fraction 2 divided by 
          volume of Sample Fraction 2A (see Section 5.3.4.)
Va=Total volume of digested sample solution (Analytical 
          Fraction 2A), ml (see Section 5.3.4.1 or 5.3.4.2, as 
          applicable).
    8.4.3  Total Train, Metals (except Hg). Calculate the total amount 
of each of the quantified metals collected in the sampling train as 
follows:

Mt=(Mfh - Mfhb) + (Mbh - 
          Mbhb)    Eq. 29-3

where:
Mt=Total mass of each metal (separately stated for each 
          metal) collected in the sampling train, g.
Mfhb=Blank correction value for mass of metal detected in 
          front-half field reagent blank, g.
Mbhb=Blank correction value for mass of metal detected in 
          back-half field reagent blank, g.
    8.4.3.1  If the measured blank value for the front half 
(Mfhb) is in the range 0.0 to ``A'' g [where ``A'' 
g equals the value determined by multiplying 1.4 g/
in.2 times the actual area in in.2 of the sample 
filter], use Mfhb to correct the emission sample value 
(Mfh); if Mfhb exceeds ``A'' g, use the 
greater of I or II:
    I. ``A'' g.
    II. the lesser of (a) Mfhb, or (b) 5 percent of 
Mfh.
    If the measured blank value for the black-half (Mbhb) is 
in the range 0.0 to 1 g, use Mbhb to correct the 
emission sample value (Mbh); if Mbhb) exceeds 1 
g, use the greater of I or II:
    I. 1 g.
    II. the lesser of (a) Mbhb or (b) 5 percent of 
Mbh.
    8.5  Hg in Source Sample.
    8.5.1  Analytical Fraction 1B; Front-Half Hg. Calculate the amount 
of Hg collected in the front-half, Sample Fraction 1, of the sampling 
train by using Equation 29-4:

[GRAPHIC] [TIFF OMITTED] TR25AP96.005

where:
Hgfh=Total mass of Hg collected in the front-half of the 
          sampling train (Sample Fraction 1), g.
Qfh=Quantity of Hg, g, TOTAL in the ALIQUOT of 
          Analytical Fraction 1B selected for digestion and analysis.
    8.5.1.1  For example, if a 10 ml aliquot of Analytical Fraction 1B 
is taken and digested and analyzed (according to Section 5.4.3 and its 
NOTES Nos. 1 and 2), then calculate and use the total amount of Hg in 
the 10 ml aliquot for Qfh.

Vsoln,1=Total volume of Analytical Fraction 1, ml.
Vf1B=Volume of aliquot of Analytical Fraction 1B analyzed, 
          ml.
    8.5.1.2  For example, if a 1 ml aliquot of Analytical Fraction 1B 
was diluted to 50 ml

[[Page 1136]]

with 0.15 percent HNO3 as described in Section 5.4.3 to bring 
it into the proper analytical range, and then 1 ml of that 50-ml wa 
digested according to Section 5.4.3 and analyzed, Vf1B would 
be 0.02 ml.
    8.5.2  Analytical Fractions 2B, 3A, 3B, and 3C; Back Half Hg.
    8.5.2.1  Calculate the amount of Hg collected in Sample Fraction 2 
by using Equation 29-5:
[GRAPHIC] [TIFF OMITTED] TR25AP96.006

where:
Hgbh2=Total mass of Hg collected in Sample Fraction 2, 
          g.
Qbh2=Quantity of Hg, g, TOTAL in the ALIQUOT of 
          Analytical Fraction 2B selected for digestion and analysis.
    8.5.2.1.1  For example, if a 10 ml aliquot of Analytical Fraction 2B 
is taken and digested and analyzed (according to Section 5.4.3 and its 
NOTES Nos. 1 and 2), then calculate and use the total amount of Hg in 
the 10 ml aliquot for Qbh2.

Vsoln,2=Total volume of Sample Fraction 2, ml.
Vf2B=Volume of Analytical Fraction 2B analyzed, ml.
    8.5.2.1.2  For example, if 1 ml of Analytical Fraction 2B was 
diluted to 10 ml with 0.15 percent HNO3 as described in 
Section 5.4.3 to bring it into the proper analytical range, and then 5 
ml of that 10-ml was analyzed, Vf2B would be 0.5 ml.
    8.5.2.2  Calculate each of the back-half Hg values for Analytical 
Fractions 3A, 3B, and 3C by using Equation 29-6:
[GRAPHIC] [TIFF OMITTED] TR25AP96.007

where:
Hgbh3(A,B,C)=Total mass of Hg collected separately in 
          Fraction 3A, 3B, or 3C, g.
Qbh3(A,B,C)=Quantity of Hg, g, TOTAL, separately, in 
          the ALIQUOT of Analytical Fraction 3A, 3B, and 3C selected for 
          digestion and analysis, (see previous notes in Sections 8.5.1 
          and 8.5.2 describing the quantity ``Q'' and calculate 
          similarly).
Vf3(A,B,C)=Volume, separately, of Analytical Fraction 3A, 3B, 
          or 3C analyzed, ml (see previous notes in Sections 8.5.1 and 
          8.5.2, describing the quantity ``V'' and calculate similarly).
Vsoln,3(A,B,C)=Total volume, separately, of Analytical 
          Fraction 3A, 3B, or 3C, ml.
    8.5.2.3  Calculate the total amount of Hg collected in the back-half 
of the sampling train by using Equation 29-7:

Hgbh=Hgbh2+Hgbh3A+Hgbh3B+Hgbh3C
            Eq. 29-7

where:
Hgbh=Total mass of Hg collected in the back-half of the 
          sampling train, g.
    8.5.3  Total Train Hg Catch. Calculate the total amount of Hg 
collected in the sampling train by using Equation 29-8:

Hgt=(Hgfh-Hgfhb)+(Hgbh-
          Hgbhb)  Eq. 29-8

where:
Hgt=Total mass of Hg collected in the sampling train, 
          g.
Hgfhb=Blank correction value for mass of Hg detected in 
          front-half field reagent blank, g.
Hgbhb=Blank correction value for mass of Hg detected in back-
          half field reagent blanks, g.
    8.5.4  If the total of the measured blank values 
(Hgfhb+Hgbhb) is in the range of 0.0 to 0.6 
g, then use the total to correct the sample value 
(Hgfh+Hgbh); if it exceeds 0.6 g, use the 
greater of I. or II:
    I. 0.6 g.
    II. the lesser of (a) (Hgfhb+Hgbhb), or (b) 5 
percent of the sample value (Hgfh+Hgbh).
    8.6  Individual Metal Concentrations in Stack Gas. Calculate the 
concentration of each metal in the stack gas (dry basis, adjusted to 
standard conditions) by using Equation 29-9:
[GRAPHIC] [TIFF OMITTED] TR25AP96.008

Cs=Concentration of a metal in the stack gas, mg/dscm.
K4=10-3 mg/g.
Mt=Total mass of that metal collected in the sampling train, 
          g; (substitute Hgt for Mt for 
          the Hg calculation).
Vm(std)=Volume of gas sample as measured by the dry gas 
          meter, corrected to dry standard conditions, dscm.

    8.7  Isokinetic Variation and Acceptable Results. Same as Method 5, 
Sections 6.11 and 6.12, respectively.

[[Page 1137]]

                             9. Bibliography

    1. Method 303F in Standard Methods for the Examination of Water 
Wastewater, 16th Edition, 1985. Available from the American Public 
Health Association, 1015 18th Street NW., Washington, DC 20036.
    2. EPA Methods 6010, 6020, 7000, 7041, 7060, 7131, 7421, 7470, 7740, 
and 7841, Test Methods for Evaluating Solid Waste: Physical/Chemical 
Methods. SW-846, Third Edition, September 1986, with updates I, II, IIA 
and IIB. Office of Solid Waste and Emergency Response, U.S. 
Environmental Protection Agency, Washington, DC 20460.
    3. EPA Method 200.7, Code of Federal Regulations, Title 40, Part 
136, Appendix C. July 1, 1987.
    4. EPA Methods 1 through 5, Code of Federal Regulations, Title 40, 
Part 60, Appendix A. July 1, 1991.
    5. EPA Method 101A, Code of Federal Regulations, Title 40, Part 61, 
Appendix B. July 1, 1991.

[36 FR 24877, Dec. 23, 1971]


    Editorial Note: For Federal Register citations affecting part 60, 
appendix A see the List of CFR Sections in the Finding Aids section of 
this volume.

    Effective Date Note: At 64 FR 26490, May 14, 1999, Appendix A to 
part 60 was amended by adding Methods 2F, 2G, and 2H and corrected at 64 
FR 37196, July 9, 1999, and 64 FR 38241, July 15, 1999, effective July 
13, 1999.

            Appendix B to Part 60--Performance Specifications

Performance Specification 1--Specifications and test procedures for 
          opacity continuous emission monitoring systems in stationary 
          sources
Performance Specification 2--Specifications and test procedures for 
          SO2 and NOx continuous emission 
          monitoring systems in stationary sources
Performance Specification 3--Specifications and test procedures for 
          O2 and CO2 continuous emission 
          monitoring systems in stationary sources
Performance Specification 4--Specifications and test procedures for 
          carbon monoxide continuous emission monitoring systems in 
          stationary sources
Performance Specification 4A--Specifications and test procedures for 
          carbon monoxide continuous emission monitoring systems in 
          stationary sources
Performance Specification 5--Specifications and test procedures for TRS 
          continuous emission monitoring systems in stationary sources
Performance Specification 6--Specifications and test procedures for 
          continuous emission rate monitoring systems in stationary 
          sources
Performance Specification 7--Specifications and test procedures for 
          hydrogen sulfide continuous emission monitoring systems in 
          stationary sources
Performance Specification 8--Performance Specifications for Volatile 
          Organic Compound Continuous Emission Monitoring Systems in 
          Stationary Sources
Performance Specification 9--Specifications and Test Procedures for Gas 
          Chromatographic Countiuous Emission Monitoring Systems in 
          Stationary Sources

  Performance Specification 1--Specifications and Test Procedures for 
  Opacity Continuous Emission Monitoring Systems in Stationary Sources

1. Applicability and Principle

    1.1  Applicability. This specification contains requirements for the 
design, performance, and installation of instruments for opacity 
continuous emission monitoring systems (CEMS's) and data computation 
procedures for evaluating the acceptability of a CEMS. Certain design 
requirements and test procedures established in this specification may 
not apply to all instrument designs. In such instances, equivalent 
design requirements and test procedures may be used with prior approval 
of the Administrator.
    Performance Specification 1 (PS 1) applies to opacity monitors 
installed after March 30, 1983. Opacity monitors installed before March 
30, 1983, are required to comply with the provisions and requirements of 
PS 1 except for the following:
    (a) Section 4. ``Installation Specifications.''
    (b) Sections 5.1.4, 5.1.6, 5.1.7, and 5.1.8 of Section 5, ``Design 
and Performance Specifications.''
    (c) Section 6.4 of Section 6 ``Design Specifications Verification 
Procedure.''
    An opacity monitor installed before March 30, 1983, need not be 
tested to demonstrate compliance with PS 1 unless required by regulatory 
action other than the promulgation of PS 1. If an existing monitor is 
replaced with a new monitor, PS 1 shall apply except that the new 
monitor may be located at the old measurement location regardless of 
whether the location meets the requirements of Section 4. If a new 
measurement location is to be determined, the new location shall meet 
the requirements of Section 4.
    1.2  Principle. The opacity of particulate matter in stack emissions 
is continuously monitored by a measurement system based upon the 
principle of transmissometry. Light having specific spectral 
characteristics is projected from a lamp through the effluent in the 
stack or duct, and the intensity of the projected light is measured by a 
sensor. The projected light is attenuated because of absorption and 
scattered by the particulate

[[Page 1138]]

matter in the effluent; the percentage of visible light attenuated is 
defined as the opacity of the emission. Transparent stack emissions that 
do not attenuate light will have a transmittance of 100 percent or an 
opacity of zero percent. Opaque stack emissions that attenuate all of 
the visible light will have a transmittance of zero percent or an 
opacity of 100 percent.
    This specification establishes specific design criteria for the 
transmissometer system. Any opacity CEMS that is expected to meet this 
specification is first checked to verify that the design specifications 
are met. Then, the opacity CEMS is calibrated, installed, and operated 
for a specified length of time. During this specified time period, the 
system is evaluated to determine conformance with the established 
performance specifications.

2. Definitions

    2.1  Continuous Emission Monitoring System. The total equipment 
required for the determination of opacity. The system consists of the 
following major subsystems:
    2.1.1  Sample Interface. That portion of CEMS that protects the 
analyzer from the effects of the stack effluent and aids in keeping the 
optical surfaces clean.
    2.1.2  Analyzer. That portion of the CEMS that senses the pollutant 
and generates an output that is a function of the opacity.
    2.1.3  Data Recorder. That portion of the CEMS that provides a 
permanent record of the analyzer output in terms of opacity. The data 
recorder may include automatic data-reduction capabilities.
    2.2  Transmissometer. That portion of the CEMS that includes the 
sample interface and the analyzer.
    2.3  Transmittance. The fraction of incident light that is 
transmitted through an optical medium.
    2.4  Opacity. The fraction of incident light that is attenuated by 
an optical medium. Opacity (Op) and transmittance (Tr) are related by: 
Op=1-Tr.
    2.5  Optical Density. A logarithmic measure of the amount of 
incident light attenuated. Optical density (D) is related to the 
transmittance and opacity as follows:
D=-log10 Tr=-log10 (1-Op).
    2.6  Peak Spectral Response. The wavelength of maximum sensitivity 
of the transmissometer.
    2.7  Mean Spectral Response. The wavelength that is the arithmetic 
mean value of the wavelength distribution for the effective spectral 
response curve of the transmissometer.
    2.8  Angle of View. The angle that contains all of the radiation 
detected by the photodetector assembly of the analyzer at a level 
greater than 2.5 percent of the peak detector response.
    2.9  Angle of Projection. The angle that contains all of the 
radiation projected from the lamp assembly of the analyzer at a level of 
greater than 2.5 percent of the peak illuminance.
    2.10  Span Value. The opacity value at which the CEMS is set to 
produce the maximum data display output as specified in the applicable 
subpart.
    2.11  Upscale Calibration Value. The opacity value at which a 
calibration check of the CEMS is performed by simulating an upscale 
opacity condition as viewed by the receiver.
    2.12  Calibration Error. The difference between the opacity values 
indicated by the CEMS and the known values of a series of calibration 
attenuators (filters or screens).
    2.13  Zero Drift. The difference in the CEMS output readings from 
the zero calibration value after a stated period of normal continuous 
operation during which no unscheduled maintenance, repair, or adjustment 
took place. A calibration value of 10 percent opacity or less may be 
used in place of the zero calibration value.
    2.14  Calibration Drift. The difference in the CEMS output readings 
from the upscale calibration value after a stated period of normal 
continuous operation during which no unscheduled maintenance, repair, or 
adjustment took place.
    2.15  Response Time. The amount of time it takes the CEMS to display 
on the data recorder 95 percent of a step change in opacity.
    2.16  Conditioning Period. A period of time (168 hours minimum) 
during which the CEMS is operated without any unscheduled maintenance, 
repair, or adjustment prior to initiation of the operational test 
period.
    2.17  Operational Test Period. A period of time (168 hours) during 
which the CEMS is expected to operate within the established performance 
specifications without any unscheduled maintenance, repair, or 
adjustment.
    2.18  Path Length. The depth of effluent in the light beam between 
the receiver and the transmitter of a single-pass transmissometer, or 
the depth of effluent between the transceiver and reflector of a double-
pass transmissometer. Two path lengths are referenced by this 
specification as follows:
    2.18.1  Monitor Path Length. The path length (depth of effluent) at 
the installed location of the CEMS.
    2.18.2  Emission Outlet Path Length. The path length (depth of 
effluent) at the location where emissions are released to the 
atmosphere. For noncircular outlets, De=(2LW)(L+W), 
where L is the length of the outlet and W is the width of the outlet. 
Note that this definition does not apply to pressure baghouse outlets 
with multiple stacks, side discharge vents, ridge roof monitors, etc.

3. Apparatus


[[Page 1139]]


    3.1  Opacity Continuous Emission Monitoring System. Any opacity CEMS 
that is expected to meet the design and performance specifications in 
Section 5 and a suitable data recorder, such as an analog strip chart 
recorder or other suitable device (e.g., digital computer) with an input 
signal range compatible with the analyzer output.
    3.2  Calibration Attenuators. Minimum of three. These attenuators 
must be optical filters or screens with neutral spectral characteristics 
selected and calibrated according to the procedures in Sections 7.1.2 
and 7.1.3, and of sufficient size to attenuate the entire light beam 
received by the detector of the transmissometer.
    3.3  Upscale Calibration Value Attenuator. An optical filter with 
neutral spectral characteristics, a screen, or other device that 
produces an opacity value (corrected for path length, if necessary) that 
is greater than or equal to the applicable opacity standard but less 
than or equal to one-half the applicable instrument span value.
    3.4  Calibration Spectrophotometer. A laboratory spectrophotometer 
meeting the following minimum design specifications:

------------------------------------------------------------------------
                 Parameter                          Specification
------------------------------------------------------------------------
Wavelength range..........................  400-700 nm.
Detector angle of view....................  <10 deg..
Accuracy..................................  <0.5 percent transmittance,
                                             NBS traceable calibration.
------------------------------------------------------------------------

4. Installation Specifications

    Install the CEMS at a location where the opacity measurements are 
representative of the total emissions from the affected facility. These 
requirements can be met as follows:
    4.1  Measurement Location. Select a measurement location that is (a) 
downstream from all particulate control equipment, (b) where condensed 
water vapor is not present, (c) free of interference from ambient light 
(applicable only if transmissometer is responsive to ambient light), and 
(d) accessible in order to permit routine maintenance. Accessibility is 
an important criterion because easy access for lens cleaning, alignment 
checks, calibration checks, and blower maintenance will help assure 
quality data.
    4.2  Measurement Path. The primary concern in locating a 
transmissometer is determining a location of well-mixed stack gas. Two 
factors contribute to complete mixing of emission gases: turbulence and 
sufficient mixing time. The criteria listed below define conditions 
under which well-mixed emissions can be expected.
    Select a measurement path that passes through a centroidal area 
equal to 25 percent of the cross section. Additional requirements or 
modifications must be met for certain locations as follows:
    4.2.1  If the location is in a straight vertical section of stack or 
duct and is less than 4 equivalent diameters downstream from a bend, use 
a path that is in the plane defined by the upstream bend (see Figure 1-
1).
    4.2.2  If the location is in a straight vertical section of stack or 
duct and is less than 4 equivalent diameters upstream from a bend, use a 
path that is in the plane defined by the bend (see Figure 1-2).

[[Page 1140]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.273


[[Page 1141]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.274

    4.2.3  If the location is in a straight vertical section of stack or 
duct and is less than 4 diameters downstream and is also less than 1 
diameter upstream from a bend, use a path in the plane defined by the 
upstream bend (see Figure 1-3).
    4.2.4  If the location is in a horizontal section of duct and is at 
least 4 diameters downstream from a vertical bend, use a path in the 
horizontal plane that is between one-third and one-half the distance up 
the vertical axis from the bottom of the duct (see Figure 1-4).
    4.2.5  If the location is in a horizontal section of duct and is 
less than 4 diameters downstream from a vertical bend, use a path in the 
horizontal plane that is between one-half and two-thirds the distance up 
the vertical axis from the bottom of the duct for upward flow in the 
vertical section, and is between one-third and one-half the distance up 
the vertical axis from the bottom of the duct for downward flow (Figure 
1-5).
    4.3  Alternative Locations and Measurement Paths. Other locations 
and measurement paths may be selected by demonstrating to the 
Administrator that the average opacity measured at the alternative 
location or path is equivalent to the opacity as measured at a location 
meeting the criteria of Sections 4.1 and 4.2. The opacity at the 
alternative location is considered equivalent if the average value 
measured at the alternative location is within the range defined by the 
average measured opacity plus-minus10 percent at the location 
meeting the installation criteria in Section 4.2, or if the difference 
between the two average opacity values is less than 2 percent opacity. 
To conduct this demonstration, measure the opacities at the two 
locations or paths for a minimum period of 2 hours and compare the 
results. The opacities of the two locations or paths may be measured at 
different times, but must be measured at the same process operating 
conditions. Alternative procedures

[[Page 1142]]

for determining acceptable locations may be used if approved by the 
Administrator.
[GRAPHIC] [TIFF OMITTED] TC01JN92.275

      

[[Page 1143]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.276


[[Page 1144]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.277

5. Design and Performance Specifications

    5.1  Design Specifications. The CEMS for opacity shall comply with 
the following design specifications:
    5.1.1  Peak and Mean Spectral Responses. The peak and mean spectral 
responses must occur between 500 nm and 600 nm. The response at any 
wavelength below 400 nm or above 700 nm shall be less than 10 percent of 
the peak spectral response.
    5.1.2  Angle of View. The total angle of view shall be no greater 
than 5 degrees.
    5.1.3  Angle of Projection. The total angle of projection shall be 
no greater than 5 degrees.
    5.1.4  Optical Alignment Sight. Each analyzer must provide some 
method for visually determining that the instrument is optically 
aligned. The method provided must be capable of indicating that the unit 
is misaligned when an error of +2 percent opacity occurs due to 
misalignment at a monitor path length of 8 meters. Instruments that are 
capable of providing an absolute zero check

[[Page 1145]]

while in operation on a stack or duct with effluent present, and while 
maintaining the same optical alignment during measurement and 
calibration, need not meet this requirement (e.g., some ``zero pipe'' 
units).
    5.1.5  Simulated Zero and Upscale Calibration System. Each analyzer 
must include a calibration system for simulating a zero (or no greater 
than 10 percent) opacity and an upscale opacity value for the purpose of 
performing periodic checks of the transmissometer calibration while on 
an operating stack or duct. This calibration system will provide, as a 
minimum, a system check of the analyzer internal optics and all 
electronic circuitry including the lamp and photodetector assembly.
    5.1.6  Access to External Optics. Each analyzer must provide a means 
of access to the optical surfaces exposed to the effluent stream in 
order to permit the surfaces to be cleaned without requiring removal of 
the unit from the source mounting or without requiring optical 
realignment of the unit.
    5.1.7  Automatic Zero Compensation Indicator. If the CEMS has a 
feature that provides automatic zero compensation for dirt accumulation 
on exposed optical surfaces, the system must also provide some means of 
indicating when a compensation of 4 percent opacity has been exceeded. 
This indicator shall be at a location accessible to the operator (e.g., 
the data output terminal). During the operational test period, the 
system must provide some means (manual or automated) for determining the 
actual amount of zero compensation at the specified 24-hour intervals so 
that the actual 24-hour zero drift can be determined (see Section 
7.4.1).
    5.1.8  Slotted Tube. For transmissometers that use slotted tubes, 
the length of the slotted portion(s) must be equal to or greater than 90 
percent of the effluent path length (distance between duct or stack 
walls). The slotted tube must be of sufficient size and orientation so 
as not to interfere with the free flow of effluent through the entire 
optical volume of the transmissometer photodetector. The manufacturer 
must also show that the transmissometer minimizes light reflections. As 
a minimum, this demonstration shall consist of laboratory operation of 
the transmissometer both with and without the slotted tube in position.
    Should the operator desire to use a slotted tube design with a 
slotted portion equal to or less than 90 percent of the monitor path 
length, the operator must demonstrate to the Administrator that 
acceptable results can be obtained. As a minimum demonstration, the 
effluent opacity shall be measured using both the slotted tube 
instrument and another instrument meeting the requirement of this 
specification but not of the slotted tube design. The measurements must 
be made at the same location and at the same process operating 
conditions for a minimum period of 2 hours with each instrument. The 
shorter slotted tube may be used if the average opacity measured is 
equivalent to the opacity measured by the nonslotted tube design. The 
average opacity measured is equivalent if it is within the opacity range 
defined by the average opacity value 10 percent measured by 
the nonslotted tube design, or if the difference between the average 
opacities is less than 2 percent opacity.
    5.1.9  External Calibration Filter Access (optional). Provisions in 
the design of the transmissometer to accommodate an external calibration 
filter assembly are recommended. An adequate design would permit 
occasional use of external (i.e., not intrinsic to the instrument) 
neutral density filters to assess monitor operation.
    5.2  Performance Specifications. The opacity CEMS specifications are 
listed in Table 1-1.

6. Design Specifications Verification Procedure

    These procedures will not apply to all instrument designs and will 
require modification in some cases; all procedural modifications are 
subject to the approval of the Administrator.
    Test each analyzer for conformance with the design specifications of 
Sections 5.1.1-5.1.4, or obtain a certificate of conformance from the 
analyzer manufacturer as follows:
    6.1  Spectral Response. Obtain detector response, lamp emissivity, 
and filter transmittance data for the components used in the measurement 
system from their respective manufacturers, and develop the effective 
spectral response curve of the transmissometer. Then determine and 
report the peak spectral response wavelength, the mean spectral response 
wavelength, and the maximum response at any wavelength below 400 nm and 
above 700 nm expressed as a percentage of the peak response.
    Alternatively, conduct a laboratory measurement of the instrument's 
spectral response curve. The procedures of this laboratory evaluation 
are subject to approval of the Administrator.

                  Table 1-1--Performance Specifications
------------------------------------------------------------------------
               Parameter                         Specifications
------------------------------------------------------------------------
1. Calibration error a................  3 percent opacity.
2. Response time......................  10 seconds.
3. Conditioning period b..............  168 hours.
4. Operational test period b..........  168 hours.
5. Zero drift (24-hour) a.............  2 percent opacity.
6. Calibration drift (24-hour) a......  2 percent opacity.
7. Data recorder resolution...........  0.5 percent opacity.
------------------------------------------------------------------------
a Expressed as the sum of the absolute value of the mean and the
  absolute value of the confidence coefficient.
b During the conditioning and operational test periods, the CEMS must
  not require any corrective maintenance, repair, replacement, or
  adjustment other than that clearly specified as routine and required
  in the operation and maintenance manuals.


[[Page 1146]]

    6.2  Angle of View. Set up the receiver as specified by the 
manufacturer's written instructions. Draw an arc with radius of 3 meters 
in the horizontal direction. Using a small (less than 3 centimeters) 
nondirectional light source, measure the receiver response at 5-
centimeter intervals on the arc for 30 centimeters on either side of the 
detector centerline. Repeat the test in the vertical direction. Then for 
both the horizontal and vertical directions, calculate the response of 
the receiver as a function of viewing angle (26 centimeters of arc with 
a radius of 3 meters equals 5 degrees), report relative angle of view 
curves, and determine and report the angle of view.
    6.3  Angle of Projection. Set up the projector as specified by the 
manufacturer's written instructions. Draw an arc with a radius of 3 
meters in the horizontal direction. Using a small (less than 3 
centimeters) photoelectric light detector, measure the light intensity 
at 5-centimeter intervals on the arc for 30 centimeters on either side 
of the light source centerline of projection. Repeat the test in the 
vertical direction. Then for both the horizontal and vertical 
directions, calculate the response of the photoelectric detector as a 
function of the projection angle (26 centimeters of arc with a radius of 
3 meters equals 5 degrees), report the relative angle of projection 
curves, and determine and report the angle of projection.
    6.4  Optical Alignment Sight. In the laboratory set the instrument 
up as specified by the manufacturer's written instructions for a monitor 
path length of 8 meters. Align, zero, and span the instrument. Insert an 
attenuator of 10 percent (nominal opacity) into the instrument path 
length. Slowly misalign the projector unit by rotating it until a 
positive or negative shift of 2 percent opacity is obtained by the data 
recorder. Then, following the manufacturer's written instructions, check 
the alignment. The alignment procedure must indicate that the instrument 
is misaligned. Repeat this test for lateral misalignment of the 
projector. Realign the instrument and follow the same procedure for 
checking misalignment of the receiver or retroreflector unit (lateral 
misalignment only).
    6.5  Manufacturer's Certificate of Conformance (alternative to 
above). Obtain from the manufacturer a certificate of conformance 
stating that the first analyzer randomly sampled from each month's 
production was tested according to Sections 6.1 through 6.4 and 
satisfactorily met all requirements of Section 5 of this specification. 
If any of the requirements were not met, the certificate must state that 
the entire month's analyzer production was resampled according to the 
military standard 105D sampling procedure (MIL-STD-105D) inspection 
level II; was retested for each of the applicable requirements under 
Section 5 of this specification; and was determined to be acceptable 
under MIL-STD-105D procedures, acceptable quality level 1.0. The 
certificate of conformance must include the results of each test 
performed for the analyzer(s) sampled during the month the analyzer 
being installed was produced.

7. Performance Specification Verification Procedure

    Test each CEMS that conforms to the design specifications (Section 
5.1) using the following procedures to determine conformance with the 
specifications of Table 1-1. These tests are to be performed using the 
data recording system to be employed during monitoring. Prior approval 
from the Administrator is required if different data recording systems 
are used during the performance test and monitoring.
    7.1  Preliminary Adjustments and Tests. Before installing the system 
on the stack, perform these steps or tests at the affected facility or 
in the manufacturer's laboratory.
    7.1.1  Equipment Preparation. Set up and calibrate the CEMS for the 
monitor path length to be used in the installation as specified by the 
manufacturer's written instructions. For this specification, the 
mounting distance between the transmitter and receiver/reflector unit at 
the source must be measured prior to performing the calibrations (do not 
use distances from engineering drawings). If the CEMS has automatic path 
length adjustment, follow the manufacturer's instructions to adjust the 
signal output from the analyzer in order to yield results based on the 
emission outlet path length. Set the instrument and data recording 
system ranges so that maximum instrument output is within the span range 
specified in the applicable subpart.
    Align the instrument so that maximum system response is obtained 
during a zero (or upscale) check performed across the simulated monitor 
path length. As part of this alignment, include rotating the reflector 
unit (detector unit for single pass instruments) on its axis until the 
point of maximum instrument response is obtained.
    Follow the manufacturer's instructions to zero and span the 
instrument. Perform the zero alignment adjustment by balancing the 
response of the CEMS so that the simulated zero check coincides with the 
actual zero check performed across the simulated monitor path length. At 
this time, measure and record the indicated upscale calibration value. 
The calibration value reading must be within the required opacity range 
(Section 3.3).
    7.1.2  Calibration Attenuator Selection. Based on the span value 
specified in the applicable subpart, select a minimum of three 
calibration attenuators (low, mid, and high range) using Table 1-2.

[[Page 1147]]

    If the system is operating with automatic path length compensation, 
calculate the attenuator values required to obtain a system response 
equivalent to the applicable values shown in Table 1-2; use Equation 1-1 
for the conversion. A series of filters with nominal optical density 
(opacity) values of 0.1(20), 0.2(37), 0.3(50), 0.4(60), 0.5(68), 
0.6(75), 0.7(80), 0.8(84), 0.9(88), and 1.0(90) are commercially 
available. Within this limitation of filter availability, select the 
calibration attenuators having the values given in Table 1-2 or having 
values closest to those calculated by Equation 1-1.

[GRAPHIC] [TIFF OMITTED] TC16NO91.237



       Table 1-2--Required Calibration Attenuator Values (Nominal)
------------------------------------------------------------------------
                                         Calibrated attenuator optical
                                        density (equivalent opacity in
    Span value (percent opacity)               parenthesis)--D2
                                     -----------------------------------
                                       Low-range   Mid-range  High-range
------------------------------------------------------------------------
40..................................   0.05 (11)    0.1 (20)    0.2 (37)
50..................................    0.1 (20)    0.2 (37)    0.3 (50)
60..................................    0.1 (20)    0.2 (37)    0.3 (50)
70..................................    0.1 (20)    0.3 (50)    0.4 (60)
80..................................    0.1 (20)    0.3 (50)    0.6 (75)
90..................................    0.1 (20)    0.4 (60)    0.7 (80)
100.................................    0.1 (20)    0.4 (60)  0.9 (87.5)
------------------------------------------------------------------------

Where:

D1=Nominal optical density value of required mid, low, or 
          high range calibration attenuators.
D2=Desired attenuator optical density output value from Table 
          1-2 at the span required by the applicable subpart.
L1=Monitor path length.
L2=Emission outlet path length.
    7.1.3  Attenuator Calibration. Select a laboratory calibration 
spectrophotometer meeting the specifications of Section 3.4. Using this 
calibration spectrophotometer, calibrate the required filters or 
screens. Make measurements at wavelength intervals of 20 nm or less. As 
an alternative procedure, use the calibration spectrophotometer to 
measure the C.I.E. DaylightC luminous transmittance of the 
attenuators. Check the attenuators several times, at different locations 
on the attenuator.
    The attenuator manufacturer must specify the period of time over 
which the attenuator values can be considered stable, as well as any 
special handling and storing procedures required to enhance attenuator 
stability. To assure stability, recheck attenuator values at intervals 
less than or equal to the period stability guaranteed by the 
manufacturer. Recheck at least every 3 months. If desired, perform the 
stability checks with an instrument (secondary) other than the 
calibration spectrophotometer. This secondary instrument must be a high-
quality laboratory transmissometer or spectrophotometer, and the same 
instrument must always be used for the stability checks. If a secondary 
instrument is to be used for stability checks, the value of the 
calibrated attenuator must be measured on this secondary instrument 
immediately following initial calibration. If over a period of time an 
attenuator value changes by more than 2 percent opacity, 
recalibrate the attenuator on the calibration spectrophotometer or 
replace it with a new attenuator.
    If this procedure is conducted by the filter or screen manufacturer 
or by an independent laboratory, obtain a statement certifying the 
values and certifying that the specified procedure, or equivalent, is 
used.
    7.1.4  Calibration Error Test. Insert the calibration attenuators 
(low, mid, and high range) in the transmissometer path at or as near the 
midpoint of the path as feasible. Place the attenuator in the 
measurement path at a point where the effluent will be measured; i.e., 
do not place the calibration attenuator in the instrument housing. If 
the instrument manufacturer recommends a procedure wherein the 
attenuators are placed in the instrument housing, the manufacturer must 
provide data showing this alternative procedure is acceptable. While 
inserting the attenuator, assure that the entire beam received by the 
detector will pass through the attenuator and that the attenuator is 
inserted in a manner which minimizes interference from reflected light. 
Make a total of five nonconsecutive readings for each filter. Record the 
monitoring system output readings in percent opacity (see example Figure 
1-6). Then, if the path length is not adjusted by the measurement 
system, subtract the actual calibration attenuator value from the value 
indicated by the measurement system recorder for each of the 15 readings 
obtained. If the path length is adjusted by the measurement system, 
subtract the ``path adjusted'' calibration attenuator values from the 
values indicated by the measurement system recorder (the ``path 
adjusted'' calibration attenuator values are calculated using Equation 
1-6 or 1-7). Calculate the arithmetic mean difference, standard 
deviation, and confidence coefficient of the five tests at each 
attenuator value using Equations 1-2, 1-3, and 1-4 (Sections 8.1-8.3). 
Calculate the sum of the absolute value of the mean difference and the 
absolute value of the confidence coefficient for each of the three test 
attenuators; report these three values as the calibration error.

[[Page 1148]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.278

    7.1.5  System Response Test. Insert the high-range calibration 
attenuator in the transmissometer path five times, and record the time 
required for the system to respond to 95 percent of final zero and high-
range filter values (see example Figure 1-7). Then calculate the mean 
time of the 10 upscale and downscale tests and report this value as the 
system response time.

[[Page 1149]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.279

    7.2  Preliminary Field Adjustments. Install the CEMS on the affected 
facility according to the manufacturer's written instructions and the 
specifications in Section 4, and perform the following preliminary 
adjustments:
    7.2.1  Optical and Zero Alignment. When the facility is not in 
operation, optically align the light beam of the transmissometer upon 
the optical surface located across the duct or stack (i.e., the 
retroreflector or photodetector, as applicable) in accordance with the 
manufacturer's instructions; verify the alignment with the optical 
alignment sight. Under clear stack conditions, verify the zero alignment 
(performed in Section 7.1.1) by assuring that the monitoring system 
response for the simulated zero check coincides with the actual zero 
measured by the transmissometer across the clear stack. Adjust the zero 
alignment, if necessary. Then, after the affected facility has been 
started up and the effluent stream reaches normal operating temperature, 
recheck the optical alignment. If the optical alignment has shifted, 
realign the optics. Note: Careful consideration should be given to 
whether a ``clear stack'' condition exists. It is suggested that the 
stack be monitored and the data output (instantaneous real-time basis) 
be examined to determine whether fluctuations from zero opacity are 
occurring before a clear stack condition is assumed to exist.
    7.2.2  Optical and Zero Alignment (Alternative Procedure). The 
procedure given in 7.2.1 is the preferred procedure and should be used 
whenever possible; however, if the facility is operating and a zero 
stack condition cannot practicably be obtained, use the zero alignment 
obtained during the preliminary adjustments (Section 7.1.1) before 
installing the transmissometer on the stack. After completing all the 
preliminary adjustments and tests required in Section 7.1, install the 
system at the source and align the optics,

[[Page 1150]]

i.e., align the light beam from the transmissometer upon the optical 
surface located across the duct or stack in accordance with the 
manufacturer's instruction. Verify the alignment with the optical 
alignment sight. The zero alignment conducted in this manner must be 
verified and adjusted, if necessary, the first time a clear stack 
condition is obtained after the operation test period has been 
completed.
    7.3  Conditioning Period. After completing the preliminary field 
adjustments (Section 7.2), operate the CEMS according to the 
manufacturer's instructions for an initial conditioning period of not 
less than 168 hours while the source is operating. Except during times 
of instrument zero and upscale calibration checks, the CEMS must analyze 
the effluent gas for opacity and produce a permanent record of the CEMS 
output. During this conditioning period there must be no unscheduled 
maintenance, repair, or adjustment. Conduct daily zero calibration and 
upscale calibration checks; and, when accumulated drift exceeds the 
daily operating limits, make adjustments and clean the exposed optical 
surfaces. The data recorder must reflect these checks and adjustments. 
At the end of the operational test period, verify that the instrument 
optical alignment is correct. If the conditioning period is interrupted 
because of source breakdown (record the dates and times of process 
shutdown), continue the 168-hour period following resumption of source 
operation. If the conditioning period is interrupted because of monitor 
failure, restart the 168-hour conditioning period when the monitor 
becomes operational.
    7.4  Operational Test Period. After completing the conditioning 
period, operate the system for an additional 168-hour period. The 168-
hour operational test period need not follow immediately after the 168-
hour conditioning period. Except during times of instrument zero and 
upscale calibration checks, the CEMS must analyze the effluent gas for 
opacity and must produce a permanent record of the CEMS output. During 
this period, there will be no unscheduled maintenance, repair, or 
adjustment. Zero and calibration adjustments, optical surface cleaning, 
and optical realignment may be performed (optional) only at 24-hour 
intervals or at such shorter intervals as the manufacturer's written 
instructions specify. Automatic zero and calibration adjustments made by 
the CEMS without operator intervention or initiation are allowable at 
any time. During the operational test period, record all adjustments, 
realignments, and lens cleanings. If the operational test period is 
interrupted because of source breakdown, continue the 168-hour period 
following resumption of source operation. If the test period is 
interrupted because of monitor failure, restart the 168-hour period when 
the monitor becomes operational. During the operational test period, 
perform the following test procedures:
    7.4.1  Zero Drift Test. At the outset of the 168-hour operational 
test period, record the initial simulated zero (or no greater than 10 
percent) and upscale opacity readings (see example Figure 1-8). After 
each 24-hour interval, check and record the final zero reading before 
any optional or required cleaning and adjustment. Zero and upscale 
calibration adjustments, optical surface cleaning, and optical 
realignment may be performed only at 24-hour intervals (or at such 
shorter intervals as the manufacturer's written instructions specify), 
but are optional. However, adjustments and cleaning must be performed 
when the accumulated zero calibration or upscale calibration drift 
exceeds the 24-hour drift specification (plus-minus2 percent 
opacity). If no adjustments are made after the zero check, record the 
final zero reading as the initial zero reading for the next 24-hour 
period. If adjustments are made, record the zero value after adjustment 
as the initial zero value for the next 24-hour period. If the instrument 
has an automatic zero compensation feature for dirt accumulation on 
exposed lenses and the zero value cannot be measured before compensation 
is entered, then record the amount of automatic zero compensation (as 
opacity) for the final zero reading of each 24-hour period. (List the 
indicated zero values of the CEMS in parenthesis.) From the initial and 
final zero readings, calculate the zero drift for each 24-hour period. 
Then calculate the arithmetic mean, standard deviation, and confidence 
coefficient of the 24-hour zero drift and the 95 percent confidence 
interval using Equations 1-2, 1-3, and 1-4. Calculate the sum of the 
absolute value of the mean and the absolute value of the confidence 
coefficient, and report this value as the 24-hour zero drift.

[[Page 1151]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.280

    7.4.2  Upscale Drift Test. At each 24-hour interval, after the zero 
calibration value has been checked and any optional or required 
adjustments have been made, check and record the simulated upscale 
calibration value. If no further adjustments are made to the calibration 
system at this time, record the final upscale calibration value as the 
initial upscale value for the next 24-hour period. If an instrument span 
adjustment is made, record the upscale value after adjustment as the 
initial upscale value for the next 24-hour period. From the initial and 
final upscale readings, calculate the upscale calibration drift for each 
24-hour period. Then calculate the arithmetic mean, standard deviation, 
and confidence coefficient of the 24-

[[Page 1152]]

hour calibration drift and the 95 percent confidence interval using 
Equations 1-2, 1-3, and 1-4. Calculate the sum of the absolute value of 
the mean and the absolute value of the confidence coefficient, and 
report this value as the 24-hour calibration drift.

8. Equations

    8.1  Arithmetic Mean. Calculate the mean, x, of a set of data as 
follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.281

where:
    n=Number of data points.
    [GRAPHIC] [TIFF OMITTED] TC16NO91.238
    
    8.2  Standard Deviation. Calculate the standard deviation Sd 
as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.282

    8.3  Confidence Coefficient. Calculate the 2.5 percent error 
confidence coefficient (one-tailed), CC, as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.283

Where:

t0.975=t-value (see Table 1-3).
    8.4  Error. Calculate the error (i.e., calibration error, zero 
drift, and calibration drift), Er, as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.284


                                               Table 1-3--t-Values
----------------------------------------------------------------------------------------------------------------
                 na                    t0.975             na             t0.975            na             t0.975
----------------------------------------------------------------------------------------------------------------
2...................................   12.706  7......................    2.447  12....................    2.201
3...................................    4.303  8......................    2.365  13....................    2.179
4...................................    3.182  9......................    2.306  14....................    2.160
5...................................    2.776  10.....................    2.262  15....................    2.145
6...................................    2.571  11.....................    2.228  16....................    2.131
----------------------------------------------------------------------------------------------------------------
a The values in this table are already corrected for n-1 degrees of freedom. Use n equal to the number of
  individual values.

    8.5  Conversion of Opacity Values from Monitor Path Length to 
Emission Outlet Path Length. When the monitor path length is different 
than the emission outlet path length, use either of the following 
equations to convert from one basis to the other (this conversion may be 
automatically calculated by the monitoring system):

             log(1-Op2)=(L2/L1) log (1-
                                               Op1)          

                                                               (Eq. 1-6)

     D2=(L2/L1) D1          
                                                               (Eq. 1-7)

Where:

Op1 = Opacity of the effluent based upon L1.
Op2 = Opacity of the effluent based upon L2.
L1 = Monitor path length.
L2 = Emission outlet path length.
D1 = Optical density of the effluent based upon 
          L1.
D2 = Optical density of the effluent based upon 
          L2.

9. Reporting

    Report the following (summarize in tabular form where appropriate).
    9.1  General Information.
    a. Facility being monitored.
    b. Person(s) responsible for operational and conditioning test 
periods and affiliation.
    c. Instrument manufacturer.
    d. Instrument model number
    e. Instrument serial number.
    f. Month/year manufactured.
    g. Schematic of monitoring system measurement path location.
    h. Monitor pathlength, meters.
    i. Emission outlet pathlength, meters.
    j. System span value, percent opacity.
    k. Upscale calibration value, percent opacity.
    l. Calibrated Attenuator values (low, mid, and high range), percent 
opacity.
    9.2  Design Specification Test Results.
    a. Peak spectral response, nm.
    b. Mean spectral response, nm.
    c. Response above 700 nm, percent of peak.
    d. Response below 400 nm, percent of peak.
    e. Total angle of view, degrees.
    f. Total angle of projection, degrees.
    g. Results of optical alignment sight test.
    h. Serial number, month/year of manufacturer for unit actually 
tested to show design conformance.
    9.3  Performance Specification Test Results.

[[Page 1153]]

    a. Calibration error, high-range, percent opacity.
    b. Calibration error, mid-range, percent opacity.
    c. Calibration error, low-range, percent opacity.
    d. Response time, seconds.
    e. 24-hour zero drift, percent opacity.
    f. 24-hour calibration drift, percent opacity.
    g. Lens cleanings, clock time.
    h. Optical alignment adjustments, clock time.
    9.4  Statements. Provide a statement that the conditioning and 
operational test periods were completed according to the requirements of 
Sections 7.3 and 7.4. In this statement, include the time periods during 
which the conditioning and operational test periods were conducted.
    9.5  Appendix. Provide the data tabulations and calculations for the 
above tabulated results.

10. Retest

    If the CEMS operates within the specified performance parameters of 
Table 1-1, the PS tests will be successfully concluded. If the CEMS 
fails one of the preliminary tests, make the necessary corrections and 
repeat the performance testing for the failed specification prior to 
conducting the operational test period. If the CEMS fails to meet the 
specifications for the operational test period, make the necessary 
corrections and repeat the operational test period; depending on the 
correction made, it may be necessary to repeat the design and 
preliminary performance tests.

11. Bibliography

    1.  Experimental Statistics. Department of Commerce. National Bureau 
of Standards Handbook 91. Paragraph 3-3.1.4 1963. pp. 3-31.
    12.  Performance Specifications for Stationary-Source Monitoring 
Systems for Gases and Visible Emissions. U.S. Environmental Protection 
Agency. Research Triangle Park, NC. EPA-650/2-74-013. January 1974.

  Performance Specification 2--Specifications and Test Procedures for 
SO2 and NOx Continuous Emission Monitoring Systems 
                          in Stationary Sources

1. Applicability and Principle
    1.1  Applicability. This specification is to be used for evaluating 
the acceptability of SO2 and NOx continuous 
emission monitoring systems (CEMS's) at the time of or soon after 
installation and whenever specified in the regulations. The CEMS may 
include, for certain stationary sources, a diluent (O2 or 
CO2 ) monitor.
    This specification is not designed to evaluate the installed CEMS 
performance over an extended period of time nor does it identify 
specific calibration techniques and other auxiliary procedures to assess 
the CEMS performance. The source owner or operator, however, is 
responsible to properly calibrate, maintain, and operate the CEMS. To 
evaluate the CEMS performance, the Administrator may require, under 
Section 114 of the Act, the operator to conduct CEMS performance 
evaluations at other times besides the initial test. See Sec. 60.13(c).
    1.2  Principle. Installation and measurement location 
specifications, performance and equipment specifications, test 
procedures, and data reduction procedures are included in this 
specification. Reference method tests and calibration drift tests are 
conducted to determined conformance of the CEMS with the specification.

2. Definitions

    2.1  Continuous Emission Monitoring System. The total equipment 
required for the determination of a gas concentration or emission rate. 
The system consists of the following major subsystems:
    2.1.1  Sample Interface. That portion of the CEMS used for one or 
more of the following: sample acquisition, sample transportation, and 
sample conditioning, or protection of the monitor from the effects of 
the stack effluent.
    2.1.2   Pollutant Analyzer. That portion of the CEMS that senses the 
pollutant gas and generates an output proportional to the gas 
concentration.
    2.1.3  Diluent Analyzer (if applicable). That portion of the CEMS 
that senses the diluent gas (e.g., CO2 or O2) and 
generates an output proportional to the gas concentration.
    2.1.4  Data Recorder. That portion of the CEMS that provides a 
permanent record of the analyzer output. The data recorder may include 
automatic data reduction capabilities.
    2.2  Point CEMS. A CEMS that measures the gas concentration either 
at a single point or along a path equal to or less than 10 percent of 
the equivalent diameter of the stack or duct cross section.
    2.3  Path CEMS. A CEMS that measures the gas concentration along a 
path greater than 10 percent of the equivalent diameter of the stack or 
duct cross section.
    2.4  Span Value. The upper limit of a gas concentration measurement 
range specified for affected source categories in the applicable subpart 
of the regulations.
    2.5  Relative Accuracy (RA). The absolute mean difference between 
the gas concentration or emission rate determined by the CEMS and the 
value determined by the RM's plus the 2.5 percent error confidence 
coefficient of a series of tests divided by the mean of the RM tests or 
the applicable emission limit.

[[Page 1154]]

    2.6  Calibration Drift (CD). The difference in the CEMS output 
readings from the established reference value after a stated period of 
operation during which no unscheduled maintenance, repair, or adjustment 
took place.
    2.7  Centroidal Area. A concentric area that is geometrically 
similar to the stack or duct cross section and is no greater than 1 
percent of the stack or duct cross-sectional area.
    2.8  Representative Results. As defined by the RM test procedure 
outlined in this specification.

3.  Installation and Measurement Location Specifications

    3.1  The CEMS Installation and Measurement Location. Install the 
CEMS at an accessible location where the pollutant concentration or 
emission rate measurements are directly representative or can be 
corrected so as to be representative of the total emissions from the 
affected facility or at the measurement location cross section. Then 
select representative measurement points or paths for monitoring in 
locations that the CEMS will pass the RA test (see Section 7). If the 
cause of failure to meet the RA test is determined to be the measurement 
location and a satisfactory correction technique cannot be established, 
the Administrator may require the CEMS to be relocated.
    Suggested measurement locations and points or paths that are most 
likely to provide data that will meet the RA requirements are listed 
below.
    3.1.1  Measurement Location. It is suggested that the measurement 
location be (1) at least two equivalent diameters downstream from the 
nearest control device, the point of pollutant generation, or other 
point at which a change in the pollutant concentration or emission rate 
may occur and (2) at least a half equivalent diameter upstream from the 
effluent exhaust or control device.
    3.1.2  Point CEMS. It is suggested that the measurement point be (1) 
no less than 1.0 meter from the stack or duct wall or (2) within or 
centrally located over the centroidal area of the stack or duct cross 
section.
    3.1.3  Path CEMS. It is suggested that the effective measurement 
path (1) be totally within the inner area bounded by a line 1.0 meter 
from the stack or duct wall, or (2) have at least 70 pebcent of the path 
within the inner 50 percent of the stack or duct cross-sectional area, 
or (3) be centrally located over any part of the centroidal area.
    3.2  Reference Method (RM) Measurement Location and Traverse Points. 
Select, as appropriate, an accessible RM measurement point at least two 
equivalent diameters downstream from the nearest control device, the 
point of pollutant generation, or other point at which a change in the 
pollutant concentration or emission rate may occur, and at least a half 
equivalent diameter upstream from the effluent exhaust or control 
device. When pollutant concentration changes are due solely to diluent 
leakage (e.g., air heater leakages) and pollutants and diluents are 
simultaneously measured at the same location, a half diameter may be 
used in lieu of two equivalent diameters. The CEMS and RM locations need 
not be the same.
    Then select traverse points that assure acquisition of 
representative samples over the stack or duct cross section. The minimum 
requirements are as follows: Establish a ``measurement line'' that 
passes through the centroidal area and in the direction of any expected 
stratification. If this line interferes with the CEMS measurements, 
displace the line up to 30 cm (or 5 percent of the equivalent diameter 
of the cross section, whichever is less) from the centroidal area. 
Locate three traverse points at 16.7, 50.0, and 83.3 percent of the 
measurement line. If the measurement line is longer than 2.4 meters and 
pollutant stratification is not expected, the tester may choose to 
locate the three traverse points on the line at 0.4, 1.2, and 2.0 meters 
from the stack or duct wall. This option must not be used after wet 
scrubbers or at points where two streams with different pollutant 
concentrations are combined. The tester may select other traverse 
points, provided that they can be shown to the satisfaction of the 
Administrator to provide a representative sample over the stack or duct 
cross section. Conduct all necessary RM tests within 3 cm (but no less 
than 3 cm from the stack or duct wall) of the traverse points.

4. Performance and Equipment Specifications

    4.1  Data Recorder Scale. The CEMS data recorder response range must 
include zero and a high-level value. The high-level value is chosen by 
the source owner or operator and is defined as follows:
    For a CEMS intended to measure an uncontrolled emission (e.g., 
SO2 measurements at the inlet of a flue gas desulfurization 
unit), the high-level value must be between 1.25 and 2 times the average 
potential emission level, unless otherwise specified in an applicable 
subpart of the regulations. For a CEMS installed to measure controlled 
emissions or emissions that are in compliance with an applicable 
regulation, the high-level value must be between 1.5 times the pollutant 
concentration corresponding to the emission standard level and the span 
value. If a lower high-level value is used, the source must have the 
capability of measuring emissions which exceed the full-scale limit of 
the CEMS in accordance with the requirements of applicable regulations.

[[Page 1155]]

    The data recorder output must be established so that the high-level 
value is read between 90 and 100 percent of the data recorder full 
scale. (This scale requirement may not be applicable to digital data 
recorders.) The calibration gas, optical filter, or cell values used to 
establish the data recorder scale should produce the zero and high-level 
values. Alternatively, a calibration gas, optical filter, or cell value 
between 50 and 100 percent of the high-level value may be used in place 
of the high-level value provided the data recorder full-scale 
requirements as described above are met.
    The CEMS design must also allow the determination of calibration 
drift at the zero and high-level values. If this is not possible or 
practical, the design must allow these determinations to be conducted at 
a low-level value (zero to 20 percent of the high-level value) and at a 
value between 50 and 100 percent of the high-level value. In special 
cases, if not already approved, the Administrator may approve a single-
point calibration-drift determination.
    4.2  Calibration Drift. The CEMS calibration must not drift or 
deviate from the reference value of the gas cylinder, gas cell, or 
optical filter by more than 2.5 percent of the span value. If the CEMS 
includes pollutant and diluent monitors, the calibration drift must be 
determined separately for each in terms of concentrations (see PS 3 for 
the diluent specifications).
    4.3  The CEMS RA. The RA of the CEMS must be no greater than 20 
percent of the mean value of the RM test data in terms of the units of 
the emission standard or 10 percent of the applicable standard, 
whichever is greater. For SO2 emission standards between 130 
and 86 ng/J (0.30 and 0.20 lb/million Btu), use 15 percent of the 
applicable standard; below 86 ng/J (0.20 lb/million Btu), use 20 percent 
of emission standard.

5. Performance Specification Test Procedure

    5.1  Pretest Preparation. Install the CEMS, prepare the RM test site 
according to the specifications in Section 3, and prepare the CEMS for 
operation according to the manufacturer's written instructions.
    5.2  Calibration Drift Test Period. While the affected facility is 
operating at more than 50 percent of normal load, or as specified in an 
applicable subpart, determine the magnitude of the calibration drift 
(CD) once each day (at 24-hour intervals) for 7 consecutive days 
according to the procedure given in Section 6. To meet the requirement 
of Section 4.2, none of the CD's must exceed the specification.
    5.3  RA Test Period. Conduct the RA test according to the procedure 
given in Section 7 while the affected facility is operating at more than 
50 percent or normal load, or as specified in an applicable subpart. To 
meet the specifications, the RA must be equal to or less than 20 percent 
of the mean value of the RM test data in terms of the units of the 
emission standard or 10 percent of the applicable standard, whichever is 
greater. For instruments that use common components to measure more than 
one effluent gas constituent, all channels must simultaneously pass the 
RA requirement, unless it can be demonstrated that any adjustments made 
to one channel did not affect the others.
    The RA test may be conducted during the CD test period.

6. The CEMS Calibration Drift Test Procedure

    The CD measurement is to verify the ability of the CEMS to conform 
to the established CEMS calibration used for determining the emission 
concentration or emission rate. Therefore, if periodic automatic or 
manual adjustments are made to the CEMS zero and calibration settings, 
conduct the CD test immediately before these adjustments, or conduct it 
in such a way that the CD can be determined.
    Conduct the CD test at the two points specified in Section 4.1. 
Introduce to the CEMS the reference gases, gas cells, or optical filters 
(these need not be certified). Record the CEMS response and subtract 
this value from the reference value (see example data sheet in Figure 2-
1).

7. Relative Accuracy Test Procedure

    7.1  Sampling Strategy for RM Tests. Conduct the RM tests in such a 
way that they will yield results representative of the emissions from 
the source and can be correlated to the CEMS data. Although it is 
preferable to conduct the diluent (if applicable), moisture (if needed), 
and pollutant measurements simultaneously, the diluent and moisture 
measurements that are taken within a 30- to 60-minute period, which 
includes the pollutant measurements, may be used to calculate dry 
pollutant concentration and emission rate.
    In order to correlate the CEMS and RM data properly, mark the 
beginning and end of each RM test period of each run (including the 
exact time of the day) on the CEMS chart recordings or other permanent 
record of output. Use the following strategies for the RM tests:
    7.1.1  For integrated samples, e.g., Method 6 and Method 4, make a 
sample traverse of at least 21 minutes, sampling for 7 minutes at each 
traverse point.
    7.1.2  For grab samples, e.g., Method 7, take one sample at each 
traverse point, scheduling the grab samples so that they are taken 
simultaneously (within a 3-minute period) or are an equal interval of 
time apart over a 21-minute (or less) period. A test run for grab 
samples must be made up of at least three separate measurements.
    Note: At times, CEMS RA tests are conducted during new source 
performance standards performance tests. In these cases, RM

[[Page 1156]]

results obtained during CEMS RA tests may be used to determine 
compliance as long as the source and test conditions are consistent with 
the applicable regulations.
    7.2  Correlation of RM and CEMS Data. Correlate the CEMS and the RM 
test data as to the time and duration by first determining from the CEMS 
final output (the one used for reporting) the integrated average 
pollutant concentration or emission rate for each pollutant RM test 
period. Consider system response time, if important, and confirm that 
the pair of results are on a consistent moisture, temperature, and 
diluent concentration basis. Then, compare each integrated CEMS value 
against the corresponding average RM value. Use the following guidelines 
to make these comparisons.
    7.2.1  If the RM has an integrated sampling technique, make a direct 
comparison of the RM results and CEMS integrated average value.
    7.2.2  If the RM has a grab sampling technique, first average the 
results from all grab samples taken during the test run and then compare 
this average value against the integrated value obtained from the CEMS 
chart recording or output during the run. If the pollutant concentration 
is varying with time over the run, the tester may choose to use the 
arithmetic average of the CEMS value recorded at the time of each grab 
sample.
    7.3  Number of RM Tests. Conduct a minimum of nine sets of all 
necessary RM tests. Conduct each set within a period of 30 to 60 
minutes.
    Note: The tester may choose to perform more than nine sets of RM 
tests. If this option is chosen, the tester may, at his discretion, 
reject a maximum of three sets of the test results so long as the total 
number of test results used to determine the RA is greater than or equal 
to nine, but he must report all data including the rejected data.
    7.4  Reference Methods. Unless otherwise specified in an applicable 
subpart of the regulations, Methods 3B, 4, 6, and 7, or their approved 
alternatives, are the reference methods for diluent (O2 and 
CO2), moisture, SO2, and NOx, 
respectively.
    7.5  Calculations. Summarize the results on a data sheet. An example 
is shown in Figure 2-2. Calculate the mean of the RM values. Calculate 
the arithmetic differences between the RM and the CEMS output sets. Then 
calculate the mean of the difference, standard deviation, confidence 
coefficient, and CEMS RA, using Equations 2-1, 2-2, 2-3, and 2-4.

8. Equations

    8.1  Arithmetic Mean. Calculate the arithmetic mean of the 
difference, d, of a data set as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.285

Where:

n=Number of data points.
[GRAPHIC] [TIFF OMITTED] TC01JN92.286

When the mean of the differences of pairs of data is calculated, be sure 
to correct the data for moisture, if applicable.
    8.2  Standard Deviation. Calculate the standard deviation, 
Sd, as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.287

    8.3  Confidence Coefficient. Calculate the 2.5 percent error 
confidence coefficient (one-tailed), CC, as follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.288

Where:

t 0.975=t-value (see Table 2-1)

                          Table 2-1-- t-Values
------------------------------------------------------------------------
   na        t0.975        na         t0.975        na         t0.975
------------------------------------------------------------------------
    2         12.706         7          2.447        12          2.201
    3          4.303         8          2.365        13          2.179
    4          3.182         9          2.306        14          2.160
    5          2.776        10          2.262        15          2.145
    6          2.571        11          2.228        16          2.131
------------------------------------------------------------------------
a The values in this table are already corrected for n-1 degrees of
  freedom. Use n equal to the number of individual values.

    8.4  Relative Accuracy. Calculate the RA of a set of data as 
follows:
[GRAPHIC] [TIFF OMITTED] TC01JN92.289

Where:
| d|=Absolute value of the mean of differences (from Equation 2-1).
| CC|=Absolute value of the confidence coefficient (from Equation 2-3).
RM=Average RM value or applicable standard.

9. Reporting

    At a minimum (check with the appropriate regional office, or State, 
or local agency for additional requirements, if any) summarize in 
tabular form the results of the CD tests and the relative accuracy tests 
or alternative RA procedure as appropriate. Include all data sheets, 
calculations, charts (records

[[Page 1157]]

of CEMS responses), cylinder gas concentration certifications, and 
calibration cell response certifications (if applicable), necessary to 
substantiate that the performance of the CEMS met the performance 
specifications.

10. Alternative Procedures

    10.1 Alternative to Relative Accuracy Procedure in section 7. 
Paragraphs 60.13(j) (1) and (2) contain criteria for which the reference 
method relative accuracy may be waived and the following procedure 
substituted.
    10.1.1 Conduct a complete CEMS status check following the 
manufacturer's written instructions. The check should include operation 
of the light source, signal receiver, timing mechanism functions, data 
acquisition and data reduction functions, data recorders, mechanically 
operated functions (mirror movements, zero pipe operation, calibration 
gas valve operations, etc.), sample filters, sample line heaters, 
moisture traps, and other related functions of the CEMS, as applicable. 
All parts of the CEMS shall be functioning properly before proceeding to 
the alternative RA procedure.
    10.1.2 Challenge each monitor (both pollutant and diluent, if 
applicable) with cylinder gases of known concentrations or calibration 
cells that produce known responses at two measurement points within the 
following ranges:

                                                Measurement Range
----------------------------------------------------------------------------------------------------------------
                                                                               Diluent monitor for
          Measurement point               Pollutant monitor    -------------------------------------------------
                                                                          CO2                       O2
----------------------------------------------------------------------------------------------------------------
1....................................  20-30 percent of span    5-8 percent by volume..  4-6 percent by volume.
                                        value.
2....................................  50-60 percent of span    10-14 percent by volume  8-12 percent by volume.
                                        value.
----------------------------------------------------------------------------------------------------------------

    Use a separate cylinder gas or calibration cell for measurement 
points 1 and 2. Challenge the CEMS and record the responses three times 
at each measurement point. Do not dilute gas from a cylinder when 
challenging the CEMS. Use the average of the three responses in 
determining relative accuracy.
    Operate each monitor in its normal sampling mode as nearly as 
possible. When using cylinder gases, pass the cylinder gas through all 
filters, scrubbers, conditioners, and other monitor components used 
during normal sampling and as much of the sampling probe as practical. 
When using calibration cells, the CEMS components used in the normal 
sampling mode should not be by-passed during the RA determination. These 
include light sources, lenses, detectors, and reference cells. The CEMS 
should be challenged at each measurement point for a sufficient period 
of time to assure adsorption-desorption reactions on the CEMS surfaces 
have stabilized.
    Use cylinder gases that have been certified by comparison to 
National Bureau of Standards (NBS) gaseous standard reference material 
(SRM) or NBS/EPA-approved gas manufacturer's certified reference 
material (CRM) (See Citation 2 in the Bibliography) following EPA 
traceability protocol Number 1 (See Citation 3 in the Bibliography). As 
an alternative to protocol Number 1 gases, CRM's may be used directly as 
alternative RA cylinder gases. A list of gas manufacturers that have 
prepared approved CRM's is available from EPA at the address shown in 
Citation 2. Procedures for preparation of CRM are described in Citation 
2.
    Use calibration cells certified by the manufacturer to produce a 
known response in the CEMS. The cell certification procedure shall 
include determination of CEMS response produced by the calibration cell 
in direct comparison with measurement of gases of known concentration. 
This can be accomplished using SRM or CRM gases in a laboratory source 
simulator or through extended tests using reference methods at the CEMS 
location in the exhaust stack. These procedures are discussed in 
Citation 4 in the Bibliography. The calibration cell certification 
procedure is subject to approval of the Administrator.
    10.1.3  The differences between the known concentrations of the 
cylinder gases and the concentrations indicated by the CEMS are used to 
assess the accuracy of the CEMS.
    The calculations and limits of acceptable relative accuracy (RA) are 
as follows:

    (a) For pollutant CEMS:
    [GRAPHIC] [TIFF OMITTED] TC16NO91.239
    
Where:
d=Difference between response and the known concentration/response.
AC=The known concentration/response of the cylinder gas or calibration 
          cell.
    (b) For diluent CEMS:
RA=|d|  0.7 percent O2 or CO2, as 
          applicable.
    Note: Waiver of the relative accuracy test in favor of the 
alternative RA procedure does not preclude the requirements to complete 
the calibration drift (CD) tests nor any other requirements specified in 
the applicable regulation(s) for reporting CEMS data and performing CEMS 
drift checks or audits.

[[Page 1158]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.290


[[Page 1159]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.291

11.Bibliography

    1.  Department of Commerce. Experimental Statistics. Handbook 91. 
Washington, DC, p. 3-31, paragraphs 3-3.1.4.
    2.  ``A Procedure for Establishing Traceability of Gas Mixtures to 
Certain National Bureau of Standards Standard Reference Materials.'' 
Joint publication by NBS and EPA. EPA-600/7-81-010. Available from

[[Page 1160]]

U.S. Environmental Protection Agency, Quality Assurance Division (MD-
77), Research Triangle Park, NC 27711.
    3.  ``Traceability Protocol for Establishing True Concentrations of 
Gases Used for Calibration and Audits of Continuous Source Emission 
Monitors. (Protocol Number 1).'' June 1978. Protocol Number 1 is 
included in the Quality Assurance Handbook for Air Pollution Measurement 
Systems, Volume III, Stationary Source Specific Methods. EPA-600/4-77-
027b. August 1977. Volume III is available from the U.S. EPA, Office of 
Research and Development Publications, 26 West St. Clair Street, 
Cincinnati, OH 45268.
    4.  ``Gaseous Continuous Emission Monitoring Systems--Performance 
Specification Guidelines for SO2, NOx, 
CO2, O2, and TRS.'' EPA-450/3-82-026. Available 
from U.S. Environmental Protection Agency, Emission Standards and 
Engineering Division (MD-19), Research Triangle Park, NC 27711.

  Performance Specification 3--Specifications and Test Procedures For 
O2 and CO2 Continuous Emission Monitoring Systems 
                          in Stationary Sources

1. Applicability and Principle
    1.1  Applicability. This specification is to be used for evaluating 
acceptability of O2 and CO2 continuous emission 
monitoring systems (CEM's) at the time of or soon after installation and 
whenever specified in an applicable subpart of the regulations. The 
specification applies to O2 or CO2 monitors that 
are not included under Performance Specification 2 (PS 2).
    This specification is not designed to evaluate the installed CEMS 
performance over an extended period of time, nor does it identify 
specific calibration techniques and other auxiliary procedures to assess 
the CEMS performance. The source owner or operator, however, is 
responsible to calibrate, maintain, and operate the CEMS properly. To 
evaluate the CEMS performance, the Administrator may require, under 
Section 114 of the Act, the operator to conduct CEMS performance 
evaluations in addition to the initial test. See Section 60.13(c).
    The definitions, installation and measurement location 
specifications, test procedures, data reduction procedures, reporting 
requirements, and bibliography are the same as in PS 2, Sections 2, 3, 
5, 6, 8, 9, and 10, and also apply to O2 and CO2 
CEMS's under this specification. The performance and equipment 
specifications and the relative accuracy (RA) test procedures for 
O2 and CO2 CEMS do not differ from those for 
SO2 and NOx CEMS, except as noted below.
    1.2  Principle. Reference method (RM) tests and calibration drift 
tests are conducted to determine conformance of the CEMS with the 
specification.

2. Performance and Equipment Specifications

    2.1  Instrument Zero and Span. This specification is the same as 
Section 4.1 of PS 2.
    2.2  Calibration Drift. The CEMS calibration must not drift by more 
than 0.5 percent O2 or CO2 from the reference 
value of the gas, gas cell, or optical filter.
    2.3  The CEMS RA. The RA of the CEMS must be no greater than 20 
percent of the mean value of the RM test data or 1.0 percent O2 
or CO2 , whichever is greater.

3. Relative Accuracy Test Procedure

    3.1  Sampling Strategy for RM Tests, Correlation of RM and CEMS 
Data, Number of RM Tests, and Calculations. This is the same as PS 2, 
Sections 7.1, 7.2, 7.3, and 7.5, respectively.
    3.2  Reference Method. Unless otherwise specified in an applicable 
subpart of the regulations, Method 3B of appendix A or any approved 
alternative is the RM for O2 or CO2.

 Performance Specification 4--Specifications and Test Procedures 
for Carbon Monoxide Continuous Emission Monitoring Systems in Stationary 
                                 Sources

1. Applicability and Principle

    1.1  Applicability. This specification is to be used for evaluating 
the acceptability of carbon monoxide (CO) continuous emission monitoring 
systems (CEMS) at the time of or soon after installation and whenever 
specified in an applicable subpart of the regulations.
    This specification is not designed to evaluate the installed CEMS 
performance over an extended period of time nor does it identify 
specific calibration techniques and other auxiliary procedures to assess 
CEMS performance. The source owner or operator, however, is responsible 
to calibrate, maintain, and operate the CEMS. To evaluate CEMS 
performance, the Administrator may require, under section 114 of the 
Act, the source owner or operator to conduct CEMS performance 
evaluations at other times besides the initial test. See Sec. 60.13(c).
    The definitions, installation specifications, test procedures, data 
reduction procedures for determining calibration drifts (CD) and 
relative accuracy (RA), and reporting of Performance Specification 2 (PS 
2), Sections 2, 3, 5, 6, 8, and 9 apply to this specification.
    1.2  Principle. Reference method (RM), CD, and RA tests are 
conducted to determine that the CEMS conforms to the specification.

2. Performance and Equipment Specifications

    2.1  Instrument Zero and Span. This specification is the same as 
Section 4.1 of PS 2.
    2.2  Calibration Drift. The CEMS calibration must not drift or 
deviate from the reference value of the calibration gas, gas cell, or 
optical filter by more than 5 percent of the established span value for 
6 out of 7 test

[[Page 1161]]

days (e.g., the established span value is 1000 ppm for subpart J 
affected facilities).
    2.3  Relative Accuracy. The RA of the CEMS shall be no greater than 
10 percent of the mean value of the RM test data in terms of the units 
of the emission standard or 5 percent of the applicable standard, 
whichever is greater.

3. Relative Accuracy Test Procedure

    3.1  Sampling Strategy for RM Tests, Correlation of RM and CEMS 
Data, Number of RM Tests, and Calculations. These are the same as PS 2, 
Sections 7.1, 7.2, 7.3, and 7.5, respectively.
    3.2  Reference Methods. Unless otherwise specified in an applicable 
subpart of the regulation, Method 10 is the RM for this PS. When 
evaluating nondispersive infrared continuous emission analyzers, Method 
10 shall use the alternative interference trap specified in section 10.1 
of the method. Method 10A or 10B is an acceptable alternative to method 
10.

4. Bibliography

    1.  Ferguson, B.B., R.E. Lester, and W.J. Mitchell. Field Evaluation 
of Carbon Monoxide and Hydrogen Sulfide Continuous Emission Monitors at 
an Oil Refinery. U.S. Environmental Protection Agency. Research Triangle 
Park, NC. Publication No. EPA-600/4-82-054. August 1982. 100 p.
    2.  Repp, M. Evaluation of Continuous Monitors for Carbon Monoxide 
in Stationary Sources. U.S. Environmental Protection Agency. Research 
Triangle Park, NC. Publication No. EPA-600/2-77-063. March 1977/ 155 p.
    3.  Smith, F., D.E. Wagoner, and R.P. Donovan. Guidelines for 
Development of a Quality Assurance Program: Volume VIII--Determination 
of CO Emissions from Stationary Sources by NDIR Spectrometry. U.S. 
Environmental Protection Agency. Research Triangle Park, NC. Publication 
No. EPA-650/4-74-005-h. February 1975. 96 p.

  Performance Specification 4A--Specifications and Test Procedures For 
  Carbon Monoxide Continuous Emission Monitoring Systems in Stationary 
                                 Sources

                     1. Applicability and Principle

    1.1  Applicability.
    1.1.1  This specification is to be used for evaluating the 
acceptability of carbon monoxide (CO) continuous emission monitoring 
systems (CEMS's) at the time of or soon after installation and whenever 
specified in an applicable subpart of the regulations.
    1.1.2  This specification is not designed to evaluate the installed 
CEMS performance over an extended period of time nor does it identify 
specific calibration techniques and other auxiliary procedures to assess 
CEMS performance. The source owner or operator, however, is responsible 
to calibrate, maintain, and operate the CEMS. To evaluate CEMS 
performance, the Administrator may require, under section 114 of the 
Act, the source owner or operator to conduct CEMS performance 
evaluations at other times besides the initial test. See Sec. 60.13(c).
    1.1.3  The definition, installation specifications, test procedures, 
data reduction procedures for determining calibration drifts (CD) and 
relative accuracy (RA), and reporting of Performance Specification 2 (PS 
2), sections 2, 3, 5, 6, 8, and 9 apply to this specification.
    1.2  Principle. Reference method (RM), CD and RA tests are conducted 
to determine that the CEMS conforms to the specification.

               2. Performance and Equipment Specifications

    2.1  Data Recorder Scale. This specification is the same as section 
4.1 of PS 2. The CEMS shall be capable of measuring emission levels 
under normal conditions and under periods of short-duration peaks of 
high concentrations. This dual-range capability may be met using two 
separate analyzers, one for each range, or by using dual-range units 
which have the capability of measuring both levels with a single unit. 
In the latter case, when the reading goes above the full-scale 
measurement value of the lower range, the higher-range operation shall 
be started automatically. The CEMS recorder range must include zero and 
a high-level value.
    For the low-range scale, the high-level value shall be between 1.5 
times the pollutant concentration corresponding to the emission standard 
level and the span value. For the high-range scale, the high-level value 
shall be set at 2000 ppm, as a minimum, and the range shall include the 
level of the span value. There shall be no concentration gap between the 
low- and high-range scales.
    2.2  Interference Check. The CEMS must be shown to be free from the 
effects of any interferences.
    2.3  Response Time. The CEMS response time shall not exceed 1.5 min 
to achieve 95 percent of the final stable value.
    2.4  Calibration Drift. The CEMS calibration must not drift or 
deviate from the reference value of the calibration gas, gas cell, or 
optical filter by more than 5 percent of the established span value for 
6 out of 7 test days.
    2.5  Relative Accuracy. The RA of the CEMS shall be no greater than 
10 percent of the mean value of the RM test data in terms of the units 
of the emission standard or 5 ppm, whichever is greater. Under 
conditions where the average CO emissions are less than 10 percent of 
the standard, a cylinder gas audit may be performed in place of the RA 
test to determine compliance with these limits. In this case, the 
cylinder gas shall contain CO in 12 percent carbon dioxide as an 
interference check. If this option is exercised,

[[Page 1162]]

Method 10 must be used to verify that emission levels are less than 10 
percent of the standard.

                     3. Response Time Test Procedure

    The response time test applies to all types of CEMS's, but will 
generally have significance only for extractive systems. The entire 
system is checked with this procedure including applicable sample 
extraction and transport, sample conditioning, gas analyses, and data 
recording.
     Introduce zero gas into the system. For extractive systems, the 
calibration gases should be introduced at the probe as near to the 
sample location as possible. For in-situ systems, introduce the zero gas 
at the sample interface so that all components active in the analysis 
are tested. When the system output has stabilized (no change greater 
than 1 percent of full scale for 30 sec), switch to monitor stack 
effluent and wait for a stable value. Record the time (upscale response 
time) required to reach 95 percent of the final stable value. Next, 
introduce a high-level calibration gas and repeat the procedure 
(stabilize, switch the sample, stabilize, record). Repeat the entire 
procedure three times and determine the mean upscale and downscale 
response times. The slower or longer of the two means is the system 
response time.

                   4. Relative Accuracy Test Procedure

    4.1  Sampling Strategy for RM Tests, Correlation of RM and CEMS 
Data, Number of RM Tests, and Calculations. These are the same as PS 2, 
sections 7.1, 7.2, 7.3, and 7.5, respectively.
    4.2  Reference Methods. Unless otherwise specified in an applicable 
subpart of the regulation, Method 10 is the RM for this PS. When 
evaluating nondispersive infrared continuous emission analyzers, Method 
10 shall use the alternative interference trap specified in section 10.1 
of the method. Method 10A or 10B is an acceptable alternative to Method 
10.

                             5. Bibliography

    1.  Same as in Performance Specification 4, section 4.
    2.  ``Gaseous Continuous Emission Monitoring Systems--Performance 
Specification Guidelines for SO2, NOx, 
CO2, O2, and TRS.'' EPA-450/3-82-026. U.S. 
Environmental Protection Agency, Technical Support Division (MD-19). 
Research Triangle Park, NC 27711.

Performance Specification 5--Specifications and Test Procedures for TRS 
      Continuous Emission Monitoring Systems in Stationary Sources

1. Applicability and Principle

    1.1  Applicability. This specification is to be used for evaluating 
the acceptability of total reduced sulfur (TRS) and whenever specified 
in an applicable subpart of the regulations. (At present, these 
performance specifications do not apply to petroleum refineries, subpart 
J.) Sources affected by the promulgation of the specification shall be 
allowed 1 year beyond the promulgation date to install, operate, and 
test the CEMS. The CEMS's may include O2 monitors which are 
subject to Performance Specification 3 (PS 3).
    The definitions, installation specifications, test procedures, and 
data reduction procedures for determining calibration drifts (CD's) and 
relative accuracy (RA), and reporting of PS 2, Sections 2, 3, 4, 5, 6, 
8, and 9 also apply to this specification and must be consulted. The 
performance and equipment specifications do not differ from PS 2 except 
as listed below and are included in this specification.
    1.2  Principle. The CD and RA tests are conducted to determine 
conformance of the CEMS with the specification.

2. Performance and Equipment Specifications

    2.1  Instrument Zero and Span. The CEMS recorder span must be set at 
90 to 100 percent of recorder full-scale using a span level between 1.5 
times the pollutant concentration corresponding to the emission standard 
level and the span value. The CEMS design shall also allow the 
determination of calibration at the zero level of the calibration curve. 
If zero calibration is not possible or is impractical, this 
determination may be conducted at a low level (up to 20 percent of span 
value) point. The components of an acceptable permeation tube system are 
listed on pages 87-94 of Citation 4.2 of the Bibliography.
    2.2  Calibration Drift. The CEMS detector calibration must not drift 
or deviate from the reference value of the calibration gas by more than 
5 percent (1.5 ppm) of the established span value of 30 ppm for 6 out of 
7 test days. If the CEMS includes pollutant and diluent monitors, the CD 
must be determined separately for each in terms of concentrations (see 
PS 3 for the diluent specifications).
    2.3  The CEMS Relative Accuracy. The RA of the CEMS shall be no 
greater than 20 percent of the mean value of the reference method (RM) 
test data in terms of the units of the emission standard or 10 percent 
of the applicable standard, whichever is greater.

3. Relative Accuracy Test Procedure

    3.1  Sampling Strategy for RM Tests, Correlation of RM and CEMS 
Data, Number of RM Tests, and Calculations. This is the same as PS 2, 
Sections 7.1, 7.2, 7.3, and 7.5, respectively. Note: For Method 16, a 
sample is made up of at least three separate injects equally spaced over 
time. For Method 16A, a sample is collected for at least 1 hour.

[[Page 1163]]

    3.2  Reference Methods. Unless otherwise specified in an applicable 
subpart of the regulations, Method 16, Method 16A, or other approved 
alternative, shall be the RM for TRS.

4. Bibliography

    1.  Department of Commerce. Experimental Statistics. National Bureau 
of Standards. Handbook 91. 1963. Paragraphs 3-3.1.4, p. 3-31.
    2.  A Guide to the Design, Maintenance and Operation of TRS 
Monitoring Systems. National Council for Air and Stream Improvement 
Technical Bulletin No. 89. September 1977.
    3.  Observation of Field Performance of TRS Monitors on a Kraft 
Recovery Furnace. National Council for Air and Stream Improvement 
Technical Bulletin No. 91. January 1978.

  Performance Specification 6--Specifications and Test Procedures For 
    Continuous Emission Rate Monitoring Systems in Stationary Sources

                     1. Applicability and Principle

    1.1  Applicability. The applicability for this specification is the 
same as Section 1.1 of Performance Specification 2 (PS 2), except this 
specification is to be used for evaluating the acceptability of 
continuous emission rate monitoring systems (CERMS's). The installation 
and measurement location specifications, performance specification test 
procedure, data reduction procedures, and reporting requirements of PS 
2, Section 3, 5, 8, and 9, apply to this specification.
    1.2  Principle. Reference method (RM), calibration drift (CD), and 
relative accuracy (RA) tests are conducted to determine that the CERMS 
conforms to the specification.

                             2. Definitions

    The definitions are the same as in Section 2 of PS 2, except that 
this specification refers to the continuous emission rate monitoring 
system rather than the continuous emission monitoring system. The 
following definitions are added:
    2.1  Continuous Emission Rate Monitoring System (CERMS). The total 
equipment required for the determination and recording of the pollutant 
mass emission rate (in terms of mass per unit of time).
    2.2  Flow Rate Sensor. That portion of the CERMS that senses the 
volumetric flow rate and generates an output proportional to flow rate. 
The flow rate sensor shall have provisions to check the CD for each flow 
rate parameter that it measures individually (e.g., velocity pressure).

               3. Performance and Equipment Specifications

    3.1  Data Recorder Scale. Same as Section 4.1 of PS 2.
    3.2  CD. Since the CERMS includes analyzers for several 
measurements, the CD shall be determined separately for each analyzer in 
terms of its specific measurement. The calibration for each analyzer 
used for the measurement of flow rate except a temperature analyzer 
shall not drift or deviate from either of its reference values by more 
than 3 percent of 1.25 times the average potential absolute value for 
that measurement. For a temperature analyzer, the specification is 1.5 
percent of 1.25 times the average potential absolute temperature. The CD 
specification for each analyzer for which other PS's have been 
established (e.g., PS 2 for SO2 and NOx), shall be 
the same as in the applicable PS.
    3.3  CERMS RA. The RA of the CERMS shall be no greater than 20 
percent of the mean value of the RM's test data in terms of the units of 
the emission standard, or 10 percent of the applicable standard, 
whichever is greater.

                          4. CD Test Procedure

    The CD measurements are to verify the ability of the CERMS to 
conform to the established CERMS calibrations used for determining the 
emission rate. Therefore, if periodic automatic or manual adjustments 
are made to the CERMS zero and calibration settings, conduct the CD 
tests immediately before these adjustments, or conduct them in such a 
way what CD can be determined.
    Conduct the CD tests for pollutant concentration at the two values 
specified in Section 4.1 of PS 2. For each of the other parameters that 
are selectively measured by the CERMS (e.g., velocity pressure), use two 
analogous values: one that represents zero to 20 percent of the high-
level value (a value that is between 1.25 and 2 times the average 
potential value) for that parameter, and one that represents 50 to 100 
percent of the high-level value. Introduce, or activate internally, the 
reference signals to the CERMS (these need not be certified). Record the 
CERMS response to each, and subtract this value from the respective 
reference value (see example data sheet in Figure 6-1).

                          5. RA Test Procedure

    5.1  Sampling Strategy for RM's Tests, Correlation of RM and CERMS 
Data, Number of RM's Tests, and Calculations. These are the same as PS 
2, Sections 7.1, 7.2, 7.3, and 7.5, respectively. Summarize the results 
on a data sheet. An example is shown in Figure 6-2. The RA test may be 
conducted during the CD test period.
    5.2  Reference Methods (RM's). Unless otherwise specified in the 
applicable subpart of the regulations, the RM for the pollutant gas is 
the appendix A method that is cited for compliance test purposes, or its 
approved alternatives. Methods 2, 2A, 2B, 2C, or 2D, as

[[Page 1164]]

applicable are the RM's for the determination of volumetric flow rate.

                             6. Bibliography

    1. Brooks, E.F., E.C. Beder, C.A. Flegal, D.J. Luciani, and R. 
Williams. Continuous Measurement of Total Gas Flow Rate from Stationary 
Sources. U.S. Envionmental Protection Agency. Research Triangle Park, 
NC. Publication No. EPA-650/2-75-020. February 1975. 248 p.

  Performance Specification 7--Specifications and Test Procedures for 
 Hydrogen Sulfide Continuous Emission Monitoring Systems in Stationary 
                                 Sources

                     1. Applicability and Principle

    1.1  Applicability. 1.1.1  This specification is to be used for 
evaluating the acceptability of hydrogen sulfide (H2S) 
continuous emission monitoring systems (CEMS's) at the time of or soon 
after installation and whenever specified in an applicable subpart of 
the regulations.
    1.1.2  This specification is not designed to evaluate the installed 
CEMS performance over an extended period of time nor does it identify 
specific calibration techniques and other auxiliary procedures to assess 
CEMS performance. The source owner or operator, however, is responsible 
to calibrate, maintain, and operate the CEMS. To evaluate CEMS 
performance, the Administrator may require, under Section 114 of the 
Act, the source owner or operator to conduct CEMS performance 
evaluations at other times besides the initial test. See Sec. 60.13(c).
    1.1.3  The definitions, installation specifications, test 
procedures, data reduction procedures for determining calibration drifts 
(CD) and relative accuracy (RA), and reporting of Performance 
Specification 2 (PS 2), Sections 2, 3, 5, 6, 8, and 9 apply to this 
specification.
    1.2  Principle. Reference method (RM), CD, and RA tests are 
conducted to determine that the CEMS conforms to the specification.

               2. Performance and Equipment Specifications

    2.1  Instrument zero and span. This specification is the same as 
Section 4.1 of PS 2.
    2.2  Calibration drift. The CEMS calibration must not drift or 
deviate from the reference value of the calibration gas or reference 
source by more than 5 percent of the established span value for 6 out of 
7 test days (e.g., the established span value is 300 ppm for subpart J 
fuel gas combustion devices).
    2.3  Relative accuracy. The RA of the CEMS shall be no greater than 
20 percent of the mean value of the RM test data in terms of the units 
of the emission standard or 10 percent of the applicable standard, 
whichever is greater.

                   3. Relative Accuracy Test Procedure

    3.1  Sampling Strategy for RM Tests, Correlation of RM and CEMS Data 
Number of RM Tests, and Calculations. These are the same as that in PS 
2, Sec. 7.1, 7.2, 7.3, and 7.5, respectively.
    3.2  Reference Methods. Unless otherwise specified in an applicable 
subpart of the regulation, Method 11 is the RM for this PS.

                             4. Bibliography

    1. U.S. Environmental Protection Agency. Standards of Performance 
for New Stationary Sources; Appendix B; Performance Specifications 2 and 
3 for SO2, NOx, CO2, and O2 
Continuous Emission Monitoring Systems; Final Rule. 48 CFR 23608. 
Washington, DC, U.S. Government Printing Office. May 25, 1983.
    2. U.S. Government Printing Office. Gaseous Continuous Emission 
Monitoring Systems--Performance Specification Guidelines for 
SO2, NOx, CO2, O2, and TRS. 
U.S. Environmental Protection Agency. Washington, DC, EPA-450/3-82-026. 
October 1982. 26p.
    3. Maines, G.D., W.C. Kelly (Scott Environmental Technology, Inc.), 
and J.B. Homolya. Evaluation of Monitors for Measuring H2S in 
Refinery Gas. Prepared for the U.S. Environmental Protection Agency. 
Research Triangle Park, NC, Contract No. 68-02-2707. 1978. 60 p.
    4. Ferguson, B.B., R.E. Lester (Harmon Engineering and Testing), and 
W.J. Mitchell. Field Evaluation of Carbon Monoxide and Hydrogen Sulfide 
Continuous Emission Monitors at an Oil Refinery. Prepared for the U.S. 
Environmental Protection Agency. Research Triangle Park, NC. Publication 
No. EPA-600/4-82-054. August 1982. 100 p.

  Performance Specification 8--Performance Specifications for Volatile 
 Organic Compound Continuous Emission Monitoring Systems in Stationary 
                                 Sources

                     1. Applicability and Principle

    1.1  Applicability.
    1.1.1  This specification is to be used for evaluating a continuous 
emission monitoring system (CEMS) that measures a mixture of volatile 
organic compounds (VOC's) and generates a single combined response 
value. The VOC detection principle may be flame ionization (FI), 
photoionization (PI), nondispersive infrared absorption (NDIR), or any 
other detection principle that is appropriate for the VOC species 
present in the emission gases and that meets this performance 
specification. The performance specification includes procedures to 
evaluate the acceptability of the CEMS at the time of or

[[Page 1165]]

soon after its installation and whenever specified in emission 
regulations or permits. This specification is not designed to evaluate 
the installed CEMS performance over an extended period of time, nor does 
it identify specific calibration techniques and other auxiliary 
procedures to assess the CEMS performance. However, it is the 
responsibility of the source owner or operator, to calibrate, maintain, 
and operate the CEMS properly. Under section 114 of the Act, the 
Administrator may require the operator to evaluate the CEMS performance 
by conducting CEMS performance evaluations in addition to the initial 
test. See section 60.13(c).
    The definitions, installation and measurement location 
specifications, test procedures, data reduction procedures, reporting 
requirements, and bibliography are the same as in PS 2, sections 2, 3, 
5, 6, 8, 9, and 10, and also apply to VOC CEMS's under this 
specification. The performance and equipment specifications and the 
relative accuracy (RA) test procedures for VOC CEMS do not differ from 
those for SO2 and NOx CEMS, except as noted below.
    1.1.2  In most emission circumstances, most VOC monitors can provide 
only a relative measure of the total mass or volume concentration of a 
mixture of organic gases, rather than an accurate quantification. This 
problem is removed when an emission standard is based on a total VOC 
measurement as obtained with a particular detection principle. In those 
situations where a true mass or volume VOC concentration is needed, the 
problem can be mitigated by using the VOC CEMS as a relative indicator 
of total VOC concentration if statistical analysis indicates that a 
sufficient margin of compliance exists for this approach to be 
acceptable. Otherwise, consideration can be given to calibrating the 
CEMS with a mixture of the same VOC's in the same proportions as they 
actually occur in the measured source. In those circumstances where only 
one organic species is present in the source, or where equal incremental 
amounts of each of the organic species present generate equal CEMS 
responses, the latter choice can be more easily achieved.
    1.2  Principle. Calibration drift and relative accuracy tests are 
conducted to determine the adherence of the CEMS to specifications given 
for those items. The performance specifications include criteria for 
installation and measurement location, equipment and performance, and 
procedures for testing and data reduction.

              2.  Performance and Equipment Specifications

    2.1  VOC CEMS Selection. When possible, select a VOC CEMS with the 
detection principle of the reference method specified in the regulation 
or permit (usually either FI, NDIR, or PI). Otherwise, use knowledge of 
the source process chemistry, previous emission studies, or gas 
chromatographic analysis of the source gas to select an appropriate VOC 
CEMS. Exercise extreme caution in choosing and installing any CEMS in an 
area with the potential for explosive hazards.
    2.2  Data Recorder Scale. Same as section 4.1 of PS 2.
    2.3  Calibration Drift. The CEMS calibration must not drift by more 
than 2.5 percent of the span value.
    2.4  CEMS Relative Accuracy. Unless stated otherwise in the 
regulation or permit, the RA of the CEMS must be no greater than 20 
percent of the mean value of the reference method (RM) test data in 
terms of the units of the emission standard, or 10 percent of the 
applicable standard, whichever is greater.

                   3. Relative Accuracy Test Procedure

    3.1  Sampling Strategy for RM Tests, Correlation of RM and CEMS 
Data, Number of RM Tests, and Calculations. Follow PS 2, sections 7.1, 
7.2, 7.3, and 7.5, respectively.
    3.2  Reference Method. Use the method specified in the applicable 
regulation or permit, or any approved alternative, as the RM.

Performance Specification 9--Specifications and Test Procedures for Gas 
  Chromatographic Continuous Emission Monitoring Systems in Stationary 
                                 Sources

                     1. Applicability and Principle

    1.1  Applicability. These requirements apply to continuous emission 
monitoring systems (CEMS) that use gas chromatography (GC) to measure 
gaseous organic compound emissions. The requirements include procedures 
intended to evaluate the acceptability of the CEMS at the time of its 
installation and whenever specified in regulations or permits. Quality 
assurance procedures for calibrating, maintaining, and operating the 
CEMS properly at all times are also given in this procedure.
    1.2  Principle. Calibration precision, calibration error, and 
performance audit tests are conducted to determine conformance of the 
CEMS with these specifications. Daily calibration and maintenance 
requirements are also specified.

                             2. Definitions

    2.1  Gas Chromatograph (GC). That portion of the system that 
separates and detects organic analytes and generates an output 
proportional to the gas concentration. The GC must be temperature 
controlled.
    Note: The term ``temperature controlled'' refers to the ability to 
maintain a certain temperature around the column. Temperature-
programmable GC is not required for this performance specification, as 
long as all other requirements for precision, linearity,

[[Page 1166]]

and accuracy listed in this performance specification are met. It should 
be noted that temperature programming a GC will speed up peak elution, 
thus allowing increased sampling frequency.
    2.1.1  Column. An analytical column capable of separating the 
analytes of interest.
    2.1.2  Detector. A detection system capable of detecting and 
quantifying all analytes of interest.
    2.1.3  Integrator. That portion of the system that quantifies the 
area under a particular sample peak generated by the GC.
    2.1.4  Data Recorder. A strip chart recorder, computer, or digital 
recorder capable of recording all readings within the instrument's 
calibration range.
    2.2  Calibration Precision. The error between triplicate injections 
of each calibration standard.

         3. Installation and Measurement Location Specifications

    Install the CEMS in a location where the measurements are 
representative of the source emissions. Consider other factors, such as 
ease of access for calibration and maintenance purposes. The location 
should not be close to air in-leakages. The sampling location should be 
at least two equivalent duct diameters downstream from the nearest 
control device, point of pollutant generation, or other point at which a 
change in the pollutant concentration or emission rate occurs. The 
location should be at least 0.5 diameter upstream from the exhaust or 
control device. To calculate equivalent duct diameter, see section 2.1 
of Method 1 (40 CFR part 60, appendix A). Sampling locations not 
conforming to the requirements in this section may be used if necessary 
upon approval of the Administrator.

            4. CEMS Performance and Equipment Specifications

    4.1 Presurvey Sample Analysis and GC Selection. Determine the 
pollutants to be monitored from the applicable regulation or permit and 
determine the approximate concentration of each pollutant (this 
information can be based on past compliance test results). Select an 
appropriate GC configuration to measure the organic compounds. The GC 
components should include a heated sample injection loop (or other 
sample introduction systems), separatory column, temperature-controlled 
oven, and detector. If the source chooses dual column and/or dual 
detector configurations, each column/detector is considered a separate 
instrument for the purpose of this performance specification and thus 
the procedures in this performance specification shall be carried out on 
each system. If this method is applied in highly explosive areas, 
caution should be exercised in selecting the equipment and method of 
installation.
    4.2  Sampling System. The sampling system shall be heat traced and 
maintained at a minimum of 120  deg.C with no cold spots. All system 
components shall be heated, including the probe, calibration valve, 
sample lines, sampling loop (or sample introduction system), GC oven, 
and the detector block (when appropriate for the type of detector being 
utilized, e.g., flame ionization detector).
    4.3  Calibration Gases. Obtain three concentrations of calibration 
gases certified by the manufacturer to be accurate to within 2 percent 
of the value on the label. A gas dilution system may be used to prepare 
the calibration gases from a high concentration certified standard if 
the gas dilution system meets the requirements specified in Test Method 
205, 40 CFR part 51, appendix M. The performance test specified in Test 
Method 205 shall be repeated quarterly, and the results of the Method 
205 test shall be included in the report. The calibration gas 
concentration of each target analyte shall be as follows (measured 
concentration is based on the presurvey concentration determined in 
section 4.1).
    Note: If the low level calibration gas concentration falls at or 
below the limit of detection for the instrument for any target 
pollutant, a calibration gas with a concentration at 4 to 5 times the 
limit of detection for the instrument may be substituted for the low-
level calibration gas listed in section 4.3.1
    4.3.1  Low-level. 40-60 percent of measured concentration.
    4.3.2  Mid-level. 90-110 percent of measured concentration.
    4.3.3  High-level. 140-160 percent of measured concentration, or 
select highest expected concentration.
    4.4  Performance Audit Gas. A certified EPA audit gas shall be used, 
when possible. A Protocol 1 gas mixture containing all the target 
compounds within the calibration range may be used when EPA performance 
audit materials are not available. The instrument relative error shall 
be 10 percent of the certified value of the audit gas.
    4.5  Calibration Error (CE). The CEMS must allow the determination 
of CE at all three calibration levels. The average CEMS calibration 
response must not differ by more than 10 percent of calibration gas 
value at each level after each 24-hour period of the initial test.
    4.6  Calibration Precision and Linearity. For each triplicate 
injection at each concentration level for each target analyte, any one 
injection shall not deviate more than 5 percent from the average 
concentration measured at that level. The linear regression curve for 
each organic compound at all three

[[Page 1167]]

levels shall have an r\2\ 0.995 (using Equation 1).
    4.7  Measurement Frequency. The sample to be analyzed shall flow 
continuously through the sampling system. The sampling system time 
constant (T) shall be 5 minutes or the sampling frequency 
specified in the applicable regulation, whichever is less. Use Equation 
3 to determine T. The analytical system shall be capable of measuring 
the effluent stream at the frequency specified in the appropriate 
regulation or permit.

             5. Performance Specification Test (PST) Periods

    5.1  Pretest Preparation Period. Using the procedures described in 
Method 18 (40 CFR part 60, appendix A), perform initial tests to 
determine GC conditions that provide good resolution and minimum 
analysis time for compounds of interest. Resolution interferences that 
may occur can be eliminated by appropriate GC column and detector choice 
or by shifting the retention times through changes in the column flow 
rate and the use of temperature programming.
    5.2  7-Day CE Test Period. At the beginning of each 24-hour period, 
set the initial instrument setpoints by conducting a multipoint 
calibration for each compound. The multipoint calibration shall meet the 
requirements in section 4.7. Throughout the 24-hour period, sample and 
analyze the stack gas at the sampling intervals prescribed in the 
regulation or permit. At the end of the 24-hour period, inject the three 
calibration gases for each compound in triplicate and determine the 
average instrument response. Determine the CE for each pollutant at each 
level using the equation in section 6.2. Each CE shall be 10 
percent. Repeat this procedure six more times for a total of 7 
consecutive days.
    5.3  Performance Audit Test Periods. Conduct the performance audit 
once during the initial 7-day CE test and quarterly thereafter. Sample 
and analyze the EPA audit gas(es) (or the Protocol 1 gas mixture if an 
EPA audit gas is not available) three times. Calculate the average 
instrument response. Report the audit results as part of the reporting 
requirements in the appropriate regulation or permit (if using a 
Protocol 1 gas mixture, report the certified cylinder concentration of 
each pollutant).

                              6. Equations

    6.1  Coefficient of Determination. Calculate r2 using 
linear regression analysis and the average concentrations obtained at 
three calibration points as shown in Equation 1.
[GRAPHIC] [TIFF OMITTED] TR15DE94.000

Where:

r2=Coefficient of determination.
n=Number of measurement points.
x=CEMS response.
y=Actual value of calibration standard.
    6.2  Calibration Error Determination. Determine the percent 
calibration error (CE) at each concentration for each pollutant using 
the following equation.
[GRAPHIC] [TIFF OMITTED] TR15DE94.001

where:

Cm=average instrument response, ppm.
Ca=cylinder gas value, ppm.
    6.3  Sampling System Time Constant (T).
    [GRAPHIC] [TIFF OMITTED] TR15DE94.002
    

[[Page 1168]]


where:

F=Flow rate of stack gas through sampling system, in liters/min.
V=Sample system volume, in Liters, which is the volume inside the sample 
          probe and tubing leading from the stack to the sampling loop.

                          7. Daily Calibration

    7.1  Initial Multipoint Calibration. After initial startup of the 
GC, after routine maintenance or repair, or at least once per month, 
conduct a multipoint calibration of the GC for each target analyte. The 
multipoint calibration for each analyte shall meet the requirements in 
section 4.7.
    7.2  Daily Calibration. Once every 24 hours, analyze the mid-level 
calibration standard for each analyte in triplicate. Calculate the 
average instrument response for each analyte. The average instrument 
response shall not vary more than 10 percent from the certified 
concentration value of the cylinder for each analyte. If the difference 
between the analyzer response and the cylinder concentration for any 
target compound is greater than 10 percent, immediately take corrective 
action on the instrument if necessary, and conduct an initial multipoint 
calibration as described in section 7.1.

                              8. Reporting

    Follow the reporting requirements of the applicable regulation or 
permit. If the reporting requirements include the results of this 
performance specification, summarize in tabular form the results of the 
CE tests. Include all data sheets, calculations, CEMS data records, 
performance audit results, and calibration gas concentrations and 
certifications.

[48 FR 13327, Mar. 30, 1983 and 48 FR 23611, May 25, 1983, as amended at 
48 FR 32986, July 20, 1983; 51 FR 31701, Aug. 5, 1985; 52 FR 17556, May 
11, 1987; 52 FR 30675, Aug. 18, 1987; 52 FR 34650, Sept. 14, 1987; 53 FR 
7515, Mar. 9, 1988; 53 FR 41335, Oct. 21, 1988; 55 FR 18876, May 7, 
1990; 55 FR 40178, Oct. 2, 1990; 55 FR 47474, Nov. 14, 1990; 56 FR 5526, 
Feb. 11, 1991; 59 FR 64593, Dec. 15, 1994]

      Appendix C to Part 60--Determination of Emission Rate Change

1. Introduction.

    1.1 The following method shall be used to determine whether a 
physical or operational change to an existing facility resulted in an 
increase in the emission rate to the atmosphere. The method used is the 
Student's t test, commonly used to make inferences from small samples.

2. Data.

    2.1 Each emission test shall consist of n runs (usually three) which 
produce n emission rates. Thus two sets of emission rates are generated, 
one before and one after the change, the two sets being of equal size.
    2.2 When using manual emission tests, except as provided in 
Sec. 60.8(b) of this part, the reference methods of appendix A to this 
part shall be used in accordance with the procedures specified in the 
applicable subpart both before and after the change to obtain the data.
    2.3 When using continuous monitors, the facility shall be operated 
as if a manual emission test were being performed. Valid data using the 
averaging time which would be required if a manual emission test were 
being conducted shall be used.

3. Procedure.

    3.1 Subscripts a and b denote prechange and postchange respectively.
    3.2 Calculate the arithmetic mean emission rate, E, for each set of 
data using Equation 1.
[GRAPHIC] [TIFF OMITTED] TC01JN92.292

Where:
Ei=Emission rate for the i th run.
n=number of runs.

    3.3 Calculate the sample variance, S2, for each set of 
data using Equation 2.
[GRAPHIC] [TIFF OMITTED] TC01JN92.293

    3.4 Calculate the pooled estimate, Sp, using Equation 3.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.294
    
    3.5 Calculate the test statistic, t, using Equation 4.
    [GRAPHIC] [TIFF OMITTED] TC01JN92.295
    
4. Results.

    4.1 If Eb>,Ea and t>t', where t' is 
the critical value of t obtained from Table 1, then with 95% confidence 
the difference between Eb and Ea is significant, 
and an increase in emission rate to the atmosphere has occurred.

                                 Table 1
------------------------------------------------------------------------
                                                                t' (95
                                                               percent
                Degrees of freedom (na=nb-2)                  confidence
                                                                level)
------------------------------------------------------------------------
2..........................................................        2.920
3..........................................................        2.353
4..........................................................        2.132

[[Page 1169]]

 
5..........................................................        2.015
6..........................................................        1.943
7..........................................................        1.895
8..........................................................        1.860
------------------------------------------------------------------------

    For greater than 8 degrees of freedom, see any standard statistical 
                                                       handbook or text.
    5.1 Assume the two performance tests produced the following set of 
data:

------------------------------------------------------------------------
                           Test a                               Test b
------------------------------------------------------------------------
Run 1. 100..................................................         115
Run 2. 95...................................................         120
Run 3. 110..................................................         125
------------------------------------------------------------------------

    5.2 Using Equation 1--
Ea=100+95+110/3=102
Eb=115+120+125/3=120
    5.3 Using Equation 2--

 Sa2=(100-102) 2+(95-102) 2+(110-102) 
                          2/3-1=58.5

 Sb2=(115-120) 2+(120-120) 2+(125-120) 
                           2/3-1=25

    5.4 Using Equation 3--

         Sp=[(3-1)(58.5)+(3+1)(25)/3+3-2] \1/2\=6.46

    5.5 Using Equation 4--
    [GRAPHIC] [TIFF OMITTED] TC01JN92.296
    
    5.6 Since (n1+n2-2)=4, t'=2.132 (from Table 
1). Thus since t>t' the difference in the values of Ea 
and Eb is significant, and there has been an increase in 
emission rate to the atmosphere.

6. Continuous Monitoring Data.

    6.1 Hourly averages from continuous monitoring devices, where 
available, should be used as data points and the above procedure 
followed.

[40 FR 58420, Dec. 16, 1975]

     Appendix D to Part 60--Required Emission Inventory Information

    (a) Completed NEDS point source form(s) for the entire plant 
containing the designated facility, including information on the 
applicable criteria pollutants. If data concerning the plant are already 
in NEDS, only that information must be submitted which is necessary to 
update the existing NEDS record for that plant. Plant and point 
identification codes for NEDS records shall correspond to those 
previously assigned in NEDS; for plants not in NEDS, these codes shall 
be obtained from the appropriate Regional Office.
    (b) Accompanying the basic NEDS information shall be the following 
information on each designated facility:
    (1) The state and county identification codes, as well as the 
complete plant and point identification codes of the designated facility 
in NEDS. (The codes are needed to match these data with the NEDS data.)
    (2) A description of the designated facility including, where 
appropriate:
    (i) Process name.
    (ii) Description and quantity of each product (maximum per hour and 
average per year).
    (iii) Description and quantity of raw materials handled for each 
product (maximum per hour and average per year).
    (iv) Types of fuels burned, quantities and characteristics (maximum 
and average quantities per hour, average per year).
    (v) Description and quantity of solid wastes generated (per year) 
and method of disposal.
    (3) A description of the air pollution control equipment in use or 
proposed to control the designated pollutant, including:
    (i) Verbal description of equipment.
    (ii) Optimum control efficiency, in percent. This shall be a 
combined efficiency when more than one device operates in series. The 
method of control efficiency determination shall be indicated (e.g., 
design efficiency, measured efficiency, estimated efficiency).
    (iii) Annual average control efficiency, in percent, taking into 
account control equipment down time. This shall be a combined efficiency 
when more than one device operates in series.
    (4) An estimate of the designated pollutant emissions from the 
designated facility (maximum per hour and average per year). The method 
of emission determination shall also be specified (e.g., stack test, 
material balance, emission factor).

[40 FR 53349, Nov. 17, 1975]

                    Appendix E to Part 60  [Reserved]

           Appendix F to Part 60--Quality Assurance Procedures

Procedure 1. Quality Assurance Requirements for Gas Continuous Emission 
          Monitoring Systems Used for Compliance Determination

1. Applicability and Principle
    1.1  Applicability. Procedure 1 is used to evaluate the 
effectiveness of quality control (QC) and quality assurance (QA) 
procedures and the quality of data produced by any continuous emission 
monitoring system (CEMS) that is used for determining compliance with 
the emission standards on a continuous basis as specified in the 
applicable regulation. The CEMS may include pollutant (e.g., 
S02 and N0x) and diluent (e.g., 02 or 
C02) monitors.

[[Page 1170]]

    This procedure specifies the minimum QA requirements necessary for 
the control and assessment of the quality of CEMS data submitted to the 
Environmental Protection Agency (EPA). Source owners and operators 
responsible for one or more CEMS's used for compliance monitoring must 
meet these minimum requirements and are encouraged to develop and 
implement a more extensive QA program or to continue such programs where 
they already exist.
    Data collected as a result of QA and QC measures required in this 
procedure are to be submitted to the Agency. These data are to be used 
by both the Agency and the CEMS operator in assessing the effectiveness 
of the CEMS QC and QA procedures in the maintenance of acceptable CEMS 
operation and valid emission data.
    Appendix F, Procedure 1 is applicable December 4, 1987. The first 
CEMS accuracy assessment shall be a relative accuracy test audit (RATA) 
(see section 5) and shall be completed by March 4, 1988 or the date of 
the initial performance test required by the applicable regulation, 
whichever is later.
    1.2  Principle. The QA procedures consist of two distinct and 
equally important functions. One function is the assessment of the 
quality of the CEMS data by estimating accuracy. The other function is 
the control and improvement of the quality of the CEMS data by 
implementing QC policies and corrective actions. These two functions 
form a control loop: When the assessment function indicates that the 
data quality is inadequate, the control effort must be increased until 
the data quality is acceptable. In order to provide uniformity in the 
assessment and reporting of data quality, this procedure explicitly 
specifies the assessment methods for response drift and accuracy. The 
methods are based on procedures included in the applicable performance 
specifications (PS's) in appendix B of 40 CFR part 60. Procedure 1 also 
requires the analysis of the EPA audit samples concurrent with certain 
reference method (RM) analyses as specified in the applicable RM's.
    Because the control and corrective action function encompasses a 
variety of policies, specifications, standards, and corrective measures, 
this procedure treats QC requirements in general terms to allow each 
source owner or operator to develop a QC system that is most effective 
and efficient for the circumstances.

2. Definitions
    2.1 Continuous Emission Monitoring System. The total equipment 
required for the determination of a gas concentration or emission rate.
    2.2 Diluent Gas. A major gaseous constituent in a gaseous pollutant 
mixture. For combustion sources, CO2 and O2 are 
the major gaseous constituents of interest.
    2.3 Span Value. The upper limit of a gas concentration measurement 
range that is specified for affected source categories in the applicable 
subpart of the regulation.
    2.4 Zero, Low-Level, and High-Level Values. The CEMS response values 
related to the source specific span value. Determination of zero, low-
level, and high-level values is defined in the appropriate PS in 
appendix B of this part.
    2.5 Calibration Drift (CD). The difference in the CEMS output 
reading from a reference value after a period of operation during which 
no unscheduled maintenance, repair or adjustment took place. The 
reference value may be supplied by a cylinder gas, gas cell, or optical 
filter and need not be certified.
    2.6 Relative Accuracy (RA). The absolute mean difference between the 
gas concentration or emission rate determined by the CEMS and the value 
determined by the RM's plus the 2.5 percent error confidence coefficient 
of a series of tests divided by the mean of the RM tests or the 
applicable emission limit.

3. QC Requirements
    Each source owner or operator must develop and implement a QC 
program. As a minimum, each QC program must include written procedures 
which should describe in detail, complete, step-by-step procedures and 
operations for each of the following activities:
    1. Calibration of CEMS.
    2. CD determination and adjustment of CEMS.
    3. Preventive maintenance of CEMS (including spare parts inventory).
    4. Data recording, calculations, and reporting.
    5. Accuracy audit procedures including sampling and analysis 
methods.
    6. Program of corrective action for malfunctioning CEMS.
    As described in Section 5.2, whenever excessive inaccuracies occur 
for two consecutive quarters, the source owner or operator must revise 
the current written procedures or modify or replace the CEMS to correct 
the deficiency causing the excessive inaccuracies.
    These written procedures must be kept on record and available for 
inspection by the enforcement agency.

4. CD Assessment
    4.1  CD Requirement. As described in 40 CFR 60.13(d), source owners 
and operators of CEMS must check, record, and quantify the CD at two 
concentration values at least once daily (approximately 24 hours) in 
accordance with the method prescribed by the manufacturer. The CEMS 
calibration must, as minimum, be adjusted whenever the daily zero (or 
low-level) CD or the daily high-level CD exceeds two times the limits of 
the applicable PS's in appendix B of this regulation.

[[Page 1171]]

    4.2  Recording Requirement for Automatic CD Adjusting Monitors. 
Monitors that automatically adjust the data to the corrected calibration 
values (e.g., microprocessor control) must be programmed to record the 
unadjusted concentration measured in the CD prior to resetting the 
calibration, if performed, or record the amount of adjustment.
    4.3  Criteria for Excessive CD. If either the zero (or low-level) or 
high-level CD result exceeds twice the applicable drift specification in 
appendix B for five, consecutive, daily periods, the CEMS is out-of-
control. If either the zero (or low-level) or high-level CD result 
exceeds four times the applicable drift specification in appendix B 
during any CD check, the CEMS is out-of-control. If the CEMS is out-of-
control, take necessary corrective action. Following corrective action, 
repeat the CD checks.
    4.3.1  Out-Of-Control Period Definition. The beginning of the out-
of-control period is the time corresponding to the completion of the 
fifth, consecutive, daily CD check with a CD in excess of two times the 
allowable limit, or the time corresponding to the completion of the 
daily CD check preceding the daily CD check that results in a CD in 
excess of four times the allowable limit. The end of the out-of-control 
period is the time corresponding to the completion of the CD check 
following corrective action that results in the CD's at both the zero 
(or low-level) and high-level measurement points being within the 
corresponding allowable CD limit (i.e., either two times or four times 
the allowable limit in appendix B).
    4.3.2  CEMS Data Status During Out-of-Control Period. During the 
period the CEMS is out-of-control, the CEMS data may not be used in 
calculating emission compliance nor be counted towards meeting minimum 
data availability as required and described in the applicable subpart 
[e.g., Sec. 60.47a(f)].
    4.4  Data Recording and Reporting. As required in Sec. 60.7(d) of 
this regulation (40 CFR part 60), all measurements from the CEMS must be 
retained on file by the source owner for at least 2 years. However, 
emission data obtained on each successive day while the CEMS is out-of-
control may not be included as part of the minimum daily data 
requirement of the applicable subpart [e.g., Sec. 60.47a(f)] nor be used 
in the calculation of reported emissions for that period.

5. Data Accuracy Assessment
    5.1  Auditing Requirements. Each CEMS must be audited at least once 
each calendar quarter. Successive quarterly audits shall occur no closer 
than 2 months. The audits shall be conducted as follows:
    5.1.1  Relative Accuracy Test Audit (RATA). The RATA must be 
conducted at least once every four calendar quarters. Conduct the RATA 
as described for the RA test procedure in the applicable PS in appendix 
B (e.g., PS 2 for SO2 and NOX). In addition, 
analyze the appropriate performance audit samples received from EPA as 
described in the applicable sampling methods (e.g., Methods 6 and 7).
    5.1.2  Cylinder Gas Audit (CGA). If applicable, a CGA may be 
conducted in three of four calendar quarters, but in no more than three 
quarters in succession.
    To conduct a CGA: (1) Challenge the CEMS (both pollutant and diluent 
portions of the CEMS, if applicable) with an audit gas of known 
concentration at two points within the following ranges:

------------------------------------------------------------------------
                                     Audit range
           -------------------------------------------------------------
   Audit                                  Diluent monitors for--
   point     Pollutant monitors ----------------------------------------
                                         CO2                  O2
------------------------------------------------------------------------
1.........  20 to 30% of span    5 to 8% by volume..  4 to 6% by volume.
             value.
2.........  50 to 60% of span    10 to 14% by volume  8 to 12% by
             value.                                    volume.
------------------------------------------------------------------------

    Challenge the CEMS three times at each audit point, and use the 
average of the three responses in determining accuracy.
    Use of separate audit gas cylinder for audit points 1 and 2. Do not 
dilute gas from audit cylinder when challenging the CEMS.
    The monitor should be challenged at each audit point for a 
sufficient period of time to assure adsorption-desorption of the CEMS 
sample transport surfaces has stabilized.
    (2) Operate each monitor in its normal sampling mode, i.e., pass the 
audit gas through all filters, scrubbers, conditioners, and other 
monitor components used during normal sampling, and as much of the 
sampling probe as is practical. At a minimum, the audit gas should be 
introduced at the connection between the probe and the sample line.
    (3) Use audit gases that have been certified by comparision to 
National Bureau of Standards (NBS) gaseous Standard Reference Materials 
(SRM's) or NBS/EPA approved gas manufacturer's Certified Reference 
Materials (CRM's) (See Citation 1) following EPA Traceability Protocol 
No. 1 (See Citation 2). As an alternative to Protocol No. 1 audit gases, 
CRM's may be used directly as audit gases. A list of gas manufacturers 
that have prepared approved CRM's is available from EPA at the address 
shown in Citation 1. Procedures for preparation of CRM's are described 
in Citation 1. Procedures for preparation of EPA Traceability Protocol 1 
materials are described in Citation 2.
    The difference between the actual concentration of the audit gas and 
the concentration indicated by the monitor is used to assess the 
accuracy of the CEMS.
    5.1.3 Relative Accuracy Audit (RAA). The RAA may be conducted three 
of four calendar quarters, but in no more than three quarters in 
succession. To conduct a RAA,

[[Page 1172]]

follow the procedure described in the applicable PS in appendix B for 
the relative accuracy test, except that only three sets of measurement 
data are required. Analyses of EPA performance audit samples are also 
required.
    The relative difference between the mean of the RM values and the 
mean of the CEMS responses will be used to assess the accuracy of the 
CEMS.
    5.1.4 Other Alternative Audits. Other alternative audit procedures 
may be used as approved by the Administrator for three of four calendar 
quarters. One RATA is required at least once every four calendar 
quarters.
    5.2  Excessive Audit Inaccuracy. If the RA, using the RATA, CGA, or 
RAA exceeds the criteria in section 5.2.3, the CEMS is out-of-control. 
If the CEMS is out-of-control, take necessary corrective action to 
eliminate the problem. Following corrective action, the source owner or 
operator must audit the CEMS with a RATA, CGA, or RAA to determine if 
the CEMS is operating within the specifications. A RATA must always be 
used following an out-of-control period resulting from a RATA. The audit 
following corrective action does not require analysis of EPA performance 
audit samples. If audit results show the CEMS to be out-of-control, the 
CEMS operator shall report both the audit showing the CEMS to be out-of-
control and the results of the audit following corrective action showing 
the CEMS to be operating within specifications.
    5.2.1 Out-Of-Control Period Definition. The beginning of the out-of-
control period is the time corresponding to the completion of the 
sampling for the RATA, RAA, or CGA. The end of the out-of-control period 
is the time corresponding to the completion of the sampling of the 
subsequent successful audit.
    5.2.2 CEMS Data Status During Out-Of-Control Period. During the 
period the monitor is out-of-control, the CEMS data may not be used in 
calculating emission compliance nor be counted towards meeting minimum 
data availabilty as required and described in the applicable subpart 
[e.g., Sec. 60.47a(f)].
    5.2.3  Criteria for Excessive Audit Inaccuracy. Unless specified 
otherwise in the applicable subpart, the criteria for excessive 
inaccuracy are:
    (1) For the RATA, the allowable RA in the applicable PS in appendix 
B.
    (2) For the CGA, 15 percent of the average audit value 
or 5 ppm, whichever is greater.
    (3) For the RAA, 15 percent of the three run average or 
7.5 percent of the applicable standard, whichever is 
greater.
    5.3 Criteria for Acceptable QC Procedure. Repeated excessive 
inaccuracies (i.e., out-of-control conditions resulting from the 
quarterly audits) indicates the QC procedures are inadequate or that the 
CEMS is incapable of providing quality data. Therefore, whenever 
excessive inaccuracies occur for two consective quarters, the source 
owner or operator must revise the QC procedures (see Section 3) or 
modify or replace the CEMS.

6. Calculations for CEMS Data Accuracy
    6.1 RATA RA Calculation. Follow the equations described in Section 8 
of appendix B, PS 2 to calculate the RA for the RATA. The RATA must be 
calculated in units of the applicable emission standard (e.g., ng/J).
    6.2 RAA Accuracy Calculation. Use Equation 1-1 to calculate the 
accuracy for the RAA. The RAA must be calculated in units of the 
applicable emission standard (e.g., ng/J).
    6.3 CGA Accuracy Calculation. Use Equation 1-1 to calculate the 
accuracy for the CGA, which is calculated in units of the appropriate 
concentration (e.g., ppm SO2 or percent O2). Each 
component of the CEMS must meet the acceptable accuracy requirement.
[GRAPHIC] [TIFF OMITTED] TC16NO91.240

where:
    A = Accuracy of the CEMS, percent.
    Cm = Average CEMS response during audit in units of 
applicable standard or appropriate concentration.
    Ca = Average audit value (CGA certified value or three-
run average for RAA) in units of applicable standard or appropriate 
concentration.
    6.4 Example Accuracy Calculations. Example calculations for the 
RATA, RAA, and CGA are available in Citation 3.

7. Reporting Requirements
    At the reporting interval specified in the applicable regulation, 
report for each CEMS the accuracy results from Section 6 and the CD 
assessment results from Section 4. Report the drift and accuracy 
information as a Data Assessment Report (DAR), and include one copy of 
this DAR for each quarterly audit with the report of emissions required 
under the applicable subparts of this part.
    As a minimum, the DAR must contain the following information:
    1. Source owner or operator name and address.
    2. Identification and location of monitors in the CEMS.
    3. Manufacturer and model number of each monitor in the CEMS.
    4. Assessment of CEMS data accuracy and date of assessment as 
determined by a RATA, RAA, or CGA described in Section 5 including the 
RA for the RATA, the A for the RAA or CGA, the RM results, the cylinder 
gases certified values, the CEMS responses, and the calculations results 
as defined in Section 6. If the accuracy audit results show the CEMS to 
be out-of-control, the CEMS operator shall report both the audit results

[[Page 1173]]

showing the CEMS to be out-of-control and the results of the audit 
following corrective action showing the CEMS to be operating within 
specifications.
    5. Results from EPA performance audit samples described in Section 5 
and the applicable RM's.
    6. Summary of all corrective actions taken when CEMS was determined 
out-of-control, as described in Sections 4 and 5.
    An example of a DAR format is shown in Figure 1.

8. Bibliography
    1. ``A Procedure for Establishing Traceability of Gas Mixtures to 
Certain National Bureau of Standards Standard Reference Materials.'' 
Joint publication by NBS and EPA-600/7-81-010. Available from the U.S. 
Environmental Protection Agency. Quality Assurance Division (MD-77). 
Research Triangle Park, NC 27711.
    2. ``Traceability Protocol for Establishing True Concentrations of 
Gases Used for Calibration and Audits of Continuous Source Emission 
Monitors (Protocol Number 1)'' June 1978. Section 3.0.4 of the Quality 
Assurance Handbook for Air Pollution Measurement Systems. Volume III. 
Stationary Source Specific Methods. EPA-600/4-77-027b. August 1977. U.S. 
Environmental Protection Agency. Office of Research and Development 
Publications, 26 West St. Clair Street, Cincinnati, OH 45268.
    3. Calculation and Interpretation of Accuracy for Continuous 
Emission Monitoring Systems (CEMS). Section 3.0.7 of the Quality 
Assurance Handbook for Air Pollution Measurement Systems, Volume III, 
Stationary Source Specific Methods. EPA-600/4-77-027b. August 1977. U.S. 
Environmental Protection Agency. Office of Research and Development 
Publications, 26 West St. Clair Street, Cincinnati, OH 45268.

           Figure 1--Example Format for Data Assessment Report

Period ending date______________________________________________________
Year____________________________________________________________________
Company name____________________________________________________________
Plant name______________________________________________________________
Source unit no._________________________________________________________
CEMS manufacturer_______________________________________________________
Model no._______________________________________________________________
CEMS serial no._________________________________________________________
CEMS type (e.g., in situ)_______________________________________________
CEMS sampling location (e.g., control device outlet)____________________
CEMS span values as per the applicable regulation: ____________ (e.g., 
SO2 ________ ppm, NOx ________ ppm).______________
    I. Accuracy assessment results (Complete A, B, or C below for each 
CEMS or for each pollutant and diluent analyzer, as applicable.) If the 
quarterly audit results show the CEMS to be out-of-control, report the 
results of both the quarterly audit and the audit following corrective 
action showing the CEMS to be operating properly.

    A. Relative accuracy test audit (RATA) for ________ (e.g., 
SO2 in ng/J).

    1. Date of audit ________.
    2. Reference methods (RM's) used ________ (e.g., Methods 3 and 6).
    3. Average RM value ________ (e.g., ng/J, mg/dsm\3\, or percent 
volume).
    4. Average CEMS value ________.
    5. Absolute value of mean difference [d] ________.
    6. Confidence coefficient [CC] ________.
    7. Percent relative accuracy (RA) ________ percent.
    8. EPA performance audit results:
    a. Audit lot number (1) ________ (2) ________
    b. Audit sample number (1) ________ (2) ________
    c. Results (mg/dsm\3\) (1) ________ (2) ________
    d. Actual value (mg/dsm\3\)* (1) ________ (2) ________
    e. Relative error* (1) ________ (2) ________

    B. Cylinder gas audit (CGA) for ________ (e.g., SO2 in 
ppm).

------------------------------------------------------------------------
                                      Audit   Audit
                                      point   point
                                        1       2
------------------------------------------------------------------------
1. Date of audit...................  ......  ......
2. Cylinder ID number..............  ......  ......
3. Date of certification...........  ......  ......
4. Type of certification...........  ......  ......  (e.g., EPA Protocol
                                                      1 or CRM).
5. Certified audit value...........  ......  ......  (e.g., ppm).
6. CEMS response value.............  ......  ......  (e.g., ppm).
7. Accuracy........................  ......  ......  percent.
------------------------------------------------------------------------


    C. Relative accuracy audit (RAA) for ________ (e.g., SO2 
in ng/J).

    1. Date of audit ________.
    2. Reference methods (RM's) used ________ (e.g., Methods 3 and 6).
    3. Average RM value ________ (e.g., ng/J).
    4. Average CEMS value ________.
    5. Accuracy ________ percent.
    6. EPA performance audit results:
    a. Audit lot number (1) ________ (2) ________
    b. Audit sample number (1) ________ (2) ________
    c. Results (mg/dsm\3\) (1) ________ (2) ________
    d. Actual value (mg/dsm\3\) *(1) ________ (2)
    e. Relative error* (1) ________ (2) ________
---------------------------------------------------------------------------

    * To be completed by the Agency.
---------------------------------------------------------------------------

    D. Corrective action for excessive inaccuracy.

    1. Out-of-control periods.
    a. Date(s) ________.
    b. Number of days ________.
  2. Corrective action taken____________________________________________
    3. Results of audit following corrective action. (Use format of A, 
B, or C above, as applicable.)


[[Page 1174]]


    II. Calibration drift assessment.

    A. Out-of-control periods.
    1. Date(s) ________.
    2. Number of days ________.

  B. Corrective action taken____________________________________________
--______________________________________________________________________

[52 FR 21008, June 4, 1987; 52 FR 27612, July 22, 1987, as amended at 56 
FR 5527, Feb. 11, 1991]

     Appendix G to Part 60--Provisions for an Alternative Method of 
Demonstrating Compliance With 40 CFR 60.43 for the Newton Power Station 
               of Central Illinois Public Service Company

    1. Designation of Affected Facilities
    1.1  The affected facilities to which this alternative compliance 
method applies are the Unit 1 and 2 coal-fired steam generating units 
located at the Central Illinois Public Service Company's (CIPS) Newton 
Power Station in Jasper County, Illinois. Each of these units is subject 
to the Standards of Performance for Fossil-Fuel-Fired Steam Generators 
for Which Construction Commenced After August 17, 1971 (subpart D).
    2. Definitions
    2.1  All definitions in subparts D and Da of part 60 apply to this 
provision except that:
    24-hour period means the period of time between 12:00 midnight and 
the following midnight.
    Boiler operating day means a 24-hour period during which any fossil 
is combusted in either the Unit 1 or Unit 2 steam generating unit and 
during which the provisions of Sec. 60.43(e) are applicable.
    CEMs means continuous emission monitoring system.
    Coal bunker means a single or group of coal trailers, hoppers, silos 
or other containers that:
    (1) are physically attached to the affected facility; and
    (2) provide coal to the coal pulverizers.
    DAFGDS means the dual alkali flue gas desulfurization system for the 
Newton Unit 1 steam generating unit.
    3. Compliance Provisions
    3.1  If the owner or operator of the affected facility elects to 
comply with the 470 ng/J (1.1 lbs/MMBTU) of combined heat input emission 
limit under Sec. 60.43(e), he shall notify the Regional Administrator, 
of the United States Environmental Protection Agency (USEPA), Region 5 
and the Director, of the Illinois Environmental Protection Agency (IEPA) 
at least 30 days in advance of the date such election is to take effect, 
stating the date such operation is to commence. When the owner or 
operator elects to comply with this limit after one or more periods of 
reverting to the 520 ng/J heat input (1.2 lbs/MMBTU) limit of 
Sec. 60.43(a)(2), as provided under 3.4, he shall notify the Regional 
Administrator of the USEPA, Region 5 and the Director of the (IEPA) in 
writing at least ten (10) days in advance of the date such election is 
to take effect.
    3.2  Compliance with the sulfur dioxide emission limit under 
Sec. 60.43(e) is determined on a continuous basis by performance testing 
using CEMs. Within 60 days after the initial operation of Units 1 and 2 
subject to the combined emission limit in Sec. 60.43(e), the owner or 
operator shall conduct an initial performance test, as required by 
Sec. 60.8, to determine compliance with the combined emission limit. 
This initial performance test is to be scheduled so that the thirtieth 
boiler operating day of the 30 successive boiler operating days is 
completed within 60 days after initial operation subject to the 470 ng/J 
(1.1 lbs/MMBTU) combined emission limit. Following the initial 
performance test, a separate performance test is completed at the end of 
each boiler operating day Unit 1 and Unit 2 are subject to 
Sec. 60.43(e), and a new 30 day average emission rate calculated.
    3.2.1  Following the initial performance test, a new 30 day average 
emission rate is calculated for each boiler operating day the affected 
facility is subject to Sec. 60.43(e). If the owner or operator of the 
affected facility elects to comply with Sec. 60.43(e) after one or more 
periods of reverting to the 520 ng/J heat input (1.2 lbs/MMBTU) limit 
under Sec. 60.43(a)(2), as provided under 3.4, the 30 day average 
emission rate under Sec. 60.43(e) is calculated using emissions data of 
the current boiler operating day and data for the previous 29 boiler 
operating days when the affected facility was subject to Sec. 60.43(e). 
Periods of operation of the affected facility under Sec. 60.43(a)(2) are 
not considered boiler operating days. Emissions data collected during 
operation under Sec. 60.43(a)(2) are not considered relative to 4.6 and 
emissions data are not included in calculations of emission under 
Sec. 60.43(e).
    3.2.2  When the affected facility is operated under the provisions 
of Sec. 60.43(e), the Unit 1 DAFGDS bypass damper must be fully closed. 
The DAFGDS bypass may be opened only during periods of DAFGDS startup, 
shutdown, malfunction or testing as described under Sections 3.5.1, 
3.5.2, 3.5.3, 3.5.4, and 4.8.2.
    3.3  Compliance with the sulfur dioxide emission limit set forth in 
Sec. 60.43(e) is based on the average combined hourly emission rate from 
Units 1 and 2 for 30 successive boiler operating days determined as 
follows:
[GRAPHIC] [TIFF OMITTED] TC15NO91.206

where:


[[Page 1175]]


n=the number of available hourly combined emission rate values in the 30 
          successive boiler operating day period where Unit 1 and Unit 2 
          are subject to Sec. 60.43(e).
E30=average emission rate for 30 successive boiler operating days where 
          Unit 1 and Unit 2 are subject to Sec. 60.43(e).
EC=the hourly combined emission rate from Units 1 and 2, in ng/J or lbs/
          MMBTU.
    3.3.1  The average hourly combined emission rate for Units 1 and 
2for each hour of operation of either Unit 1 or 2, or both, is 
determined as follows:

EC=[(E1)+(E2)]/[H1+H2]

where:

EC=the hourly combined SO2 emission rate, lbs/MMBTU, from 
          Units 1 and 2 when Units 1 and 2 are subject to Sec. 60.43(e).
E1=the hourly SO2 mass emission, lb/hr, from Unit 1 as 
          determined from CEMs data using the calculation procedures in 
          section 4 of this appendix.
E2=the hourly SO2 mass emission, lb/hr, from Unit 2 as 
          determined from CEMs data using the calculation procedures in 
          section 4 of this appendix.
H1=the hourly heat input, MMBTU/HR to Unit 1 as determined in section 4 
          of this appendix.
H2=the hourly heat input, MMBTU/HR, to Unit 2 as determined by section 4 
          of this appendix.
    3.3.2  If data for any of the four hourly parameters (E1, E2, H1and 
H2, under 3.3.1 are unavailable during an hourly period, the combined 
emission rate (EC) is not calculated and the period is counted as 
missing data under 4.6.1., except as provided under 3.5. and 4.4.2.
    3.4  After the date of initial operation subject to the combined 
emission limit, Units 1 and 2 shall remain subject to the combined 
emission limit and the owner or operator shall remain subject to the 
requirements of this Appendix until the initial performance test as 
required by 3.2 is completed and the owner or operator of the affected 
facility elects and provides notice to revert on a certain date to the 
520 ng/J heat input (1.2 lbs/MMBTU) limit of Sec. 60.43(a)(2) applicable 
separately at each unit. The Regional Administrator of the USEPA, Region 
5 and the Director, of the IEPA shall be given written notification from 
CIPS as soon as possible of CIPs' decision to revert to the 520 ng/J 
heat input (1.2 lbs/MMBTU) limit of Sec. 60.43(a)(2) separately at each 
unit, but no later than 10 days in advance of the date such election is 
to take effect.
    3.5  Emission monitoring data for Unit 1 may be excluded from 
calculations of the 30 day rolling average only during the following 
times:
    3.5.1  Periods of DAFGDS startup.
    3.5.2  Periods of DAFGDS shutdown.
    3.5.3  Periods of DAFGDS malfunction during system emergencies as 
defined in Sec. 60.41a.
    3.5.4  The first 250 hours per calendar year of DAFGDS malfunctions 
of Unit 1 DAFGDS provided that efforts are made to minimize emissions 
from Unit 1 in accordance with Sec. 60.11(d), and if, after 16 hours but 
not more than 24 hours of DAFGDS malfunction, the owner or operator of 
the affected facility begins (following the customary loading 
procedures) loading into the Unit 1 coal bunker, coal with a potential 
SO2 emission rate equal to or less than the emission rate of 
Unit 2 recorded at the beginning of the DAFGDS malfunction. Malfunction 
periods under 3.5.3 are not counted toward the 250 hour/yr limit under 
this section.
    3.5.4.1  The malfunction exemption in 3.5.4 is limited to the first 
250 hours per calendar year of DAFGDS malfunction.
    3.5.4.2  For malfunctions of the DAFGDS after the 250 hours per 
calendar year limit (cumulative), other than those defined in 3.5.3, the 
owner or operator of the affected facility shall combust lower sulfur 
coal or use any other method to comply with the 470 ng/J (1.1 lbs/MMBTU) 
combined emission limit.
    3.5.4.3  During the first 250 hours of DAFGDS malfunction per year 
or during periods of DAFGDS startup, or DAFGDS shutdown, CEMs emissions 
data from Unit 2 shall continue to be included in the daily calculation 
of the combined 30 day rolling average emission rate; that is, the load 
on Unit 1 is assumed to be zero (H1 and E1=O; EC=E2/H2).
    3.5.5--3.5.7  [Reserved]
    3.6  The provision for excluding CEMs data from Unit 1 during the 
first 250 hours of DAFGDS malfunctions from combined hourly emissions 
calculations supersedes the provisions of Sec. 60.11(d). However, the 
general purpose contained in Sec. 60.11(d) (i.e., following good control 
practices to minimize air pollution emission during malfunctions) has 
not been superseded.

                    4. Continuous Emission Monitoring

    4.1  The CEMs required under Section 3.2 are operated and data are 
recorded for all periods of operation of the affected facility including 
periods of the DAFGDS startup, shutdown and malfunction except for CEMs 
breakdowns, repairs, calibration checks, and zero and span adjustment. 
All provisions of Sec. 60.45 apply except as follows:
    4.2  The owner or operator shall install, calibrate, maintain, and 
operate CEMs and monitoring devices for measuring the following:
    4.2.1  For Unit 1:
    4.2.1.1  Sulfur dioxide, oxygen or carbon dioxide, and volumetric 
flow rate for the Unit 1 DAFGDS stack.
    4.2.1.2  Sulfur dioxide, oxygen or carbon dioxide, and volumetric 
flow rate for the Unit 1 DAFGDS bypass stack.

[[Page 1176]]

    4.2.1.3  Moisture content of the flue gas must be determined 
continuously for the Unit 1 DAFGDS stack and the Unit 1 DAFGDS bypass 
stack, if the sulfur dioxide concentration in each stack is measured on 
a dry basis.
    4.2.2  For Unit 2, sulfur dioxide, oxygen or carbon dioxide, and 
volumetric flow rate.
    4.2.2.1  Moisture content of the flue gas must be determined 
continuously for the Unit 2 stack, if the sulfur dioxide concentration 
in the stack is measured on a dry basis.
    4.2.3  For Units 1 and 2, the hourly heat input, the hourly steam 
production rate, or the hourly gross electrical power output from each 
unit.
    4.3  For the Unit 1 bypass stack and the Unit 2 stack, the span 
value of the sulfur dioxide analyzer shall be equivalent to 200 percent 
of the maximum estimated hourly potential sulfur dioxide emissions of 
the fuel fired in parts per million sulfur dioxide. For the Unit 1 
DAFGDS stack, the span value of the sulfur dioxide analyzer shall be 
equivalent to 100 percent of the maximum estimated hourly potential 
emissions of the fuel fired in parts per million sulfur dioxide. The 
span value for volumetric flow monitors shall be equivalent to 125 
percent of the maximum estimated hourly flow in standard cubic meters/
minute (standard cubic feet per minute). The span value of the 
continuous moisture monitors, if required by 4.2.1.3 and 4.2.2.1, shall 
be equivalent to 100 percent by volume. The span value of the oxygen or 
carbon dioxide analyzers shall be equivalent to 25 percent by volume.
    4.3.1--4.3.2  [Reserved]
    4.4  The monitoring devices required in 4.2 shall be installed, 
calibrated, and maintained as follows:
    4.4.1  Each volumetric flow rate monitoring device specified in 4.2 
shall be installed at approximately the same location as the sulfur 
dioxide emission monitoring sample location.
    4.4.2  Hourly steam production rate and hourly electrical power 
output monitoring devices for Unit 1 and Unit 2 shall be calibrated and 
maintained according to manufacturer's specifications. The data from 
either of these devices may be used in the calculation of the combined 
emission rate in Section 3.3.1, only when the hourly heat input for Unit 
1 (H1) or the hourly heat input for Unit 2 (H2) cannot be determined 
from CEM data, and the hourly heat input to steam production or hourly 
heat input to electrical power output efficiency over a given segment of 
each boiler or generator operating range, respectively, varies by less 
than 5 percent within the specified operating range, or the efficiencies 
of the boiler/generator units differ by less than 5 percent. The hourly 
heat input for Unit 1 (H1) or the hourly heat input for Unit 2 (H2) in 
Section 3.3.1 may also be calculated based on the fuel firing rates and 
fuel analysis.
    4.4.3--4.4.5  [Reserved]
    4.5  The hourly mass emissions from Unit 1 (E1) and Unit 2 (E2) and 
the hourly heat inputs from Unit 1 (H1) and Unit 2 (H2) used to 
determine the hourly combined emission rate for Units 1 and 2 (EC) in 
Section 3.3.1 are calculated using CEM data for each respective stack as 
follows:
    4.5.1  The hourly SO2 mass emission from each respective 
stack is determined as follows:

E=(C)  (F)  (D)  (K)

Where:

E=SO2 mass emission from the respective stack in lb per hour
C=SO2 concentration from the respective stack ppm
F=flue gas flow rate from the respective stack in scfm
D=density of SO2 in lb per standard cubic feet
K=time conversion, 60 mins./hr
    4.5.2  The hourly heat input from each respective stack is 
determined as follows:

H=[(F)  (C)  (K)/(Fc)

where:

H=heat input from the respective stack in MMBTU per hour
C=CO2 or O2 concentration from the respective 
          stack as a decimal
F=flue gas flow rate from the respective stack in scfm
K=time conversion, 60 mins./hr
Fc=fuel constant for the appropriate diluent in scf/MMBTU as 
          per Secs. 60.45(f) (4) and (5)
    4.5.3  The hourly SO2 mass emission for Unit 1 in pounds 
per hour (E1) is calculated as follows, when leakage or diversion of any 
DAFGDS inlet gas to the bypass stack occurs:

E1=(EF)+(EB)

Where:

EF=Hourly SO2 mass emission measured in DAFGDS stack, lb/hr, 
          using the calculation in Section 4.5.1.
EB=Hourly SO2 mass emission measured in bypass stack, lb/hr, 
          using the calculation in Section 4.5.1.
Other than during conditions under 3.5.1, 3.5.2, 3.5.3, 3.5.4, or 4.8.2, 
          the DAFGDS bypass damper must be fully closed and any leakage 
          will be indicated by the bypass stack volumetric flow and 
          SO2 measurements, and when no leakage through the 
          bypass damper is indicated:

E1=EF
    4.5.4  The hourly heat input for Unit 1 in MMBTU per hour (H1) is 
calculated as follows, when leakage or diversion of any DAFGDS inlet gas 
to the bypass stack occurs:

H1=(HF)+(HB)


[[Page 1177]]


where:

HF=Hourly heat input as determined from the DAFGDS stack CEMs, in MMBTU 
          per hour, using the calculation in Section 4.5.2
HB=Hourly heat input as determined from the DAFGDS bypass stack CEMs, in 
          MMBTU per hour, using the calculation in Section 4.5.2
    4.6  For the CEMs required for Unit 1 and Unit 2, the owner or 
operator of the affected facility shall maintain and operate the CEMs 
and obtain combined emission data values (EC) for at least 75 percent of 
the boiler operting hours per day for at least 26 out of each 30 
successive boiler operating days.
    4.6.1  When hourly SO2 emission data are not obtained by 
the CEMs because of CEMs breakdowns, repairs, calibration checks and 
zero and span adjustment, hourly emission data required by 4.6 are 
obtained by using Methods 6 or 6C and 3 or 3A, 6A, or 8 and 3, or by 
other alternative methods approved by the Regional Administrator of the 
USEPA, Region 5 and the Director, of the IEPA. Failure to obtain the 
minimum data requirements of 4.6 by CEMs, or by CEMs supplemented with 
alternative methods of this section, is a violation of performance 
testing requirements.
    4.6.2  Independent of complying with the minimum data requirements 
of 4.6, all valid emissions data collected are used to calculate 
combined hourly emission rates (EC) and 30-day rolling average emission 
rates (E30) are calculated and used to judge compliance with 60.43(e).
    4.7  For each continuous emission monitoring system, a quality 
control plan shall be prepared by CIPS and submitted to the Regional 
Administrator of the USEPA, Region 5 and the Director, of the IEPA. The 
plan is to be submitted to the Regional Administrator of the USEPA, 
Region 5 and the Director, of the IEPA 45 days before initiation of the 
initial performance test. At a minimum, the plan shall contain the 
following quality control elements:
    4.7.1  Calibration of continuous emission monitoring systems (CEMs) 
and volumetric flow measurement devices.
    4.7.2  Calibration drift determination and adjustment of CEMs and 
volumetric flow measurement devices.
    4.7.3  Periodic CEMs, volumetric flow measurement devices and 
relative accuracy determinations.
    4.7.4  Preventive maintenance of CEMs and volumetric flow 
measurement devices (including spare parts inventory).
    4.7.5  Data recording and reporting.
    4.7.6  Program of corrective action for malfunctioning CEMs and 
volumetric flow measurement devices.
    4.7.7  Criteria for determining when the CEMs and volumetric flow 
measurement devices are not producing valid data.
    4.7.8  Calibration and periodic checks of monitoring devices 
identified in 4.4.2.
    4.8  For the purpose of conducting the continuous emission 
monitoring system performance specification tests as required by 
Sec. 60.13 and appendix B, the following conditions apply:
    4.8.1  The calibration drift specification of Performance 
Specification 2, appendix B shall be determined separately for each of 
the Unit 1 SO2 CEMs and the Unit 2 SO2 CEMs. The 
calibration drift specification of Performance Specification 3, appendix 
B shall be determined separately for each of the Unit 1 diluent CEMs and 
Unit 2 diluent CEMs.
    4.8.2  The relative accuracy of the combined SO2 emission 
rate for Unit 1 and Unit 2, as calculated from CEMs and volumetric flow 
data using the procedures in 3.3.1, 4.5.1, 4.5.2 and 4.5.3 shall be no 
greater than 20 percent of the mean value of the combined emission rate, 
as determined from testing conducted simultaneously on the DAFGDS stack, 
the DAFGDS bypass stack and the Unit 2 stack using reference methods 2, 
3, or 3A and 6 or 6C, or shall be no greater than 10 percent of the 
emission limit in Sec. 60.43(e), whichever criteria is less stringent. 
The relative accuracy shall be computed from at least nine comparisons 
of the combined emission rate values using the procedures in section 7 
and the equations in section 8, Performance Specification 2, appendix B. 
Throughout, but only during, the relative accuracy test period the 
DAFGDS bypass damper shall be partially opened such that there is a 
detectable flow.
    4.8.3--4.8.3.4  [Reserved]
    4.9  The total monitoring system required by 4.2 shall be subject 
only to an annual relative accuracy test audit (RATA) in accordance with 
the quality assurance requirements of section 5.1.1 of 40 CFR part 60, 
appendix F. Each SO2 and diluent CEMs shall be subject to 
cylinder gas audits (OGA) in accordance with the quality assurance 
requirements of section 5.1.2 of appendix F with the exception that any 
SO2 or diluent CEMs without any type of probe or sample line 
shall be exempt from the OGA requirements.

                      5. Recordkeeping Requirements

    5.1  The plant owner or operator shall keep a record of each hourly 
emission rate, each hourly SO2 CEMs value and hourly flow 
rate value, and each hourly Btu heat input rate, hourly steam rate, or 
hourly electrical power output, and a record of each hourly weighted 
average emission rate. These records shall be kept for all periods of 
operation of Unit 1 or 2 under provisions of Sec. 60.43(e), including 
operations of Unit 1 (E1) during periods of DAFGDS startup, shutdown, 
and malfunction when H1 and E1 are assumed to be zero (0) (see 4.5).

[[Page 1178]]

    5.2  The plant owner or operator shall keep a record of each hourly 
gas flow rate through the DAFGDS stack, each hourly stack gas flow rate 
through the bypass stack during any periods that the DAFGDS bypass 
damper is opened or flow is indicated, and reason for bypass operation.

                        6. Reporting Requirements

    6.1  The owner or operator of any affected facility shall submit the 
written reports required under 6.2 of this section and subpart A to the 
Regional Administrator of the USEPA, Region 5 and the Director, of the 
IEPA for every calendar quarter. All quarterly reports shall be 
submitted by the 30th day following the end of each calendar quarter.
    6.2  For sulfur dioxide, the following data resubmitted to the 
Regional Administrator of the USEPA, Region 5 and the Director, of the 
IEPA for each 24-hour period:
    6.2.1  Calendar date
    6.2.2  The combined average sulfur dioxide emission rate (ng/J or 
lb/million Btu) for the past 30 successive boiler operating days (ending 
with the last 30-day period in the quarter); and, for any noncompliance 
periods, reasons for noncompliance with the emission standards and 
description of corrective action taken.
    6.2.3  Identification of the boiler operating days for which valid 
sulfur dioxide emissions data required by 4.6 have not been obtained for 
75 percent of the boiler operating hours; reasons for not obtaining 
sufficient data; and description of corrective actions taken to prevent 
recurrence.
    6.2.4  Identification of the time periods (hours) when Unit 1 or 
Unit 2 were operated but combined hourly emission rates (EC) were not 
calculated because of the unavailability of parameters E1, E2, H1, or H2 
as described in 3.2.
    6.2.5  Identification of the time periods (hours) when Unit 1 and 
Unit 2 were operated and where the combined hourly emission rate (EC) 
equalled Unit 2 (E2/H2) emissions because of the Unit 1 malfunction 
provisions under 3.5.3, and 3.5.4.
    6.2.6  Identification of the time periods (hours) when emissions 
from the Unit 1 DAFGDS have been excluded from the calculation of 
average sulfur dioxide emission rates because of Unit 1 DAFGDS startup, 
shutdown, malfunction, or other reasons; and justification for excluding 
data for reasons other than startup or shutdown. Reporting of hourly 
emission rate of Unit 1 (E1/H2) during each hour of the DAFGDS startup, 
malfunction under 3.5.1, 3.5.2, 3.5.3, and 3.5.4 (see 4.5).
    6.2.7  Identification of the number of days in the calendar quarter 
that the affected facility was operated (any fuel fired).
    6.2.8  Identify any periods where Unit 1 DAFGDS malfunctions 
occurred and the cumulative hours of Unit 1 DAFGDS malfunction for the 
quarter.
    6.2.9  Identify any periods of time that any exhaust gases were 
discharged to the DAFGDS bypass stack and the hourly gas flow rate 
through the DAFGDS stack and through the DAFGDS bypass stack during such 
periods and reason for bypass operation.
    6.2.10  [Reserved]

[52 FR 28955, Aug. 4, 1987, as amended at 58 FR 28785, May 17, 1993; 59 
FR 8135, Feb. 18, 1994]

                    Appendix H to Part 60  [Reserved]

        Appendix I to Part 60--Removable Label and Owner's Manual

                             1. Introduction

    The purpose of this appendix is to provide guidance to the 
manufacturer for compliance with the temporary labeling and owner's 
manual provisions of subpart AAA. Section 2 provides guidance for the 
content and presentation of information on the temporary labels. Section 
3 provides guidance for the contents of the owner's manual.

                           2. Temporary Labels

                              2.1  General

    Temporary labels shall be printed on 90 pound bond paper and shall 
measure 5 inches wide by 7 inches long. All labels shall be printed in 
black ink on one side of the label only. The type font that shall be 
used for all printing is helvetica. Specific instructions for drafting 
labels are provided below depending upon the compliance status of the 
wood heater model. Figures 1 through 7 illustrate the various label 
types that may apply.

                       2.2 Certified Wood Heaters

    The design and content of certified wood heaters vary according to 
the following:
     Catalyst or noncatalyst,
     Measured or default thermal efficiency value, and
     Compliance with 1988 or 1990 emission limit.
    There are five parts of a label. These include:
     Identification and compliance status,
     Emission value,
     Efficiency value,
     Heat output value, and
     Caveats.
    Instructions for drafting each of these five parts are discussed 
below in terms of the three variables listed above. Figures 1 and 2 
illustrate the variations in label design. Figure 1 is a temporary label 
for a hypothetical catalyst wood heater that meets the 1990 standard, 
has a certification test emission composite value of 3.5 g/h, and has a 
default efficiency of 72 percent. The label in Figure

[[Page 1179]]

2 is for a hypothetical noncatalyst wood heater with a certification 
test emission composite value of 7.8 g/h and a measured efficiency of 68 
percent. It meets the 1988 but not the 1990 standard. All labels for 
wood heaters that have been certified and tested should conform as much 
as possible to the general layout, the type font and type size 
illustrated in Figures 1 and 2.

               2.2.1  Identification and Compliance Status

    The top 1.5 inches of the label should contain the following items 
(and location on the label):
     Manufacturer name (upper left hand corner,
     Model name/number (upper left hand corner,
     The words ``U.S. ENVIRONMENTAL PROTECTION AGENCY'' 
(centered at top and enclosed in a box with rounded edges),
     For catalytic wood heaters, in large bold print the words 
``CATALYST EQUIPPED'' (centered below the words ``U.S. ENVIRONMENTAL 
PROTECTION AGENCY''),
     Text indicating compliance status for catalytic wood 
heaters. For those catalytic wood heaters which comply with the 1988 
emission limits, but not the 1990 emission limits, the words: ``Meets 
EPA particulate matter (smoke) control requirements for catalytic wood 
heaters built on or after July 1, 1988, and before July 1, 1990.'' For 
those catalytic wood heaters which comply with the 1990 emission limits, 
the words: ``Meets EPA particulate matter (smoke) control requirements 
for catalytic wood heaters built on or after July 1, 1990.'' Finally, 
for all catalytic wood heaters, the following text should be included: 
``See catalyst warranty. Illegal to operate when catalyst is not 
working. See owner's manual for operation and maintenance.''
     Text indicating compliance status for noncatalytic wood 
heaters. For those noncatalytic wood heaters that comply with the 1988 
emission limits but not the 1990 emission limits, the words: ``Meets EPA 
particulate matter (smoke) control requirements for NONCATALYTIC wood 
heaters built on or after July 1, 1988, and before July 1, 1990.'' For 
those noncatalytic wood heaters that comply with 1990 emission limits, 
the words: ``Meets EPA particulate matter (smoke) control requirements 
for NONCATALYTIC wood heaters built on or after July 1, 1990.''

                          2.2.2  Emission Value

    Between 1.5 and 3.0 inches down from the top of the label is the 
part that graphically illustrates the particulate matter, or smoke, 
emission value. This part consists of the word ``SMOKE'' in large bold 
print and a 3.0 inch line with words ``(grams per hour)'' centered 
beneath the line. A blunt end arrow with a base (blunt end) that spans 2 
g/hr shall be centered over the point on the emissions line that 
represents the composite emission value for the model as measured in the 
certification test.
    For catalyst equipped wood heaters the 3.0 inch line shall be 
labeled ``0'' on the left end of the line (centered below the end) and 
``5.5'' on the right end (centered below the end). To find where to 
center the large blunt end arrow, measure 0.55 inches from the left end 
for each g/h of the composite emission value. Thus, a 4 g/h value would 
be 2.2 inches from the left end. The base of the blunt end should always 
be 1.1 inches wide (2 g/hr). The words ``This Model'' should be centered 
above or within the blunt end arrow.
    For noncatalyst equipped wood heaters, the 3.0 inch line should be 
labeled ``0'' on the left end of the line (centered below the end) and 
``8.5'' on the right end of the line (centered below the end). To find 
where to center the large blunt end arrow, measure 0.35 inches from the 
left end for each g/h of the composite emission value. Thus, a 4 g/h 
value would be 1.4 inches from the left end. The base of the blunt end 
should always be 0.7 inches wide (2 g/h). The words ``This Model'' 
should be centered above or within the blunt end arrow.

                         2.2.3  Efficiency Value

    Between 3.0 and 4.75 inches down from the top of the label is the 
part that illustrates overall thermal efficiency value. The efficiency 
value may either be a measured value or a calculated or default value as 
provided in Sec. 60.536(i)(3) of the regulation. Regardless of how the 
efficiency is derived, the words ``EFFICIENCY'' shall be centered above 
a 4 inch line. The 4 inch line should be divided into 5 equal lengths 
(each 0.8 inches) and labeled ``50%,'' ``60%,'' * * * ``100%'' as 
indicated in Figures 1 and 2. As with the smoke line in 2.2.2, a blunt 
end arrow shall be centered over the point on the line where the 
efficiency value would be located. The base of the blunt end arrow shall 
be 0.48 inches wide (6 percentage points). To find where to center the 
blunt end arrow, measure 0.08 inches for each percentage point to the 
right of the nearest labeled value. For example, a value of 82 percent 
would be 0.16 inches to the right of the ``80%'' mark.
    For default efficiency values, an asterisk shall follow the word 
``EFFICIENCY'' as in Figure 1. The asterisk refers to a note in 
parentheses that shall say ``Not tested for efficiency. Value indicated 
is for similar catalyst equipped (or noncatalytic, as appropriate) wood 
heaters.''
    For measured efficiency values measured with the method in appendix 
J, the words ``Tested Efficiency'' shall be centered above the blunt end 
arrow as in Figure 2.
    The last item required for this part is a sentence that says ``Wood 
heaters with higher efficiencies cost less to operate.''

[[Page 1180]]

                        2.2.4  Heat Output Value

    Between 4.75 and 6.0 inches down from the top of the label is the 
heat output part. The words ``HEAT OUTPUT'' in large bold print are 
centered above the Heat Output range numbers in Btu/hr, as derived from 
the certification test. The words ``Use this to choose the right size 
appliance for your needs. ASK DEALER FOR HELP'' should follow the heat 
output range numbers as in Figures 1 and 2. (Note that ``ASK DEALER FOR 
HELP'' is a single line, centered in the label.) The low end of the burn 
rate range indicated on the label should reflect the low end of the burn 
rate range achievable by the wood heater as sold and not as tested in 
the laboratory (see Sec. 60.536(i)(4)).

                             2.2.5  Caveats

    In the lower 0.75 inch of the label, the following text shall be 
presented:
    ``This wood heater will achieve low smoke output and high efficiency 
only if properly operated and maintained. See owner's manual.''

                         2.3  Coal-Only Heaters

    For those heaters which meet the definition of ``coal only heater'' 
in Sec. 60.531, the temporary label should contain the identical 
material (same layout and print font and size) as that illustrated in 
Figure 3, except that the hypothetical manufacturer and model name 
should be replaced with the appropriate actual names.

              2.4  Small Manufacturer Exempted Wood Heaters

    For those wood heaters exempted under Sec. 60.530(d), the small 
manufacturer exemption, the temporary label should contain the identical 
material (same layout and print font and size) as that illustrated in 
Figure 4, except that the hypothetical manufacturer and model name 
should be replaced with the appropriate actual names.

                2.5  Wood Heaters that Are Not Certified

    For those wood heaters that do not meet applicable emission limits 
under Sec. 60.532 and are not otherwise exempted, the temporary label 
should contain the identical material (same layout and print font and 
size) as those illustrated in Figures 5, 6, and 7, as appropriate. The 
hypothetical manufacturer and model names should be replaced with the 
appropriate actual names.
    There are three kinds of wood heaters which fall into this category 
of ``not certified.'' Each requires a separate label. If a wood heater 
is tested but fails to meet the applicable limits, the label in Figure 5 
applies. Such a label should be printed on red rather than white paper. 
If a wood heater is tested and does meet the emission limit but is not 
subsequently certified, the label in Figure 6 applies. (An example would 
be a one-of-a-kind wood heater which is not part of a model line. 
Because of the costs of testing, this circumstance is not expected to 
arise often, if at all.) If a wood heater is not tested and is not 
certified, it should bear the label illustrated in Figure 7. As with 
Figure 5, this label should be printed on red paper.

       3.0 Guidance for Preparation of Wood Heater Owner's Manuals

                            3.1  Introduction

    Although the owner's manuals do not require premarket approval, EPA 
will monitor the contents to ensure that sufficient information is 
included to provide heater operation and maintenance information 
affecting emissions to consumers. The purpose of this section is to 
provide guidance to manufacturers in complying with the owner's manual 
provisions of Sec. 60.536(1). A checklist of topics and illustrative 
language is provided as a guideline. Owner's manuals should be tailored 
to specific wood heater models, as appropriate.

         3.2  Topics Required To Be Addressed in Owner's Manual

     Wood heater description and compliance status,
     Tamper warning,
     Catalyst information and warranty (if catalyst equipped),
     Fuel selection,
     Achieving and maintaining catalyst light-off (if catalyst 
equipped),
     Catalyst monitoring (if catalyst equipped),
     Troubleshooting catalytic equipped heaters (if catalyst 
equipped),
     Catalyst replacement (if catalyst equipped),
     Wood heater operation and maintenance, and
     Wood heater installation: achieving proper draft.

                      3.3  Sample Text/Descriptions

    The following are example texts and/or further descriptions 
illustrating the topics identified above. Although the regulation 
requires manufacturers to address (where applicable) the ten topics 
identified above, the exact language is not specified. Manuals should be 
written specific to the model and design of the wood heater. The 
following guidance is composed of generic descriptions and texts. If 
manufacturers choose to use the language provided in the example, the 
portion in italics should be revised as appropriate. Any manufacturer 
electing to use the EPA example language shall be in compliance with 
owner's manual requirements provided that the particular language is 
printed

[[Page 1181]]

in full with only such changes as are necessary to ensure accuracy. 
Example language is not provided for certain topics, since these areas 
are generally heater specific. For these topics, manufacturers should 
develop text that is specific to the operation and maintenance of their 
particular products.

          3.3.1  Wood Heater Description and Compliance Status

    Owner's Manuals shall include:
    A. Manufacturer and model,
    B. Compliance status (exempt, 1988 std., 1990 std., etc.), and
    C. Heat output range (as indicated on temporary label).
    Example Text covering A, B, and C above:

``This manual describes the installation and operation of the Brand X, 
Model 0 catalytic equipped wood heater. This heater meets the U.S. 
Environmental Protection Agency's emission limits for wood heaters sold 
between July 1, 1990, and July 1, 1992. Under specific test conditions 
this heater has been shown to deliver heat at rates ranging from 8,000 
to 35,000 Btu/hr.''

                          3.3.2  Tamper Warning

    This consists of the following statement which must be included in 
the owner's manual for catalyst equipped units:
    Example Text covering legal prohibition on tampering:
    ``This wood heater contains a catalytic combustor, which needs 
periodic inspection and replacement for proper operation. It is against 
the law to operate this wood heater in a manner inconsistent with 
operating instructions in this manual, or if the catalytic element is 
deactivated or removed.''

                       3.3.3  Catalyst Information

    Included with or supplied in the owner's and warranty manuals shall 
be the following information:
    A. Catalyst manufacturer, model,
    B. Catalyst warranty details, and
    C. Instructions for warranty claims.
    Example Text covering A, B, and C:
    ``The combustor supplied with this heater is a Brand Z, Long Life 
Combustor. Consult the catalytic combustor warranty also supplied with 
this wood heater. Warranty claims should be addressed to:

Stove or Catalyst Manufacturer__________________________________________
Address_________________________________________________________________
Phone _________________________________________________________________

This section should also provide clear guidance on how to exercise the 
warranty (how to package for return shipment, etc.).

                          3.3.4  Fuel Selection

    Owner's manuals shall include:
    A. Instructions on acceptable fuels, and
    B. Warning against inappropriate fuels.
    Example Text covering A and B:
    ``This heater is designed to burn natural wood only. Higher 
efficiencies and lower emissions generally result when burning air dried 
seasoned hardwoods, as compared to softwoods or to green or freshly cut 
hardwoods.
    DO NOT BURN:
     Treated Wood.
     Coal.
     Garbage.
     Cardboard.
     Solvents.
     Colored Paper.
     Trash.
    Burning treated wood, garbage, solvents, colored paper or trash may 
result in release of toxic fumes and may poison or render ineffective 
the catalytic combustor.
    Burning coal, cardboard, or loose paper can produce soot, or large 
flakes of char or fly ash that can coat the combustor, causing smoke 
spillage into the room, and rendering the combustor ineffective.''

           3.3.5 Achieving and Maintaining Catalyst Light-Off

    Owner's manuals shall describe in detail proper procedures for:
    A. Operation of catalyst bypass (stove specific),
    B. Achieving catalyst light-off from a cold start, and
    C. Achieving catalyst light-off when refueling.
    No example text is supplied for describing operation of catalyst 
bypass mechanisms (Item A) since these are typically stove-specific. 
Manufacturers however must provide instructions specific to their model 
describing:
    1. Bypass position during start-up,
    2. Bypass position during normal operation, and
    3. Bypass position during reloading.
    Example Text for item B:
    ``The temperature in the stove and the gases entering the combustor 
must be raised to between 500 deg. to 700 deg.F for catalytic activity 
to be initiated. During the start-up of a cold stove, a medium to high 
firing rate must be maintained for about 20 minutes. This ensures that 
the stove, catalyst, and fuel are all stabilized at proper operating 
temperatures. Even though it is possible to have gas temperatures reach 
600  deg.F within two to three minutes after a fire is started, if the 
fire is allowed to die down immediately it may go out or the combustor 
may stop working. Once the combustor starts working, heat generated in 
it by burning the smoke will keep it working.''
    Example Text for item C:
    REFUELING:
    ``During the refueling and rekindling of a cool fire, or a fire that 
has burned down to the charcoal phase, operate the stove at a

[[Page 1182]]

medium to high firing rate for about 10 minutes to ensure that the 
catalyst reaches approximately 600  deg.F.''

                        3.3.6 Catalyst Monitoring

    Owner's manuals shall include:
    A. Recommendation to visually inspect combustor at least three times 
during the heating season,
    B. Discussion on expected combustor temperatures for monitor-
equipped units, and
    C. Suggested monitoring and inspection techniques.
    Example Text covering A, B, and C:
    ``It is important to periodically monitor the operation of the 
catalytic combustor to ensure that it is functioning properly and to 
determine when it needs to be replaced. A non-functioning combustor will 
result in a loss of heating efficiency, and an increase in creosote and 
emissions. Following is a list of items that should be checked on a 
periodic basis.
     Combustors should be visually inspected at least three 
times during the heating season to determine if physical degradation has 
occurred. Actual removal of the combustor is not recommended unless more 
detailed inspection is warranted because of decreased performance. If 
any of these conditions exist, refer to Catalyst Troubleshooting section 
of this owner's manual.
     This catalytic heater is equipped with a temperature probe 
to monitor catalyst operation. Properly functioning combustors typically 
maintain temperatures in excess of 500  deg.F, and often reach 
temperatures in excess of 1,000  deg.F. If catalyst temperatures are not 
in excess of 500  deg.F, refer to Catalyst Troubleshooting section of 
this owner's manual.
     You can get an indication of whether the catalyst is 
working by comparing the amount of smoke leaving the chimney when the 
smoke is going through the combustor and catalyst light-off has been 
achieved, to the amount of smoke leaving the chimney when the smoke is 
not routed through the combustor (bypass mode).
    Step 1--Light stove in accordance with instructions in 3.3.5.
    Step 2--With smoke routed through the catalyst, go outside and 
observe the emissions leaving the chimney.
    Step 3--Engage the bypass mechanism and again observe the emissions 
leaving the chimney.
    Significantly more smoke should be seen when the exhaust is not 
routed through the combustor (bypass mode). Be careful not to confuse 
smoke with steam from wet wood.''

                     3.3.7 Catalyst Troubleshooting

    The owner's manual should provide clear descriptions of symptoms and 
remedies to common combustor problems. It is recommended that 
photographs of catalyst peeling, plugging, thermal cracking, mechanical 
cracking, and masking be included in the manual to aid the consumer in 
identifying problems and to provide direction for corrective action.

                       3.3.8 Catalyst Replacement

    The owner's manual should provide clear step-by-step instructions on 
how to remove and replace the catalytic combustor. The section should 
include diagrams and/or photographs.

               3.3.9 Wood Heater Operation and Maintenance

    Owner's manual shall include:
    A. Recommendations about building and maintaining a fire,
    B. Instruction on proper use of air controls,
    C. Ash removal and disposal,
    D. Instruction on gasket replacement, and
    E. Warning against overfiring.
    No example text is supplied for A, B, and D since these items are 
model specific. Manufacturers should provide detailed instructions on 
building and maintaining a fire including selection of fuel pieces, fuel 
quantity, and stacking arrangement. Manufacturers should also provide 
instruction on proper air settings (both primary and secondary) for 
attaining minimum and maximum heat outputs and any special instructions 
for operating thermostatic controls. Step-by-step instructions on 
inspection and replacement of gaskets should also be included. 
Manufacturers should provide diagrams and/or photographs to assist the 
consumer. Gasket type and size should be specified.
    Example Text for item C:
    ``Whenever ashes get 3 to 4 inches deep in your firebox or ash pan, 
and when the fire has burned down and cooled, remove excess ashes. Leave 
an ash bed approximately 1 inch deep on the firebox bottom to help 
maintain a hot charcoal bed.''
    ``Ashes should be placed in a metal container with a tight-fitting 
lid. The closed container of ashes should be placed on a noncombustible 
floor or on the ground, away from all combustible materials, pending 
final disposal. The ashes should be retained in the closed container 
until all cinders have thoroughly cooled.''
    Example Text covering item E:
    ``DO NOT OVERFIRE THIS HEATER''
    ``Attempts to achieve heat output rates that exceed heater design 
specifications can result in permanent damage to the heater and to the 
catalytic combustor if so equipped.''

         3.3.10 Wood Heater Installation: Achieving Proper Draft

    Owner's manual shall include:
    A. Importance of proper draft,

[[Page 1183]]

    B. Conditions indicating inadequate draft, and
    C. Conditions indicating excessive draft.
    Example Text for Item A:
    ``Draft is the force which moves air from the appliance up through 
the chimney. The amount of draft in your chimney depends on the length 
of the chimney, local geography, nearby obstructions, and other factors. 
Too much draft may cause excessive temperatures in the appliance and may 
damage the catalytic combustor. Inadequate draft may cause backpuffing 
into the room and `plugging' of the chimney or the catalyst.''
    Example text for Item B:
    ``Inadequate draft will cause the appliance to leak smoke into the 
room through appliance and chimney connector joints.''
    Example text Item C:
    ``An uncontrollable burn or a glowing red stove part or chimney 
connector indicates excessive draft.''

[[Page 1184]]

[GRAPHIC] [TIFF OMITTED] TC01JN92.297


[[Page 1185]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.298


[[Page 1186]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.299


[[Page 1187]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.300


[[Page 1188]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.301


[[Page 1189]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.302


[[Page 1190]]


[GRAPHIC] [TIFF OMITTED] TC01JN92.303


[53 FR 5913, Feb. 26, 1988]


[[Page 1191]]



                              FINDING AIDS




  --------------------------------------------------------------------

  A list of CFR titles, subtitles, chapters, subchapters and parts and 
an alphabetical list of agencies publishing in the CFR are included in 
the CFR Index and Finding Aids volume to the Code of Federal Regulations 
which is published separately and revised annually.

  Material Approved for Incorporation by Reference
  Table of CFR Titles and Chapters
  Alphabetical List of Agencies Appearing in the CFR
  List of CFR Sections Affected

[[Page 1193]]

            Material Approved for Incorporation by Reference

                      (Revised as of July 1, 1999)

  The Director of the Federal Register has approved under 5 U.S.C. 
552(a) and 1 CFR Part 51 the incorporation by reference of the following 
publications. This list contains only those incorporations by reference 
effective as of the revision date of this volume. Incorporations by 
reference found within a regulation are effective upon the effective 
date of that regulation. For more information on incorporation by 
reference, see the preliminary pages of this volume.


40 CFR (PART 60):

ENVIRONMENTAL PROTECTION AGENCY
                                                                  40 CFR


American Hospital Association (AHA) Service, Inc.

  P.O. Box 92683, Chicago, IL 60675-2683
``An Ounce of Prevention: Waste Reduction                          60.17
  Strategies for Health Care Facilities'', 
  American Society for Health Care Environmental 
  Services of the American Hospital Association, 
  1993. AHA Catalog No. 057007. ISBN 0-87258-673-
  5.


American Petroleum Institute

  1220 L Street, NW., Washington, DC 20005-4070; 
  Telephone: (202) 682-8000
API Publication 2517, Evaporation Loss from           60.17; 60.111(1); 
  External Floating-Roof Tanks, Second Edition,             60.111a(g); 
  February 1980.                                            60.111b(g); 
                                                       60.116b(f)(2)(ii)


American Public Health Association, American Water Works Association, 
and Water Pollution Control Federation

  800 I Street NW., Washington, DC 20001-3710; 
  Telephone: (202) 777-APHA
Standard Methods for the Examination of Waste and          60.17(e)(1); 
  Wastewater, 15th ed. (1980) Method 209A, Total               60.683(b)
  Residue Dried at 1031/2 to 1051/2 C.
Standard Methods for the Examination of Water and         60.17(a)(22); 
  Wastewater, 16th ed. (1985), Method 308 F.         Appendix A to Part 
                                                   60, Method 29, pars. 
                                                      4.2.2, 4.4.2, and 
                                                                   4.5.6


American Society of Mechanical Engineers

  Three Park Avenue, New York, NY 10016-5990; 
  Telephone: (800) THE-ASME
ASME Interim Supplement 19.5 on Instruments and                  60.17; 
  Apparatus; Application, Part II of Fluid Meters,    60.58a(h)(6)(ii); 
  6th Edition (1971).                                   60.58b(i)(6)(ii)
ASME PTC 4.1-1964 (Reaffirmed 1991), Power Test       60.17(h); 60.46b; 
  Codes: Test Code for Steam Generating Units         60.58a(h)(6)(ii); 
  (with 1968 and 1969 Addenda).                         60.58b(i)(6)(ii)
ASME QRO-1-1994 Standard for the Qualification and    60.17; 60.56a(d); 
  Certification of Resource Recovery Facility       60.54b(a); 60.54b(b)
Operators.
[[Page 1194]]

American Society for Testing and Materials

  100 Barr Harbor Drive, West Conshohocken, PA 
  19428-2959; Telephone: (610) 832-9585, FAX 
  (610): 832-9555
ASTM A99-76, Standard Specification for                           60.261
  Ferromanganese.
ASTM A100-69 (Reapproved 1974), Standard                          60.261
  Specification for Ferrosilicon.
ASTM A101-73, Standard Specification for                          60.261
  Ferrochromium.
ASTM A482-76, Standard Specification for                          60.261
  Ferrochromesilicon.
ASTM A483-64 (Reapproved 1974), Standard                          60.261
  Specification for Silicomanganese.
ASTM A495-76, Standard Specification for Calcium-                 60.261
  Silicon and Calcium Manganese-Silicon.
ASTM D86-78, Distillation of Petroleum Products... 60.17(a); 60.593(d); 
                                                               60.633(h)
ASTM D129-64 (Reapproved 1978), Standard Test        Appendix A to Part 
  Method for Sulfur in Petroleum Products (General       60, Method 19; 
  Bomb Method).                                           60.17(a)(56); 
                                                            60.106(h)(2)
ASTM D240-76, Standard Test Method for Heat of     60.46(g); 60.296(f); 
  Combustion of Liquid Hydrocarbon Fuels by Bomb     Appendix A to Part 
  Calorimeter.                                             60, Method 19
ASTM D270-65 (Reapproved 1975), Standard Method of   Appendix A to Part 
  Sampling Petroleum and Petroleum Products.               60, Method 19
ASTM D323-82 Test Method for Vapor Pressure of            60.17(a)(13); 
  Petroleum Products (Reid Method).                          60.111(l); 
                                                            60.111a(g); 
                                                            60.111b(g); 
                                                       60.116b(f)(2)(ii)
ASTM D388-77, Standard Specification for            60.17(a); 60.41(f); 
  Classification of Coals by Rank.                     60.45(f)(4) (i), 
                                                    (ii), (vi); 60.41a; 
                                                        60.41b; 60.41c; 
                                                         60.251 (b), (c)
ASTM D396-78, Standard Specification for Fuel Oils    60.17(a); 60.40b; 
                                                        60.41b; 60.41c; 
                                                   60.111(b); 60.111a(b)
ASTM D975-78, Standard Specification for Diesel    60.111(b); 60.111a(b)
  Fuel Oils.
ASTM D1072-56 (Reapproved 1975), Standard Test              60.335(b)(2)
  Method for Total Sulfur in Fuel Gases.
ASTM D1137-53 (Reapproved 1975), Standard Method          60.45(f)(5)(i)
for Analysis of Natural Gases and Related Types 
[[Page 1195]]ixtures by the Mass Spectrometer.

ASTM D1193-77, Standard Specification for Reagent         60.17(a)(22); 
  Water.                                             Appendix A to Part 
                                                     60, Method 6, par. 
                                                   3.1.1; Method 7, par. 
                                                      3.2.2; Method 7C, 
                                                     par. 3.1.1; Method 
                                                        7D, par. 3.1.1; 
                                                   Method 8, par. 3.1.3; 
                                                        Method 12, par. 
                                                     4.1.3; Method 14A, 
                                                   par. 7.1; Method 25D, 
                                                   par. 3.2.2.4; Method 
                                                       26A, par. 3.1.1; 
                                                    61.18(a)(2); Method 
                                                   29, pars. 5.4.3, 6.3, 
                                                      and 7.2.3; Method 
                                                       101, par. 6.1.1; 
                                                      Method 101A, par. 
                                                     6.1.1; Method 104, 
                                                              par. 3.1.2
ASTM D1266-87, Standard Test Method for Sulfur in         60.17(a)(57); 
  Petroleum Products (Lamp Method).                         60.106(h)(2)
ASTM D1475-60 (Reapproved 1980), Standard Test            60.435(d)(1); 
  Method for Density of Paint, Varnish, Lacquer,   60.485(d); Appendix A 
  and Related Products.                              to Part 60, Method 
                                                      24, par. 2.1, and 
                                                    Method 24A, par. 2.2
ASTM D1552-83, Standard Test Method for Sulfur in    Appendix A to Part 
  Petroleum Products (High-Temperature Method).          60, Method 19; 
                                                          60.17(a)(58); 
                                                            60.106(h)(2)
ASTM D1608-77, Standard Test Method for Oxides of   Method 7, par. 3.2.2
  Nitrogen in Gaseous Combustion Products (Phenol-
  Disulfonic Acid Procedures).
ASTM D1826-77, Standard Test Method for Calorific      60.45(f)(5)(ii); 
  Value of Gases in Natural Gas Range by           60.46(g); 60.296(f); 
  Continuous Recording Calorimeter.                  Appendix A to Part 
                                                           60, Method 19
ASTM D1835-86, Standard Specification for          60.17(a)(49); 60.41b; 
  Liquefied Petroleum (LP) Gases.                                 60.41c
ASTM D1945-64 (Reapproved 1976), Standard Method          60.45(f)(5)(i)
  for Analysis of Natural Gas by Gas 
  Chromatography.
ASTM D1946-77, Standard Method for Analysis of             60.17(a)(6); 
  Reformed Gas by Gas Chromatography.                         60.18(f); 
                                                        60.45(f)(5)(i); 
                                                   60.614(d)(2)(ii) and 
                                                                (d)(4); 
                                                   60.664(d)(2)(ii) and 
                                                   (d)(4); 60.704(d)(2) 
                                                              and (d)(4)

[[Page 1196]]

ASTM D2013-72, Standard Method of Preparing Coal     Appendix A to Part 
  Samples for Analysis.                                    60, Method 19
ASTM D2015-77, Standard Test Method for Gross          60.45(f)(5)(ii); 
  Calorific Value of Solid Fuel by the Adiabatic   60.46(g); Appendix to 
  Bomb Calorimeter.                                   Part 60, Method 19
ASTM D2016-74 (Reapproved 1983), Standard Text            60.17(a)(53); 
  Methods for Moisture Content of Wood.              Appendix A to Part 
                                                           60, Method 28
ASTM D2234-76, Standard Methods for Collection of    Appendix A to Part 
  a Gross Sample of Coal.                                  60, Method 19
ASTM D2369-81, Standard Test Method for Volatile     Appendix A to Part 
  Content of Coatings.                                     60, Method 24
ASTM D2382-76, Heat of Combustion of Hydrocarbon          60.17(a)(38); 
  Fuels by Bomb Calorimeter (High Precision        60.18(f); 60.485(g); 
  Method).                                                60.614(d)(4); 
                                                          60.664(d)(4); 
                                                            60.704(d)(4)
ASTM D2504-67 (Reapproved 1977) Noncondensable                 60.485(g)
  Gases in C3 and Lighter Hydrocarbon Products by 
  Gas Chromatography.
ASTM D2584-68 (Reapproved 1979), Ignition Loss of         60.17(a)(45); 
  Cured Reinforced Resins.                                     60.685(e)
ASTM D2622-87, Standard Test Method for Sulfur in         60.17(a)(59); 
  Petroleum Products by X-Ray Spectrometry.                 60.106(h)(2)
ASTM D2879-83, Test Method for Vapor Pressure-     60.17; 60.111b(f)(3); 
  Temperature Relationship and Initial               60.116b(e)(3)(ii), 
  Decomposition Temperature of Liquids by             60.116b(f)(2)(i); 
  Isoteniscope.                                                60.485(e)
ASTM D2880-78, Standard Specification for Gas                60.111(b); 
  Turbine Fuel Oils.                                        60.111a(b); 
                                                            60.335(b)(2)
ASTM D2908-74, Standard for Measuring Volatile       60.17(a); 60.564(j)
  Organic Matter in Water by Aqueous-Injection Gas 
  Chromatography.
ASTM D2986-71 (Reapproved 1978), Standard Method     Appendix A to Part 
  for Evaluation of Air, Assay Media by the          60, Method 5, par. 
  Monodisperse DOP (Dioctyl Phthalate) Smoke Test.    3.1.1; Method 12, 
                                                     par. 4.1.1; Method 
                                                        17, par. 3.1.1; 
                                                    61.18(a)(7); Method 
                                                       103, par. 2.1.3; 
                                                       Method 104, par. 
                                                                   3.1.1
ASTM D 2986-95A, Standard Practice for Evaluation    Appendix A to Part 
  of Air Assay Media by the Monodisperse DOP       60, Method 315, par. 
  (Dioctyl Phthalate) Smoke Test.                                  7.1.1
ASTM D3031-81. Standard Test Method for Total               60.335(b)(2)
  Sulfur in Natural gas by Hydrogenation.
ASTM D3173-73, Standard Test Method for Moisture     Appendix A to Part 
  in the Analysis Sample of Coal and Coke.                 60, Method 19
ASTM D3176-74, Standard Method for Ultimate             60.45(f)(5)(i); 
  Analysis of Coal and Coke.                         Appendix A to Part 
                                                           60, Method 19

[[Page 1197]]

ASTM D3177-75, Standard Test Methods for Total       Appendix A to Part 
  Sulfur in the Analysis Sample of Coal and Coke.          60, Method 19
ASTM D3178-73, Standard Test Methods for Carbon           60.45(f)(5)(i)
  and Hydrogen in the Analysis Sample of Coal and 
  Coke.
ASTM D3246-81, Standard Method for Sulfur in                60.335(b)(2)
  Petroleum Gas by Oxidative Microcoulometry.
ASTM D3286-85, Standard Test Method for Gross             60.17(a)(50); 
  Calorific Value of Coal and Coke by the            Appendix A to Part 
  Isothermal-Jacket Bomb calorimeter.                      60, Method 19
ASTM D3370-76, Standard Practices for Sampling       60.17(a); 60.564(j)
  Water.
ASTM D3431-80, Standard Test Method for Trace             60.17(a)(46); 
  Nitrogen in Liquid Petroleum Hydrocarbons          Appendix A to Part 
  (Microcoulometric Method).                               60, Method 19
ASTM D3792-79, Standard Test Method for Water        Appendix A to Part 
  Content of Water-Reducible Paints by Direct       60, Method 24, par. 
  Injection Into a Gas Chromatograph.                                2.3
ASTM D4017-81, Standard Test Method for Water in     Appendix A to Part 
  Paints and Paint Materials by the Karl Fischer    60, Method 24, par. 
  Titration Method.                                                  2.4
ASTM D4057-81, Standard Practive for Manual               60.17(a)(51); 
  Sampling of Petroleum and Petroleum Products.      Appendix A to Part 
                                                           60, Method 19
ASTM D4084-82, Standard Method for Analysis of              60.335(b)(2)
  Hydrogen Sulfides in Gaseous Fuels (Lead Acetate 
  Reaction Rate Method).
ASTM D4239-85, Standard Test Methods for Sulfur in        60.17(a)(52); 
  the Analysis Sample of Coal and Coke Using High    Appendix A to Part 
  Temperature Tube Furnace Combustion Methods.             60, Method 19
ASTM D4442-84, Standard Test Methods for Direct           60.17(a)(54); 
  Moisture Content Measurement of Wood and Wood-     Appendix A to Part 
  base Materials.                                          60, Method 28
ASTM D4457-85, Test Method for Determination of           60.17(a)(62); 
  Dichloromethane and 1,1,1-Trichloroethane in       Appendix A to Part 
  Paints and Coatings by Direct Injection into a           60, Method 24
  Gas Chromatograph.
ASTM E168-67 (Reapproved 1977), General Techniques         60.17(a)(35; 
  of Infrared Qualitative Analysis.                60.485(d); 60.593(b); 
                                                               60.632(f)
ASTM E169-63 (Reapproved 1977), General Techniques        60.17(a)(34); 
  of Ultraviolet Quantitative Analysis.            60.485(d); 60.593(b); 
                                                               60.632(f)
ASTM E260-73, General Gas Chromatography                  60.17(a)(36); 
  Procedures.                                      60.485(d); 60.593(b); 
                                                               60.632(f)


AOAC International (Association of Official Analytical Chemists)

  481 N. Frederick Ave., Suite 500, Gaithersburg, 
  MD 20877-2407; Telephone: (301) 924-7077

[[Page 1198]]

AOAC Method 9, Official Methods of Analysis of the        60.204(d)(2); 
  Association of Official Analytical Chemists,            60.214(d)(2); 
  Eleventh Edition, 1970, pp. 11-12.                      60.224(d)(2); 
                                                            60.234(d)(2)


Management and Budget Office

  Available from: National Technical Information 
  Services, 5285 Port Royal Road, Springfield, VA 
  22161
NTIS No. PB 93-192-664. OMB Bulletin No. 93-17.                    60.17
  Revised Definitions for Metropolitan Areas 
  (MAs), June 30, 1993.


Technical Association of the Pulp and Paper Industry

  Dunwoody Park, Atlanta, Georgia 30341
TAPPI Method T624 os-68...........................          60.285(d)(4)


U.S. Environmental Protection Agency

  401 M Street, SW., Washington, DC 20460
Test Methods for Evaluating Solid Waste, Physical/     60.17(a)(22)(i); 
  Chemical Methods, EPA Publication SW-846 Third     Appendix A to Part 
  Edition (November, 1986), as amended by Updates  60, Method 29, pars. 
  I (July 1992), II (September 1994), IIA (August    2.2.1, 2.3.1, 2.5, 
  1993) and IIB (January 1995).                     3.3.12.1, 3.3.12.2, 
                                                        3.3.13, 3.3.14, 
                                                       5.4.3, 6.2, 6.3, 
                                                      7.2.1, 7.2.3, and 
                                                              Table 29-2


Underwriters Laboratories, Inc.

  Available from: Global Engineering Documents, 15 
  Inverness Way East, Englewood, CO 80112; 
  Telephone: (800) 854-7179 or
  Global Engineering Documents, 7730 Carondelet 
  Ave., Suite 470, Clayton, MO 63105; Telephone: 
  (800) 854-7179
UL 103, Sixth Ed., revised as of September 3,                60.17(f)(1)
  1986, Standard for Chimneys, Factory-built, 
  Residential Type and Building Heating Appliance.


West Coast Lumber Inspection Bureau

  6980 SW Barnes Road, Portland Oregon 97223
West Coast Lumber Standard Grading Rules, No. 16,            60.17(g)(1)
  pages 5-21, 90, and 91, September 3, 1970, 
  revised 1984.



[[Page 1199]]



                    Table of CFR Titles and Chapters




                      (Revised as of July 1, 1999)

                      Title 1--General Provisions

         I  Administrative Committee of the Federal Register 
                (Parts 1--49)
        II  Office of the Federal Register (Parts 50--299)
        IV  Miscellaneous Agencies (Parts 400--500)

                          Title 2--[Reserved]

                        Title 3--The President

         I  Executive Office of the President (Parts 100--199)

                           Title 4--Accounts

         I  General Accounting Office (Parts 1--99)
        II  Federal Claims Collection Standards (General 
                Accounting Office--Department of Justice) (Parts 
                100--299)

                   Title 5--Administrative Personnel

         I  Office of Personnel Management (Parts 1--1199)
        II  Merit Systems Protection Board (Parts 1200--1299)
       III  Office of Management and Budget (Parts 1300--1399)
        IV  Advisory Committee on Federal Pay (Parts 1400--1499)
         V  The International Organizations Employees Loyalty 
                Board (Parts 1500--1599)
        VI  Federal Retirement Thrift Investment Board (Parts 
                1600--1699)
       VII  Advisory Commission on Intergovernmental Relations 
                (Parts 1700--1799)
      VIII  Office of Special Counsel (Parts 1800--1899)
        IX  Appalachian Regional Commission (Parts 1900--1999)
        XI  Armed Forces Retirement Home (Part 2100)
       XIV  Federal Labor Relations Authority, General Counsel of 
                the Federal Labor Relations Authority and Federal 
                Service Impasses Panel (Parts 2400--2499)
        XV  Office of Administration, Executive Office of the 
                President (Parts 2500--2599)
       XVI  Office of Government Ethics (Parts 2600--2699)
       XXI  Department of the Treasury (Parts 3100--3199)

[[Page 1200]]

      XXII  Federal Deposit Insurance Corporation (Part 3201)
     XXIII  Department of Energy (Part 3301)
      XXIV  Federal Energy Regulatory Commission (Part 3401)
       XXV  Department of the Interior (Part 3501)
      XXVI  Department of Defense (Part 3601)
    XXVIII  Department of Justice (Part 3801)
      XXIX  Federal Communications Commission (Parts 3900--3999)
       XXX  Farm Credit System Insurance Corporation (Parts 4000--
                4099)
      XXXI  Farm Credit Administration (Parts 4100--4199)
    XXXIII  Overseas Private Investment Corporation (Part 4301)
      XXXV  Office of Personnel Management (Part 4501)
        XL  Interstate Commerce Commission (Part 5001)
       XLI  Commodity Futures Trading Commission (Part 5101)
      XLII  Department of Labor (Part 5201)
     XLIII  National Science Foundation (Part 5301)
       XLV  Department of Health and Human Services (Part 5501)
      XLVI  Postal Rate Commission (Part 5601)
     XLVII  Federal Trade Commission (Part 5701)
    XLVIII  Nuclear Regulatory Commission (Part 5801)
         L  Department of Transportation (Part 6001)
       LII  Export-Import Bank of the United States (Part 6201)
      LIII  Department of Education (Parts 6300--6399)
       LIV  Environmental Protection Agency (Part 6401)
      LVII  General Services Administration (Part 6701)
     LVIII  Board of Governors of the Federal Reserve System (Part 
                6801)
       LIX  National Aeronautics and Space Administration (Part 
                6901)
        LX  United States Postal Service (Part 7001)
       LXI  National Labor Relations Board (Part 7101)
      LXII  Equal Employment Opportunity Commission (Part 7201)
     LXIII  Inter-American Foundation (Part 7301)
       LXV  Department of Housing and Urban Development (Part 
                7501)
      LXVI  National Archives and Records Administration (Part 
                7601)
      LXIX  Tennessee Valley Authority (Part 7901)
      LXXI  Consumer Product Safety Commission (Part 8101)
     LXXIV  Federal Mine Safety and Health Review Commission (Part 
                8401)
     LXXVI  Federal Retirement Thrift Investment Board (Part 8601)
    LXXVII  Office of Management and Budget (Part 8701)

                          Title 6--[Reserved]

                         Title 7--Agriculture

            Subtitle A--Office of the Secretary of Agriculture 
                (Parts 0--26)
            Subtitle B--Regulations of the Department of 
                Agriculture

[[Page 1201]]

         I  Agricultural Marketing Service (Standards, 
                Inspections, Marketing Practices), Department of 
                Agriculture (Parts 27--209)
        II  Food and Nutrition Service, Department of Agriculture 
                (Parts 210--299)
       III  Animal and Plant Health Inspection Service, Department 
                of Agriculture (Parts 300--399)
        IV  Federal Crop Insurance Corporation, Department of 
                Agriculture (Parts 400--499)
         V  Agricultural Research Service, Department of 
                Agriculture (Parts 500--599)
        VI  Natural Resources Conservation Service, Department of 
                Agriculture (Parts 600--699)
       VII  Farm Service Agency, Department of Agriculture (Parts 
                700--799)
      VIII  Grain Inspection, Packers and Stockyards 
                Administration (Federal Grain Inspection Service), 
                Department of Agriculture (Parts 800--899)
        IX  Agricultural Marketing Service (Marketing Agreements 
                and Orders; Fruits, Vegetables, Nuts), Department 
                of Agriculture (Parts 900--999)
         X  Agricultural Marketing Service (Marketing Agreements 
                and Orders; Milk), Department of Agriculture 
                (Parts 1000--1199)
        XI  Agricultural Marketing Service (Marketing Agreements 
                and Orders; Miscellaneous Commodities), Department 
                of Agriculture (Parts 1200--1299)
      XIII  Northeast Dairy Compact Commission (Parts 1300--1399)
       XIV  Commodity Credit Corporation, Department of 
                Agriculture (Parts 1400--1499)
        XV  Foreign Agricultural Service, Department of 
                Agriculture (Parts 1500--1599)
       XVI  Rural Telephone Bank, Department of Agriculture (Parts 
                1600--1699)
      XVII  Rural Utilities Service, Department of Agriculture 
                (Parts 1700--1799)
     XVIII  Rural Housing Service, Rural Business-Cooperative 
                Service, Rural Utilities Service, and Farm Service 
                Agency, Department of Agriculture (Parts 1800--
                2099)
      XXVI  Office of Inspector General, Department of Agriculture 
                (Parts 2600--2699)
     XXVII  Office of Information Resources Management, Department 
                of Agriculture (Parts 2700--2799)
    XXVIII  Office of Operations, Department of Agriculture (Parts 
                2800--2899)
      XXIX  Office of Energy, Department of Agriculture (Parts 
                2900--2999)
       XXX  Office of the Chief Financial Officer, Department of 
                Agriculture (Parts 3000--3099)
      XXXI  Office of Environmental Quality, Department of 
                Agriculture (Parts 3100--3199)
     XXXII  Office of Procurement and Property Management, 
                Department of Agriculture (Parts 3200--3299)

[[Page 1202]]

    XXXIII  Office of Transportation, Department of Agriculture 
                (Parts 3300--3399)
     XXXIV  Cooperative State Research, Education, and Extension 
                Service, Department of Agriculture (Parts 3400--
                3499)
      XXXV  Rural Housing Service, Department of Agriculture 
                (Parts 3500--3599)
     XXXVI  National Agricultural Statistics Service, Department 
                of Agriculture (Parts 3600--3699)
    XXXVII  Economic Research Service, Department of Agriculture 
                (Parts 3700--3799)
   XXXVIII  World Agricultural Outlook Board, Department of 
                Agriculture (Parts 3800--3899)
       XLI  [Reserved]
      XLII  Rural Business-Cooperative Service and Rural Utilities 
                Service, Department of Agriculture (Parts 4200--
                4299)

                    Title 8--Aliens and Nationality

         I  Immigration and Naturalization Service, Department of 
                Justice (Parts 1--499)

                 Title 9--Animals and Animal Products

         I  Animal and Plant Health Inspection Service, Department 
                of Agriculture (Parts 1--199)
        II  Grain Inspection, Packers and Stockyards 
                Administration (Packers and Stockyards Programs), 
                Department of Agriculture (Parts 200--299)
       III  Food Safety and Inspection Service, Department of 
                Agriculture (Parts 300--599)

                           Title 10--Energy

         I  Nuclear Regulatory Commission (Parts 0--199)
        II  Department of Energy (Parts 200--699)
       III  Department of Energy (Parts 700--999)
         X  Department of Energy (General Provisions) (Parts 
                1000--1099)
      XVII  Defense Nuclear Facilities Safety Board (Parts 1700--
                1799)

                      Title 11--Federal Elections

         I  Federal Election Commission (Parts 1--9099)

                      Title 12--Banks and Banking

         I  Comptroller of the Currency, Department of the 
                Treasury (Parts 1--199)
        II  Federal Reserve System (Parts 200--299)
       III  Federal Deposit Insurance Corporation (Parts 300--399)

[[Page 1203]]

        IV  Export-Import Bank of the United States (Parts 400--
                499)
         V  Office of Thrift Supervision, Department of the 
                Treasury (Parts 500--599)
        VI  Farm Credit Administration (Parts 600--699)
       VII  National Credit Union Administration (Parts 700--799)
      VIII  Federal Financing Bank (Parts 800--899)
        IX  Federal Housing Finance Board (Parts 900--999)
        XI  Federal Financial Institutions Examination Council 
                (Parts 1100--1199)
       XIV  Farm Credit System Insurance Corporation (Parts 1400--
                1499)
        XV  Department of the Treasury (Parts 1500--1599)
      XVII  Office of Federal Housing Enterprise Oversight, 
                Department of Housing and Urban Development (Parts 
                1700--1799)
     XVIII  Community Development Financial Institutions Fund, 
                Department of the Treasury (Parts 1800--1899)

               Title 13--Business Credit and Assistance

         I  Small Business Administration (Parts 1--199)
       III  Economic Development Administration, Department of 
                Commerce (Parts 300--399)

                    Title 14--Aeronautics and Space

         I  Federal Aviation Administration, Department of 
                Transportation (Parts 1--199)
        II  Office of the Secretary, Department of Transportation 
                (Aviation Proceedings) (Parts 200--399)
       III  Commercial Space Transportation, Federal Aviation 
                Administration, Department of Transportation 
                (Parts 400--499)
         V  National Aeronautics and Space Administration (Parts 
                1200--1299)

                 Title 15--Commerce and Foreign Trade

            Subtitle A--Office of the Secretary of Commerce (Parts 
                0--29)
            Subtitle B--Regulations Relating to Commerce and 
                Foreign Trade
         I  Bureau of the Census, Department of Commerce (Parts 
                30--199)
        II  National Institute of Standards and Technology, 
                Department of Commerce (Parts 200--299)
       III  International Trade Administration, Department of 
                Commerce (Parts 300--399)
        IV  Foreign-Trade Zones Board, Department of Commerce 
                (Parts 400--499)
       VII  Bureau of Export Administration, Department of 
                Commerce (Parts 700--799)

[[Page 1204]]

      VIII  Bureau of Economic Analysis, Department of Commerce 
                (Parts 800--899)
        IX  National Oceanic and Atmospheric Administration, 
                Department of Commerce (Parts 900--999)
        XI  Technology Administration, Department of Commerce 
                (Parts 1100--1199)
      XIII  East-West Foreign Trade Board (Parts 1300--1399)
       XIV  Minority Business Development Agency (Parts 1400--
                1499)
            Subtitle C--Regulations Relating to Foreign Trade 
                Agreements
        XX  Office of the United States Trade Representative 
                (Parts 2000--2099)
            Subtitle D--Regulations Relating to Telecommunications 
                and Information
     XXIII  National Telecommunications and Information 
                Administration, Department of Commerce (Parts 
                2300--2399)

                    Title 16--Commercial Practices

         I  Federal Trade Commission (Parts 0--999)
        II  Consumer Product Safety Commission (Parts 1000--1799)

             Title 17--Commodity and Securities Exchanges

         I  Commodity Futures Trading Commission (Parts 1--199)
        II  Securities and Exchange Commission (Parts 200--399)
        IV  Department of the Treasury (Parts 400--499)

          Title 18--Conservation of Power and Water Resources

         I  Federal Energy Regulatory Commission, Department of 
                Energy (Parts 1--399)
       III  Delaware River Basin Commission (Parts 400--499)
        VI  Water Resources Council (Parts 700--799)
      VIII  Susquehanna River Basin Commission (Parts 800--899)
      XIII  Tennessee Valley Authority (Parts 1300--1399)

                       Title 19--Customs Duties

         I  United States Customs Service, Department of the 
                Treasury (Parts 1--199)
        II  United States International Trade Commission (Parts 
                200--299)
       III  International Trade Administration, Department of 
                Commerce (Parts 300--399)

[[Page 1205]]

                     Title 20--Employees' Benefits

         I  Office of Workers' Compensation Programs, Department 
                of Labor (Parts 1--199)
        II  Railroad Retirement Board (Parts 200--399)
       III  Social Security Administration (Parts 400--499)
        IV  Employees' Compensation Appeals Board, Department of 
                Labor (Parts 500--599)
         V  Employment and Training Administration, Department of 
                Labor (Parts 600--699)
        VI  Employment Standards Administration, Department of 
                Labor (Parts 700--799)
       VII  Benefits Review Board, Department of Labor (Parts 
                800--899)
      VIII  Joint Board for the Enrollment of Actuaries (Parts 
                900--999)
        IX  Office of the Assistant Secretary for Veterans' 
                Employment and Training, Department of Labor 
                (Parts 1000--1099)

                       Title 21--Food and Drugs

         I  Food and Drug Administration, Department of Health and 
                Human Services (Parts 1--1299)
        II  Drug Enforcement Administration, Department of Justice 
                (Parts 1300--1399)
       III  Office of National Drug Control Policy (Parts 1400--
                1499)

                      Title 22--Foreign Relations

         I  Department of State (Parts 1--199)
        II  Agency for International Development (Parts 200--299)
       III  Peace Corps (Parts 300--399)
        IV  International Joint Commission, United States and 
                Canada (Parts 400--499)
         V  United States Information Agency (Parts 500--599)
       VII  Overseas Private Investment Corporation (Parts 700--
                799)
        IX  Foreign Service Grievance Board Regulations (Parts 
                900--999)
         X  Inter-American Foundation (Parts 1000--1099)
        XI  International Boundary and Water Commission, United 
                States and Mexico, United States Section (Parts 
                1100--1199)
       XII  United States International Development Cooperation 
                Agency (Parts 1200--1299)
      XIII  Board for International Broadcasting (Parts 1300--
                1399)
       XIV  Foreign Service Labor Relations Board; Federal Labor 
                Relations Authority; General Counsel of the 
                Federal Labor Relations Authority; and the Foreign 
                Service Impasse Disputes Panel (Parts 1400--1499)
        XV  African Development Foundation (Parts 1500--1599)
       XVI  Japan-United States Friendship Commission (Parts 
                1600--1699)
      XVII  United States Institute of Peace (Parts 1700--1799)

[[Page 1206]]

                          Title 23--Highways

         I  Federal Highway Administration, Department of 
                Transportation (Parts 1--999)
        II  National Highway Traffic Safety Administration and 
                Federal Highway Administration, Department of 
                Transportation (Parts 1200--1299)
       III  National Highway Traffic Safety Administration, 
                Department of Transportation (Parts 1300--1399)

                Title 24--Housing and Urban Development

            Subtitle A--Office of the Secretary, Department of 
                Housing and Urban Development (Parts 0--99)
            Subtitle B--Regulations Relating to Housing and Urban 
                Development
         I  Office of Assistant Secretary for Equal Opportunity, 
                Department of Housing and Urban Development (Parts 
                100--199)
        II  Office of Assistant Secretary for Housing-Federal 
                Housing Commissioner, Department of Housing and 
                Urban Development (Parts 200--299)
       III  Government National Mortgage Association, Department 
                of Housing and Urban Development (Parts 300--399)
        IV  Office of Multifamily Housing Assistance 
                Restructuring, Department of Housing and Urban 
                Development (Parts 400--499)
         V  Office of Assistant Secretary for Community Planning 
                and Development, Department of Housing and Urban 
                Development (Parts 500--599)
        VI  Office of Assistant Secretary for Community Planning 
                and Development, Department of Housing and Urban 
                Development (Parts 600--699) [Reserved]
       VII  Office of the Secretary, Department of Housing and 
                Urban Development (Housing Assistance Programs and 
                Public and Indian Housing Programs) (Parts 700--
                799)
      VIII  Office of the Assistant Secretary for Housing--Federal 
                Housing Commissioner, Department of Housing and 
                Urban Development (Section 8 Housing Assistance 
                Programs, Section 202 Direct Loan Program, Section 
                202 Supportive Housing for the Elderly Program and 
                Section 811 Supportive Housing for Persons With 
                Disabilities Program) (Parts 800--899)
        IX  Office of Assistant Secretary for Public and Indian 
                Housing, Department of Housing and Urban 
                Development (Parts 900--999)
         X  Office of Assistant Secretary for Housing--Federal 
                Housing Commissioner, Department of Housing and 
                Urban Development (Interstate Land Sales 
                Registration Program) (Parts 1700--1799)
       XII  Office of Inspector General, Department of Housing and 
                Urban Development (Parts 2000--2099)
        XX  Office of Assistant Secretary for Housing--Federal 
                Housing Commissioner, Department of Housing and 
                Urban Development (Parts 3200--3899)
       XXV  Neighborhood Reinvestment Corporation (Parts 4100--
                4199)

[[Page 1207]]

                           Title 25--Indians

         I  Bureau of Indian Affairs, Department of the Interior 
                (Parts 1--299)
        II  Indian Arts and Crafts Board, Department of the 
                Interior (Parts 300--399)
       III  National Indian Gaming Commission, Department of the 
                Interior (Parts 500--599)
        IV  Office of Navajo and Hopi Indian Relocation (Parts 
                700--799)
         V  Bureau of Indian Affairs, Department of the Interior, 
                and Indian Health Service, Department of Health 
                and Human Services (Part 900)
        VI  Office of the Assistant Secretary-Indian Affairs, 
                Department of the Interior (Part 1001)
       VII  Office of the Special Trustee for American Indians, 
                Department of the Interior (Part 1200)

                      Title 26--Internal Revenue

         I  Internal Revenue Service, Department of the Treasury 
                (Parts 1--799)

           Title 27--Alcohol, Tobacco Products and Firearms

         I  Bureau of Alcohol, Tobacco and Firearms, Department of 
                the Treasury (Parts 1--299)

                   Title 28--Judicial Administration

         I  Department of Justice (Parts 0--199)
       III  Federal Prison Industries, Inc., Department of Justice 
                (Parts 300--399)
         V  Bureau of Prisons, Department of Justice (Parts 500--
                599)
        VI  Offices of Independent Counsel, Department of Justice 
                (Parts 600--699)
       VII  Office of Independent Counsel (Parts 700--799)

                            Title 29--Labor

            Subtitle A--Office of the Secretary of Labor (Parts 
                0--99)
            Subtitle B--Regulations Relating to Labor
         I  National Labor Relations Board (Parts 100--199)
        II  Office of Labor-Management Standards, Department of 
                Labor (Parts 200--299)
       III  National Railroad Adjustment Board (Parts 300--399)
        IV  Office of Labor-Management Standards, Department of 
                Labor (Parts 400--499)
         V  Wage and Hour Division, Department of Labor (Parts 
                500--899)
        IX  Construction Industry Collective Bargaining Commission 
                (Parts 900--999)
         X  National Mediation Board (Parts 1200--1299)

[[Page 1208]]

       XII  Federal Mediation and Conciliation Service (Parts 
                1400--1499)
       XIV  Equal Employment Opportunity Commission (Parts 1600--
                1699)
      XVII  Occupational Safety and Health Administration, 
                Department of Labor (Parts 1900--1999)
        XX  Occupational Safety and Health Review Commission 
                (Parts 2200--2499)
       XXV  Pension and Welfare Benefits Administration, 
                Department of Labor (Parts 2500--2599)
     XXVII  Federal Mine Safety and Health Review Commission 
                (Parts 2700--2799)
        XL  Pension Benefit Guaranty Corporation (Parts 4000--
                4999)

                      Title 30--Mineral Resources

         I  Mine Safety and Health Administration, Department of 
                Labor (Parts 1--199)
        II  Minerals Management Service, Department of the 
                Interior (Parts 200--299)
       III  Board of Surface Mining and Reclamation Appeals, 
                Department of the Interior (Parts 300--399)
        IV  Geological Survey, Department of the Interior (Parts 
                400--499)
        VI  Bureau of Mines, Department of the Interior (Parts 
                600--699)
       VII  Office of Surface Mining Reclamation and Enforcement, 
                Department of the Interior (Parts 700--999)

                 Title 31--Money and Finance: Treasury

            Subtitle A--Office of the Secretary of the Treasury 
                (Parts 0--50)
            Subtitle B--Regulations Relating to Money and Finance
         I  Monetary Offices, Department of the Treasury (Parts 
                51--199)
        II  Fiscal Service, Department of the Treasury (Parts 
                200--399)
        IV  Secret Service, Department of the Treasury (Parts 
                400--499)
         V  Office of Foreign Assets Control, Department of the 
                Treasury (Parts 500--599)
        VI  Bureau of Engraving and Printing, Department of the 
                Treasury (Parts 600--699)
       VII  Federal Law Enforcement Training Center, Department of 
                the Treasury (Parts 700--799)
      VIII  Office of International Investment, Department of the 
                Treasury (Parts 800--899)

                      Title 32--National Defense

            Subtitle A--Department of Defense
         I  Office of the Secretary of Defense (Parts 1--399)
         V  Department of the Army (Parts 400--699)
        VI  Department of the Navy (Parts 700--799)

[[Page 1209]]

       VII  Department of the Air Force (Parts 800--1099)
            Subtitle B--Other Regulations Relating to National 
                Defense
       XII  Defense Logistics Agency (Parts 1200--1299)
       XVI  Selective Service System (Parts 1600--1699)
       XIX  Central Intelligence Agency (Parts 1900--1999)
        XX  Information Security Oversight Office, National 
                Archives and Records Administration (Parts 2000--
                2099)
       XXI  National Security Council (Parts 2100--2199)
      XXIV  Office of Science and Technology Policy (Parts 2400--
                2499)
     XXVII  Office for Micronesian Status Negotiations (Parts 
                2700--2799)
    XXVIII  Office of the Vice President of the United States 
                (Parts 2800--2899)
      XXIX  Presidential Commission on the Assignment of Women in 
                the Armed Forces (Part 2900)

               Title 33--Navigation and Navigable Waters

         I  Coast Guard, Department of Transportation (Parts 1--
                199)
        II  Corps of Engineers, Department of the Army (Parts 
                200--399)
        IV  Saint Lawrence Seaway Development Corporation, 
                Department of Transportation (Parts 400--499)

                          Title 34--Education

            Subtitle A--Office of the Secretary, Department of 
                Education (Parts 1--99)
            Subtitle B--Regulations of the Offices of the 
                Department of Education
         I  Office for Civil Rights, Department of Education 
                (Parts 100--199)
        II  Office of Elementary and Secondary Education, 
                Department of Education (Parts 200--299)
       III  Office of Special Education and Rehabilitative 
                Services, Department of Education (Parts 300--399)
        IV  Office of Vocational and Adult Education, Department 
                of Education (Parts 400--499)
         V  Office of Bilingual Education and Minority Languages 
                Affairs, Department of Education (Parts 500--599)
        VI  Office of Postsecondary Education, Department of 
                Education (Parts 600--699)
       VII  Office of Educational Research and Improvement, 
                Department of Education (Parts 700--799)
        XI  National Institute for Literacy (Parts 1100--1199)
            Subtitle C--Regulations Relating to Education
       XII  National Council on Disability (Parts 1200--1299)

[[Page 1210]]

                        Title 35--Panama Canal

         I  Panama Canal Regulations (Parts 1--299)

             Title 36--Parks, Forests, and Public Property

         I  National Park Service, Department of the Interior 
                (Parts 1--199)
        II  Forest Service, Department of Agriculture (Parts 200--
                299)
       III  Corps of Engineers, Department of the Army (Parts 
                300--399)
        IV  American Battle Monuments Commission (Parts 400--499)
         V  Smithsonian Institution (Parts 500--599)
       VII  Library of Congress (Parts 700--799)
      VIII  Advisory Council on Historic Preservation (Parts 800--
                899)
        IX  Pennsylvania Avenue Development Corporation (Parts 
                900--999)
         X  Presidio Trust (Parts 1000--1099)
        XI  Architectural and Transportation Barriers Compliance 
                Board (Parts 1100--1199)
       XII  National Archives and Records Administration (Parts 
                1200--1299)
       XIV  Assassination Records Review Board (Parts 1400--1499)

             Title 37--Patents, Trademarks, and Copyrights

         I  Patent and Trademark Office, Department of Commerce 
                (Parts 1--199)
        II  Copyright Office, Library of Congress (Parts 200--299)
        IV  Assistant Secretary for Technology Policy, Department 
                of Commerce (Parts 400--499)
         V  Under Secretary for Technology, Department of Commerce 
                (Parts 500--599)

           Title 38--Pensions, Bonuses, and Veterans' Relief

         I  Department of Veterans Affairs (Parts 0--99)

                       Title 39--Postal Service

         I  United States Postal Service (Parts 1--999)
       III  Postal Rate Commission (Parts 3000--3099)

                  Title 40--Protection of Environment

         I  Environmental Protection Agency (Parts 1--799)
         V  Council on Environmental Quality (Parts 1500--1599)
       VII  Environmental Protection Agency and Department of 
                Defense; Uniform National Discharge Standards for 
                Vessels of the Armed Forces (Parts 1700--1799)

          Title 41--Public Contracts and Property Management

            Subtitle B--Other Provisions Relating to Public 
                Contracts

[[Page 1211]]

        50  Public Contracts, Department of Labor (Parts 50-1--50-
                999)
        51  Committee for Purchase From People Who Are Blind or 
                Severely Disabled (Parts 51-1--51-99)
        60  Office of Federal Contract Compliance Programs, Equal 
                Employment Opportunity, Department of Labor (Parts 
                60-1--60-999)
        61  Office of the Assistant Secretary for Veterans 
                Employment and Training, Department of Labor 
                (Parts 61-1--61-999)
            Subtitle C--Federal Property Management Regulations 
                System
       101  Federal Property Management Regulations (Parts 101-1--
                101-99)
       105  General Services Administration (Parts 105-1--105-999)
       109  Department of Energy Property Management Regulations 
                (Parts 109-1--109-99)
       114  Department of the Interior (Parts 114-1--114-99)
       115  Environmental Protection Agency (Parts 115-1--115-99)
       128  Department of Justice (Parts 128-1--128-99)
            Subtitle D--Other Provisions Relating to Property 
                Management [Reserved]
            Subtitle E--Federal Information Resources Management 
                Regulations System
       201  Federal Information Resources Management Regulation 
                (Parts 201-1--201-99) [Reserved]
            Subtitle F--Federal Travel Regulation System
       300  General (Parts 300-1--300.99)
       301  Temporary Duty (TDY) Travel Allowances (Parts 301-1--
                301-99)
       302  Relocation Allowances (Parts 302-1--302-99)
       303  Payment of Expenses Connected with the Death of 
                Certain Employees (Parts 303-1--303-2)
       304  Payment from a Non-Federal Source for Travel Expenses 
                (Parts 304-1--304-99)

                        Title 42--Public Health

         I  Public Health Service, Department of Health and Human 
                Services (Parts 1--199)
        IV  Health Care Financing Administration, Department of 
                Health and Human Services (Parts 400--499)
         V  Office of Inspector General-Health Care, Department of 
                Health and Human Services (Parts 1000--1999)

                   Title 43--Public Lands: Interior

            Subtitle A--Office of the Secretary of the Interior 
                (Parts 1--199)
            Subtitle B--Regulations Relating to Public Lands
         I  Bureau of Reclamation, Department of the Interior 
                (Parts 200--499)
        II  Bureau of Land Management, Department of the Interior 
                (Parts 1000--9999)

[[Page 1212]]

       III  Utah Reclamation Mitigation and Conservation 
                Commission (Parts 10000--10005)

             Title 44--Emergency Management and Assistance

         I  Federal Emergency Management Agency (Parts 0--399)
        IV  Department of Commerce and Department of 
                Transportation (Parts 400--499)

                       Title 45--Public Welfare

            Subtitle A--Department of Health and Human Services 
                (Parts 1--199)
            Subtitle B--Regulations Relating to Public Welfare
        II  Office of Family Assistance (Assistance Programs), 
                Administration for Children and Families, 
                Department of Health and Human Services (Parts 
                200--299)
       III  Office of Child Support Enforcement (Child Support 
                Enforcement Program), Administration for Children 
                and Families, Department of Health and Human 
                Services (Parts 300--399)
        IV  Office of Refugee Resettlement, Administration for 
                Children and Families Department of Health and 
                Human Services (Parts 400--499)
         V  Foreign Claims Settlement Commission of the United 
                States, Department of Justice (Parts 500--599)
        VI  National Science Foundation (Parts 600--699)
       VII  Commission on Civil Rights (Parts 700--799)
      VIII  Office of Personnel Management (Parts 800--899)
         X  Office of Community Services, Administration for 
                Children and Families, Department of Health and 
                Human Services (Parts 1000--1099)
        XI  National Foundation on the Arts and the Humanities 
                (Parts 1100--1199)
       XII  Corporation for National and Community Service (Parts 
                1200--1299)
      XIII  Office of Human Development Services, Department of 
                Health and Human Services (Parts 1300--1399)
       XVI  Legal Services Corporation (Parts 1600--1699)
      XVII  National Commission on Libraries and Information 
                Science (Parts 1700--1799)
     XVIII  Harry S. Truman Scholarship Foundation (Parts 1800--
                1899)
       XXI  Commission on Fine Arts (Parts 2100--2199)
      XXII  Christopher Columbus Quincentenary Jubilee Commission 
                (Parts 2200--2299)
     XXIII  Arctic Research Commission (Part 2301)
      XXIV  James Madison Memorial Fellowship Foundation (Parts 
                2400--2499)
       XXV  Corporation for National and Community Service (Parts 
                2500--2599)

[[Page 1213]]

                          Title 46--Shipping

         I  Coast Guard, Department of Transportation (Parts 1--
                199)
        II  Maritime Administration, Department of Transportation 
                (Parts 200--399)
       III  Coast Guard (Great Lakes Pilotage), Department of 
                Transportation (Parts 400--499)
        IV  Federal Maritime Commission (Parts 500--599)

                      Title 47--Telecommunication

         I  Federal Communications Commission (Parts 0--199)
        II  Office of Science and Technology Policy and National 
                Security Council (Parts 200--299)
       III  National Telecommunications and Information 
                Administration, Department of Commerce (Parts 
                300--399)

           Title 48--Federal Acquisition Regulations System

         1  Federal Acquisition Regulation (Parts 1--99)
         2  Department of Defense (Parts 200--299)
         3  Department of Health and Human Services (Parts 300--
                399)
         4  Department of Agriculture (Parts 400--499)
         5  General Services Administration (Parts 500--599)
         6  Department of State (Parts 600--699)
         7  United States Agency for International Development 
                (Parts 700--799)
         8  Department of Veterans Affairs (Parts 800--899)
         9  Department of Energy (Parts 900--999)
        10  Department of the Treasury (Parts 1000--1099)
        12  Department of Transportation (Parts 1200--1299)
        13  Department of Commerce (Parts 1300--1399)
        14  Department of the Interior (Parts 1400--1499)
        15  Environmental Protection Agency (Parts 1500--1599)
        16  Office of Personnel Management Federal Employees 
                Health Benefits Acquisition Regulation (Parts 
                1600--1699)
        17  Office of Personnel Management (Parts 1700--1799)
        18  National Aeronautics and Space Administration (Parts 
                1800--1899)
        19  United States Information Agency (Parts 1900--1999)
        20  Nuclear Regulatory Commission (Parts 2000--2099)
        21  Office of Personnel Management, Federal Employees 
                Group Life Insurance Federal Acquisition 
                Regulation (Parts 2100--2199)
        23  Social Security Administration (Parts 2300--2399)
        24  Department of Housing and Urban Development (Parts 
                2400--2499)
        25  National Science Foundation (Parts 2500--2599)
        28  Department of Justice (Parts 2800--2899)
        29  Department of Labor (Parts 2900--2999)

[[Page 1214]]

        34  Department of Education Acquisition Regulation (Parts 
                3400--3499)
        35  Panama Canal Commission (Parts 3500--3599)
        44  Federal Emergency Management Agency (Parts 4400--4499)
        51  Department of the Army Acquisition Regulations (Parts 
                5100--5199)
        52  Department of the Navy Acquisition Regulations (Parts 
                5200--5299)
        53  Department of the Air Force Federal Acquisition 
                Regulation Supplement (Parts 5300--5399)
        54  Defense Logistics Agency, Department of Defense (Part 
                5452)
        57  African Development Foundation (Parts 5700--5799)
        61  General Services Administration Board of Contract 
                Appeals (Parts 6100--6199)
        63  Department of Transportation Board of Contract Appeals 
                (Parts 6300--6399)
        99  Cost Accounting Standards Board, Office of Federal 
                Procurement Policy, Office of Management and 
                Budget (Parts 9900--9999)

                       Title 49--Transportation

            Subtitle A--Office of the Secretary of Transportation 
                (Parts 1--99)
            Subtitle B--Other Regulations Relating to 
                Transportation
         I  Research and Special Programs Administration, 
                Department of Transportation (Parts 100--199)
        II  Federal Railroad Administration, Department of 
                Transportation (Parts 200--299)
       III  Federal Highway Administration, Department of 
                Transportation (Parts 300--399)
        IV  Coast Guard, Department of Transportation (Parts 400--
                499)
         V  National Highway Traffic Safety Administration, 
                Department of Transportation (Parts 500--599)
        VI  Federal Transit Administration, Department of 
                Transportation (Parts 600--699)
       VII  National Railroad Passenger Corporation (AMTRAK) 
                (Parts 700--799)
      VIII  National Transportation Safety Board (Parts 800--999)
         X  Surface Transportation Board, Department of 
                Transportation (Parts 1000--1399)
        XI  Bureau of Transportation Statistics, Department of 
                Transportation (Parts 1400--1499)

                   Title 50--Wildlife and Fisheries

         I  United States Fish and Wildlife Service, Department of 
                the Interior (Parts 1--199)

[[Page 1215]]

        II  National Marine Fisheries Service, National Oceanic 
                and Atmospheric Administration, Department of 
                Commerce (Parts 200--299)
       III  International Fishing and Related Activities (Parts 
                300--399)
        IV  Joint Regulations (United States Fish and Wildlife 
                Service, Department of the Interior and National 
                Marine Fisheries Service, National Oceanic and 
                Atmospheric Administration, Department of 
                Commerce); Endangered Species Committee 
                Regulations (Parts 400--499)
         V  Marine Mammal Commission (Parts 500--599)
        VI  Fishery Conservation and Management, National Oceanic 
                and Atmospheric Administration, Department of 
                Commerce (Parts 600--699)

                      CFR Index and Finding Aids

            Subject/Agency Index
            List of Agency Prepared Indexes
            Parallel Tables of Statutory Authorities and Rules
            List of CFR Titles, Chapters, Subchapters, and Parts
            Alphabetical List of Agencies Appearing in the CFR



[[Page 1217]]





           Alphabetical List of Agencies Appearing in the CFR




                      (Revised as of July 1, 1999)

                                                  CFR Title, Subtitle or 
                     Agency                               Chapter

Administrative Committee of the Federal Register  1, I
Advanced Research Projects Agency                 32, I
Advisory Commission on Intergovernmental          5, VII
     Relations
Advisory Committee on Federal Pay                 5, IV
Advisory Council on Historic Preservation         36, VIII
African Development Foundation                    22, XV
  Federal Acquisition Regulation                  48, 57
Agency for International Development, United      22, II
     States
  Federal Acquisition Regulation                  48, 7
Agricultural Marketing Service                    7, I, IX, X, XI
Agricultural Research Service                     7, V
Agriculture Department
  Agricultural Marketing Service                  7, I, IX, X, XI
  Agricultural Research Service                   7, V
  Animal and Plant Health Inspection Service      7, III; 9, I
  Chief Financial Officer, Office of              7, XXX
  Commodity Credit Corporation                    7, XIV
  Cooperative State Research, Education, and      7, XXXIV
       Extension Service
  Economic Research Service                       7, XXXVII
  Energy, Office of                               7, XXIX
  Environmental Quality, Office of                7, XXXI
  Farm Service Agency                             7, VII, XVIII
  Federal Acquisition Regulation                  48, 4
  Federal Crop Insurance Corporation              7, IV
  Food and Nutrition Service                      7, II
  Food Safety and Inspection Service              9, III
  Foreign Agricultural Service                    7, XV
  Forest Service                                  36, II
  Grain Inspection, Packers and Stockyards        7, VIII; 9, II
       Administration
  Information Resources Management, Office of     7, XXVII
  Inspector General, Office of                    7, XXVI
  National Agricultural Library                   7, XLI
  National Agricultural Statistics Service        7, XXXVI
  Natural Resources Conservation Service          7, VI
  Operations, Office of                           7, XXVIII
  Procurement and Property Management, Office of  7, XXXII
  Rural Business-Cooperative Service              7, XVIII, XLII
  Rural Development Administration                7, XLII
  Rural Housing Service                           7, XVIII, XXXV
  Rural Telephone Bank                            7, XVI
  Rural Utilities Service                         7, XVII, XVIII, XLII
  Secretary of Agriculture, Office of             7, Subtitle A
  Transportation, Office of                       7, XXXIII
  World Agricultural Outlook Board                7, XXXVIII
Air Force Department                              32, VII
  Federal Acquisition Regulation Supplement       48, 53
Alcohol, Tobacco and Firearms, Bureau of          27, I
AMTRAK                                            49, VII
American Battle Monuments Commission              36, IV
American Indians, Office of the Special Trustee   25, VII
Animal and Plant Health Inspection Service        7, III; 9, I
Appalachian Regional Commission                   5, IX

[[Page 1218]]

Architectural and Transportation Barriers         36, XI
     Compliance Board
Arctic Research Commission                        45, XXIII
Armed Forces Retirement Home                      5, XI
Army Department                                   32, V
  Engineers, Corps of                             33, II; 36, III
  Federal Acquisition Regulation                  48, 51
Assassination Records Review Board                36, XIV
Benefits Review Board                             20, VII
Bilingual Education and Minority Languages        34, V
     Affairs, Office of
Blind or Severely Disabled, Committee for         41, 51
     Purchase From People Who Are
Board for International Broadcasting              22, XIII
Census Bureau                                     15, I
Central Intelligence Agency                       32, XIX
Chief Financial Officer, Office of                7, XXX
Child Support Enforcement, Office of              45, III
Children and Families, Administration for         45, II, III, IV, X
Christopher Columbus Quincentenary Jubilee        45, XXII
     Commission
Civil Rights, Commission on                       45, VII
Civil Rights, Office for                          34, I
Coast Guard                                       33, I; 46, I; 49, IV
Coast Guard (Great Lakes Pilotage)                46, III
Commerce Department                               44, IV
  Census Bureau                                   15, I
  Economic Affairs, Under Secretary               37, V
  Economic Analysis, Bureau of                    15, VIII
  Economic Development Administration             13, III
  Emergency Management and Assistance             44, IV
  Export Administration, Bureau of                15, VII
  Federal Acquisition Regulation                  48, 13
  Fishery Conservation and Management             50, VI
  Foreign-Trade Zones Board                       15, IV
  International Trade Administration              15, III; 19, III
  National Institute of Standards and Technology  15, II
  National Marine Fisheries Service               50, II, IV, VI
  National Oceanic and Atmospheric                15, IX; 50, II, III, IV, 
       Administration                             VI
  National Telecommunications and Information     15, XXIII; 47, III
       Administration
  National Weather Service                        15, IX
  Patent and Trademark Office                     37, I
  Productivity, Technology and Innovation,        37, IV
       Assistant Secretary for
  Secretary of Commerce, Office of                15, Subtitle A
  Technology, Under Secretary for                 37, V
  Technology Administration                       15, XI
  Technology Policy, Assistant Secretary for      37, IV
Commercial Space Transportation                   14, III
Commodity Credit Corporation                      7, XIV
Commodity Futures Trading Commission              5, XLI; 17, I
Community Planning and Development, Office of     24, V, VI
     Assistant Secretary for
Community Services, Office of                     45, X
Comptroller of the Currency                       12, I
Construction Industry Collective Bargaining       29, IX
     Commission
Consumer Product Safety Commission                5, LXXI; 16, II
Cooperative State Research, Education, and        7, XXXIV
     Extension Service
Copyright Office                                  37, II
Corporation for National and Community Service    45, XII, XXV
Cost Accounting Standards Board                   48, 99
Council on Environmental Quality                  40, V
Customs Service, United States                    19, I
Defense Contract Audit Agency                     32, I
Defense Department                                5, XXVI; 32, Subtitle A; 
                                                  40, VII
  Advanced Research Projects Agency               32, I
  Air Force Department                            32, VII

[[Page 1219]]

  Army Department                                 32, V; 33, II; 36, III, 
                                                  48, 51
  Defense Intelligence Agency                     32, I
  Defense Logistics Agency                        32, I, XII; 48, 54
  Engineers, Corps of                             33, II; 36, III
  Federal Acquisition Regulation                  48, 2
  National Imagery and Mapping Agency             32, I
  Navy Department                                 32, VI; 48, 52
  Secretary of Defense, Office of                 32, I
Defense Contract Audit Agency                     32, I
Defense Intelligence Agency                       32, I
Defense Logistics Agency                          32, XII; 48, 54
Defense Nuclear Facilities Safety Board           10, XVII
Delaware River Basin Commission                   18, III
Drug Enforcement Administration                   21, II
East-West Foreign Trade Board                     15, XIII
Economic Affairs, Under Secretary                 37, V
Economic Analysis, Bureau of                      15, VIII
Economic Development Administration               13, III
Economic Research Service                         7, XXXVII
Education, Department of                          5, LIII
  Bilingual Education and Minority Languages      34, V
       Affairs, Office of
  Civil Rights, Office for                        34, I
  Educational Research and Improvement, Office    34, VII
       of
  Elementary and Secondary Education, Office of   34, II
  Federal Acquisition Regulation                  48, 34
  Postsecondary Education, Office of              34, VI
  Secretary of Education, Office of               34, Subtitle A
  Special Education and Rehabilitative Services,  34, III
       Office of
  Vocational and Adult Education, Office of       34, IV
Educational Research and Improvement, Office of   34, VII
Elementary and Secondary Education, Office of     34, II
Employees' Compensation Appeals Board             20, IV
Employees Loyalty Board                           5, V
Employment and Training Administration            20, V
Employment Standards Administration               20, VI
Endangered Species Committee                      50, IV
Energy, Department of                             5, XXIII; 10, II, III, X
  Federal Acquisition Regulation                  48, 9
  Federal Energy Regulatory Commission            5, XXIV; 18, I
  Property Management Regulations                 41, 109
Energy, Office of                                 7, XXIX
Engineers, Corps of                               33, II; 36, III
Engraving and Printing, Bureau of                 31, VI
Environmental Protection Agency                   5, LIV; 40, I, VII
  Federal Acquisition Regulation                  48, 15
  Property Management Regulations                 41, 115
Environmental Quality, Office of                  7, XXXI
Equal Employment Opportunity Commission           5, LXII; 29, XIV
Equal Opportunity, Office of Assistant Secretary  24, I
     for
Executive Office of the President                 3, I
  Administration, Office of                       5, XV
  Environmental Quality, Council on               40, V
  Management and Budget, Office of                25, III, LXXVII; 48, 99
  National Drug Control Policy, Office of         21, III
  National Security Council                       32, XXI; 47, 2
  Presidential Documents                          3
  Science and Technology Policy, Office of        32, XXIV; 47, II
  Trade Representative, Office of the United      15, XX
       States
Export Administration, Bureau of                  15, VII
Export-Import Bank of the United States           5, LII; 12, IV
Family Assistance, Office of                      45, II
Farm Credit Administration                        5, XXXI; 12, VI
Farm Credit System Insurance Corporation          5, XXX; 12, XIV
Farm Service Agency                               7, VII, XVIII
Federal Acquisition Regulation                    48, 1

[[Page 1220]]

Federal Aviation Administration                   14, I
  Commercial Space Transportation                 14, III
Federal Claims Collection Standards               4, II
Federal Communications Commission                 5, XXIX; 47, I
Federal Contract Compliance Programs, Office of   41, 60
Federal Crop Insurance Corporation                7, IV
Federal Deposit Insurance Corporation             5, XXII; 12, III
Federal Election Commission                       11, I
Federal Emergency Management Agency               44, I
  Federal Acquisition Regulation                  48, 44
Federal Employees Group Life Insurance Federal    48, 21
     Acquisition Regulation
Federal Employees Health Benefits Acquisition     48, 16
     Regulation
Federal Energy Regulatory Commission              5, XXIV; 18, I
Federal Financial Institutions Examination        12, XI
     Council
Federal Financing Bank                            12, VIII
Federal Highway Administration                    23, I, II; 49, III
Federal Home Loan Mortgage Corporation            1, IV
Federal Housing Enterprise Oversight Office       12, XVII
Federal Housing Finance Board                     12, IX
Federal Labor Relations Authority, and General    5, XIV; 22, XIV
     Counsel of the Federal Labor Relations 
     Authority
Federal Law Enforcement Training Center           31, VII
Federal Maritime Commission                       46, IV
Federal Mediation and Conciliation Service        29, XII
Federal Mine Safety and Health Review Commission  5, LXXIV; 29, XXVII
Federal Pay, Advisory Committee on                5, IV
Federal Prison Industries, Inc.                   28, III
Federal Procurement Policy Office                 48, 99
Federal Property Management Regulations           41, 101
Federal Property Management Regulations System    41, Subtitle C
Federal Railroad Administration                   49, II
Federal Register, Administrative Committee of     1, I
Federal Register, Office of                       1, II
Federal Reserve System                            12, II
  Board of Governors                              5, LVIII
Federal Retirement Thrift Investment Board        5, VI, LXXVI
Federal Service Impasses Panel                    5, XIV
Federal Trade Commission                          5, XLVII; 16, I
Federal Transit Administration                    49, VI
Federal Travel Regulation System                  41, Subtitle F
Fine Arts, Commission on                          45, XXI
Fiscal Service                                    31, II
Fish and Wildlife Service, United States          50, I, IV
Fishery Conservation and Management               50, VI
Food and Drug Administration                      21, I
Food and Nutrition Service                        7, II
Food Safety and Inspection Service                9, III
Foreign Agricultural Service                      7, XV
Foreign Assets Control, Office of                 31, V
Foreign Claims Settlement Commission of the       45, V
     United States
Foreign Service Grievance Board                   22, IX
Foreign Service Impasse Disputes Panel            22, XIV
Foreign Service Labor Relations Board             22, XIV
Foreign-Trade Zones Board                         15, IV
Forest Service                                    36, II
General Accounting Office                         4, I, II
General Services Administration                   5, LVII
  Contract Appeals, Board of                      48, 61
  Federal Acquisition Regulation                  48, 5
  Federal Property Management Regulations System  41, 101, 105
  Federal Travel Regulation System                41, Subtitle F
  General                                         41, 300
  Payment From a Non-Federal Source for Travel    41, 304
       Expenses
  Payment of Expenses Connected With the Death    41, 303
       of Certain Employees
  Relocation Allowances                           41, 302

[[Page 1221]]

  Temporary Duty (TDY) Travel Allowances          41, 301
Geological Survey                                 30, IV
Government Ethics, Office of                      5, XVI
Government National Mortgage Association          24, III
Grain Inspection, Packers and Stockyards          7, VIII; 9, II
     Administration
Harry S. Truman Scholarship Foundation            45, XVIII
Health and Human Services, Department of          5, XLV; 45, Subtitle A
  Child Support Enforcement, Office of            45, III
  Children and Families, Administration for       45, II, III, IV, X
  Community Services, Office of                   45, X
  Family Assistance, Office of                    45, II
  Federal Acquisition Regulation                  48, 3
  Food and Drug Administration                    21, I
  Health Care Financing Administration            42, IV
  Human Development Services, Office of           45, XIII
  Indian Health Service                           25, V
  Inspector General (Health Care), Office of      42, V
  Public Health Service                           42, I
  Refugee Resettlement, Office of                 45, IV
Health Care Financing Administration              42, IV
Housing and Urban Development, Department of      5, LXV; 24, Subtitle B
  Community Planning and Development, Office of   24, V, VI
       Assistant Secretary for
  Equal Opportunity, Office of Assistant          24, I
       Secretary for
  Federal Acquisition Regulation                  48, 24
  Federal Housing Enterprise Oversight, Office    12, XVII
       of
  Government National Mortgage Association        24, III
  Housing--Federal Housing Commissioner, Office   24, II, VIII, X, XX
       of Assistant Secretary for
  Inspector General, Office of                    24, XII
  Multifamily Housing Assistance Restructuring,   24, IV
       Office of
  Public and Indian Housing, Office of Assistant  24, IX
       Secretary for
  Secretary, Office of                            24, Subtitle A, VII
Housing--Federal Housing Commissioner, Office of  24, II, VIII, X, XX
     Assistant Secretary for
Human Development Services, Office of             45, XIII
Immigration and Naturalization Service            8, I
Independent Counsel, Office of                    28, VII
Indian Affairs, Bureau of                         25, I, V
Indian Affairs, Office of the Assistant           25, VI
     Secretary
Indian Arts and Crafts Board                      25, II
Indian Health Service                             25, V
Information Agency, United States                 22, V
  Federal Acquisition Regulation                  48, 19
Information Resources Management, Office of       7, XXVII
Information Security Oversight Office, National   32, XX
     Archives and Records Administration
Inspector General
  Agriculture Department                          7, XXVI
  Health and Human Services Department            42, V
  Housing and Urban Development Department        24, XII
Institute of Peace, United States                 22, XVII
Inter-American Foundation                         5, LXIII; 22, X
Intergovernmental Relations, Advisory Commission  5, VII
     on
Interior Department
  American Indians, Office of the Special         25, VII
       Trustee
  Endangered Species Committee                    50, IV
  Federal Acquisition Regulation                  48, 14
  Federal Property Management Regulations System  41, 114
  Fish and Wildlife Service, United States        50, I, IV
  Geological Survey                               30, IV
  Indian Affairs, Bureau of                       25, I, V
  Indian Affairs, Office of the Assistant         25, VI
       Secretary
  Indian Arts and Crafts Board                    25, II
  Land Management, Bureau of                      43, II
  Minerals Management Service                     30, II
  Mines, Bureau of                                30, VI

[[Page 1222]]

  National Indian Gaming Commission               25, III
  National Park Service                           36, I
  Reclamation, Bureau of                          43, I
  Secretary of the Interior, Office of            43, Subtitle A
  Surface Mining and Reclamation Appeals, Board   30, III
       of
  Surface Mining Reclamation and Enforcement,     30, VII
       Office of
Internal Revenue Service                          26, I
International Boundary and Water Commission,      22, XI
     United States and Mexico, United States 
     Section
International Development, United States Agency   22, II
     for
  Federal Acquisition Regulation                  48, 7
International Development Cooperation Agency,     22, XII
     United States
  International Development, United States        22, II; 48, 7
       Agency for
  Overseas Private Investment Corporation         5, XXXIII; 22, VII
International Fishing and Related Activities      50, III
International Investment, Office of               31, VIII
International Joint Commission, United States     22, IV
     and Canada
International Organizations Employees Loyalty     5, V
     Board
International Trade Administration                15, III; 19, III
International Trade Commission, United States     19, II
Interstate Commerce Commission                    5, XL
James Madison Memorial Fellowship Foundation      45, XXIV
Japan-United States Friendship Commission         22, XVI
Joint Board for the Enrollment of Actuaries       20, VIII
Justice Department                                5, XXVIII; 28, I
  Drug Enforcement Administration                 21, II
  Federal Acquisition Regulation                  48, 28
  Federal Claims Collection Standards             4, II
  Federal Prison Industries, Inc.                 28, III
  Foreign Claims Settlement Commission of the     45, V
       United States
  Immigration and Naturalization Service          8, I
  Offices of Independent Counsel                  28, VI
  Prisons, Bureau of                              28, V
  Property Management Regulations                 41, 128
Labor Department                                  5, XLII
  Benefits Review Board                           20, VII
  Employees' Compensation Appeals Board           20, IV
  Employment and Training Administration          20, V
  Employment Standards Administration             20, VI
  Federal Acquisition Regulation                  48, 29
  Federal Contract Compliance Programs, Office    41, 60
       of
  Federal Procurement Regulations System          41, 50
  Labor-Management Standards, Office of           29, II, IV
  Mine Safety and Health Administration           30, I
  Occupational Safety and Health Administration   29, XVII
  Pension and Welfare Benefits Administration     29, XXV
  Public Contracts                                41, 50
  Secretary of Labor, Office of                   29, Subtitle A
  Veterans' Employment and Training, Office of    41, 61; 20, IX
       the Assistant Secretary for
  Wage and Hour Division                          29, V
  Workers' Compensation Programs, Office of       20, I
Labor-Management Standards, Office of             29, II, IV
Land Management, Bureau of                        43, II
Legal Services Corporation                        45, XVI
Library of Congress                               36, VII
  Copyright Office                                37, II
Management and Budget, Office of                  5, III, LXXVII; 48, 99
Marine Mammal Commission                          50, V
Maritime Administration                           46, II
Merit Systems Protection Board                    5, II
Micronesian Status Negotiations, Office for       32, XXVII
Mine Safety and Health Administration             30, I
Minerals Management Service                       30, II
Mines, Bureau of                                  30, VI

[[Page 1223]]

Minority Business Development Agency              15, XIV
Miscellaneous Agencies                            1, IV
Monetary Offices                                  31, I
Multifamily Housing Assistance Restructuring,     24, IV
     Office of
National Aeronautics and Space Administration     5, LIX; 14, V
  Federal Acquisition Regulation                  48, 18
National Agricultural Library                     7, XLI
National Agricultural Statistics Service          7, XXXVI
National Archives and Records Administration      5, LXVI; 36, XII
  Information Security Oversight Office           32, XX
National Bureau of Standards                      15, II
National Capital Planning Commission              1, IV
National Commission for Employment Policy         1, IV
National Commission on Libraries and Information  45, XVII
     Science
National and Community Service, Corporation for   45, XII, XXV
National Council on Disability                    34, XII
National Credit Union Administration              12, VII
National Drug Control Policy, Office of           21, III
National Foundation on the Arts and the           45, XI
     Humanities
National Highway Traffic Safety Administration    23, II, III; 49, V
National Imagery and Mapping Agency               32, I
National Indian Gaming Commission                 25, III
National Institute for Literacy                   34, XI
National Institute of Standards and Technology    15, II
National Labor Relations Board                    5, LXI; 29, I
National Marine Fisheries Service                 50, II, IV, VI
National Mediation Board                          29, X
National Oceanic and Atmospheric Administration   15, IX; 50, II, III, IV, 
                                                  VI
National Park Service                             36, I
National Railroad Adjustment Board                29, III
National Railroad Passenger Corporation (AMTRAK)  49, VII
National Science Foundation                       5, XLIII; 45, VI
  Federal Acquisition Regulation                  48, 25
National Security Council                         32, XXI
National Security Council and Office of Science   47, II
     and Technology Policy
National Telecommunications and Information       15, XXIII; 47, III
     Administration
National Transportation Safety Board              49, VIII
National Weather Service                          15, IX
Natural Resources Conservation Service            7, VI
Navajo and Hopi Indian Relocation, Office of      25, IV
Navy Department                                   32, VI
  Federal Acquisition Regulation                  48, 52
Neighborhood Reinvestment Corporation             24, XXV
Northeast Dairy Compact Commission                7, XIII
Nuclear Regulatory Commission                     5, XLVIII; 10, I
  Federal Acquisition Regulation                  48, 20
Occupational Safety and Health Administration     29, XVII
Occupational Safety and Health Review Commission  29, XX
Offices of Independent Counsel                    28, VI
Operations Office                                 7, XXVIII
Overseas Private Investment Corporation           5, XXXIII; 22, VII
Panama Canal Commission                           48, 35
Panama Canal Regulations                          35, I
Patent and Trademark Office                       37, I
Payment From a Non-Federal Source for Travel      41, 304
     Expenses
Payment of Expenses Connected With the Death of   41, 303
     Certain Employees
Peace Corps                                       22, III
Pennsylvania Avenue Development Corporation       36, IX
Pension and Welfare Benefits Administration       29, XXV
Pension Benefit Guaranty Corporation              29, XL
Personnel Management, Office of                   5, I, XXXV; 45, VIII
  Federal Acquisition Regulation                  48, 17
  Federal Employees Group Life Insurance Federal  48, 21
     Acquisition Regulation
[[Page 1224]]

  Federal Employees Health Benefits Acquisition   48, 16
       Regulation
Postal Rate Commission                            5, XLVI; 39, III
Postal Service, United States                     5, LX; 39, I
Postsecondary Education, Office of                34, VI
President's Commission on White House             1, IV
     Fellowships
Presidential Commission on the Assignment of      32, XXIX
     Women in the Armed Forces
Presidential Documents                            3
Presidio Trust                                    36, X
Prisons, Bureau of                                28, V
Procurement and Property Management, Office of    7, XXXII
Productivity, Technology and Innovation,          37, IV
     Assistant Secretary
Public Contracts, Department of Labor             41, 50
Public and Indian Housing, Office of Assistant    24, IX
     Secretary for
Public Health Service                             42, I
Railroad Retirement Board                         20, II
Reclamation, Bureau of                            43, I
Refugee Resettlement, Office of                   45, IV
Regional Action Planning Commissions              13, V
Relocation Allowances                             41, 302
Research and Special Programs Administration      49, I
Rural Business-Cooperative Service                7, XVIII, XLII
Rural Development Administration                  7, XLII
Rural Housing Service                             7, XVIII, XXXV
Rural Telephone Bank                              7, XVI
Rural Utilities Service                           7, XVII, XVIII, XLII
Saint Lawrence Seaway Development Corporation     33, IV
Science and Technology Policy, Office of          32, XXIV
Science and Technology Policy, Office of, and     47, II
     National Security Council
Secret Service                                    31, IV
Securities and Exchange Commission                17, II
Selective Service System                          32, XVI
Small Business Administration                     13, I
Smithsonian Institution                           36, V
Social Security Administration                    20, III; 48, 23
Soldiers' and Airmen's Home, United States        5, XI
Special Counsel, Office of                        5, VIII
Special Education and Rehabilitative Services,    34, III
     Office of
State Department                                  22, I
  Federal Acquisition Regulation                  48, 6
Surface Mining and Reclamation Appeals, Board of  30, III
Surface Mining Reclamation and Enforcement,       30, VII
     Office of
Surface Transportation Board                      49, X
Susquehanna River Basin Commission                18, VIII
Technology Administration                         15, XI
Technology Policy, Assistant Secretary for        37, IV
Technology, Under Secretary for                   37, V
Tennessee Valley Authority                        5, LXIX; 18, XIII
Thrift Supervision Office, Department of the      12, V
     Treasury
Trade Representative, United States, Office of    15, XX
Transportation, Department of                     5, L
  Coast Guard                                     33, I; 46, I; 49, IV
  Coast Guard (Great Lakes Pilotage)              46, III
  Commercial Space Transportation                 14, III
  Contract Appeals, Board of                      48, 63
  Emergency Management and Assistance             44, IV
  Federal Acquisition Regulation                  48, 12
  Federal Aviation Administration                 14, I
  Federal Highway Administration                  23, I, II; 49, III
  Federal Railroad Administration                 49, II
  Federal Transit Administration                  49, VI
  Maritime Administration                         46, II
  National Highway Traffic Safety Administration  23, II, III; 49, V
  Research and Special Programs Administration    49, I
  Saint Lawrence Seaway Development Corporation   33, IV

[[Page 1225]]

  Secretary of Transportation, Office of          14, II; 49, Subtitle A
  Surface Transportation Board                    49, X
  Transportation Statistics Bureau                49, XI
Transportation, Office of                         7, XXXIII
Transportation Statistics Brureau                 49, XI
Travel Allowances, Temporary Duty (TDY)           41, 301
Treasury Department                               5, XXI; 12, XV; 17, IV
  Alcohol, Tobacco and Firearms, Bureau of        27, I
  Community Development Financial Institutions    12, XVIII
       Fund
  Comptroller of the Currency                     12, I
  Customs Service, United States                  19, I
  Engraving and Printing, Bureau of               31, VI
  Federal Acquisition Regulation                  48, 10
  Federal Law Enforcement Training Center         31, VII
  Fiscal Service                                  31, II
  Foreign Assets Control, Office of               31, V
  Internal Revenue Service                        26, I
  International Investment, Office of             31, VIII
  Monetary Offices                                31, I
  Secret Service                                  31, IV
  Secretary of the Treasury, Office of            31, Subtitle A
  Thrift Supervision, Office of                   12, V
Truman, Harry S. Scholarship Foundation           45, XVIII
United States and Canada, International Joint     22, IV
     Commission
United States and Mexico, International Boundary  22, XI
     and Water Commission, United States Section
Utah Reclamation Mitigation and Conservation      43, III
     Commission
Veterans Affairs Department                       38, I
  Federal Acquisition Regulation                  48, 8
Veterans' Employment and Training, Office of the  41, 61; 20, IX
     Assistant Secretary for
Vice President of the United States, Office of    32, XXVIII
Vocational and Adult Education, Office of         34, IV
Wage and Hour Division                            29, V
Water Resources Council                           18, VI
Workers' Compensation Programs, Office of         20, I
World Agricultural Outlook Board                  7, XXXVIII

[[Page 1227]]



List of CFR Sections Affected




All changes in this volume of the Code of Federal Regulations which were 
made by documents published in the Federal Register since January 1, 
1986, are enumerated in the following list. Entries indicate the nature 
of the changes effected. Page numbers refer to Federal Register pages. 
The user should consult the entries for chapters and parts as well as 
sections for revisions.
For the period before January 1, 1986, see the ``List of CFR Sections 
Affected, 1949-1963, 1964-1972, and 1973-1985'' published in seven 
separate volumes.

                                  1986

40 CFR
                                                                   51 FR
                                                                    Page
Chapter I
60  Authority delegation notices...................................3171,
3172, 6736, 8673, 9190, 11021, 11727, 12144, 14993, 15886, 20648, 22520 
26546, 27033-27037, 27407, 32641, 32642, 33041-33046, 34216, 44984, 
46856
    Existing regulations unchanged.................................43572
60.4  (b)(RR) amended..............................................4344,
    (b)(FF) revised................................................15770
    (b)(MM) introductory text and (ix) revised.....................23419
    (b)(FF)(1) table amended; (b)(BBB) revised.....................26547
    (b)(Q) and (AA) revised; (b)(R) added..........................37910
60.11  (e)(4) corrected.............................................1790
60.13  (c) introductory text amended; (c)(1) and (2) added.........21765
60.16  Amended.....................................................42796
60.17  (a)(38) revised; (a)(46) added...............................2702
    (a)(1) and (10) revised; (a)(47) added.........................42794
60.18  Added........................................................2701
60.40b--60.49b (Subpart Db)  Added.................................42788
60.44  (a)(1) and (2) revised......................................42797
60.45  (c)(1) revised..............................................21166
60.46  (a)(2), (4), and (5), (f)(2), (3) introductory text and (i) 
        revised; (c) amended.......................................21166
    (a)(2) and (3), (b), (c), and (f)(3)(ii) revised...............42841
60.46b  (d)(1), (2) introductory text, (i), and (ii), (5), and (6) 
        revised; (d)(2)(iii) added.................................42841
60.47a  (h)(1) and (4) amended; (i)(1) revised.....................21166
60.48a  (a)(1) revised.............................................21166
    (a)(1) through (6) revised; (a)(7) removed.....................42842
60.90--60.93 (Subpart I)  Heading revised (classification 
        corrected at 51 FR 12325)...................................3300
    Heading correctly republished..................................12325
60.90  (a) revised (classification corrected at 51 FR 12325)........3300
    (a) correctly republished......................................12325
60.91  Revised (classification corrected at 51 FR 12325)............3300
    Correctly republished..........................................12325
60.106  (a)(1)(i) and (2) revised..................................42842
60.140--60.144 (Subpart N)  Heading revised..........................160
60.141  (a), (b), and (c) revised; (d) added.........................160
60.142  (a) introductory text revised; (b) and (c) added.............161
60.143  (b)(2) and (c) revised; OMB number...........................161
60.144  (b) revised; OMB number......................................161
60.140a--60.145a (Subpart Na)  Added.................................161
60.280  Revised....................................................18544
60.281  (e) revised................................................18544

[[Page 1228]]

60.283  (a)(1) introductory text, (iv), and (v) and (4) revised....18544
60.284  (a)(2) introductory text and (b)(1) introductory text, (d) 
        introductory text, (3) introductory text and (ii) revised; 
        (c)(4) added; OMB number...................................18545
60.466  (c) revised................................................22938
60.482-10  (d) revised..............................................2702
60.633  (g) revised.................................................2702
60  Appendix A amended......................................20288, 21166
    Appendix A corrected...........................................29104
    Appendix A amended......................................32455, 42842
    Appendix B amended.............................................21766

                                  1987

40 CFR
                                                                   52 FR
                                                                    Page
Chapter I
60  Appendix F corrected...........................................27612
    Appendix G amended; eff. 7-31-87...............................24749
60  Authority delegation notices...8585-8587, 9164, 23178, 28255, 33934, 
          35083-35085, 35087, 35088, 35090, 35091, 36033, 36417, 36418, 
                                                                   42114
    Authority citation corrected...................................37874
60.4  (b)(FF)(1) revised...........................................19512
60.7  (a)(7) added..................................................9781
60.11  (b) revised; (e)(1) amended; (e)(5), (6), and (7) 
        redesignated as (e)(6), (7), and (8); new (e)(5) added; 
        new (e)(6) revised..........................................9781
60.13  (c) revised..................................................9782
    (j) correctly added............................................17555
    (a) revised....................................................21007
60.16  Amended.....................................................11428
60.17  (a)(1), (3), (7) through (10), (24) through (28), and (47) 
        revised; (a)(48) through (53) added........................47842
60.17  (a)(13) and (37) and (c) introductory text and (1) revised 
                                                                   11429
60.40b--60.49b (Subpart Db)  Revised...............................47842
60.43  (a)(2) revised; (e) added...................................28954
60.45  (c)(1) revised..............................................21007
60.46  (h) added...................................................28955
60.47a  (h) introductory text, (1) and (2) and (i)(1) revised......21007
60.106  (d) introductory text amended; (d)(2) revised..............20392
60.110--60.113 (Subpart K)  Heading revised........................11429
60.111  (l) revised................................................11429
60.110a--60.115a (Subpart Ka)  Heading revised.....................11429
60.111a  (g) revised...............................................11429
60.113a  (a)(1)(i) introductory text revised; (a)(1)(i)(D) and (E) 
        added......................................................11429
60.114a  Revised...................................................11429
60.110b--60.117b (Subpart Kb)  Added...............................11429
60.117b  (b) correctly revised.....................................22780
60.285  (d)(1) and (3) revised.....................................36409
60.300  (b) correctly revised......................................42434
60.330  Correctly revised..........................................42434
60.343  (b) revised.................................................4773
60.344  (c) revised.................................................4774
60.540--60.548 (Subpart BBB)  Added................................34874
60.543  (a) and (h) introductory text corrected....................37874
60.546  (c)(2) corrected...........................................37874
60  Appendix A amended....5106, 9658, 20392, 34639, 36410, 36415, 41425, 
                                                                   47853
    Appendix A corrected...............10852, 19797, 22888, 33316, 42061
    Appendixes A and B amended.....................................30675
    Appendix B amended.............................................34650
    Appendix B corrected...........................................17556
    Appendix F added...............................................21007
60  Appendix F corrected...........................................27612
    Appendix G added...............................................28955

                                  1988

40 CFR
                                                                   53 FR
                                                                    Page
Chapter I
60  Authority citation revised......................................2675
    Authority delegation notices...................................3891,
8182, 12517, 17038, 22172, 23390, 24698, 27685, 45764, 46614
60.4  (b)(G), (BB), (JJ), (QQ), (TT), and (ZZ) revised; (b) Region 
        VIII table removed; (c) added..............................12520
    (b)(P), (Y), and (KK) revised..................................18985
    (b)(WW)(iii) revised...........................................24449
    (c) table revised..............................................50527
60.17  (a)(54) and (55) and (g) added...............................5872
60.61  (b), (c), and (d) added.....................................50363
60.63  (b), (c), (d), and (e) added................................50363
60.64  (a)(5) added................................................50364
60.65  Added.......................................................50364
60.66  Added.......................................................50364
60.106  (b) amended................................................41333

[[Page 1229]]

60.153  (a) introductory text republished; (a)(1) revised; (b), 
        (c), (d), and (e) added....................................39416
60.154  (d) added..................................................39417
60.155  Added......................................................39417
60.156  Added......................................................39418
60.286  (a)(2) introductory text revised...........................12009
60.530--60.539a (Subpart January 1, 1988)  Added....................5873
60.533  (k)(2) introductory text corrected.........................14889
60.536  (j) introductory text and (3) through (8) correctly 
        removed; (j)(1) and (2) correctly revised..................12009
60.538  (a) corrected..............................................14889
60.690--60.699 (Subpart QQQ)  Added................................47623
60.710--60.718 (Subpart SSS)  Added................................38914
60.711  (c) Table 1B corrected.....................................43799
    (b)(26) and Table 1A corrected.................................47955
    Correctly designated...........................................49822
60.713  (a)(2) and (b)(1)(iii)(C) and (9)(ii) corrected............43799
    (a) introductory text and (3)(i) and (b)(5)(i)(D) corrected....47955
60.715  (d) corrected..............................................43799
60.717  (f) introductory text and (1) corrected....................43799
    (d)(2), (4)(ii)(C), and (7) and (h) corrected..................47955
60.718  (b) corrected..............................................47955
60.720--60.726 (Subpart TTT)  Added.................................2676
60.726  (b) correctly revised......................................19300
60  Appendix A corrected...........................................2914,
11591, 12498, 14889
    Appendix A amended.............................................4142,
5884, 29682
    Appendixes A and B amended.....................................41333
    Appendix A corrected...........................................41649
    Appendix B amended..............................................7515
    Appendix I added................................................5913

                                  1989

40 CFR
                                                                   54 FR
                                                                    Page
Chapter I
60  Authority delegation notices...................................5078,
12627, 12910, 18495-18496, 26041, 50754
    Determination of status........................................13385
    Petition denied................................................27166
60.2  Amended.......................................................6662
60.4  (a) amended; (b)(E), (T), (GG) and (LL)(i) revised...........32445
    (b)(I) amended.................................................40664
    (b)(GG)(i) added...............................................52032
60.8  (b) and (e)(1) amended........................................6662
    (b) corrected..................................................21344
60.17  (a)(56), (57), (58), and (59) added.........................34026
    (h) added......................................................51825
60.22  (a) revised.................................................52189
60.41b  Amended....................................................51819
60.42b  (a) amended; (d), (e) and (f) revised; (j) added...........51819
60.43a  (h)(1) and (2) amended......................................6663
    (h)(1) and (2) corrected.......................................21344
60.43b  (b) and (f) revised........................................51819
60.44a  (a)(1) and (c) amended......................................6664
60.44b  (a) and (b) amended; (h) revised; (i), (j), and (k) added 
                                                                   51825
60.45  (c)(1) revised; (f)(3) amended...............................6662
60.45b  (d) introductory text revised; (j) added...................51820
    (b) revised....................................................51825
60.46  Revised......................................................6662
    (b)(1) corrected...............................................21344
60.46a  (d)(3) and (h) amended......................................6664
60.46b  (d) introductory text revised..............................51820
    (c) revised; (g) and (h) added.................................51825
60.47a  (f), (h), (i) introductory text, (1) and (2) revised; (j) 
        added.......................................................6664
60.47b  (a) amended; (f) added.....................................51820
60.48a  (d) redesignated as (f); new (d) added; (a), (b), (c) and 
        (e) added...................................................6664
60.48b  (b) revised; (i) added.....................................51825
60.49b  (r) added..................................................51820
    (a)(2), (b), (e), (g) introductory text revised; (p) and (q) 
added..............................................................51825
60.54  Revised......................................................6665
60.64  Revised......................................................6666
60.73  (a) revised; (b) amended.....................................6666
60.74  Revised......................................................6666
60.84  (a), (b), and (d) amended....................................6666
60.85  Revised......................................................6666
60.93  Revised......................................................6667
60.100  Heading and (b) revised; (c), (d), and (e) added...........34026
60.101  (m), (n), (o), (p), and (q) added..........................34027

[[Page 1230]]

60.102  Introductory text added; (a) introductory text revised.....34027
60.103  Revised....................................................34027
60.104  Heading and (a) introductory text revised; (b), (c), and 
        (d) added..................................................34027
60.105  Heading and (a) introductory text and (c) revised; (a)(8), 
        (9), (10), (11), (12), (13), and (14) added; (e)(4) 
        removed....................................................34028
60.106  (a)(7) amended; (e), (f), (g), and (h) added...............34028
60.107  Added......................................................34029
60.108  Added......................................................34030
60.109  Added......................................................34031
60.110b  (c) revised...............................................32973
60.111b  (f) introductory text revised.............................32973
60.113b  (a)(2) and (4) revised....................................32973
60.123  Revised.....................................................6667
60.133  Revised.....................................................6667
60.143  (b)(5) and (c) amended......................................6667
60.144  Revised.....................................................6667
60.144a  (d)(1) and (2) redesignated as (c)(1) and (2); (a), (b), 
        (c) introductory text and (d) revised.......................6667
60.154  Revised.....................................................6668
    (c) and (d) added..............................................27015
60.165  (b)(2)(i) and (ii) amended..................................6668
60.166  Revised.....................................................6668
60.175  (a)(2)(i) and (ii) amended..................................6668
60.176  Revised.....................................................6669
60.185  (a)(2)(i) and (ii) amended..................................6668
60.186  Revised.....................................................6669
60.194  (c) and (d) redesignated from 60.195 (a) and (b)............6669
60.195  (a) and (b) redesignated as 60.194 (c) and (d); revised.....6669
60.203  (b) amended.................................................6669
60.204  Revised.....................................................6669
60.213  (b) amended.................................................6670
60.214  Revised.....................................................6670
60.223  (b) amended.................................................6670
60.224  Revised.....................................................6670
60.233  (b) amended.................................................6670
60.234  Revised.....................................................6670
    (b)(3)(ii) corrected...........................................21344
60.243  (b) amended.................................................6671
60.244  Revised.....................................................6671
60.253  (b) amended.................................................6671
60.254  Revised.....................................................6671
60.266  Revised.....................................................6671
    (c)(1) corrected...............................................21344
60.273  (c) revised.................................................6672
60.275  (c) redesignated as 60.276 (c); (a), (b), (d), (e), (f) 
        revised; new (c) added......................................6672
    (b) correctly designated; (e)(2) corrected.....................21344
60.276  (c) redesignated from 60.275 (c); (b) amended...............6672
60.273a  (c) revised................................................6672
60.275a  (d) redesignated as 60.276a (f); (a), (b), (c), (e) and 
        (f) revised; new (d) added..................................6673
    (e)(2) corrected...............................................21344
60.276a  (f) redesignated from 60.275a (d); (e) amended.............6673
60.285  Revised.....................................................6673
    (c)(1), (2) and (d)(3) corrected...............................21344
60.292  (a)(2) amended..............................................6674
60.296  Revised.....................................................6674
    (b)(1) and (d)(1) corrected....................................21344
60.303  Revised.....................................................6674
60.335  Revised.....................................................6675
    (c)(1) amended.................................................27016
60.343  (e) amended.................................................6675
60.344  Revised.....................................................6675
60.374  Revised.....................................................6675
60.385  (c) amended.................................................6676
60.386  Revised.....................................................6676
60.404  Revised.....................................................6676
    (b)(1) corrected...............................................21344
60.424  Revised.....................................................6676
60.474  Revised.....................................................6677
    (c)(4) introductory text amended...............................27016
60.485  Revised.....................................................6678
    (g)(4) amended.................................................27016
60.502  (h) amended.................................................6678
60.503  Revised.....................................................6678
    (c)(3) corrected...............................................21344
60.540  (a) and (b) revised........................................38635
60.542a  Added.....................................................38635
60.543  (b)(1) and (2) amended; (b)(4), (f)(2)(iv) and (n) added; 
        (d) and (f)(2) introductory text revised...................38635
60.545  (f) added..................................................38637
60.546  (c)(7), (i), and (j) added.................................38637
60.547  (a)(5) added...............................................38638
60.643  (b) revised.................................................6679
60.644  Revised.....................................................6679
60.645  Removed.....................................................6679
60.646  (a)(2), (4) and (d) amended.................................6680
60.675  Revised.....................................................6680
60.676  (d) amended.................................................6680
60.685  Revised.....................................................6680
60.721  (a) amended................................................25459

[[Page 1231]]

60.740--60.748 (Subpart VVV)  Added................................37551
60  Appendix A amended...............................12622, 46235, 46238
    Appendix A corrected...........................................51550

                                  1990

40 CFR
                                                                   55 FR
                                                                    Page
Chapter I
60  Authority delegation notices.....................................28,
5990, 19882, 23077, 28393, 48233
    New stationary sources performance standards review............11338
60.1  Introductory text designated as (a); (b) added...............51382
60.2  Amended......................................................51382
60.4  (c) table revised............................................29016
    (c) table revised..............................................39406
60.7  (c) introductory text and (1) revised; (d) through (f) 
        redesignated as (e) through (g); new (d) and Figure 1 
        added......................................................51382
60.17  (a)(6) and (38) revised; (a)(46) removed; (a)(47) through 
        (55) redesignated as (a)(46) through (54)..................26922
    (a)(6) and (38) amended........................................26942
    (a)(1), (10), and (50) revised.................................37683
    (a)(6), (38), and (40) revised; (a)(60) and (61) added.........51053
    (a)(56) through (59) amended...................................40175
60.40c--60.48c (Subpart Dc)  Added.................................37683
60.45  (c)(1) amended..............................................18876
    (g) introductory text revised..................................51382
60.46  (b)(2)(ii), (4)(ii), (5)(ii), (d)(1)(ii), (4) and (6) 
        amended; (d)(7) added.......................................5212
60.46b  (d)(1) amended.............................................18876
60.47a  (h)(3), (j)(1) and (3) amended; (j)(4) added................5212
    (i)(1) amended.................................................18876
60.47b  (b)(2) amended..............................................5212
    Corrected......................................................18876
60.48a  (b)(2)(ii) amended..........................................5212
60.54  (b)(3), (c)(1)(iii) and (2)(ii) amended......................5212
60.103  (a) amended................................................40175
60.104  (a)(1), (2)(i) and (ii) revised............................40175
60.105  (a)(1) through (7), (13)(i), (d) and (e) revised; (a)(14) 
        removed....................................................40175
60.106  (a) through (d) revised; (e) through (h) redesignated as 
        (g) through (j); new (e), (f) and (k) added................40176
    (h)(3) through (5), (i) introductory text, (2)(i) and (7) 
amended............................................................40178
    (j)(3)(ii) amended.............................................40178
60.107  (b)(1)(ii), (2), (c)(1)(i) through (iii) amended...........40178
60.108  (d) amended................................................40178
60.109  (b)(2) amended.............................................40178
60.266  (c)(5) amended..............................................5212
60.285  (b)(2) and (d)(2) amended...................................5212
60.315  (b) revised; (c) redesignated as (d); new (c) added (OMB 
        number)....................................................51383
60.395  (b) and (c) revised (OMB number)...........................51383
60.447  (b) revised; (c) redesignated as (d); new (c) added........51383
60.455  (b) revised; (c) redesignated as (d); new (c) added (OMB 
        number)....................................................51383
60.465  (c) redesignated as (e); new (c) and (d) added (OMB 
        number)....................................................51383
60.495  (b) revised; (c) and (d) redesignated as (d) and (e); new 
        (c) added..................................................51384
60.560--60.566 (Subpart DDD)  Added................................51035
60.604  (a)(2) revised.............................................51384
60.610--60.618 (Subpart III)  Added................................26922
60.611  Corrected..................................................36932
60.614  (e)(2) table corrected.....................................36932
60.615  (b)(3) corrected...........................................36932
60.660--60.668 (Subpart NNN)  Added................................26942
60.665  (g)(4) corrected...........................................36932
60  Appendix A amended.............................................5212,
5616, 21753, 25604
    Appendix A amended.......................................47472-47474
    Appendix A corrected...........................................48208
    Appendix B amended.............................................18876
    Appendix B amended......................................40178, 47474

                                  1991

40 CFR
                                                                   56 FR
                                                                    Page
Chapter I
60  Authority delegation notices...................................8280,
13079, 13589, 29182, 50518, 55826, 59886, 63875, 65994

[[Page 1232]]

60.4  (c) table revised; eff. 8-19-91..............................28324
    (c) table corrected............................................41391
60.17  (h) revised; eff. 8-12-91....................................5506
60.30  Revised......................................................5523
60.32  Removed......................................................5525
60.33  Removed......................................................5525
60.34  Removed......................................................5525
60.30a--60.39a (Subpart Ca)  Added..................................5523
60.30b--60.32b (Subpart Cb)  Added..................................5525
60.50a--60.59a (Subpart Ea)  Added; eff. 8-12-91....................5506
60.106  (b)(2) revised..............................................4176
60.465  (c) corrected..............................................20497
60.495  (c)(2) corrected...........................................20497
60.561  Corrected...................................................9178
60.562-1  (a)(1)(i)(A), (ii) Table 3, (iii) introductory text, (c) 
        introductory text and (1)(i)(B) corrected...................9178
60.564  (e)(1) and (j)(1)(iii) corrected............................9178
60.565  (a)(3)(i), (c)(2)(ii), (e)(2), (f)(1)(i), (ii), (2), (3) 
        and (h) introductory text corrected.........................9178
60  Appendix B amended..............................................5526
    Appendix F amended..............................................5527
    Appendix A amended........................................5760, 5774

                                  1992

40 CFR
                                                                   57 FR
                                                                    Page
Chapter I
60  Authority delegation notices...................................5388,
19262, 22176, 29649, 48563, 55113
    Authority citation revised.....................................32338
60.2  Amended......................................................32338
60.4  (b)(H), (U), (W), (EE), (OO) and (UU) revised.................1226
60.14  (h) through (l) added.......................................32339
60.17  (a)(31) amended; (a)(62) added..............................30656
60.539  (h)(1) and (3) amended; (h)(2) revised......................5328
60.730--60.737 (Subpart UUU)  Added................................44503
60  Appendix A corrected...........................................24550
    Appendix A amended.............................................30656

                                  1993

40 CFR
                                                                   58 FR
                                                                    Page
Chapter I
60  Authority delegation notices.........................21, 7189, 33025
    OMB number.....................................................34370
    Authority citation revised.....................................40591
60.4  (c) table revised......................................5298, 64160
60.17  (a)(6) and (38) amended.....................................45962
60.48  Added (OMB number)..........................................18015
    Removed........................................................34375
60.49a  OMB number.................................................18015
60.55  Added (OMB number)..........................................18015
    Removed........................................................34375
60.59a  OMB number.................................................18015
60.75  Added (OMB number)..........................................18015
    Removed........................................................34375
60.94  Added (OMB number)..........................................18015
    Removed........................................................34375
60.107  OMB number.................................................18015
60.115b  OMB number................................................18015
60.116a  Added (OMB number)........................................18015
    Removed........................................................34375
60.124  Added (OMB number).........................................18015
    Removed........................................................34375
60.134  Added (OMB number).........................................18015
    Removed........................................................34375
60.155  OMB number.................................................18015
60.205  Added (OMB number).........................................18015
    Removed........................................................34375
60.215  Added (OMB number).........................................18015
    Removed........................................................34375
60.225  Added (OMB number).........................................18015
    Removed........................................................34375
60.235  Added (OMB number).........................................18015
    Removed........................................................34375
60.245  Added (OMB number).........................................18015
    Removed........................................................34375
60.255  Added (OMB number).........................................18015
    Removed........................................................34375
60.276  OMB number.................................................18015
60.297  Added (OMB number).........................................18015
    Removed........................................................34375
60.305  Added (OMB number).........................................18015
    Removed........................................................34375
60.336  Added (OMB number).........................................18016
    Removed........................................................34375
60.343  OMB number.................................................18016
60.375  Added (OMB number).........................................18016
    Removed........................................................34375
60.405  Added (OMB number).........................................18016
    Removed........................................................34375
60.434  OMB number.................................................18016
60.475  Added (OMB number).........................................18016
    Removed........................................................34375
60.537  OMB number.................................................18016
60.565  OMB number.................................................18016

[[Page 1233]]

60.594  Added (OMB number).........................................18016
    Removed........................................................34375
60.615  OMB number.................................................18016
60.616  OMB number.................................................18016
60.665  OMB number.................................................18016
60.666  OMB number.................................................18016
60.684  OMB number.................................................18016
60.700--60.708 (Subpart RRR)  Added (OMB number pending)...........45962
60.735  (b) and (c)(2) amended.....................................40591
    (c)(3) amended.................................................40592
60  Appendix G amended; eff. 7-16-93...............................28785

                                  1994

40 CFR
                                                                   59 FR
                                                                    Page
Chapter I
60  Authority delegation notices....................................9093
5955, 22758, 22759, 40258, 49581
    Technical correction...........................................49466
60.1  (c) added....................................................12427
60.2  Amended......................................................12427
60.4  (b) amended..................................................47265
60.7  (e), (f) and (g) redesignated as (f), (g) and (h); new (e) 
        added......................................................12428
60.17  (a)(22) revised.............................................19308
60.19  Added.......................................................12428
60.154  (d)(3), (4) and (5) removed.................................5108
60.391  (a) and (b) amended........................................51386
60.392  (a) revised................................................51386
60.393  (c)(1)(i)(E) added.........................................51387
60.604  Note removed; eff. 7-25-94.................................32341
60  Appendix G amended..............................................8135
    Appendix A amended............................................19308,
19309, 19311, 19319, 62924
    Appendix B amended.............................................64593

                                  1995

40 CFR
                                                                   60 FR
                                                                    Page
Chapter I
60  Technical correction...........................................35452
    Authority delegation notices.....................52329, 52331, 64329
    Authority citation revised.....................................65384
60.17  (a)(63) added...............................................47096
    (h)(1), (2) and (3) revised.............................65384, 65414
60.23  (a)(1) revised..............................................65414
60.24  (f) introductory text revised...............................65414
60.30  Revised.....................................................65414
60.30a--60.39a (Subpart Ca)  Removed...............................65414
60.30b--60.32b (Subpart Cb)  Redesignated as 60.30d--60.32d 
        (Subpart Cd); new 60.30b--60.39b (Subpart Cb) added........65414
60.30d--60.32d (Subpart Cd)  Redesignated from 60.30b--60.32b 
        (Subpart Cb) and revised...................................65414
60.47  Removed.....................................................33925
60.49b  (t) added..................................................28062
60.50a--60.59a (Subpart Ea)  Heading revised.......................65384
60.50a  (a) and (c) through (f) revised; (g) removed; (h) and (i) 
        redesignated as (l) and (m); new (g), new (h), new (i), 
        (j) and (k) added..........................................65384
60.50b--60.59b (Subpart Eb)  Added.................................65419
60.51a  Amended....................................................65384
60.56a  (a) Table 1 amended; (d) revised; (f)(9) removed...........65386
60.58a  (h)(1), (2), (6)(i), (ii), (10) and (j)(4) revised; 
        (h)(6)(iii) redesignated as (h)(6)(v); new (h)(6)(iii) and 
        new (iv) added; (j)(3) removed.............................65387
60.59a  (a)(1), (b)(14), (15) and (m) removed; (e) amended.........65387
60.286  Removed....................................................33925
60.481  Amended....................................................43258
60.482-5  Revised..................................................43258
60.482-10  (f) and (g) revised; (h) through (l) added..............43258
60.530  (c) and (d) removed........................................33925
60.532  (a) removed................................................33925
60.533  (e)(2), (h), (j)(1)(i) and (p)(4)(ii)(B) removed...........33925
60.535  (a)(2) and (c) removed.....................................33925
60.537  (b)(2) and (e) removed.....................................33925
60.539a  (b)(1) removed............................................33925
60.665  (l)(5) and (6) amended.....................................58238
60.667  Table amended..............................................58237
60.691  Amended....................................................43259
60.692-3  (d) revised..............................................43259
60.693-2  (a)(1)(i) introductory text and (A) revised..............43259
60.695  (a)(3)(i) and (ii) added...................................43259
60.697  (f)(3)(i) and (ii) revised; (f)(3)(x)(A) and (B) added.....43259
60.698  (d)(3)(i) and (ii) added...................................43260

[[Page 1234]]

60.700  (c)(2), (3) and (4) amended................................58238
60.704  (e)(1) introductory text, (f)(1) and (h)(3) amended........58238
60.705  (l)(1), (4), (5) and (8) amended...........................58238
60.707  Table amended..............................................58238
60  Regulation at 59 FR 62924 eff. date delayed to 12-6-95.........26828
    Appendix A amended.............................................47096
    Regulation at 59 FR 62924 eff. date delayed to 6-6-96..........56952

                                  1996

40 CFR
                                                                   61 FR
                                                                    Page
Chapter I
60  Authority delegation notices..............15721, 21080, 42808, 59832
60.4  (c) table revised............................................52868
60.16  Amended......................................................9919
60.17  (a)(22) revised; (i) and (j) added..........................18262
60.30  (c) added....................................................9919
60.30c--60.36c (Subpart Cc)  Added..................................9919
60.40c  (a) revised; (c) and (d) added.............................20736
60.41c  Amended....................................................20736
60.42  (b)(3) removed..............................................49976
60.45  (g)(1)(iii) removed.........................................49976
60.49b  (s) added..................................................14031
60.62  (a)(3) correctly removed; CFR correction....................14637
60.482-10  (j) introductory text revised...........................29878
60.699  Corrected; CFR correction..................................29485
60.750--60.759 (Subpart WWW)  Added.................................9919
60  Appendix A amended.......................................9929, 18262

                                  1997

40 CFR
                                                                   62 FR
                                                                    Page
Chapter I
60  Determination............................................4463, 36663
    Authority citation revised...............................8328, 48379
    Authority delagation notices.....................19679, 32033, 53245
    Clarification..................................................62953
60.1  (d) added....................................................52641
60.4  (a) amended; (b)(O), (P), (X), (KK)(ii), (iii), (iv), (vi), 
        (ix), (xii) and (xiii) revised..............................1833
    (c) table corrected......................................6619, 20066
    (c) table amended; eff. 7-7-97.................................24826
60.11  (a) and (f) revised; (g) added...............................8328
60.17  (b)(1) amended; (k) and (l) added...........................48379
    (a)(22) amended................................................52399
60.30  Revised.....................................................48379
60.30b--60.39b (Subpart Cb)  Heading revised.......................45119
60.31b  Amended.............................................45119, 45125
60.32b  (a) and (b) introductory text revised; (b)(2) amended; (m) 
        added......................................................45119
    (b)(1), (d), (e), (f)(1) and (i)(1) amended....................45125
60.33b  (a)(1)(i), (iii), (2)(i), (iii), (3), (b)(1)(i), (2)(i), 
        (c)(1) introductory text, (d) Table 1 and (1)(i) amended; 
        (a)(1)(ii), (2)(ii), (iv), (b)(1)(ii), (2)(ii) and (c)(2) 
        removed....................................................45119
    (a)(4), (b)(3) and (d)(3) added; (d) Table 2 amended; 
(d)(1)(i)(B) revised...............................................45120
    (a)(3) amended.................................................45125
60.34b  (a) amended.........................................45120, 45125
60.35b  Amended....................................................45120
60.38b  (b) amended; (c) removed...................................45120
60.39b  (b), (c)(1) introductory text, (2), (4)(ii), (iii) 
        introductory text and (5) amended; (c)(3) and (4)(i) 
        removed; (d) revised; (e) and (f) added....................45120
    (c)(4)(iii)(B) amended.........................................45125
60.30e--60.39e (Subpart Ce)  Added.................................48379
60.49b  (u) added..................................................52641
60.50b--60.59b (Subpart Eb)  Heading revised.......................45120
60.50b  (b)(2) amended.............................................45120
    (a) and (b) introductory text revised; (p) added...............45121
    (b)(1), (e), (f), (g)(1) and (i)(1) amended....................45125
    (j) introductory text amended..................................45126
60.51b  Amended.............................................45121, 45126
60.52b  (c)(1) amended.............................................45121
    (a)(1) through (5), (b)(1), (2), (c)(2), (d)(1) and (2) 
amended............................................................45126
60.53b  (a) introductory text, Table 1, (b) introductory text and 
        (c) introductory text amended..............................45126

[[Page 1235]]

60.54b  (a), (b), (c) introductory text, (d), (e) introductory 
        text and (f) introductory text amended; (c)(i) and (ii) 
        redesignated as (c)(1) and (2).............................45126
60.55b  (a) amended................................................45126
60.56b  Amended....................................................45126
60.57b  (a) introductory text, (b) introductory text and (c) 
        amended....................................................45126
60.58b  (b) introductory text, (3), (6)(i), (c)(2), (4), (7), (9), 
        (11), (d)(1)(ii), (v), (vii), (2)(ii), (vii), (viii), 
        (ix), (e)(3), (12)(i)(B), (f)(4), (7), (g)(2), (5) 
        introductory text, (i), (iii), (8), (h)(2), (3), (4), (10) 
        introductory text, (i)(B), (i)(3)(ii)(B), (5), (j)(1) 
        introductory text, (i), (2) and (m)(3) introductory text 
        amended; (b)(7), (h) introductory text and (k) 
        introductory text revised; (c)(10), (d)(1)(viii), (ix), 
        (2)(x), (f)(8) and (g)(5)(ii) removed; (k)(4) added........45126
60.59b  (a) introductory text and (b) introductory text amended....45121
    (b)(4), (d) introductory text, (2)(i)(C), (ii)(B), (3), 
(6)(ii), (8), (11), (12)(ii), (f) introductory text, (g) 
introductory text, (h) introductory text and (l) amended...........45127
60.50c--60.58c (Subpart Ec)  Added.................................48382
60.112b  (c) added.................................................52641
60.190  (b) revised; (c) added.....................................52399
60.241  (a) and (d) revised........................................18280
60.242  (b) added..................................................18280
60.243  (b) and (c) revised; (d) added.............................18280
60.244  (a)(2) revised.............................................18280
60.670  (a) and (d)(2) revised; (f) added..........................31359
60.671  Amended....................................................31359
60.672  (a)(1) amended; (b) and (c) revised; (f), (g) and (h) 
        added......................................................31359
60.675  (b) introductory text revised; (c) introductory text, (1), 
        (2) and (3) redesignated as (c)(1) introductory text, (i), 
        (ii) and (iii); (c)(2), (3), (4), (g) and (h) added........31360
60.676  (b) removed; (g) redesignated as (j); (f) and new (j) 
        revised; new (g), (h) and (i) added........................31360
60  Appendix A amended.............................................52399

                                  1998

40 CFR
                                                                   63 FR
                                                                    Page
Chapter I
60  Authority delegation notices........1746, 5891, 27854, 50162, 50163, 
                                                                   70675
    Interpretation.................................................53288
    Technical correction............................................7199
60.4  (c) table amended............................................45727
    (c) table corrected.....................................49382, 56707
60.11  Regulation at 62 FR 8328 eff. date corrected to 12-30-97......414
60.17  Regulation at 61 FR 18262 eff. date corrected to 2-9-98......6493
    (a)(6) revised.................................................24444
60.18  (c)(3) and (4)(i) revised...................................24444
60.32c  (c) and (d) added; eff. 8-17-98............................32750
60.36c  (a) revised; eff. 8-17-98..................................32750
60.40a  (b) revised................................................49453
60.41a  Amended....................................................49453
60.44a  (a) introductory text and (c) introductory text revised; 
        (d) added..................................................49453
60.46a  (i) added..................................................49454
60.47a  (c) revised; (k) and (l) added.............................49454
60.49a  (i) amended; (j) added.....................................49454
60.40b  (h) and (i) added..........................................49454
60.44b  (a) introductory text, (b) introductory text, (c), and (e) 
        introductory text revised; (l) added.......................49454
60.48b  (b) revised................................................49455
60.49b  (v) added..................................................49455
60.533  (l)(1)(ii) revised.........................................64874
60.538  (e) revised................................................64874
60.750  (a) and (b) amended; (c) added; eff. 8-17-98...............32750
60.751  Amended; eff. 8-17-98......................................32750
60.752  (a), (b) introductory text, (2)(ii), (iii)(B), and (v)(A) 
        revised; (c) and (d) added; eff. 8-17-98...................32751
60.753  Introductory text revised; (d) and (g) amended; eff. 8-17-
        98.........................................................32751

[[Page 1236]]

60.754  (a)(1) introductory text and (c) revised; (a)(1)(i), (ii), 
        (4)(ii), (5), (b)(3) and (d) amended; eff. 8-17-98.........32751
60.755  (a)(3), (5), (b) introductory text and (c)(1) amended; 
        (a)(4) revised; eff. 8-17-98...............................32752
60.756  (a) introductory text, (b)(1) and (2) introductory text 
        amended; eff. 8-17-98......................................32752
60.757  (a)(1), (2), (3), (b)(1)(i) and (g) introductory text 
        revised; eff. 8-17-98......................................32752
60.758  Introductory text removed; (a), (b) introductory text, (c) 
        introductory text, (d) introductory text and (e) amended; 
        (f) added; eff. 8-17-98....................................32752
60.759  (a)(3)(iii) amended; eff. 8-17-98..........................32753
60 Appendix A  Regulation at 61 FR 18262 eff. date corrected to 2-
        9-98........................................................6493

                                  1999

    (Regulations published from January 1, 1999 through July 1, 1999)

40 CFR
                                                                   64 FR
                                                                    Page
Chapter I
60  Authority citation revised......................................7463
    Authority notice delegation....................................14393
60.7  (a) introductory text and (c) introductory text revised; 
        (a)(2) removed; (f) amended; (f)(1), (2) and (3) added......7463
60.8  (d) revised...................................................7463
60.13  (h) amended..................................................7463
60.19  (b) revised..................................................7463
60.33c  (a)(2) amended; (d) and (e) added...........................9261
60.35c  (a) and (b) added...........................................9262
60.41c  Amended; CFR correction....................................24049
60.45  (g) introductory text revised................................7463
60.49a  (i) revised.................................................7463
60.49b  (d), (e), (h) introductory text, (i), (j), (k)(2), (3), 
        (m) introductory text, (n) introductory text, (1), (2), 
        (q) introductory text, (2), (3), (r) and (s) revised........7464
60.48c  (c), (d), (e) introductory text, (2), (3) and (11) 
        revised; (j) added..........................................7465
60.59a  (e), (f) and (g) revised....................................7465
60.107  (a), (c) introductory text, (d) and (e) revised.............7465
60.108  (e) revised.................................................7466
60.271  (h) and (j) revised........................................10109
60.272  (a)(3)(iii) revised........................................10109
60.273  (b) revised; (d) added.....................................10110
60.274  (b), (c), (f) and (g) revised..............................10110
60.276  (d) added..................................................10110
60.270a--60.276a (Subpart AAa)  Heading revised....................10110
60.271a  Amended...................................................10110
60.273a  (d) added.................................................10111
60.274a  (b), (c), (f) and (g) revised.............................10111
60.276a  (g) added.................................................10111
60.293  (c)(4), (5), (d)(3) introductory text and (3)(iii) revised
                                                                    7466
60.403  (f) revised.................................................7466
60.502  (e)(3) and (4) revised......................................7466
60.531  Amended.....................................................7466
60.536  (f)(3) revised..............................................7466
60.564  (h) introductory text revised..............................11541
60.714  (a) revised.................................................7467
60.717  (c) and (d) introductory text revised.......................7467
60.751  Amended.....................................................9262
60.759  (a)(3)(iii) amended.........................................9262
60  Appendix A amended; eff. 7-13-99...............................26490

                                  1999

            (Corrections published July 9 and July 15, 1999)

40 CFR
                                                                   64 FR
                                                                    Page
Chapter I
60 Appendix A  corrected....................................37196, 38241


                                  
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