[Title 40 CFR ]
[Code of Federal Regulations (annual edition) - July 1, 2024 Edition]
[From the U.S. Government Publishing Office]
[[Page i]]
Title 40
Protection of Environment
________________________
Part 60 (Sec. 60.500 to end of part 60 sections)
Revised as of July 1, 2024
Containing a codification of documents of general
applicability and future effect
As of July 1, 2024
Published by the Office of the Federal Register
National Archives and Records Administration as a
Special Edition of the Federal Register
[[Page ii]]
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[[Page iii]]
Table of Contents
Page
Explanation................................................. v
Title 40:
Chapter I--Environmental Protection Agency
(Continued) 3
Finding Aids:
Table of CFR Titles and Chapters........................ 1337
Alphabetical List of Agencies Appearing in the CFR...... 1357
List of CFR Sections Affected........................... 1367
[[Page iv]]
----------------------------
Cite this Code: CFR
To cite the regulations in
this volume use title,
part and section number.
Thus, 40 CFR 60.500 refers
to title 40, part 60,
section 500.
----------------------------
[[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
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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
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collection request.
[[Page vi]]
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(b) The matter incorporated is in fact available to the extent
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(c) The incorporating document is drafted and submitted for
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[[Page vii]]
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Oliver A. Potts,
Director,
Office of the Federal Register
July 1, 2024
[[Page ix]]
THIS TITLE
Title 40--Protection of Environment is composed of thirty-seven
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-
52.2019), part 52 (52.2020-end of part 52), parts 53-59, part 60 (60.1-
60.499), part 60 (60.500-end of part 60, sections), part 60
(Appendices), parts 61-62, part 63 (63.1-63.599), part 63 (63.600-
63.1199), part 63 (63.1200-63.1439), part 63 (63.1440-63.6175), part 63
(63.6580-63.8830), part 63 (63.8980-end of part 63), parts 64-71, parts
72-78, parts 79-80, part 81, parts 82-84, parts 85-96, parts 97-99,
parts 100-135, 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
700-722, parts 723-789, parts 790-999, parts 1000-1059, and part 1060 to
end. The contents of these volumes represent all current regulations
codified under this title of the CFR as of July 1, 2024.
Chapter I--Environmental Protection Agency appears in all thirty-
seven volumes. OMB control numbers for title 40 appear in Sec. 9.1 of
this chapter.
Chapters IV-IX--Regulations issued by the Environmental Protection
Agency and Department of Justice, Council on Environmental Quality,
Chemical Safety and Hazard Investigation Board, Environmental Protection
Agency and Department of Defense; Uniform National Discharge Standards
for Vessels of the Armed Forces, Gulf Coast Ecosystem Restoration
Council, and the Federal Permitting Improvement Steering Council appear
in volume thirty-seven.
For this volume, Gabrielle E. Burns was Chief Editor. The Code of
Federal Regulations publication program is under the direction of John
Hyrum Martinez, assisted by Stephen J. Frattini.
[[Page 1]]
TITLE 40--PROTECTION OF ENVIRONMENT
(This book contains part 60, Sec. 60.500 to end of part 60 sections)
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Part
chapter i--Environmental Protection Agency (Continued)...... 60
[[Page 3]]
CHAPTER I--ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)
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Editorial Note: Nomenclature changes to chapter I appear at 65 FR
47324, 47325, Aug. 2, 2000 and 66 FR 34375, 34376, June 28, 2001.
SUBCHAPTER C--AIR PROGRAMS (CONTINUED)
Part Page
60 Standards of performance for new stationary
sources (Continued)..................... 5
[[Page 5]]
SUBCHAPTER C_AIR PROGRAMS (CONTINUED)
PART 60_STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES
(CONTINUED)--Table of Contents
Subpart XX_Standards of Performance for Bulk Gasoline Terminals That
Commenced Construction, Modification, or Reconstruction After December
17, 1980, and On or Before June 10, 2022
Sec.
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.
Subpart XXa--Standards of Performance for Bulk Gasoline Terminals that
Commenced Construction, Modification, or Reconstruction After June 10, 2022
60.500a Applicability and designation of affected facility.
60.501a Definitions.
60.502a Standard for volatile organic compound (VOC) emissions from bulk
gasoline terminals.
60.503a Test methods and procedures.
60.504a Monitoring requirements.
60.505a Reporting and recordkeeping.
Subpart AAA_Standards of Performance for New Residential Wood Heaters
60.530 Am I subject to this subpart?
60.531 What definitions must I know?
60.532 What standards and associated requirements must I meet and by
when?
60.533 What compliance and certification requirements must I meet and by
when?
60.534 What test methods and procedures must I use to determine
compliance with the standards and requirements for
certification?
60.535 What procedures must I use for EPA approval of a test laboratory
or EPA approval of a third-party certifier?
60.536 What requirements must I meet for permanent labels, temporary
labels (hangtags), and owner's manuals?
60.537 What records must I keep and what reports must I submit?
60.538 What activities are prohibited under this subpart?
60.539 What hearing and appeal procedures apply to me?
60.539a Who implements and enforces this subpart?
60.539b What parts of the General Provisions do not apply to me?
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.
[[Page 6]]
60.585 Reporting requirements.
Subpart GGG_Standards of Performance for Equipment Leaks of VOC in
Petroleum Refineries for Which Construction, Reconstruction, or
Modification Commenced After January 4, 1983, and on or Before November
7, 2006
60.590 Applicability and designation of affected facility.
60.591 Definitions.
60.592 Standards.
60.593 Exceptions.
Subpart GGGa_Standards of Performance for Equipment Leaks of VOC in
Petroleum Refineries for Which Construction, Reconstruction, or
Modification Commenced After November 7, 2006
60.590a Applicability and designation of affected facility.
60.591a Definitions.
60.592a Standards.
60.593a 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 IIIa_Standards of Performance for Volatile Organic Compound
(VOC) Emissions From the Synthetic Organic Chemical Manufacturing
Industry (SOCMI) Air Oxidation Unit Processes for Which Construction,
Reconstruction, or Modification Commenced After April 25, 2023
60.610a Am I subject to this subpart?
60.611a What definitions must I know?
60.612a What standards and associated requirements must I meet?
60.613a What are my monitoring, installation, operation, and maintenance
requirements?
60.614a What test methods and procedures must I use to determine
compliance with the standards?
60.615a What records must I keep and what reports must I submit?
60.616a What do the terms associated with reconstruction mean for this
subpart?
60.617a What are the chemicals that I must produce to be affected by
subpart IIIa?
60.618a [Reserved]
60.619a What are my requirements if I use a flare to comply with this
subpart?
60.620a What are my requirements for closed vent systems?
Table 1 to Subpart IIIa of Part 60--Emission Limits and Standards for
Vent Streams
Table 2 to Subpart IIIa of Part 60--Monitoring Requirements for
Complying With 98 Weight-Percent Reduction of Total Organic
Compounds Emissions or a Limit of 20 Parts Per Million by
Volume
Table 3 to Subpart IIIa of Part 60--Operating Parameters, Operating
Parameter Limits and Data Monitoring, Recordkeeping and
Compliance Frequencies
Table 4 to Subpart IIIa of Part 60--Calibration and Quality Control
Requirements for Continuous Parameter Monitoring System (CPMS)
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.
[[Page 7]]
60.625 Recordkeeping requirements.
Subpart KKK_Standards of Performance for Equipment Leaks of VOC From
Onshore Natural Gas Processing Plants for Which Construction,
Reconstruction, or Modification Commenced After January 20, 1984, and on
or Before August 23, 2011
60.630 Applicability and designation of affected facility.
60.631 Definitions.
60.632 Standards.
60.633 Exceptions.
60.634 Alternative means of emission limitation.
60.635 Recordkeeping requirements.
60.636 Reporting requirements.
Subpart LLL_Standards of Performance for SO2 Emissions From Onshore
Natural Gas Processing for Which Construction, Reconstruction, or
Modification Commenced After January 20, 1984, and on or Before August
23, 2011
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 After December 30, 1983, and on or Before April
25, 2023
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 NNNa_Standards of Performance for Volatile Organic Compound
(VOC) Emissions From Synthetic Organic Chemical Manufacturing Industry
(SOCMI) Distillation Operations for Which Construction, Reconstruction,
or Modification Commenced After April 25, 2023
60.660a Am I subject to this subpart?
60.661a What definitions must I know?
60.662a What standards and associated requirements must I meet?
60.663a What are my monitoring, installation, operation, and maintenance
requirements?
60.664a What test methods and procedures must I use to determine
compliance with the standards?
60.665a What records must I keep and what reports must I submit?
60.666a What do the terms associated with reconstruction mean for this
subpart?
60.667a What are the chemicals that I must produce to be affected by
subpart NNNa?
60.668a [Reserved]
60.669a What are my requirements if I use a flare to comply with this
subpart?
60.670a What are my requirements for closed vent systems?
Table 1 to Subpart NNNa of Part 60--Emission Limits and Standards for
Vent Streams
Table 2 to Subpart NNNa of Part 60--Monitoring Requirements for
Complying With 98 Weight-Percent Reduction of Total Organic
Compounds Emissions or a Limit of 20 Parts Per Million by
Volume
Table 3 to Subpart NNNa of Part 60--Operating Parameters, Operating
Parameter Limits and Data Monitoring, Recordkeeping and
Compliance Frequencies
Table 4 to Subpart NNNa of Part 60--Calibration and Quality Control
Requirements for Continuous Parameter Monitoring System (CPMS)
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 (PM).
60.673 Reconstruction.
60.674 Monitoring of operations.
60.675 Test methods and procedures.
60.676 Reporting and recordkeeping.
Table 1 to Subpart OOO of Part 60--Exceptions to Applicability of
Subpart A to Subpart OOO
[[Page 8]]
Table 2 to Subpart OOO of Part 60--Stack Emission Limits for Affected
Facilities With Capture Systems
Table 3 to Subpart OOO of Part 60--Fugitive Emission Limits
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 After June 29, 1990, and on or Before April 25, 2023
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 RRRa_Standards of Performance for Volatile Organic Compound
Emissions From Synthetic Organic Chemical Manufacturing Industry (SOCMI)
Reactor Processes for Which Construction, Reconstruction, or
Modification Commenced After April 25, 2023
60.700a Am I subject to this subpart?
60.701a What definitions must I know?
60.702a What standards and associated requirements must I meet?
60.703a What are my monitoring, installation, operation, and maintenance
requirements?
60.704a What test methods and procedures must I use to determine
compliance with the standards?
60.705a What records must I keep and what reports must I submit?
60.706a What do the terms associated with reconstruction mean for this
subpart?
60.707a What are the chemicals that I must produce to be affected by
subpart RRRa?
60.708a [Reserved]
60.709a What are my requirements if I use a flare to comply with this
subpart?
60.710a What are my requirements for closed vent systems?
Table 1 to Subpart RRRa of Part 60--Emission Limits and Standards for
Vent Streams
Table 2 to Subpart RRRa of Part 60--Monitoring Requirements for
Complying With 98 Weight-Percent Reduction of Total Organic
Compounds Emissions or a Limit of 20 Parts per Million by
Volume
Table 3 to Subpart RRRa of Part 60--Operating Parameters, Operating
Parameter Limits and Data Monitoring, Recordkeeping and
Compliance Frequencies
Table 4 to Subpart RRRa of Part 60--Calibration and Quality Control
Requirements for Continuous Parameter Monitoring System (CPMS)
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 9]]
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 TTTa_Standards of Performance for Industrial Surface Coating:
Surface Coating of Plastic Parts for Business Machines for Which
Construction, Reconstruction, or Modification Commenced After June 21,
2022
60.720a Applicability and designation of affected facility.
60.721a Definitions.
60.722a Standards for volatile organic compounds.
60.723a Performance tests and compliance provisions.
60.724a Reporting and recordkeeping requirements.
60.725a Test methods and procedures.
60.726a 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 volatile 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
That Commenced Construction, Reconstruction, or Modification on or After
May 30, 1991, but Before July 18, 2014
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.
Subpart XXX_Standards of Performance for Municipal Solid Waste Landfills
That Commenced Construction, Reconstruction, or Modification After July
17, 2014
60.760 Applicability, designation of affected source, and delegation of
authority.
60.761 Definitions.
60.762 Standards for air emissions from municipal solid waste landfills.
60.763 Operational standards for collection and control systems.
60.764 Test methods and procedures.
60.765 Compliance provisions.
60.766 Monitoring of operations.
60.767 Reporting requirements.
60.768 Recordkeeping requirements.
60.769 Specifications for active collection systems.
Subparts YYY-ZZZ [Reserved]
Subpart AAAA_Standards of Performance for Small Municipal Waste
Combustion Units for Which Construction is Commenced After August 30,
1999 or for Which Modification or Reconstruction is Commenced After June
6, 2001
Introduction
60.1000 What does this subpart do?
60.1005 When does this subpart become effective?
[[Page 10]]
Applicability
60.1010 Does this subpart apply to my municipal waste combustion unit?
60.1015 What is a new municipal waste combustion unit?
60.1020 Does this subpart allow any exemptions?
60.1025 Do subpart E new source performance standards also apply to my
municipal waste combustion unit?
60.1030 Can the Administrator delegate authority to enforce these
Federal new source performance standards to a State agency?
60.1035 How are these new source performance standards structured?
60.1040 Do all five components of these new source performance standards
apply at the same time?
60.1045 Are there different subcategories of small municipal waste
combustion units within this subpart?
Preconstruction Requirements: Materials Separation Plan
60.1050 Who must submit a materials separation plan?
60.1055 What is a materials separation plan?
60.1060 What steps must I complete for my materials separation plan?
60.1065 What must I include in my draft materials separation plan?
60.1070 How do I make my draft materials separation plan available to
the public?
60.1075 When must I accept comments on the materials separation plan?
60.1080 Where and when must I hold a public meeting on my draft
materials separation plan?
60.1085 What must I do with any public comments I receive during the
public comment period on my draft materials separation plan?
60.1090 What must I do with my revised materials separation plan?
60.1095 What must I include in the public meeting on my revised
materials separation plan?
60.1100 What must I do with any public comments I receive on my revised
materials separation plan?
60.1105 How do I submit my final materials separation plan?
Preconstruction Requirements: Siting Analysis
60.1110 Who must submit a siting analysis?
60.1115 What is a siting analysis?
60.1120 What steps must I complete for my siting analysis?
60.1125 What must I include in my siting analysis?
60.1130 How do I make my siting analysis available to the public?
60.1135 When must I accept comments on the siting analysis and revised
materials separation plan?
60.1140 Where and when must I hold a public meeting on the siting
analysis?
60.1145 What must I do with any public comments I receive during the
public comment period on my siting analysis?
60.1150 How do I submit my siting analysis?
Good Combustion Practices: Operator Training
60.1155 What types of training must I do?
60.1160 Who must complete the operator training course? By when?
60.1165 Who must complete the plant-specific training course?
60.1170 What plant-specific training must I provide?
60.1175 What information must I include in the plant-specific operating
manual?
60.1180 Where must I keep the plant-specific operating manual?
Good Combustion Practices: Operator Certification
60.1185 What types of operator certification must the chief facility
operator and shift supervisor obtain and by when must they
obtain it?
60.1190 After the required date for operator certification, who may
operate the municipal waste combustion unit?
60.1195 What if all the certified operators must be temporarily offsite?
Good Combustion Practices: Operating Requirements
60.1200 What are the operating practice requirements for my municipal
waste combustion unit?
60.1205 What happens to the operating requirements during periods of
startup, shutdown, and malfunction?
Emission Limits
60.1210 What pollutants are regulated by this subpart?
60.1215 What emission limits must I meet? By when?
60.1220 What happens to the emission limits during periods of startup,
shutdown, and malfunction?
Continuous Emission Monitoring
60.1225 What types of continuous emission monitoring must I perform?
60.1230 What continuous emission monitoring systems must I install for
gaseous pollutants?
60.1235 How are the data from the continuous emission monitoring systems
used?
60.1240 How do I make sure my continuous emission monitoring systems are
operating correctly?
[[Page 11]]
60.1245 Am I exempt from any appendix B or appendix F requirements to
evaluate continuous emission monitoring systems?
60.1250 What is my schedule for evaluating continuous emission
monitoring systems?
60.1255 What must I do if I choose to monitor carbon dioxide instead of
oxygen as a diluent gas?
60.1260 What is the minimum amount of monitoring data I must collect
with my continuous emission monitoring systems and is the data
collection requirement enforceable?
60.1265 How do I convert my 1-hour arithmetic averages into the
appropriate averaging times and units?
60.1270 What is required for my continuous opacity monitoring system and
how are the data used?
60.1275 What additional requirements must I meet for the operation of my
continuous emission monitoring systems and continuous opacity
monitoring system?
60.1280 What must I do if any of my continuous emission monitoring
systems are temporarily unavailable to meet the data
collection requirements?
Stack Testing
60.1285 What types of stack tests must I conduct?
60.1290 How are the stack test data used?
60.1295 What schedule must I follow for the stack testing?
60.1300 What test methods must I use to stack test?
60.1305 May I conduct stack testing less often?
60.1310 May I deviate from the 13-month testing schedule if unforeseen
circumstances arise?
Other Monitoring Requirements
60.1315 Must I meet other requirements for continuous monitoring?
60.1320 How do I monitor the load of my municipal waste combustion unit?
60.1325 How do I monitor the temperature of flue gases at the inlet of
my particulate matter control device?
60.1330 How do I monitor the injection rate of activated carbon?
60.1335 What is the minimum amount of monitoring data I must collect
with my continuous parameter monitoring systems and is the
data collection requirement enforceable?
Recordkeeping
60.1340 What records must I keep?
60.1345 Where must I keep my records and for how long?
60.1350 What records must I keep for the materials separation plan and
siting analysis?
60.1355 What records must I keep for operator training and
certification?
60.1360 What records must I keep for stack tests?
60.1365 What records must I keep for continuously monitored pollutants
or parameters?
60.1370 What records must I keep for municipal waste combustion units
that use activated carbon?
Reporting
60.1375 What reports must I submit before I submit my notice of
construction?
60.1380 What must I include in my notice of construction?
60.1385 What reports must I submit after I submit my notice of
construction and in what form?
60.1390 What are the appropriate units of measurement for reporting my
data?
60.1395 When must I submit the initial report?
60.1400 What must I include in my initial report?
60.1405 When must I submit the annual report?
60.1410 What must I include in my annual report?
60.1415 What must I do if I am out of compliance with the requirements
of this subpart?
60.1420 If a semiannual report is required, when must I submit it?
60.1425 What must I include in the semiannual out-of-compliance reports?
60.1430 Can reporting dates be changed?
Air Curtain Incinerators That Burn 100 Percent Yard Waste
60.1435 What is an air curtain incinerator?
60.1440 What is yard waste?
60.1445 What are the emission limits for air curtain incinerators that
burn 100 percent yard waste?
60.1450 How must I monitor opacity for air curtain incinerators that
burn 100 percent yard waste?
60.1455 What are the recordkeeping and reporting requirements for air
curtain incinerators that burn 100 percent yard waste?
Equations
60.1460 What equations must I use?
Definitions
60.1465 What definitions must I know?
Table 1 to Subpart AAAA of Part 60--Emission Limits For New Small
Municipal Waste Combustion Units
Table 2 to Subpart AAAA of Part 60--Carbon Monoxide Emission Limits For
New
[[Page 12]]
Small Municipal Waste Combustion Units
Table 3 to Subpart AAAA of Part 60--Requirements For Validating
Continuous Emission Monitoring Systems (CEMS)
Table 4 to Subpart AAAA of Part 60--Requirements For Continuous Emission
Monitoring Systems (CEMS)
Table 5 to Subpart AAAA of Part 60--Requirements For Stack Tests
Subpart BBBB_Emission Guidelines and Compliance Times for Small
Municipal Waste Combustion Units Constructed on or Before August 30,
1999
Introduction
60.1500 What is the purpose of this subpart?
60.1505 Am I affected by this subpart?
60.1510 Is a State plan required for all States?
60.1515 What must I include in my State plan?
60.1520 Is there an approval process for my State plan?
60.1525 What if my State plan is not approvable?
60.1530 Is there an approval process for a negative declaration letter?
60.1535 What compliance schedule must I include in my State plan?
60.1540 Are there any State plan requirements for this subpart that
supersede the requirements specified in subpart B?
60.1545 Does this subpart directly affect municipal waste combustion
unit owners and operators in my State?
Applicability of State Plans
60.1550 What municipal waste combustion units must I address in my State
plan?
60.1555 Are any small municipal waste combustion units exempt from my
State plan?
60.1560 Can an affected municipal waste combustion unit reduce its
capacity to less than 35 tons per day rather than comply with
my State plan?
60.1565 What subcategories of small municipal waste combustion units
must I include in my State plan?
Use of Model Rule
60.1570 What is the ``model rule'' in this subpart?
60.1575 How does the model rule relate to the required elements of my
State plan?
60.1580 What are the principal components of the model rule?
Model Rule--Increments of Progress
60.1585 What are my requirements for meeting increments of progress and
achieving final compliance?
60.1590 When must I complete each increment of progress?
60.1595 What must I include in the notifications of achievement of my
increments of progress?
60.1600 When must I submit the notifications of achievement of
increments of progress?
60.1605 What if I do not meet an increment of progress?
60.1610 How do I comply with the increment of progress for submittal of
a control plan?
60.1615 How do I comply with the increment of progress for awarding
contracts?
60.1620 How do I comply with the increment of progress for initiating
onsite construction?
60.1625 How do I comply with the increment of progress for completing
onsite construction?
60.1630 How do I comply with the increment of progress for achieving
final compliance?
60.1635 What must I do if I close my municipal waste combustion unit and
then restart my municipal waste combustion unit?
60.1640 What must I do if I plan to permanently close my municipal waste
combustion unit and not restart it?
Model Rule--Good Combustion Practices: Operator Training
60.1645 What types of training must I do?
60.1650 Who must complete the operator training course? By when?
60.1655 Who must complete the plant-specific training course?
60.1660 What plant-specific training must I provide?
60.1665 What information must I include in the plant-specific operating
manual?
60.1670 Where must I keep the plant-specific operating manual?
Model Rule--Good Combustion Practices: Operator Certification
60.1675 What types of operator certification must the chief facility
operator and shift supervisor obtain and by when must they
obtain it?
60.1680 After the required date for operator certification, who may
operate the municipal waste combustion unit?
60.1685 What if all the certified operators must be temporarily offsite?
Model Rule--Good Combustion Practices: Operating Requirements
60.1690 What are the operating practice requirements for my municipal
waste combustion unit?
60.1695 What happens to the operating requirements during periods of
startup, shutdown, and malfunction?
[[Page 13]]
Model Rule--Emission Limits
60.1700 What pollutants are regulated by this subpart?
60.1705 What emission limits must I meet? By when?
60.1710 What happens to the emission limits during periods of startup,
shutdown, and malfunction?
Model Rule--Continuous Emission Monitoring
60.1715 What types of continuous emission monitoring must I perform?
60.1720 What continuous emission monitoring systems must I install for
gaseous pollutants?
60.1725 How are the data from the continuous emission monitoring systems
used?
60.1730 How do I make sure my continuous emission monitoring systems are
operating correctly?
60.1735 Am I exempt from any appendix B or appendix F requirements to
evaluate continuous emission monitoring systems?
60.1740 What is my schedule for evaluating continuous emission
monitoring systems?
60.1745 What must I do if I choose to monitor carbon dioxide instead of
oxygen as a diluent gas?
60.1750 What is the minimum amount of monitoring data I must collect
with my continuous emission monitoring systems and is the data
collection requirement enforceable?
60.1755 How do I convert my 1-hour arithmetic averages into appropriate
averaging times and units?
60.1760 What is required for my continuous opacity monitoring system and
how are the data used?
60.1765 What additional requirements must I meet for the operation of my
continuous emission monitoring systems and continuous opacity
monitoring system?
60.1770 What must I do if any of my continuous emission monitoring
systems are temporarily unavailable to meet the data
collection requirements?
Model Rule--Stack Testing
60.1775 What types of stack tests must I conduct?
60.1780 How are the stack test data used?
60.1785 What schedule must I follow for the stack testing?
60.1790 What test methods must I use to stack test?
60.1795 May I conduct stack testing less often?
60.1800 May I deviate from the 13-month testing schedule if unforeseen
circumstances arise?
Model Rule--Other Monitoring Requirements
60.1805 Must I meet other requirements for continuous monitoring?
60.1810 How do I monitor the load of my municipal waste combustion unit?
60.1815 How do I monitor the temperature of flue gases at the inlet of
my particulate matter control device?
60.1820 How do I monitor the injection rate of activated carbon?
60.1825 What is the minimum amount of monitoring data I must collect
with my continuous parameter monitoring systems and is the
data collection requirement enforceable?
Model Rule--Recordkeeping
60.1830 What records must I keep?
60.1835 Where must I keep my records and for how long?
60.1840 What records must I keep for operator training and
certification?
60.1845 What records must I keep for stack tests?
60.1850 What records must I keep for continuously monitored pollutants
or parameters?
60.1855 What records must I keep for municipal waste combustion units
that use activated carbon?
Model Rule--Reporting
60.1860 What reports must I submit and in what form?
60.1865 What are the appropriate units of measurement for reporting my
data?
60.1870 When must I submit the initial report?
60.1875 What must I include in my initial report?
60.1880 When must I submit the annual report?
60.1885 What must I include in my annual report?
60.1890 What must I do if I am out of compliance with the requirements
of this subpart?
60.1895 If a semiannual report is required, when must I submit it?
60.1900 What must I include in the semiannual out-of-compliance reports?
60.1905 Can reporting dates be changed?
Model Rule--Air Curtain Incinerators That Burn 100 Percent Yard Waste
60.1910 What is an air curtain incinerator?
60.1915 What is yard waste?
60.1920 What are the emission limits for air curtain incinerators that
burn 100 percent yard waste?
60.1925 How must I monitor opacity for air curtain incinerators that
burn 100 percent yard waste?
[[Page 14]]
60.1930 What are the recordkeeping and reporting requirements for air
curtain incinerators that burn 100 percent yard waste?
Equations
60.1935 What equations must I use?
Definitions
60.1940 What definitions must I know?
Table 1 to Subpart BBBB of Part 60--Model Rule--Compliance Schedules and
Increments of Progress
Table 2 to Subpart BBBB of Part 60--Model Rule--Class I Emission Limits
For Existing Small Municipal Waste Combustion Units
Table 3 to Subpart BBBB of Part 60--Model Rule--Class I Nitrogen Oxides
Emission Limits For Existing Small Municipal Waste Combustion
Units
Table 4 to Subpart BBBB of Part 60--Model Rule--Class II Emission Limits
For Existing Small Municipal Waste Combustion Units
Table 5 to Subpart BBBB of Part 60--Model Rule--Carbon Monoxide Emission
Limits For Existing Small Municipal Waste Combustion Units
Table 6 to Subpart BBBB of Part 60--Model Rule--Requirements for
Validating Continuous Emission Monitoring Systems (CEMS)
Table 7 to Subpart BBBB of Part 60--Model Rule--Requirements for
Continuous Emission Monitoring Systems (CEMS)
Table 8 to Subpart BBBB of Part 60--Model Rule--Requirements for Stack
Tests
Subpart CCCC_Standards of Performance for Commercial and Industrial
Solid Waste Incineration Units
Introduction
60.2000 What does this subpart do?
60.2005 When did this subpart become effective?
Applicability
60.2010 Does this subpart apply to my incineration unit?
60.2015 What is a new incineration unit?
60.2020 What combustion units are exempt from this subpart?
60.2030 Who implements and enforces this subpart?
60.2035 How are these new source performance standards structured?
60.2040 Do all eleven components of these new source performance
standards apply at the same time?
Preconstruction Siting Analysis
60.2045 Who must prepare a siting analysis?
60.2050 What is a siting analysis?
Waste Management Plan
60.2055 What is a waste management plan?
60.2060 When must I submit my waste management plan?
60.2065 What should I include in my waste management plan?
Operator Training and Qualification
60.2070 What are the operator training and qualification requirements?
60.2075 When must the operator training course be completed?
60.2080 How do I obtain my operator qualification?
60.2085 How do I maintain my operator qualification?
60.2090 How do I renew my lapsed operator qualification?
60.2095 What site-specific documentation is required?
60.2100 What if all the qualified operators are temporarily not
accessible?
Emission Limitations and Operating Limits
60.2105 What emission limitations must I meet and by when?
60.2110 What operating limits must I meet and by when?
60.2115 What if I do not use a wet scrubber, fabric filter, activated
carbon injection, selective noncatalytic reduction, an
electrostatic precipitator, or a dry scrubber to comply with
the emission limitations?
Performance Testing
60.2125 How do I conduct the initial and annual performance test?
60.2130 How are the performance test data used?
Initial Compliance Requirements
60.2135 How do I demonstrate initial compliance with the emission
limitations and establish the operating limits?
60.2140 By what date must I conduct the initial performance test?
60.2141 By what date must I conduct the initial air pollution control
device inspection?
Continuous Compliance Requirements
60.2145 How do I demonstrate continuous compliance with the emission
limitations and the operating limits?
60.2150 By what date must I conduct the annual performance test?
60.2151 By what date must I conduct the annual air pollution control
device inspection?
60.2155 May I conduct performance testing less often?
[[Page 15]]
60.2160 May I conduct a repeat performance test to establish new
operating limits?
Monitoring
60.2165 What monitoring equipment must I install and what parameters
must I monitor?
60.2170 Is there a minimum amount of monitoring data I must obtain?
Recordkeeping and Reporting
60.2175 What records must I keep?
60.2180 Where and in what format must I keep my records?
60.2185 What reports must I submit?
60.2190 What must I submit prior to commencing construction?
60.2195 What information must I submit prior to initial startup?
60.2200 What information must I submit following my initial performance
test?
60.2205 When must I submit my annual report?
60.2210 What information must I include in my annual report?
60.2215 What else must I report if I have a deviation from the operating
limits or the emission limitations?
60.2220 What must I include in the deviation report?
60.2225 What else must I report if I have a deviation from the
requirement to have a qualified operator accessible?
60.2230 Are there any other notifications or reports that I must submit?
60.2235 In what form can I submit my reports?
60.2240 Can reporting dates be changed?
Title V Operating Permits
60.2242 Am I required to apply for and obtain a Title V operating permit
for my unit?
Air Curtain Incinerators (ACIs)
60.2245 What is an air curtain incinerator?
60.2250 What are the emission limitations for air curtain incinerators?
60.2255 How must I monitor opacity for air curtain incinerators?
60.2260 What are the recordkeeping and reporting requirements for air
curtain incinerators?
Definitions
60.2265 What definitions must I know?
Table 1 to Subpart CCCC of Part 60--Emission Limitations for
Incinerators for Which Construction is Commenced After
November 30, 1999, But no Later Than June 4, 2010, or for
Which Modification or Reconstruction is Commenced on or After
June 1, 2001, But no Later Than August 7, 2013
Table 2 to Subpart CCCC of Part 60--Operating Limits for Wet Scrubbers
Table 3 to Subpart CCCC of Part 60--Toxic Equivalency Factors
Table 4 to Subpart CCCC of Part 60--Summary of Reporting Requirements
Table 5 to Subpart CCCC of Part 60--Emission Limitations for
Incinerators That Commenced Construction After June 4, 2010,
or That Commenced Reconstruction or Modification After August
7, 2013
Table 6 to Subpart CCCC of Part 60--Emission Limitations for Energy
Recovery Units That Commenced Construction After June 4, 2010,
or That Commenced Reconstruction or Modification After August
7, 2013
Table 7 to Subpart CCCC of Part 60--Emission Limitations for Waste-
Burning Kilns That Commenced Construction After June 4, 2010,
or Reconstruction or Modification After August 7, 2013
Table 8 to Subpart CCCC of Part 60--Emission Limitations for Small,
Remote Incinerators That Commenced Construction After June 4,
2010, or That Commenced Reconstruction or Modification After
August 7, 2013
Subpart DDDD_Emissions Guidelines and Compliance Times for Commercial
and Industrial Solid Waste Incineration Units
Introduction
60.2500 What is the purpose of this subpart?
60.2505 Am I affected by this subpart?
60.2510 Is a state plan required for all states?
60.2515 What must I include in my state plan?
60.2520 Is there an approval process for my state plan?
60.2525 What if my state plan is not approvable?
60.2530 Is there an approval process for a negative declaration letter?
60.2535 What compliance schedule must I include in my state plan?
60.2540 Are there any state plan requirements for this subpart that
apply instead of the requirements specified in subpart B?
60.2541 In lieu of a state plan submittal, are there other acceptable
option(s) for a state to meet its Clean Air Act section
111(d)/129(b)(2) obligations?
60.2542 What authorities will not be delegated to state, local, or
tribal agencies?
60.2545 Does this subpart directly affect CISWI owners and operators in
my state?
Applicability of State Plans
60.2550 What CISWIs must I address in my state plan?
[[Page 16]]
60.2555 What combustion units are exempt from my state plan?
Use of Model Rule
60.2560 What is the ``model rule'' in this subpart?
60.2565 How does the model rule relate to the required elements of my
state plan?
60.2570 What are the principal components of the model rule?
Model Rule--Increments of Progress
60.2575 What are my requirements for meeting increments of progress and
achieving final compliance?
60.2580 When must I complete each increment of progress?
60.2585 What must I include in the notifications of achievement of
increments of progress?
60.2590 When must I submit the notifications of achievement of
increments of progress?
60.2595 What if I do not meet an increment of progress?
60.2600 How do I comply with the increment of progress for submittal of
a control plan?
60.2605 How do I comply with the increment of progress for achieving
final compliance?
60.2610 What must I do if I close my CISWI and then restart it?
60.2615 What must I do if I plan to permanently close my CISWI and not
restart it?
Model Rule--Waste Management Plan
60.2620 What is a waste management plan?
60.2625 When must I submit my waste management plan?
60.2630 What should I include in my waste management plan?
Model Rule--Operator Training and Qualification
60.2635 What are the operator training and qualification requirements?
60.2640 When must the operator training course be completed?
60.2645 How do I obtain my operator qualification?
60.2650 How do I maintain my operator qualification?
60.2655 How do I renew my lapsed operator qualification?
60.2660 What site-specific documentation is required?
60.2665 What if all the qualified operators are temporarily not
accessible?
Model Rule--Emission Limitations and Operating Limits
60.2670 What emission limitations must I meet and by when?
60.2675 What operating limits must I meet and by when?
60.2680 What if I do not use a wet scrubber, fabric filter, activated
carbon injection, selective noncatalytic reduction, an
electrostatic precipitator, or a dry scrubber to comply with
the emission limitations?
Model Rule--Performance Testing
60.2690 How do I conduct the initial and annual performance test?
60.2695 How are the performance test data used?
Model Rule--Initial Compliance Requirements
60.2700 How do I demonstrate initial compliance with the amended
emission limitations and establish the operating limits?
60.2705 By what date must I conduct the initial performance test?
60.2706 By what date must I conduct the initial air pollution control
device inspection?
Model Rule--Continuous Compliance Requirements
60.2710 How do I demonstrate continuous compliance with the amended
emission limitations and the operating limits?
60.2715 By what date must I conduct the annual performance test?
60.2716 By what date must I conduct the annual air pollution control
device inspection?
60.2720 May I conduct performance testing less often?
60.2725 May I conduct a repeat performance test to establish new
operating limits?
Model Rule--Monitoring
60.2730 What monitoring equipment must I install and what parameters
must I monitor?
60.2735 Is there a minimum amount of monitoring data I must obtain?
Model Rule--Recordkeeping and Reporting
60.2740 What records must I keep?
60.2745 Where and in what format must I keep my records?
60.2750 What reports must I submit?
60.2755 When must I submit my waste management plan?
60.2760 What information must I submit following my initial performance
test?
60.2765 When must I submit my annual report?
60.2770 What information must I include in my annual report?
60.2775 What else must I report if I have a deviation from the operating
limits or the emission limitations?
60.2780 What must I include in the deviation report?
[[Page 17]]
60.2785 What else must I report if I have a deviation from the
requirement to have a qualified operator accessible?
60.2790 Are there any other notifications or reports that I must submit?
60.2795 In what form can I submit my reports?
60.2800 Can reporting dates be changed?
Model Rule--Title V Operating Permits
60.2805 Am I required to apply for and obtain a Title V operating permit
for my unit?
Model Rule--Air Curtain Incinerators (ACIs)
60.2810 What is an air curtain incinerator?
60.2815 What are my requirements for meeting increments of progress and
achieving final compliance?
60.2820 When must I complete each increment of progress?
60.2825 What must I include in the notifications of achievement of
increments of progress?
60.2830 When must I submit the notifications of achievement of
increments of progress?
60.2835 What if I do not meet an increment of progress?
60.2840 How do I comply with the increment of progress for submittal of
a control plan?
60.2845 How do I comply with the increment of progress for achieving
final compliance?
60.2850 What must I do if I close my air curtain incinerator and then
restart it?
60.2855 What must I do if I plan to permanently close my air curtain
incinerator and not restart it?
60.2860 What are the emission limitations for air curtain incinerators?
60.2865 How must I monitor opacity for air curtain incinerators?
60.2870 What are the recordkeeping and reporting requirements for air
curtain incinerators?
Model Rule--Definitions
60.2875 What definitions must I know?
Table 1 to Subpart DDDD of Part 60--Model Rule--Increments of Progress
and Compliance Schedules
Table 2 to Subpart DDDD of Part 60--Model Rule--Emission Limitations
That Apply to Incinerators Before [Date To Be Specified in
State Plan]
Table 3 to Subpart DDDD of Part 60--Model Rule--Operating Limits for Wet
Scrubbers
Table 4 to Subpart DDDD of Part 60--Model Rule--Toxic Equivalency
Factors
Table 5 to Subpart DDDD of Part 60--Model Rule--Summary of Reporting
Requirements
Table 6 to Subpart DDDD of Part 60--Model Rule--Emission Limitations
That Apply to Incinerators on and After [Date To Be Specified
in State Plan]
Table 7 to Subpart DDDD of Part 60--Model Rule--Emission Limitations
That Apply to Energy Recovery Units After May 20, 2011
Table 8 to Subpart DDDD of Part 60--Model Rule--Emission Limitations
That Apply to Waste-Burning Kilns After May 20, 2011
Table 9 to Subpart DDDD of Part 60--Model Rule--Emission Limitations
That Apply to Small, Remote Incinerators After May 20, 2011
[Date To Be Specified in State Plan]
Subpart EEEE_Standards of Performance for Other Solid Waste Incineration
Units for Which Construction is Commenced After December 9, 2004, or for
Which Modification or Reconstruction is Commenced on or After June 16,
2006
Introduction
60.2880 What does this subpart do?
60.2881 When does this subpart become effective?
Applicability
60.2885 Does this subpart apply to my incineration unit?
60.2886 What is a new incineration unit?
60.2887 What combustion units are excluded from this subpart?
60.2888 Are air curtain incinerators regulated under this subpart?
60.2889 Who implements and enforces this subpart?
60.2890 How are these new source performance standards structured?
60.2891 Do all components of these new source performance standards
apply at the same time?
Preconstruction Siting Analysis
60.2894 Who must prepare a siting analysis?
60.2895 What is a siting analysis?
Waste Management Plan
60.2899 What is a waste management plan?
60.2900 When must I submit my waste management plan?
60.2901 What should I include in my waste management plan?
Operator Training and Qualification
60.2905 What are the operator training and qualification requirements?
[[Page 18]]
60.2906 When must the operator training course be completed?
60.2907 How do I obtain my operator qualification?
60.2908 How do I maintain my operator qualification?
60.2909 How do I renew my lapsed operator qualification?
60.2910 What site-specific documentation is required?
60.2911 What if all the qualified operators are temporarily not
accessible?
Emission Limitations and Operating Limits
60.2915 What emission limitations must I meet and by when?
60.2916 What operating limits must I meet and by when?
60.2917 What if I do not use a wet scrubber to comply with the emission
limitations?
60.2918 What happens during periods of startup, shutdown, and
malfunction?
Performance Testing
60.2922 How do I conduct the initial and annual performance test?
60.2923 How are the performance test data used?
Initial Compliance Requirements
60.2927 How do I demonstrate initial compliance with the emission
limitations and establish the operating limits?
60.2928 By what date must I conduct the initial performance test?
Continuous Compliance Requirements
60.2932 How do I demonstrate continuous compliance with the emission
limitations and the operating limits?
60.2933 By what date must I conduct the annual performance test?
60.2934 May I conduct performance testing less often?
60.2935 May I conduct a repeat performance test to establish new
operating limits?
Monitoring
60.2939 What continuous emission monitoring systems must I install?
60.2940 How do I make sure my continuous emission monitoring systems are
operating correctly?
60.2941 What is my schedule for evaluating continuous emission
monitoring systems?
60.2942 What is the minimum amount of monitoring data I must collect
with my continuous emission monitoring systems, and is the
data collection requirement enforceable?
60.2943 How do I convert my 1-hour arithmetic averages into the
appropriate averaging times and units?
60.2944 What operating parameter monitoring equipment must I install,
and what operating parameters must I monitor?
60.2945 Is there a minimum amount of operating parameter monitoring data
I must obtain?
Recordkeeping and Reporting
60.2949 What records must I keep?
60.2950 Where and in what format must I keep my records?
60.2951 What reports must I submit?
60.2952 What must I submit prior to commencing construction?
60.2953 What information must I submit prior to initial startup?
60.2954 What information must I submit following my initial performance
test?
60.2955 When must I submit my annual report?
60.2956 What information must I include in my annual report?
60.2957 What else must I report if I have a deviation from the operating
limits or the emission limitations?
60.2958 What must I include in the deviation report?
60.2959 What else must I report if I have a deviation from the
requirement to have a qualified operator accessible?
60.2960 Are there any other notifications or reports that I must submit?
60.2961 In what form can I submit my reports?
60.2962 Can reporting dates be changed?
Title V Operating Permits
60.2966 Am I required to apply for and obtain a title V operating permit
for my unit?
60.2967 When must I submit a title V permit application for my new unit?
Temporary-Use Incinerators and Air Curtain Incinerators Used in Disaster
Recovery
60.2969 [Reserved]
Air Curtain Incinerators That Burn Only Wood Waste, Clean Lumber, and
Yard Waste
60.2970 What is an air curtain incinerator?
60.2971 What are the emission limitations for air curtain incinerators
that burn only wood waste, clean lumber, and yard waste?
60.2972 How must I monitor opacity for air curtain incinerators that
burn only wood waste, clean lumber, and yard waste?
60.2973 What are the recordkeeping and reporting requirements for air
curtain incinerators that burn only wood waste, clean lumber,
and yard waste?
60.2974 [Reserved]
Equations
60.2975 What equations must I use?
[[Page 19]]
Definitions
60.2977 What definitions must I know?
Tables to Subpart EEEE of Part 60
Table 1 to Subpart EEEE of Part 60--Emission Limitations
Table 2 to Subpart EEEE of Part 60--Operating Limits for Incinerators
and Wet Scrubbers
Table 3 to Subpart EEEE of Part 60--Requirements for Continuous Emission
Monitoring Systems (CEMS)
Table 4 to Subpart EEEE of Part 60--Summary of Reporting Requirements
Subpart FFFF_Emission Guidelines and Compliance Times for Other
Introduction
60.2980 What is the purpose of this subpart?
60.2981 Am I affected by this subpart?
60.2982 Is a State plan required for all States?
60.2983 What must I include in my State plan?
60.2984 Is there an approval process for my State plan?
60.2985 What if my State plan is not approvable?
60.2986 Is there an approval process for a negative declaration letter?
60.2987 What compliance schedule must I include in my State plan?
60.2988 Are there any State plan requirements for this subpart that
apply instead of the requirements specified in subpart B of
this part?
60.2989 Does this subpart directly affect incineration unit owners and
operators in my State?
60.2990 What Authorities are withheld by EPA?
Applicability of State Plans
60.2991 What incineration units must I address in my State plan?
60.2992 What is an existing incineration unit?
60.2993 Are any combustion units excluded from my State plan?
60.2994 Are air curtain incinerators regulated under this subpart?
Model Rule--Use of Model Rule
60.2996 What is the purpose of the ``model rule'' in this subpart?
60.2997 How does the model rule relate to the required elements of my
State plan?
60.2998 What are the principal components of the model rule?
Model Rule--Compliance Schedule
60.3000 When must I comply?
60.3001 What must I do if I close my OSWI unit and then restart it?
60.3002 What must I do if I plan to permanently close my OSWI unit and
not restart it?
Model Rule--Waste Management Plan
60.3010 What is a waste management plan?
60.3011 When must I submit my waste management plan?
60.3012 What should I include in my waste management plan?
Model Rule--Operator Training and Qualification
60.3014 What are the operator training and qualification requirements?
60.3015 When must the operator training course be completed?
60.3016 How do I obtain my operator qualification?
60.3017 How do I maintain my operator qualification?
60.3018 How do I renew my lapsed operator qualification?
60.3019 What site-specific documentation is required?
60.3020 What if all the qualified operators are temporarily not
accessible?
Model Rule--Emission Limitations and Operating Limits
60.3022 What emission limitations must I meet and by when?
60.3023 What operating limits must I meet and by when?
60.3024 What if I do not use a wet scrubber to comply with the emission
limitations?
60.3025 What happens during periods of startup, shutdown, and
malfunction?
Model Rule--Performance Testing
60.3027 How do I conduct the initial and annual performance test?
60.3028 How are the performance test data used?
Model Rule--Initial Compliance Requirements
60.3030 How do I demonstrate initial compliance with the emission
limitations and establish the operating limits?
60.3031 By what date must I conduct the initial performance test?
Model Rule--Continuous Compliance Requirements
60.3033 How do I demonstrate continuous compliance with the emission
limitations and the operating limits?
60.3034 By what date must I conduct the annual performance test?
60.3035 May I conduct performance testing less often?
60.3036 May I conduct a repeat performance test to establish new
operating limits?
[[Page 20]]
Model Rule--Monitoring
60.3038 What continuous emission monitoring systems must I install?
60.3039 How do I make sure my continuous emission monitoring systems are
operating correctly?
60.3040 What is my schedule for evaluating continuous emission
monitoring systems?
60.3041 What is the minimum amount of monitoring data I must collect
with my continuous emission monitoring systems, and is the
data collection requirement enforceable?
60.3042 How do I convert my 1-hour arithmetic averages into the
appropriate averaging times and units?
60.3043 What operating parameter monitoring equipment must I install,
and what operating parameters must I monitor?
60.3044 Is there a minimum amount of operating parameter monitoring data
I must obtain?
Model Rule--Recordkeeping and Reporting
60.3046 What records must I keep?
60.3047 Where and in what format must I keep my records?
60.3048 What reports must I submit?
60.3049 What information must I submit following my initial performance
test?
60.3050 When must I submit my annual report?
60.3051 What information must I include in my annual report?
60.3052 What else must I report if I have a deviation from the operating
limits or the emission limitations?
60.3053 What must I include in the deviation report?
60.3054 What else must I report if I have a deviation from the
requirement to have a qualified operator accessible?
60.3055 Are there any other notifications or reports that I must submit?
60.3056 In what form can I submit my reports?
60.3057 Can reporting dates be changed?
Model Rule--Title V Operating Permits
60.3059 Am I required to apply for and obtain a title V operating permit
for my unit?
60.3060 [Reserved]
Model Rule--Temporary-Use Incinerators and Air Curtain Incinerators Used
in Disaster Recovery
60.3061 What are the requirements for temporary-use incinerators and air
curtain incinerators used in disaster recovery?
Model Rule--Air Curtain Incinerators That Burn Only Wood Waste, Clean
Lumber, and Yard Waste
60.3062 What is an air curtain incinerator?
60.3063 When must I comply if my air curtain incinerator burns only wood
waste, clean lumber, and yard waste?
60.3064 What must I do if I close my air curtain incinerator that burns
only wood waste, clean lumber, and yard waste and then restart
it?
60.3065 What must I do if I plan to permanently close my air curtain
incinerator that burns only wood waste, clean lumber, and yard
waste and not restart it?
60.3066 What are the emission limitations for air curtain incinerators
that burn only wood waste, clean lumber, and yard waste?
60.3067 How must I monitor opacity for air curtain incinerators that
burn only wood waste, clean lumber, and yard waste?
60.3068 What are the recordkeeping and reporting requirements for air
curtain incinerators that burn only wood waste, clean lumber,
and yard waste?
60.3069 Am I required to apply for and obtain a title V operating permit
for my air curtain incinerator that burns only wood waste,
clean lumber, and yard waste?
Model Rule--Equations
60.3076 What equations must I use?
Model Rule--Definitions
60.3078 What definitions must I know?
Tables to Subpart FFFF of Part 60
Table 1 to Subpart FFFF of Part 60--Model Rule--Compliance Schedule
Table 2 to Subpart FFFF of Part 60--Model Rule--Emission Limitations
Table 3 to Subpart FFFF of Part 60--Model Rule--Operating Limits for
Incinerators and Wet Scrubbers
Table 4 to Subpart FFFF of Part 60--Model Rule--Requirements for
Continuous Emission Monitoring Systems (CEMS)
Table 5 to Subpart FFFF of Part 60--Model Rule--Summary of Reporting
Requirements \a\
Subparts GGGG-HHHH [Reserved]
Subpart IIII_Standards of Performance for Stationary Compression
Ignition Internal Combustion Engines
What This Subpart Covers
60.4200 Am I subject to this subpart?
Emission Standards for Manufacturers
60.4201 What emission standards must I meet for non-emergency engines if
I am a
[[Page 21]]
stationary CI internal combustion engine manufacturer?
60.4202 What emission standards must I meet for emergency engines if I
am a stationary CI internal combustion engine manufacturer?
60.4203 How long must my engines meet the emission standards if I am a
manufacturer of stationary CI internal combustion engines?
Emission Standards for Owners and Operators
60.4204 What emission standards must I meet for non-emergency engines if
I am an owner or operator of a stationary CI internal
combustion engine?
60.4205 What emission standards must I meet for emergency engines if I
am an owner or operator of a stationary CI internal combustion
engine?
60.4206 How long must I meet the emission standards if I am an owner or
operator of a stationary CI internal combustion engine?
Fuel Requirements for Owners and Operators
60.4207 What fuel requirements must I meet if I am an owner or operator
of a stationary CI internal combustion engine subject to this
subpart?
Other Requirements for Owners and Operators
60.4208 What is the deadline for importing or installing stationary CI
ICE produced in previous model years?
60.4209 What are the monitoring requirements if I am an owner or
operator of a stationary CI internal combustion engine?
Compliance Requirements
60.4210 What are my compliance requirements if I am a stationary CI
internal combustion engine manufacturer?
60.4211 What are my compliance requirements if I am an owner or operator
of a stationary CI internal combustion engine?
Testing Requirements for Owners and Operators
60.4212 What test methods and other procedures must I use if I am an
owner or operator of a stationary CI internal combustion
engine with a displacement of less than 30 liters per
cylinder?
60.4213 What test methods and other procedures must I use if I am an
owner or operator of a stationary CI internal combustion
engine with a displacement of greater than or equal to 30
liters per cylinder?
Notification, Reports, and Records for Owners and Operators
60.4214 What are my notification, reporting, and recordkeeping
requirements if I am an owner or operator of a stationary CI
internal combustion engine?
Special Requirements
60.4215 What requirements must I meet for engines used in Guam, American
Samoa, or the Commonwealth of the Northern Mariana Islands?
60.4216 What requirements must I meet for engines used in Alaska?
60.4217 What emission standards must I meet if I am an owner or operator
of a stationary internal combustion engine using special
fuels?
General Provisions
60.4218 What General Provisions and confidential information provisions
apply to me?
Definitions
60.4219 What definitions apply to this subpart?
Table 1 to Subpart IIII of Part 60--Emission Standards for Stationary
Pre-2007 Model Year Engines with a displacement of <10 liters
per cylinder and 2007-2010 Model Year Engines 2,237
KW (3,000 HP) and with a displacement of <10 liters per
cylinder
Table 2 to Subpart IIII of Part 60--Emission Standards for 2008 Model
Year and Later Emergency Stationary CI ICE <37 KW (50 HP) and
with a Displacement of <10 liters per cylinder
Table 3 to Subpart IIII of Part 60--Certification Requirements for
Stationary Fire Pump Engines
Table 4 to Subpart IIII of Part 60--Emission Standards for Stationary
Fire Pump Engines
Table 5 to Subpart IIII of Part 60--Labeling and Recordkeeping
Requirements for New Stationary Emergency Engines
Table 6 to Subpart IIII of Part 60--Optional 3-Mode Test Cycle for
Stationary Fire Pump Engines
Table 7 to Subpart IIII of Part 60--Requirements for Performance Tests
for Stationary CI ICE with a displacement of =30
liters per cylinder
[[Page 22]]
Table 8 to Subpart IIII of Part 60--Applicability of General Provisions
to Subpart IIII
Subpart JJJJ_Standards of Performance for Stationary Spark Ignition
Internal Combustion Engines
What This Subpart Covers
60.4230 Am I subject to this subpart?
Emission Standards for Manufacturers
60.4231 What emission standards must I meet if I am a manufacturer of
stationary SI internal combustion engines or equipment
containing such engines?
60.4232 How long must my engines meet the emission standards if I am a
manufacturer of stationary SI internal combustion engines?
Emission Standards for Owners and Operators
60.4233 What emission standards must I meet if I am an owner or operator
of a stationary SI internal combustion engine?
60.4234 How long must I meet the emission standards if I am an owner or
operator of a stationary SI internal combustion engine?
Other Requirements for Owners and Operators
60.4235 What fuel requirements must I meet if I am an owner or operator
of a stationary SI gasoline fired internal combustion engine
subject to this subpart?
60.4236 What is the deadline for importing or installing stationary SI
ICE produced in previous model years?
60.4237 What are the monitoring requirements if I am an owner or
operator of an emergency stationary SI internal combustion
engine?
Compliance Requirements for Manufacturers
60.4238 What are my compliance requirements if I am a manufacturer of
stationary SI internal combustion engines <=19 KW (25 HP) or a
manufacturer of equipment containing such engines?
60.4239 What are my compliance requirements if I am a manufacturer of
stationary SI internal combustion engines 19 KW (25
HP) that use gasoline or a manufacturer of equipment
containing such engines?
60.4240 What are my compliance requirements if I am a manufacturer of
stationary SI internal combustion engines 19 KW (25
HP) that are rich burn engines that use LPG or a manufacturer
of equipment containing such engines?
60.4241 What are my compliance requirements if I am a manufacturer of
stationary SI internal combustion engines participating in the
voluntary certification program or a manufacturer of equipment
containing such engines?
60.4242 What other requirements must I meet if I am a manufacturer of
stationary SI internal combustion engines or equipment
containing stationary SI internal combustion engines or a
manufacturer of equipment containing such engines?
Compliance Requirements for Owners and Operators
60.4243 What are my compliance requirements if I am an owner or operator
of a stationary SI internal combustion engine?
Testing Requirements for Owners and Operators
60.4244 What test methods and other procedures must I use if I am an
owner or operator of a stationary SI internal combustion
engine?
Notification, Reports, and Records for Owners and Operators
60.4245 What are my notification, reporting, and recordkeeping
requirements if I am an owner or operator of a stationary SI
internal combustion engine?
General Provisions
60.4246 What General Provisions and confidential information provisions
apply to me?
Mobile Source Provisions
60.4247 What parts of the mobile source provisions apply to me if I am a
manufacturer of stationary SI internal combustion engines or a
manufacturer of equipment containing such engines?
Definitions
60.4248 What definitions apply to this subpart?
Tables to Subpart JJJJ of Part 60
Table 1 to Subpart JJJJ of Part 60--NOX, CO, and VOC Emission
Standards for Stationary Non-Emergency SI Engines
=100 HP (Except Gasoline and Rich Burn LPG),
Stationary SI Landfill/Digester Gas Engines, and Stationary
Emergency Engines 25 HP
Table 2 to Subpart JJJJ of Part 60--Requirements for Performance Tests
Table 3 to Subpart JJJJ of Part 60--Applicability of General Provisions
to Subpart JJJJ
[[Page 23]]
Table 4 to Subpart JJJJ of Part 60--Applicability of Mobile Source
Provisions for Manufacturers Participating in the Voluntary
Certification Program and Certifying Stationary SI ICE to
Emission Standards in Table 1 of Subpart JJJJ
Subpart KKKK_Standards of Performance for Stationary Combustion Turbines
Introduction
60.4300 What is the purpose of this subpart?
Applicability
60.4305 Does this subpart apply to my stationary combustion turbine?
60.4310 What types of operations are exempt from these standards of
performance?
Emission Limits
60.4315 What pollutants are regulated by this subpart?
60.4320 What emission limits must I meet for nitrogen oxides
(NOX)?
60.4325 What emission limits must I meet for NOX if my
turbine burns both natural gas and distillate oil (or some
other combination of fuels)?
60.4330 What emission limits must I meet for sulfur dioxide
(SO2)?
General Compliance Requirements
60.4333 What are my general requirements for complying with this
subpart?
Monitoring
60.4335 How do I demonstrate compliance for NOX if I use
water or steam injection?
60.4340 How do I demonstrate continuous compliance for NOX if
I do not use water or steam injection?
60.4345 What are the requirements for the continuous emission monitoring
system equipment, if I choose to use this option?
60.4350 How do I use data from the continuous emission monitoring
equipment to identify excess emissions?
60.4355 How do I establish and document a proper parameter monitoring
plan?
60.4360 How do I determine the total sulfur content of the turbine's
combustion fuel?
60.4365 How can I be exempted from monitoring the total sulfur content
of the fuel?
60.4370 How often must I determine the sulfur content of the fuel?
Reporting
60.4375 What reports must I submit?
60.4380 How are excess emissions and monitor downtime defined for
NOX?
60.4385 How are excess emissions and monitoring downtime defined for
SO2?
60.4390 What are my reporting requirements if I operate an emergency
combustion turbine or a research and development turbine?
60.4395 When must I submit my reports?
Performance Tests
60.4400 How do I conduct the initial and subsequent performance tests,
regarding NOX?
60.4405 How do I perform the initial performance test if I have chosen
to install a NOX-diluent CEMS?
60.4410 How do I establish a valid parameter range if I have chosen to
continuously monitor parameters?
60.4415 How do I conduct the initial and subsequent performance tests
for sulfur?
Definitions
60.4420 What definitions apply to this subpart?
Table 1 to Subpart KKKK of Part 60--Nitrogen Oxide Emission Limits for
New Stationary Combustion Turbines
Subpart LLLL_Standards of Performance for New Sewage Sludge Incineration
Units
Introduction
60.4760 What does this subpart do?
60.4765 When does this subpart become effective?
Applicability and Delegation of Authority
60.4770 Does this subpart apply to my sewage sludge incineration unit?
60.4775 What is a new sewage sludge incineration unit?
60.4780 What sewage sludge incineration units are exempt from this
subpart?
60.4785 Who implements and enforces this subpart?
60.4790 How are these new source performance standards structured?
60.4795 Do all nine components of these new source performance standards
apply at the same time?
Preconstruction Siting Analysis
60.4800 Who must prepare a siting analysis?
60.4805 What is a siting analysis?
Operator Training and Qualification
60.4810 What are the operator training and qualification requirements?
60.4815 When must the operator training course be completed?
60.4820 How do I obtain my operator qualification?
60.4825 How do I maintain my operator qualification?
60.4830 How do I renew my lapsed operator qualification?
[[Page 24]]
60.4835 What if all the qualified operators are temporarily not
accessible?
60.4840 What site-specific documentation is required and how often must
it be reviewed by qualified operators and plant personnel?
Emission Limits, Emission Standards, and Operating Limits and
Requirements
60.4845 What emission limits and standards must I meet and by when?
60.4850 What operating limits and requirements must I meet and by when?
60.4855 How do I establish operating limits if I do not use a wet
scrubber, fabric filter, electrostatic precipitator, or
activated carbon injection, or if I limit emissions in some
other manner, to comply with the emission limits?
60.4860 Do the emission limits, emission standards, and operating limits
apply during periods of startup, shutdown, and malfunction?
60.4861 How do I establish affirmative defense for exceedance of an
emission limit or standard during malfunction?
Initial Compliance Requirements
60.4865 How and when do I demonstrate initial compliance with the
emission limits and standards?
60.4870 How do I establish my operating limits?
60.4875 By what date must I conduct the initial air pollution control
device inspection and make any necessary repairs?
60.4880 How do I develop a site-specific monitoring plan for my
continuous monitoring, bag leak detection, and ash handling
systems, and by what date must I conduct an initial
performance evaluation?
Continuous Compliance Requirements
60.4885 How and when do I demonstrate continuous compliance with the
emission limits and standards?
60.4890 How do I demonstrate continuous compliance with my operating
limits?
60.4895 By what date must I conduct annual air pollution control device
inspections and make any necessary repairs?
Performance Testing, Monitoring, and Calibration Requirements
60.4900 What are the performance testing, monitoring, and calibration
requirements for compliance with the emission limits and
standards?
60.4905 What are the monitoring and calibration requirements for
compliance with my operating limits?
Recordkeeping and Reporting
60.4910 What records must I keep?
60.4915 What reports must I submit?
Title V Operating Permits
60.4920 Am I required to apply for and obtain a Title V operating permit
for my unit?
60.4925 When must I submit a title V permit application for my new SSI
unit?
Definitions
60.4930 What definitions must I know?
Tables
Table 1 to Subpart LLLL of Part 60--Emission Limits and Standards for
Fluidized Bed New Sewage Sludge Incineration Units
Table 2 to Subpart LLLL of Part 60--Emission Limits and Standards for
New Multiple Hearth Sewage Sludge Incineration Units
Table 3 to Subpart LLLL of Part 60--Operating Parameters for New Sewage
Sludge Incineration Units
Table 4 to Subpart LLLL of Part 60--Toxic Equivalency Factors
Table 5 to Subpart LLLL of Part 60--Summary of Reporting Requirements
for New Sewage Sludge Incineration Units
Subpart MMMM_Emission Guidelines and Compliance Times for Existing
Sewage Sludge Incineration Units
Introduction
60.5000 What is the purpose of this subpart?
60.5005 Am I affected by this subpart?
60.5010 Is a state plan required for all states?
60.5015 What must I include in my state plan?
60.5020 Is there an approval process for my state plan?
60.5025 What if my state plan is not approvable?
60.5030 Is there an approval process for a negative declaration letter?
60.5035 What compliance schedule must I include in my state plan?
60.5040 Are there any state plan requirements for this subpart that
apply instead of the requirements specified in subpart B?
60.5045 In lieu of a state plan submittal, are there other acceptable
option(s) for a state to meet its section 111(d)/129 (b)(2)
obligations?
60.5050 What authorities will not be delegated to state, local, or
tribal agencies?
60.5055 Does this subpart directly affect SSI unit owners and operators
in my state?
Applicability of State Plans
60.5060 What SSI units must I address in my state plan?
60.5065 What SSI units are exempt from my state plan?
[[Page 25]]
Use of Model Rule
60.5070 What is the ``model rule'' in this subpart?
60.5075 How does the model rule relate to the required elements of my
state plan?
60.5080 What are the principal components of the model rule?
Model Rule--Increments of Progress
60.5085 What are my requirements for meeting increments of progress and
achieving final compliance?
60.5090 When must I complete each increment of progress?
60.5095 What must I include in the notifications of achievement of
increments of progress?
60.5100 When must I submit the notifications of achievement of
increments of progress?
60.5105 What if I do not meet an increment of progress?
60.5110 How do I comply with the increment of progress for submittal of
a control plan?
60.5115 How do I comply with the increment of progress for achieving
final compliance?
60.5120 What must I do if I close my SSI unit and then restart it?
60.5125 What must I do if I plan to permanently close my SSI unit and
not restart it?
Model Rule--Operator Training and Qualification
60.5130 What are the operator training and qualification requirements?
60.5135 When must the operator training course be completed?
60.5140 How do I obtain my operator qualification?
60.5145 How do I maintain my operator qualification?
60.5150 How do I renew my lapsed operator qualification?
60.5155 What if all the qualified operators are temporarily not
accessible?
60.5160 What site-specific documentation is required and how often must
it be reviewed by qualified operators and plant personnel?
Model Rule--Emission Limits, Emission Standards, and Operating Limits
and Requirements
60.5165 What emission limits and standards must I meet and by when?
60.5170 What operating limits and requirements must I meet and by when?
60.5175 How do I establish operating limits if I do not use a wet
scrubber, fabric filter, electrostatic precipitator, activated
carbon injection, or afterburner, or if I limit emissions in
some other manner, to comply with the emission limits?
60.5180 Do the emission limits, emission standards, and operating limits
apply during periods of startup, shutdown, and malfunction?
60.5181 How do I establish affirmative defense for exceedance of an
emission limit or standard during malfunction?
Model Rule--Initial Compliance Requirements
60.5185 How and when do I demonstrate initial compliance with the
emission limits and standards?
60.5190 How do I establish my operating limits?
60.5195 By what date must I conduct the initial air pollution control
device inspection and make any necessary repairs?
60.5200 How do I develop a site-specific monitoring plan for my
continuous monitoring, bag leak detection, and ash handling
systems, and by what date must I conduct an initial
performance evaluation?
Model Rule--Continuous Compliance Requirements
60.5205 How and when do I demonstrate continuous compliance with the
emission limits and standards?
60.5210 How do I demonstrate continuous compliance with my operating
limits?
60.5215 By what date must I conduct annual air pollution control device
inspections and make any necessary repairs?
Model Rule--Performance Testing, Monitoring, and Calibration
Requirements
60.5220 What are the performance testing, monitoring, and calibration
requirements for compliance with the emission limits and
standards?
60.5225 What are the monitoring and calibration requirements for
compliance with my operating limits?
Model Rule--Recordkeeping and Reporting
60.5230 What records must I keep?
60.5235 What reports must I submit?
Model Rule--Title V Operating Permits
60.5240 Am I required to apply for and obtain a title V operating permit
for my existing SSI unit?
60.5245 When must I submit a title V permit application for my existing
SSI unit?
Model Rule--Definitions
60.5250 What definitions must I know?
Tables
Table 1 to Subpart MMMM of Part 60--Model Rule--Increments of Progress
[[Page 26]]
and Compliance Schedules for Existing Sewage Sludge
Incineration Units
Table 2 to Subpart MMMM of Part 60--Model Rule--Emission Limits and
Standards for Existing Fluidized Bed Sewage Sludge
Incineration Units
Table 3 to Subpart MMMM of Part 60--Model Rule--Emission Limits and
Standards for Existing Multiple Hearth Sewage Sludge
Incineration Units
Table 4 to Subpart MMMM of Part 60--Model Rule--Operating Parameters for
Existing Sewage Sludge Incineration Units
Table 5 to Subpart MMMM of Part 60--Model Rule--Toxic Equivalency
Factors
Table 6 to Subpart MMMM of Part 60--Model Rule--Summary of Reporting
Requirements for Existing Sewage Sludge Incineration Units
Subpart NNNN [Reserved]
Subpart OOOO_Standards of Performance for Crude Oil and Natural Gas
Facilities for Which Construction, Modification, or Reconstruction
Commenced After August 23, 2011, and on or Before September 18, 2015
60.5360 What is the purpose of this subpart?
60.5365 Am I subject to this subpart?
60.5370 When must I comply with this subpart?
60.5371 What standards apply to super-emitter events?
60.5375 What standards apply to gas well affected facilities?
60.5380 What standards apply to centrifugal compressor affected
facilities?
60.5385 What standards apply to reciprocating compressor affected
facilities?
60.5390 What standards apply to pneumatic controller affected
facilities?
60.5395 What standards apply to storage vessel affected facilities?
60.5400 What equipment leak standards apply to affected facilities at an
onshore natural gas processing plant?
60.5401 What are the exceptions to the equipment leak standards for
affected facilities at onshore natural gas processing plants?
60.5402 What are the alternative emission limitations for equipment
leaks from onshore natural gas processing plants?
60.5405 What standards apply to sweetening units at onshore natural gas
processing plants?
60.5406 What test methods and procedures must I use for my sweetening
units affected facilities at onshore natural gas processing
plants?
60.5407 What are the requirements for monitoring of emissions and
operations from my sweetening unit affected facilities at
onshore natural gas processing plants?
60.5408 What is an optional procedure for measuring hydrogen sulfide in
acid gas--Tutwiler Procedure?
60.5410 How do I demonstrate initial compliance with the standards for
my gas well affected facility, my centrifugal compressor
affected facility, my reciprocating compressor affected
facility, my pneumatic controller affected facility, my
storage vessel affected facility, and my equipment leaks and
sweetening unit affected facilities at onshore natural gas
processing plants?
60.5411 What additional requirements must I meet to determine initial
compliance for my covers and closed vent systems routing
materials from storage vessels, reciprocating compressors and
centrifugal compressor wet seal degassing systems?
60.5412 What additional requirements must I meet for determining initial
compliance with control devices used to comply with the
emission standards for my storage vessel or centrifugal
compressor affected facility?
60.5413 What are the performance testing procedures for control devices
used to demonstrate compliance at my storage vessel or
centrifugal compressor affected facility?
60.5415 How do I demonstrate continuous compliance with the standards
for my gas well affected facility, my centrifugal compressor
affected facility, my stationary reciprocating compressor
affected facility, my pneumatic controller affected facility,
my storage vessel affected facility, and my affected
facilities at onshore natural gas processing plants?
60.5416 What are the initial and continuous cover and closed vent system
inspection and monitoring requirements for my storage vessel,
centrifugal compressor and reciprocating compressor affected
facilities?
60.5417 What are the continuous control device monitoring requirements
for my storage vessel or centrifugal compressor affected
facility?
60.5420 What are my notification, reporting, and recordkeeping
requirements?
60.5421 What are my additional recordkeeping requirements for my
affected facility subject to VOC requirements for onshore
natural gas processing plants?
60.5422 What are my additional reporting requirements for my affected
facility subject to VOC requirements for onshore natural gas
processing plants?
60.5423 What additional recordkeeping and reporting requirements apply
to my sweetening unit affected facilities at onshore natural
gas processing plants?
[[Page 27]]
60.5425 What parts of the General Provisions apply to me?
60.5430 What definitions apply to this subpart?
Table 1 to Subpart OOOO of Part 60--Required Minimum Initial
SO2 Emission Reduction Efficiency (Zi)
Table 2 to Subpart OOOO of Part 60--Required Minimum SO2
Emission Reduction Efficiency (Zc)
Table 3 to Subpart OOOO of Part 60--Applicability of General Provisions
to Subpart OOOO
Subpart OOOOa_Standards of Performance for Crude Oil and Natural Gas
Facilities for Which Construction, Modification or Reconstruction
Commenced After September 18, 2015 and On or Before December 6, 2022
60.5360a What is the purpose of this subpart?
60.5365a Am I subject to this subpart?
60.5370a When must I comply with this subpart?
60.5371a What standards apply to super-emitter events?
60.5375a What GHG and VOC standards apply to well affected facilities?
60.5380a What GHG and VOC standards apply to centrifugal compressor
affected facilities?
60.5385a What GHG and VOC standards apply to reciprocating compressor
affected facilities?
60.5390a What GHG and VOC standards apply to pneumatic controller
affected facilities?
60.5393a What GHG and VOC standards apply to pneumatic pump affected
facilities?
60.5395a What VOC standards apply to storage vessel affected facilities?
60.5397a What fugitive emissions GHG and VOC standards apply to the
affected facility which is the collection of fugitive
emissions components at a well site and the affected facility
which is the collection of fugitive emissions components at a
compressor station?
60.5398a What are the alternative means of emission limitations for GHG
and VOC from well completions, reciprocating compressors, the
collection of fugitive emissions components at a well site and
the collection of fugitive emissions components at a
compressor station?
60.5399a What alternative fugitive emissions standards apply to the
affected facility which is the collection of fugitive
emissions components at a well site and the affected facility
which is the collection of fugitive emissions components at a
compressor station: Equivalency with state, local, and tribal
programs?
60.5400a What equipment leak GHG and VOC standards apply to affected
facilities at an onshore natural gas processing plant?
60.5401a What are the exceptions to the equipment leak GHG and VOC
standards for affected facilities at onshore natural gas
processing plants?
60.5402a What are the alternative means of emission limitations for GHG
and VOC equipment leaks from onshore natural gas processing
plants?
60.5405a What standards apply to sweetening unit affected facilities?
60.5406a What test methods and procedures must I use for my sweetening
unit affected facilities?
60.5407a What are the requirements for monitoring of emissions and
operations from my sweetening unit affected facilities?
60.5408a What is an optional procedure for measuring hydrogen sulfide in
acid gas--Tutwiler Procedure?
60.5410a How do I demonstrate initial compliance with the standards for
my well, centrifugal compressor, reciprocating compressor,
pneumatic controller, pneumatic pump, storage vessel,
collection of fugitive emissions components at a well site,
collection of fugitive emissions components at a compressor
station, and equipment leaks at onshore natural gas processing
plants and sweetening unit affected facilities?
60.5411a What additional requirements must I meet to determine initial
compliance for my covers and closed vent systems routing
emissions from centrifugal compressor wet seal fluid degassing
systems, reciprocating compressors, pneumatic pumps and
storage vessels?
60.5412a What additional requirements must I meet for determining
initial compliance with control devices used to comply with
the emission standards for my centrifugal compressor, and
storage vessel affected facilities?
60.5413a What are the performance testing procedures for control devices
used to demonstrate compliance at my centrifugal compressor
and storage vessel affected facilities?
60.5415a How do I demonstrate continuous compliance with the standards
for my well, centrifugal compressor, reciprocating compressor,
pneumatic controller, pneumatic pump, storage vessel,
collection of fugitive emissions components at a well site,
and collection of fugitive emissions components at a
compressor station affected facilities, equipment leaks at
onshore natural gas processing plants and sweetening unit
affected facilities?
60.5416a What are the initial and continuous cover and closed vent
system inspection
[[Page 28]]
and monitoring requirements for my centrifugal compressor,
reciprocating compressor, pneumatic pump, and storage vessel
affected facilities?
60.5417a What are the continuous control device monitoring requirements
for my centrifugal compressor and storage vessel affected
facilities?
60.5420a What are my notification, reporting, and recordkeeping
requirements?
60.5421a What are my additional recordkeeping requirements for my
affected facility subject to GHG and VOC requirements for
onshore natural gas processing plants?
60.5422a What are my additional reporting requirements for my affected
facility subject to GHG and VOC requirements for onshore
natural gas processing plants?
60.5423a What additional recordkeeping and reporting requirements apply
to my sweetening unit affected facilities?
60.5425a What parts of the General Provisions apply to me?
60.5430a What definitions apply to this subpart?
60.5432a How do I determine whether a well is a low pressure well using
the low pressure well equation?
60.5433a-60.5439a [Reserved]
Table 1 to Subpart OOOOa of Part 60--Required Minimum Initial
SO2 Emission Reduction Efficiency (Zi)
Table 2 to Subpart OOOOa of Part 60--Required Minimum SO2
Emission Reduction Efficiency (Zc)
Table 3 to Subpart OOOOa of Part 60--Applicability of General Provisions
to Subpart OOOOa
Subpart OOOOb_Standards of Performance for Crude Oil and Natural Gas
Facilities for Which Construction, Modification or Reconstruction
Commenced After December 6, 2022
60.5360b What is the purpose of this subpart?
60.5365b Am I subject to this subpart?
60.5370b When must I comply with this subpart?
60.5371b What GHG and VOC standards apply to super-emitter events?
60.5375b What GHG and VOC standards apply to well completions at well
affected facilities?
60.5376b What GHG and VOC standards apply to gas well liquids unloading
operations at well affected facilities?
60.5377b What GHG and VOC standards apply to associated gas wells at
well affected facilities?
60.5380b What GHG and VOC standards apply to centrifugal compressor
affected facilities?
60.5385b What GHG and VOC standards apply to reciprocating compressor
affected facilities?
60.5386b What test methods and procedures must I use for my centrifugal
compressor and reciprocating compressor affected facilities?
60.5390b What GHG and VOC standards apply to process controller affected
facilities?
60.5393b What GHG and VOC standards apply to pump affected facilities?
60.5395b What GHG and VOC standards apply to storage vessel affected
facilities?
60.5397b What GHG and VOC standards apply to fugitive emissions
components affected facilities?
60.5398b What alternative GHG and VOC standards apply to fugitive
emissions components affected facilities and what inspection
and monitoring requirements apply to covers and closed vent
systems when using an alternative technology?
60.5399b What are the alternative means of emission limitations for GHG
and VOC from well completions, liquids unloading operations,
centrifugal compressors, reciprocating compressors, fugitive
emissions components, and process unit equipment affected
facilities; and what are the alternative fugitive emissions
standards based on State, local, and Tribal programs?
60.5400b What GHG and VOC standards apply to process unit equipment
affected facilities?
60.5401b What are the alternative GHG and VOC standards for process unit
equipment affected facilities?
60.5402b What are the exceptions to the GHG and VOC standards for
process unit equipment affected facilities?
60.5403b What test methods and procedures must I use for my process unit
equipment affected facilities?
60.5405b What standards apply to sweetening unit affected facilities?
60.5406b What test methods and procedures must I use for my sweetening
unit affected facilities?
60.5407b What are the requirements for monitoring of emissions and
operations from my sweetening unit affected facilities?
60.5408b What is an optional procedure for measuring hydrogen sulfide in
acid gas--Tutwiler Procedure?
60.5410b How do I demonstrate initial compliance with the standards for
each of my affected facilities?
60.5411b What additional requirements must I meet to determine initial
compliance for my covers and closed vent systems?
60.5412b What additional requirements must I meet for determining
initial compliance of my control devices?
[[Page 29]]
60.5413b What are the performance testing procedures for control
devices?
60.5415b How do I demonstrate continuous compliance with the standards
for each of my affected facilities?
60.5416b What are the initial and continuous cover and closed vent
system inspection and monitoring requirements?
60.5417b What are the continuous monitoring requirements for my control
devices?
60.5420b What are my notification, reporting, and recordkeeping
requirements?
60.5421b What are my additional recordkeeping requirements for process
unit equipment affected facilities?
60.5422b What are my additional reporting requirements for process unit
equipment affected facilities?
60.5423b What are my additional recordkeeping and reporting requirements
for sweetening unit affected facilities?
60.5424b What are my additional recordkeeping and reporting requirements
if I comply with the alternative GHG and VOC standards for
fugitive emissions components affected facilities and covers
and closed vent systems?
60.5425b What parts of the General Provisions apply to me?
60.5430b What definitions apply to this subpart?
60.5432b How do I determine whether a well is a low pressure well using
the low pressure well equation?
60.5433b-60.5439b [Reserved]
Table 1 to Subpart OOOOb of Part 60--Alternative Technology Periodic
Screening Frequency at Well Sites, Centralized Production
Facilities, and Compressor Stations Subject to AVO Inspections
With Quarterly OGI or EPA Method 21 Monitoring
Table 2 to Subpart OOOOb of Part 60--Alternative Technology Periodic
Screening Frequency at Well Sites and Centralized Production
Facilities Subject to AVO Inspections and/or Semiannual OGI or
EPA Method 21 Monitoring
Table 3 to Subpart OOOOb of Part 60--Required Minimum Initial SO2
Emission Reduction Efficiency (Zi)
Table 4 to Subpart OOOOb of Part 60--Required Minimum SO2 Emission
Reduction Efficiency (Zc)
Table 5 to Subpart OOOOb of Part 60--Applicability of General Provisions
to Subpart OOOOb
Subpart OOOOc_Emissions Guidelines for Greenhouse Gas Emissions From
Existing Crude Oil and Natural Gas Facilities
Introduction
60.5360c What is the purpose of this subpart?
60.5361c Which pollutants are regulated by this subpart?
60.5362c Am I affected by this subpart?
60.5363c What must I include in my state or Tribal plan?
60.5364c How do I apply to use my state standards as part of my state or
Tribal plan submission?
60.5365c How do I apply for a less stringent standard taking into
consideration the remaining useful life of a designated
facility and other factors?
60.5366c [Reserved]
60.5367c Is there an approval process for my state or Tribal plan?
60.5368c What if my state or Tribal plan is not approvable?
60.5369c Is there an approval process for a negative declaration letter?
60.5370c What compliance schedule must I include in my state or Tribal
plan?
60.5371c What requirements apply to revisions to my state or Tribal
plan?
60.5372c In lieu of a state or Tribal plan submittal, are there other
acceptable option(s) for a state to meet its Clean Air Act
section 111(d) obligations?
60.5373c What authorities will not be delegated to state, local, or
Tribal agencies?
60.5374c Does this subpart directly affect designated facility owners
and operators in my state?
Applicability of State or Tribal Plans
60.5375c What designated facilities must I address in my state or Tribal
plan?
Use of Model Rule
60.5376c What is the ``model rule'' in this subpart?
60.5377c How does the model rule relate to the required elements of my
state or Tribal plan?
60.5378c What are the principal components of the model rule?
Model Rule--Increments of Progress
60.5379c What are my requirements for meeting increments of progress and
achieving final compliance?
60.5380c What if I do not meet the final control plan increment of
progress compliance date?
60.5381c How do I comply with the increment of progress for submittal of
a final compliance control plan?
Model Rule--Applicability
60.5385c What is the purpose of this subpart?
60.5386c Am I subject to this subpart?
60.5387c When must I comply with this subpart?
[[Page 30]]
Model Rule--Emission and Work Practice Standards
60.5388c What standards apply to super-emitter events?
60.5390c What GHG standards apply to gas well liquids unloading
operations at well designated facilities?
60.5391c What GHG standards apply to associated gas wells at well
designated facilities?
60.5392c What GHG standards apply to centrifugal compressor designated
facilities?
60.5393c What GHG standards apply to reciprocating compressor designated
facilities?
60.5394c What GHG standards apply to process controller designated
facilities?
60.5395c What GHG standards apply to pump designated facilities?
60.5396c What GHG standards apply to storage vessel designated
facilities?
60.5397c What GHG standards apply to fugitive emissions components
designated facilities?
60.5398c What alternative GHG standards apply to fugitive emissions
components designated facilities and what monitoring and
inspection requirements apply to covers and closed vent
systems when using an alternative technology?
60.5400c What GHG standards apply to process unit equipment designated
facilities?
60.5401c What are the alternative GHG standards for process unit
equipment designated facilities?
60.5402c What are the exceptions to the GHG standards for process unit
equipment designated facilities?
Model Rule--Test Methods and Performance Testing
60.5405c What test methods and procedures must I use for my centrifugal
compressor and reciprocating compressor designated facilities?
60.5406c What test methods and procedures must I use for my process unit
equipment designated facilities?
Model Rule--Initial Compliance Requirements
60.5410c How do I demonstrate initial compliance with the standards for
each of my designated facilities?
60.5411c What additional requirements must I meet to determine initial
compliance for my covers and closed vent systems?
60.5412c What additional requirements must I meet for determining
initial compliance of my control devices?
60.5413c What are the performance testing procedures for control
devices?
Model Rule--Continuous Compliance Requirements
60.5415c How do I demonstrate continuous compliance with the standards
for each of my designated facilities?
60.5416c What are the initial and continuous cover and closed vent
system inspection and monitoring requirements?
60.5417c What are the continuous monitoring requirements for my control
devices?
Model Rule--Recordkeeping and Reporting
60.5420c What are my notification, reporting, and recordkeeping
requirements?
60.5421c What are my additional recordkeeping requirements for process
unit equipment designated facilities?
60.5422c What are my additional reporting requirements for process unit
equipment designated facilities?
60.5424c What are my additional recordkeeping and reporting requirements
if I comply with the alternative GHG standards for fugitive
emissions components designated facilities and covers and
closed vent systems?
60.5425c What parts of the General Provisions apply to me?
Model Rule--Definitions
60.5430c What definitions apply to this subpart?
60.5431c-60.5439c [Reserved]
Table 1 to Subpart OOOOc of Part 60--Designated Facility Presumptive
Standards and Regulated Entity Compliance Dates
Table 2 to Subpart OOOOc of Part 60--Alternative Technology Periodic
Screening Frequency at Well Sites, Centralized Production
Facilities, and Compressor Stations Subject to AVO Inspections
With Quarterly OGI or EPA Method 21 Monitoring
Table 3 to Subpart OOOOc of Part 60--Alternative Technology Periodic
Screening Frequency at Well Sites and Centralized Production
Facilities Subject to AVO Inspections and/or Semiannual OGI or
EPA Method 21 Monitoring
Table 4 to Subpart OOOOc of Part 60--Applicability of General Provisions
to Subpart OOOOc
Subpart PPPP [Reserved]
Subpart QQQQ_Standards of Performance for New Residential Hydronic
Heaters and Forced-Air Furnaces
60.5472 Am I subject to this subpart?
60.5473 What definitions must I know?
[[Page 31]]
60.5474 What standards and requirements must I meet and by when?
60.5475 What compliance and certification requirements must I meet and
by when?
60.5476 What test methods and procedures must I use to determine
compliance with the standards and requirements for
certification?
60.5477 What procedures must I use for EPA approval of a test laboratory
or EPA approval of a third-party certifier?
60.5478 What requirements must I meet for permanent labels, temporary
labels (hangtags), and owner's manuals?
60.5479 What records must I keep and what reports must I submit?
60.5480 What activities are prohibited under this subpart?
60.5481 What hearing and appeal procedures apply to me?
60.5482 Who implements and enforces this subpart?
60.5483 What parts of the General Provisions do not apply to me?
Subparts RRRR-SSSS [Reserved]
Subpart TTTT_Standards of Performance for Greenhouse Gas Emissions for
Electric Generating Units
Applicability
60.5508 What is the purpose of this subpart?
60.5509 Am I subject to this subpart?
Emission Standards
60.5515 Which pollutants are regulated by this subpart?
60.5520 What CO2 emissions standard must I meet?
General Compliance Requirements
60.5525 What are my general requirements for complying with this
subpart?
Monitoring and Compliance Determination Procedures
60.5535 How do I monitor and collect data to demonstrate compliance?
60.5540 How do I demonstrate compliance with my CO[ihel2] emissions
standard and determine excess emissions?
Notifications, Reports, and Records
60.5550 What notifications must I submit and when?
60.5555 What reports must I submit and when?
60.5560 What records must I maintain?
60.5565 In what form and how long must I keep my records?
Other Requirements and Information
60.5570 What parts of the general provisions apply to my affected EGU?
60.5575 Who implements and enforces this subpart?
60.5580 What definitions apply to this subpart?
Table 1 to Subpart TTTT of Part 60--CO2 Emission Standards
for Affected Steam Generating Units and Integrated
Gasification Combined Cycle Facilities That Commenced
Construction After January 8, 2014 and Reconstruction or
Modification After June 18, 2014
Table 2 to Subpart TTTT of Part 60--CO2 Emission Standards
for Affected Stationary Combustion Turbines That Commenced
Construction After January 8, 2014 and Reconstruction After
June 18, 2014 (Net Energy Output-Based Standards Applicable as
Approved by the Administrator)
Table 3 to Subpart TTTT of Part 60--Applicability of Subpart A of Part
60 (General Provisions) to Subpart TTTT
Subpart TTTTa_Standards of Performance for Greenhouse Gas Emissions for
Modified Coal-Fired Steam Electric Generating Units and New Construction
and Reconstruction Stationary Combustion Turbine Electric Generating
Units
Applicability
60.5508a What is the purpose of this subpart?
60.5509a Am I subject to this subpart?
Emissions Standards
60.5515a Which pollutants are regulated by this subpart?
60.5520a What CO2 emissions standard must I meet?
60.5525a What are my general requirements for complying with this
subpart?
Monitoring and Compliance Determination Procedures
60.5535a How do I monitor and collect data to demonstrate compliance?
60.5540a How do I demonstrate compliance with my CO2
emissions standard and determine excess emissions?
Notification, Reports, and Records
60.5550a What notifications must I submit and when?
60.5555a What reports must I submit and when?
60.5560a What records must I maintain?
60.5565a In what form and how long must I keep my records?
Other Requirements and Information
60.5570a What parts of the general provisions apply to my affected EGU?
60.5575a Who implements and enforces this subpart?
[[Page 32]]
60.5580a What definitions apply to this subpart?
Table 1 to Subpart TTTTa of Part 60--CO2 Emission Standards
for Affected Stationary Combustion Turbines That Commenced
Construction or Reconstruction After May 23, 2023 (Gross or
Net Energy Output-Based Standards Applicable as Approved by
the Administrator)
Table 2 to Subpart TTTTa of Part 60--CO2 Emission Standards
for Affected Steam Generating Units or IGCC That Commenced
Modification After May 23, 2023
Table 3 to Subpart TTTTa of Part 60--Applicability of Subpart A of Part
60 (General Provisions) to Subpart TTTTa
Subpart UUUUa_Emission Guidelines for Greenhouse Gas Emissions From
Existing Electric Utility Generating Units
Introduction
60.5700a What is the purpose of this subpart?
60.5705a Which pollutants are regulated by this subpart?
60.5710a Am I affected by this subpart?
60.5715a What is the review and approval process for my plan?
60.5720a What if I do not submit a plan, my plan is incomplete, or my
plan is not approvable?
60.5725a In lieu of a State plan submittal, are there other acceptable
option(s) for a State to meet its CAA section 111(d)
obligations?
60.5730a Is there an approval process for a negative declaration letter?
State Plan Requirements
60.5735a What must I include in my federally enforceable State plan?
60.5740a What must I include in my plan submittal?
60.5745a What are the timing requirements for submitting my plan?
60.5750a What schedules and compliance periods must I include in my
plan?
60.5755a What standards of performance must I include in my plan?
60.5760a What is the procedure for revising my plan?
60.5765a What must I do to meet my plan obligations?
Applicablity of Plans to Designated Facilities
60.5770a Does this subpart directly affect EGU owners or operators in my
State?
60.5775a What designated facilities must I address in my State plan?
60.5780a What EGUs are excluded from being designated facilities?
60.5785a What applicable monitoring, recordkeeping, and reporting
requirements do I need to include in my plan for designated
facilities?
Recordkeeping and Reporting Requirements
60.5790a What are my recordkeeping requirements?
60.5795a What are my reporting and notification requirements?
60.5800a How do I submit information required by these Emission
Guidelines to the EPA?
Definitions
60.5805a What definitions apply to this subpart?
Subpart UUUUb_Emission Guidelines for Greenhouse Gas Emissions for
Electric Utility Generating Units
Introduction
60.5700b What is the purpose of this subpart?
60.5705b Which pollutants are regulated by this subpart?
60.5710b Am I affected by this subpart?
60.5715b What is the review and approval process for my State plan?
60.5720b What if I do not submit a State plan or my State plan is not
approvable?
60.5725b In lieu of a State plan submittal, are there other acceptable
option(s) for a State to meet its CAA section 111(d)
obligations?
60.5730b Is there an approval process for a negative declaration letter?
State Plan Requirements
60.5740b What must I include in my federally enforceable State plan?
60.5775b What standards of performance must I include in my State plan?
60.5780b What compliance dates and compliance periods must I include in
my State plan?
60.5785b What are the timing requirements for submitting my State plan?
60.5790b What is the procedure for revising my State plan?
60.5795b Commitment to review emission guidelines for coal-fired
affected EGUs
Applicability of State Plans to Affected EGUs
60.5840b Does this subpart directly affect EGU owners or operators in my
State?
60.5845b What affected EGUs must I address in my State plan?
60.5850b What EGUs are excluded from being affected EGUs?
[[Page 33]]
Recordkeeping and Reporting Requirements
60.5860b What applicable monitoring, recordkeeping, and reporting
requirements do I need to include in my State plan for
affected EGUs?
60.5865b What are my recordkeeping requirements?
60.5870b What are my reporting and notification requirements?
60.5875b How do I submit information required by these emission
guidelines to the EPA?
60.5876b What are the recordkeeping and reporting requirements for EGUs
that have committed to permanently cease operations by January
1, 2032?
Definitions
60.5880b What definitions apply to this subpart?
Authority: 42 U.S.C. 7401 et seq.
Source: 36 FR 24877, Dec. 23, 1971, unless otherwise noted.
Subpart XX_Standards of Performance for Bulk Gasoline Terminals That
Commenced Construction, Modification, or Reconstruction After December
17, 1980, and On or Before June 10, 2022
Source: 48 FR 37590, Aug. 18, 1983, unless otherwise noted.
Effective Date Note: At 89 FR 39344, May 8, 2024, the heading for
subpart XX was revised, effective July 8, 2024.
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 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.
Effective Date Note: At 89 FR 39344, May 8, 2024, Sec. 60.500 was
amended by revising paragraph (b), effective July 8, 2024. For the
convenience of the user, the added and revised text is set forth as
follows:
Sec. 60.500 Applicability and designation of affected facility.
* * * * *
(b) Each facility under paragraph (a) of this section, the
construction or modification of which is commenced after December 17,
1980, and on or before June 10, 2022, is subject to the provisions of
this subpart.
* * * * *
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.
[[Page 34]]
Flare means a thermal oxidation system using an open (without
enclosure) flame.
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.
Thermal oxidation system means a combustion device used to mix and
ignite fuel, air pollutants, and air to provide a flame to heat and
oxidize hazardous air pollutants. Auxiliary fuel may be used to heat air
pollutants to combustion temperatures.
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 Method 27.
[48 FR 37590, Aug. 18, 1983, as amended at 65 FR 61763, Oct. 17, 2000;
68 FR 70965, Dec. 19, 2003]
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 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.
[[Page 35]]
(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]
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.
[[Page 36]]
(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 10\6\ for propane and 2.41 x
10\6\ 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.
(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.
(e) The performance test requirements of paragraph (c) of this
section do not apply to flares defined in Sec. 60.501 and meeting the
requirements in Sec. 60.18(b) through (f). The owner or operator shall
demonstrate that the flare and associated vapor collection system is in
compliance with the requirements in Sec. Sec. 60.18(b) through (f) and
60.503(a), (b), and (d).
(f) The owner or operator shall use alternative test methods and
procedures in accordance with the alternative test method provisions in
[[Page 37]]
Sec. 60.8(b) for flares that do not meet the requirements in Sec.
60.18(b).
[54 FR 6678, Feb. 14, 1989; 54 FR 21344, May 17, 1989, as amended at 68
FR 70965, Dec. 19, 2003]
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) As an alternative to keeping records at the terminal of each
gasoline cargo tank test result as required in paragraphs (a), (c), and
(d) of this section, an owner or operator may comply with the
requirements in either paragraph (e)(1) or (2) of this section.
(1) An electronic copy of each record is instantly available at the
terminal.
(i) The copy of each record in paragraph (e)(1) of this section is
an exact duplicate image of the original paper record with certifying
signatures.
(ii) The permitting authority is notified in writing that each
terminal using this alternative is in compliance with paragraph (e)(1)
of this section.
(2) For facilities that utilize a terminal automation system to
prevent gasoline cargo tanks that do not have valid cargo tank vapor
tightness documentation from loading (e.g., via a card lock-out system),
a copy of the documentation is made available (e.g., via facsimile) for
inspection by permitting authority representatives during the course of
a site visit, or within a mutually agreeable time frame.
(i) The copy of each record in paragraph (e)(2) of this section is
an exact duplicate image of the original paper record with certifying
signatures.
(ii) The permitting authority is notified in writing that each
terminal using this alternative is in compliance with paragraph (e)(2)
of this section.
(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, as amended at
68 FR 70965, Dec. 19, 2003]
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
[[Page 38]]
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 XXa_Standards of Performance for Bulk Gasoline Terminals that
Commenced Construction, Modification, or Reconstruction After June 10,
2022
Source: , unless otherwise noted.
Effective Date Note: At 89 FR 39344, May 8, 2024, subpart XXa was
added, effective July 8, 2024.
Sec. 60.500a Applicability and designation of affected facility.
(a) You are subject to the applicable provisions of this subpart if
you are the owner or operator of one or more of the affected facilities
listed in paragraphs (a)(1) and (2) of this section.
(1) Each gasoline loading rack affected facility, which is the total
of all the loading racks at a bulk gasoline terminal that deliver liquid
product into gasoline cargo tanks including the gasoline loading racks,
the vapor collection systems, and the vapor processing system.
(2) Each collection of equipment at a bulk gasoline terminal
affected facility, which is the total of all equipment associated with
the loading of gasoline at a bulk gasoline terminal including the lines
and pumps transferring gasoline from storage vessels, the gasoline
loading racks, the vapor collection systems, and the vapor processing
system.
(b) Each affected facility under paragraph (a) of this section for
which construction, modification (as defined in Sec. 60.2 and detailed
in Sec. 60.14), or reconstruction (as detailed in Sec. 60.15 and
paragraph (e) of this section) is commenced after June 10, 2022, is
subject to the provisions of this subpart.
(c) All standards including emission limitations shall apply at all
times, including periods of startup, shutdown, and malfunction. As
provided in Sec. 60.11(f), this paragraph (c) supersedes the exemptions
for periods of startup, shutdown, and malfunction in subpart A of this
part.
(d) A newly constructed gasoline loading rack affected facility that
was subject to the standards in Sec. 60.502a(b) will continue to be
subject to the standards in Sec. 60.502a(b) for newly constructed
gasoline loading rack affected facilities if they are subsequently
modified or reconstructed.
(e) For purposes of this subpart:
(1) The cost of the following frequently replaced components of the
gasoline loading rack affected facility 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 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.
(2) 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 (e)(1) of this
section which are or will be replaced pursuant to all continuous
programs of component replacement which are commenced within any 2-year
period following June 10, 2022. For purposes of this paragraph (e)(2),
``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. 60.501a Definitions.
The terms used in this subpart are defined in the Clean Air Act, in
Sec. 60.2, or in this section as follows:
3-hour rolling average means the arithmetic mean of the previous
thirty-six 5-minute periods of valid operating data collected, as
specified, for the monitored parameter. Valid data excludes data
collected during periods when the monitoring system is out of
[[Page 39]]
control, while conducting repairs associated with periods when the
monitoring system is out of control, or while conducting required
monitoring system quality assurance or quality control activities. The
thirty-six 5-minute periods should be consecutive, but not necessarily
continuous if operations or the collection of valid data were
intermittent.
Bulk gasoline terminal means any gasoline facility which receives
gasoline by pipeline, ship, barge, or cargo tank and subsequently loads
all or a portion of the gasoline into gasoline cargo tanks for transport
to bulk gasoline plants or gasoline dispensing facilities and has a
gasoline throughput greater than 20,000 gallons per day (75,700 liters
per day). Gasoline throughput shall be the maximum calculated design
throughput for the facility 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 monitoring system is a comprehensive term that may
include, but is not limited to, continuous emission monitoring systems,
continuous parameter monitoring systems, or other manual or automatic
monitoring that is used for demonstrating compliance on a continuous
basis.
Equipment means each valve, pump, pressure relief device, open-ended
valve or line, sampling connection system, and flange or other connector
in the gasoline liquid transfer and vapor collection systems. This
definition also includes the entire vapor processing system except the
exhaust port(s) or stack(s).
Flare means a thermal combustion device using an open or shrouded
flame (without full enclosure) such that the pollutants are not emitted
through a conveyance suitable to conduct a performance test.
Gasoline means any petroleum distillate or petroleum distillate/
alcohol blend having a Reid vapor pressure of 4.0 pounds per square inch
(27.6 kilopascals) or greater which is used as a fuel for internal
combustion engines.
Gasoline cargo tank means a delivery tank truck or railcar which is
loading gasoline or which has loaded gasoline on the immediately
previous load.
In gasoline service means that a piece of equipment is used in a
system that transfers gasoline or gasoline vapors.
Loading rack means the loading arms, pumps, meters, shutoff valves,
relief valves, and other piping and valves necessary to fill gasoline
cargo tanks.
Submerged filling means the filling of a gasoline cargo tank through
a submerged fill pipe whose discharge is no more than the 6 inches from
the bottom of the tank. Bottom filling of gasoline cargo tanks is
included in this definition.
Thermal oxidation system means an enclosed combustion device used to
mix and ignite fuel, air pollutants, and air to provide a flame to heat
and oxidize air pollutants. Auxiliary fuel may be used to heat air
pollutants to combustion temperatures. Thermal oxidation systems emit
pollutants through a conveyance suitable to conduct a performance test.
Total organic compounds (TOC) means those compounds measured
according to the procedures in Method 25, 25A, or 25B of appendix A-7 to
this part. The methane content may be excluded from the TOC
concentration as described in Sec. 60.503a.
Vapor collection system means any equipment used for containing
total organic compounds vapors displaced during the loading of gasoline
cargo tanks.
Vapor processing system means all equipment used for recovering or
oxidizing total organic compounds vapors displaced from the affected
facility.
Vapor recovery system means processing equipment used to absorb and/
or condense collected vapors and return the total organic compounds for
blending with gasoline or other petroleum products or return to a
petroleum refinery or transmix facility for further processing. Vapor
recovery systems include but are not limited to carbon adsorption
systems or refrigerated condensers.
Vapor-tight gasoline cargo tank means a gasoline cargo tank which
has demonstrated within the 12 preceding months that it meets the annual
certification test requirements in Sec. 60.503a(f).
[[Page 40]]
Sec. 60.502a Standard for volatile organic compound (VOC)
emissions from bulk gasoline terminals.
(a) Each gasoline loading rack affected facility shall be equipped
with a vapor collection system designed and operated to collect the
total organic compounds vapors displaced from gasoline cargo tanks
during product loading.
(b) For each newly constructed gasoline loading rack affected
facility, the facility owner or operator must meet the applicable
emission limitations in paragraph (b)(1) or (2) of this section no later
than the date on which Sec. 60.8(a) requires a performance test to be
completed. A flare cannot be used to comply with the emission
limitations in this paragraph (b).
(1) If a thermal oxidation system is used, maintain the emissions to
the atmosphere from the vapor collection system due to the loading of
liquid product into gasoline cargo tanks at or below 1.0 milligram of
total organic compounds per liter of gasoline loaded (mg/L). Continual
compliance with this requirement must be demonstrated as specified in
paragraphs (b)(1)(i) and (ii) of this section.
(i) Conduct initial and periodic performance tests as specified in
Sec. 60.503a(a) through (c) and meet the emission limitation in this
paragraph (b)(1).
(ii) Maintain combustion zone temperature of the thermal oxidation
system at or above the 3-hour rolling average operating limit
established during the performance test when loading liquid product into
gasoline cargo tanks. Valid operating data must exclude periods when
there is no liquid product being loaded. If previous contents of the
cargo tanks are known, you may also exclude periods when liquid product
is loaded but no gasoline cargo tanks are being loaded provided that you
excluded these periods in the determination of the combustion zone
temperature operating limit according to the provisions in Sec.
60.503a(c)(8)(ii).
(2) If a vapor recovery system is used:
(i) Maintain the emissions to the atmosphere from the vapor
collection system at or below 550 parts per million by volume (ppmv) of
TOC as propane determined on a 3-hour rolling average when the vapor
recovery system is operating;
(ii) Operate the vapor recovery system during all periods when the
vapor recovery system is capable of processing gasoline vapors,
including periods when liquid product is being loaded, during carbon bed
regeneration, and when preparing the beds for reuse; and
(iii) Operate the vapor recovery system to minimize air or nitrogen
intrusion except as needed for the system to operate as designed for the
purpose of removing VOC from the adsorption media or to break vacuum in
the system and bring the system back to atmospheric pressure. Consistent
with Sec. 60.12, the use of gaseous diluents to achieve compliance with
a standard which is based on the concentration of a pollutant in the
gases discharged to the atmosphere is prohibited.
(c) For each modified or reconstructed gasoline loading rack
affected facility, the facility owner or operator must meet the
applicable emission limitations in paragraphs (c)(1) through (3) of this
section no later than the date on which Sec. 60.8(a) requires a
performance test to be completed.
(1) If a thermal oxidation system is used, maintain the emissions to
the atmosphere from the vapor collection system due to the loading of
liquid product into gasoline cargo tanks at or below 10 mg/L. Continual
compliance with this requirement must be demonstrated as specified in
paragraphs (c)(1)(i) through (iii) of this section.
(i) Conduct initial and periodic performance tests as specified in
Sec. 60.503a(a) through (c) and meet the emission limitation in this
paragraph (c)(1).
(ii) Maintain combustion zone temperature of the thermal oxidation
system at or above the 3-hour rolling average operating limit
established during the performance test when loading liquid product into
gasoline cargo tanks. Valid operating data must exclude periods when
there is no liquid product being loaded. If previous contents of the
cargo tanks are known, you may also exclude periods when liquid product
is loaded but no gasoline cargo tanks are being loaded provided that you
excluded these periods in the determination of the combustion zone
[[Page 41]]
temperature operating limit according to the provisions in Sec.
60.503a(c)(8)(ii).
(iii) As an alternative to the combustion zone temperature operating
limit, you may elect to use the monitoring provisions as specified in
paragraph (c)(3) of this section.
(2) If a vapor recovery system is used:
(i) Maintain the emissions to the atmosphere from the vapor
collection system at or below 5,500 ppmv of TOC as propane determined on
a 3-hour rolling average when the vapor recovery system is operating;
(ii) Operate the vapor recovery system during all periods when the
vapor recovery system is capable of processing gasoline vapors,
including periods when liquid product is being loaded, during carbon bed
regeneration, and when preparing the beds for reuse; and
(iii) Operate the vapor recovery system to minimize air or nitrogen
intrusion except as needed for the system to operate as designed for the
purpose of removing VOC from the adsorption media or to break vacuum in
the system and bring the system back to atmospheric pressure. Consistent
with Sec. 60.12, the use of gaseous diluents to achieve compliance with
a standard which is based on the concentration of a pollutant in the
gases discharged to the atmosphere is prohibited.
(3) If a flare is used or if a thermal oxidation system for which
these provisions are specified as a monitoring alternative is used, meet
all applicable requirements specified in Sec. 63.670(b) through (g) and
(i) through (n) of this chapter except as provided in paragraphs
(c)(3)(i) through (ix) of this section.
(i) For the purpose of this subpart, ``regulated materials'' refers
to ``vapors displaced from gasoline cargo tanks during product
loading''. If you do not know the previous contents of the cargo tank,
you must assume that cargo tank is a gasoline cargo tank.
(ii) In Sec. 63.670(c) of this chapter for visible emissions:
(A) The phrase ``specify the smokeless design capacity of each flare
and'' does not apply.
(B) The phrase ``and the flare vent gas flow rate is less than the
smokeless design capacity of the flare'' does not apply.
(C) Substitute ``The owner or operator shall monitor for visible
emissions from the flare as specified in Sec. 60.504a(c)(4).'' for the
sentence ``The owner or operator shall monitor for visible emissions
from the flare as specified in paragraph (h) of this section.''
(iii) The phrase ``and the flare vent gas flow rate is less than the
smokeless design capacity of the flare'' in Sec. 63.670(d) of this
chapter for flare tip velocity requirements does not apply.
(iv) Substitute ``pilot flame or flare flame'' for each occurrence
of ``pilot flame.''
(v) Substitute ``gasoline distribution facility'' for each
occurrence of ``petroleum refinery'' or ``refinery.''
(vi) As an alternative to the flow rate monitoring alternatives
provided in Sec. 63.670(i) of this chapter, you may elect to determine
flare waste gas flow rate by monitoring the cumulative loading rates of
all liquid products loaded into cargo tanks for which the displaced
vapors are managed by the affected facility's vapor collection system
and vapor processing system.
(vii) If using provision in Sec. 63.670(j)(6) of this chapter for
flare vent gas composition monitoring, you must comply with those
provisions as specified in paragraphs (c)(3)(vii)(A) through (G) of this
section.
(A) You must submit a separate written application to the
Administrator for an exemption from monitoring, as described in Sec.
63.670(j)(6)(i) of this chapter.
(B) You must determine the minimum ratio of gasoline loaded to total
liquid product loaded for which the affected source must operate at or
above at all times when liquid product is loaded into cargo tanks for
which vapors collected are sent to the flare or, if applicable, thermal
oxidation system and include that in the explanation of conditions
expected to produce the flare gas with lowest net heating value as
required in Sec. 63.670(j)(6)(i)(C) of this chapter. For air assisted
flares or thermal oxidation systems, you must also establish a minimum
gasoline loading rate (i.e., volume of gasoline loaded in a 15-minute
period) for which the affected source must operate at or above
[[Page 42]]
at all times and include that in the explanation of conditions that
ensure the flare gas net heating value is consistent and representative
of the lowest net heating value as required in Sec. 63.670(j)(6)(i)(C).
(C) As required in Sec. 63.670(j)(6)(i)(D) of this chapter, samples
must be collected at the conditions identified in Sec.
63.670(j)(6)(i)(C) of this chapter, which includes the applicable
conditions specified in paragraph (c)(3)(vii)(B) of this section.
(D) The first change from winter gasoline to summer gasoline or from
summer gasoline to winter gasoline, whichever comes first, is considered
a change in operating conditions under Sec. 63.670(j)(6)(iii) of this
chapter and must be evaluated according to the provisions in Sec.
63.670(j)(6)(iii). If separate net heating values are determined for
summer gasoline loading versus winter gasoline loading, you may use the
summer net heating value for all subsequent summer gasoline loading
operations and the winter net heating value for all subsequent winter
gasoline loading operations provided there are no other changes in
operations.
(E) You must monitor the volume of gasoline loaded and the total
volume of liquid product loaded on a 5-minute block basis and maintain
the ratio of gasoline loaded to total liquid product loaded at or above
the value determined in paragraph (c)(3)(vii)(B) of this section and,
for air assisted flares or thermal oxidation systems, maintain the
gasoline loading rate at or above the value determined in paragraph
(c)(3)(vii)(B) on a rolling 15-minute period basis, calculated based on
liquid product loaded during 3 contiguous 5-minute blocks, considering
only those periods when liquid product is loaded into gasoline cargo
tanks for any portion of three contiguous 5-minute block periods.
(F) For unassisted or perimeter air assisted flares or thermal
oxidation systems, if the net heating value determined in Sec.
63.670(j)(6)(i)(F) of this chapter meets or exceeds 270 British thermal
units per standard cubic feet (Btu/scf), compliance with the ratio of
gasoline loaded to total liquid product loaded as specified in paragraph
(c)(3)(vii)(E) of this section demonstrates compliance with the flare
combustion zone net heating value (NHVcz) operating limit in
Sec. 63.670(e) of this chapter.
(G) For perimeter air assisted flares or thermal oxidation systems,
if the net heating value determined in Sec. 63.670(j)(6)(i)(F) of this
chapter meets or exceeds the net heating value dilution parameter
(NHVdil) operating limit of 22 British thermal units per
square foot (Btu/ft\2\) at the flow rate associated with the minimum
gasoline loading rate determined in paragraph (c)(3)(vii)(B) of this
section at any air assist rate used, compliance with the minimum
gasoline loading rate as specified in paragraph (c)(3)(vii)(E) of this
section demonstrates compliance with the NHVdil operating
limit in Sec. 63.670(f) of this chapter.
(viii) You may elect to establish a minimum supplemental gas
addition rate and monitor the supplemental gas addition rate, in
addition to the operating limits in paragraph (c)(3)(vii)(E) of this
section, to demonstrate compliance with the flare combustion zone
operating limit in Sec. 63.670(e) of this chapter and, if applicable,
flare dilution operating limit in Sec. 63.670(f) of this chapter, as
follows.
(A) Use the minimum flare vent gas net heating value prior to
addition of supplemental gas as established in paragraph (c)(3)(vii) of
this section.
(B) Determine the maximum flow rate based on the maximum cumulative
loading rate for a 15-minute block period considering all loading racks
at the affected facility and considering restrictions on maximum loading
rates necessary for compliance with the maximum pressure limits for the
vapor collection and liquid loading equipment specified in paragraph (h)
of this section.
(C) Determine the supplemental gas addition rate needed to yield
NHVcz of 270 Btu/scf using equation in Sec. 63.670(m)(1) of
this chapter.
(D) For flares (or thermal oxidation systems) with perimeter assist
air, determine the supplemental gas addition rate needed to yield
NHVdil of 22 Btu/ft\2\ using equation in Sec. 63.670(n)(1)
of this chapter at the flare vent gas net heating value determined in
paragraph (c)(3)(vii) of this section, the flare gas
[[Page 43]]
flow rate associated with the minimum gasoline loading rate as
determined in paragraph (c)(3)(vii)(B) of this section, and the fixed
air assist rate. If the air assist rate is varied based on total liquid
product loading rates, you must use the air assist rate used at low flow
rates and repeat the calculation using the minimum flow rate associated
with each air assist rate setting and select the maximum supplemental
gas addition rate across any of the air assist rate settings.
(E) Maintain the supplemental gas addition rate above the greater of
the values determined in paragraphs (c)(3)(viii)(C) and, if applicable,
(c)(3)(viii)(D) of this section on a 15-minute block period basis when
liquid product is loaded into gasoline cargo tanks for at least 15-
minutes.
(ix) As an alternative to determining the flare tip velocity rate
for each 15-minute block to determine compliance with the flare tip
velocity operating limit as specified in Sec. 63.670(k)(2) of this
chapter, you may elect to conduct a one-time flare tip velocity
operating limit compliance assessment as provided in paragraphs
(c)(3)(ix)(A) through (D) of this section. If the flare or loading rack
configurations change (e.g., flare tip modified or additional loading
racks are added for which vapors are directed to the flare), you must
repeat this one-time assessment based on the new configuration.
(A) Determine the unobstructed cross-sectional area of the flare
tip, in units of square feet, as specified in Sec. 63.670(k)(1) of this
chapter.
(B) Determine the maximum flow rate, in units of cubic feet per
second, based on the maximum cumulative loading rate for a 15-minute
block period considering all loading racks at the gasoline loading racks
affected facility and considering restrictions on maximum loading rates
necessary for compliance with the maximum pressure limits for the vapor
collection and liquid loading equipment specified in paragraph (h) of
this section.
(C) Calculate the maximum flare tip velocity as the maximum flow
rate from paragraph (c)(3)(ix)(B) of this section divided by the
unobstructed cross-sectional area of the flare tip from paragraph
(c)(3)(ix)(A) of this section.
(D) Demonstrate that the maximum flare tip velocity as calculated in
paragraph (c)(3)(ix)(C) of this section is less than 60 feet per second.
(d) Each vapor collection system for the gasoline loading rack
affected facility 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 cargo tanks at a
gasoline loading rack affected facility shall be limited to vapor-tight
gasoline cargo tanks according to the methods in Sec. 60.503a(f) using
the following procedures:
(1) The owner or operator shall obtain the vapor tightness annual
certification test documentation described in Sec. 60.505a(a)(3) for
each gasoline cargo tank which is to be loaded at the affected facility.
If you do not know the previous contents of a cargo tank, you must
assume that cargo tank is a gasoline cargo tank.
(2) The owner or operator shall obtain and record the cargo tank
identification number of each gasoline cargo tank which is to be loaded
at the affected facility.
(3) The owner or operator shall cross-check each cargo tank
identification number obtained in paragraph (e)(2) of this section with
the file of gasoline cargo tank vapor tightness documentation specified
in paragraph (e)(1) of this section prior to loading any liquid product
into the gasoline cargo tank.
(f) Loading of liquid product into gasoline cargo tanks at a
gasoline loading rack affected facility shall be conducted using
submerged filling, as defined in Sec. 60.501a, and only into gasoline
cargo tanks equipped with vapor collection equipment that is compatible
with the terminal's vapor collection system. If you do not know the
previous contents of a cargo tank, you must assume that cargo tank is a
gasoline cargo tank.
(g) Loading of liquid product into gasoline cargo tanks at a
gasoline loading rack affected facility shall only be conducted when the
terminal's and the cargo tank's vapor collection systems are connected.
If you do not know the previous contents of a cargo tank, you
[[Page 44]]
must assume that cargo tank is a gasoline cargo tank.
(h) The vapor collection and liquid loading equipment for a gasoline
loading rack affected facility shall be designed and operated to prevent
gauge pressure in the gasoline cargo tank from exceeding 18 inches of
water (460 millimeters (mm) of water) during product loading. This level
is not to be exceeded and must be continuously monitored according to
the procedures specified in Sec. 60.504a(d).
(i) No pressure-vacuum vent in the gasoline loading rack affected
facility's vapor collection system shall begin to open at a system
pressure less than 18 inches of water (460 mm of water) or at a vacuum
of less than 6.0 inches of water (150 mm of water).
(j) Each owner or operator of a collection of equipment at a bulk
gasoline terminal affected facility shall perform leak inspection and
repair of all equipment in gasoline service, which includes all
equipment in the vapor collection system, the vapor processing system,
and each loading rack and loading arm handling gasoline, according to
the requirements in paragraphs (j)(1) through (8) of this section. The
owner or operator must keep a list, summary description, or diagram(s)
showing the location of all equipment in gasoline service at the
facility.
(1) Conduct leak detection monitoring of all pumps, valves, and
connectors in gasoline service using either of the methods specified in
paragraph (j)(1)(i) or (ii) of this section.
(i) Use optical gas imaging (OGI) to quarterly monitor all pumps,
valves, and connectors in gasoline service as specified in Sec.
60.503a(e)(2).
(ii) Use Method 21 of appendix A-7 to this part as specified in
Sec. 60.503a(e)(1) and paragraphs (j)(1)(ii)(A) through (C) of this
section.
(A) All pumps must be monitored quarterly, unless the pump meets one
of the requirements in Sec. 60.482-1a(d) or Sec. 60.482-2a(d) through
(g). An instrument reading of 10,000 ppm or greater is a leak.
(B) All valves must be monitored quarterly, unless the valve meets
one of the requirements in Sec. 60.482-1a(d) or Sec. 60.482-7a(f)
through (h). An instrument reading of 10,000 ppm or greater is a leak.
(C) All connectors must be monitored annually, unless the connector
meets one of the requirements in Sec. 60.482-1a(d) or Sec. 60.482-
11a(e) or (f). An instrument reading of 10,000 ppm or greater is a leak.
(2) During normal duties, record leaks identified by audio, visual,
or olfactory methods.
(3) If evidence of a potential leak is found at any time by audio,
visual, olfactory, or any other detection method for any equipment (as
defined in Sec. 60.501a), a leak is detected.
(4) For pressure relief devices, comply with the requirements in
paragraphs (j)(4)(i) through (ii) of this section.
(i) Conduct instrument monitoring of each pressure relief device
quarterly and within 5 calendar days after each pressure release to
detect leaks by the methods specified in paragraph (j)(1) of this
section, except as provided in Sec. 60.482-4a(c).
(ii) If emissions are observed when using OGI, a leak is detected.
If Method 21 is used, an instrument reading of 10,000 ppm or greater
indicates a leak is detected.
(5) For sampling connection systems, comply with the requirements in
Sec. 60.482-5a.
(6) For open-ended valves or lines, comply with the requirements in
Sec. 60.482-6a.
(7) When a leak is detected for any equipment, comply with the
requirements of paragraphs (j)(7)(i) through (iii) of this section.
(i) A weatherproof and readily visible identification, marked with
the equipment identification number, must be attached to the leaking
equipment. The identification on equipment may be removed after it has
been repaired.
(ii) An initial attempt at repair shall be made as soon as
practicable, but no later than 5 calendar days after the leak is
detected. An initial attempt at repair is not required if the leak is
detected using OGI and the equipment identified as leaking would require
elevating the repair personnel more than 2 meters above a support
surface.
(iii) Repair or replacement of leaking equipment shall be completed
within 15
[[Page 45]]
calendar days after detection of each leak, except as provided in
paragraph (j)(8) of this section.
(A) For leaks identified pursuant to instrument monitoring required
under paragraph (j)(1) of this section, the leak is repaired when
instrument re-monitoring of the equipment does not detect a leak.
(B) For leaks identified pursuant to paragraph (j)(2) of this
section, the leak is repaired when the leak can no longer be identified
using audio, visual, or olfactory methods.
(8) Delay of repair of leaking equipment will be allowed according
to the provisions in paragraphs (j)(8)(i) though (iv) of this section.
The owner or operator shall provide in the semiannual report specified
in Sec. 60.505a(c), the reason(s) why the repair was delayed and the
date each repair was completed.
(i) Delay of repair of equipment will be allowed for equipment that
is isolated from the affected facility and that does not remain in
gasoline service.
(ii) Delay of repair for valves and connectors will be allowed if:
(A) 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
(B) When repair procedures are effected, the purged material is
collected and destroyed or recovered in a control device complying with
Sec. 60.482-10a or the requirements in paragraph (b) or (c) of this
section, as applicable.
(iii) Delay of repair will be allowed for a valve, but not later
than 3 months after the leak was detected, if valve assembly replacement
is necessary, valve assembly supplies have been depleted, and valve
assembly supplies had been sufficiently stocked before the supplies were
depleted.
(iv) Delay of repair for pumps will be allowed if:
(A) Repair requires the use of a dual mechanical seal system that
includes a barrier fluid system; and
(B) Repair is completed as soon as practicable, but not later than 6
months after the leak was detected.
(k) You must not allow gasoline to be handled at a bulk gasoline
terminal that contains an affected facility listed under Sec.
60.500a(a) in a manner that would result in vapor releases to the
atmosphere for extended periods of time. Measures to be taken include,
but are not limited to, the following:
(1) Minimize gasoline spills;
(2) Clean up spills as expeditiously as practicable;
(3) Cover all open gasoline containers and all gasoline storage tank
fill-pipes with a gasketed seal when not in use; and
(4) Minimize gasoline sent to open waste collection systems that
collect and transport gasoline to reclamation and recycling devices,
such as oil/water separators.
Sec. 60.503a Test methods and procedures.
(a) General performance test and performance evaluation
requirements. (1) In conducting the performance tests or evaluations
required by this subpart (or as requested by the Administrator), the
owner or operator shall use the test 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.
(2) Immediately before the performance test, conduct leak detection
monitoring following the methods in paragraph (e)(1) of this section to
identify leakage of vapor from all equipment, including loading arms, in
the gasoline loading rack affected facility while gasoline is being
loaded into a gasoline cargo tank to ensure the terminal's vapor
collection system equipment is operated with no detectable emissions.
The owner or operator shall repair all leaks identified with readings of
500 ppmv (as methane) or greater above background before conducting the
performance test and within the timeframe specified in Sec.
60.502a(j)(7).
(b) Performance test or performance evaluation timing. (1) For each
gasoline loading rack affected facility subject to the mass emission
limits in Sec. 60.502a(b)(1) or (c)(1), conduct the initial performance
test of the vapor collection and processing systems according to the
timing specified in Sec. 60.8(a). For each gasoline loading rack
affected
[[Page 46]]
facility subject to the emission limits in Sec. 60.502a(b)(2) or
(c)(2), conduct the initial performance evaluation of the continuous
emissions monitoring system (CEMS) according to the timing specified for
performance tests in Sec. 60.8(a).
(2) For each gasoline loading rack affected facility complying with
the mass emission limits in Sec. 60.502a(b)(1) or (c)(1), conduct
subsequent performance test of the vapor collection and processing
system no later than 60 calendar months after the previous performance
test.
(3) For each gasoline loading rack affected facility complying with
the concentration emission limits in Sec. 60.502a(b)(2) or (c)(2),
conduct subsequent performance evaluations of CEMS for the vapor
collection and processing system no later than 12 calendar months after
the previous performance evaluation.
(c) Performance test requirements for mass loading emission limit.
The owner or operator of a gasoline loading rack affected facility shall
conduct performance tests of the vapor collection and processing system
subject to the emission limits in Sec. 60.502a(b)(1) or (c)(1), as
specified in paragraphs (c)(1) through (8) of this section.
(1) The performance test shall be 6 hours long during which at least
80,000 gallons (300,000 liters) of gasoline is loaded. If this is not
possible, the test may be continued the same day until 80,000 gallons
(300,000 liters) of gasoline is loaded. If 80,000 gallons (300,000
liters) cannot be loaded during the first day of testing, the test may
be resumed the next day with another 6-hour period. During the second
day of testing, the 80,000-gallon (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 of gasoline normally
occurs.
(2) If the vapor processing system is intermittent in operation and
employs an intermediate vapor holder to accumulate total organic
compounds vapors collected from gasoline cargo tanks, 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] TR08MY24.015
Equation 1 to paragraph (c)(3)
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 10\6\ for propane, 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 accounted for when determining the average total organic
compounds concentration corresponding to the volume exhausted.
(5) Method 2B of appendix A-1 to this part shall be used to
determine the volume (Vesi) of air-vapor mixture exhausted at
each interval.
(6) Method 25, 25A, or 25B of appendix A-7 to this part shall be
used for determining the total organic compounds concentration
(Cei) at each interval. Method 25 must not be used if the
outlet TOC concentration is less than 50
[[Page 47]]
ppmv. The calibration gas shall be propane. If the owner or operator
conducts the performance test using either Method 25A or Method 25B, the
methane content in the exhaust vent may be excluded following the
procedures in paragraphs (c)(6)(i) through (v) of this section.
Alternatively, an instrument that uses gas chromatography with a flame
ionization detector may be used according to the procedures in paragraph
(c)(6)(vi) of this section.
(i) Measure the methane concentration by Method 18 of appendix A-6
to this part or Method 320 of appendix A to part 63 of this chapter.
(ii) Calibrate the Method 25A or Method 25B analyzer using both
propane and methane to develop response factors to both compounds.
(iii) Determine the TOC concentration with the Method 25A or Method
25B analyzer on an as methane basis.
(iv) Subtract the methane measured according to paragraph (c)(6)(i)
of this section from the concentration determined in paragraph
(c)(6)(iii) of this section.
(v) Convert the concentration difference determined in paragraph
(c)(6)(iv) of this section to TOC (minus methane), as propane, by using
the response factors determined in paragraph (c)(6)(ii) of this section.
Multiply the concentration difference in paragraph (c)(6)(iv) of this
section by the ratio of the response factor for propane to the response
factor for methane.
(vi) Methane must be separated by the gas chromatograph and measured
by the flame ionization detector, followed by a back-flush of the
chromatographic column to directly measure TOC concentration minus
methane. Use a direct interface and heated sampling line from the
sampling point to the gas chromatographic injection valve. All sampling
components leading to the analyzer must be heated to greater than 110
[deg]C. Calibrate the instrument with propane. Calibration error and
calibration drift must be demonstrated according to Method 25A, and the
appropriate procedures in Method 25A must be followed to ensure the
calibration error and calibration drift are within Method 25A limits.
The TOC concentration minus methane must be recorded at least once every
15 minutes. The performance test report must include the calibration
results and the results demonstrating proper separation of methane from
the TOC concentration.
(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.
(8) Monitor the temperature in the combustion zone using the
continuous parameter monitoring system (CPMS) required in Sec.
60.504a(a) and determine the operating limit for the combustion device
using the following procedures:
(i) Record the temperature or average temperature for each 5-minute
period during the performance test.
(ii) Using only the 5-minute periods in which liquid product is
loaded into gasoline cargo tanks, determine the 1-hour average
temperature for each hour of the performance test. If you do not know
the previous contents of the cargo tank, you must assume liquid product
loading is performed in gasoline cargo tanks such that you use all 5-
minute periods in which liquid product is loaded into gasoline cargo
tanks when determining the 1-hour average temperature for each hour of
the performance test.
(iii) Starting at the end of the third hour of the performance test
and at the end of each successive hour, calculate the 3-hour rolling
average temperature using the 1-hour average values in paragraph
(c)(8)(ii) of this section. For a 6-hour test, this would result in four
3-hour averages (averages for hours 1 through 3, 2 through 4, 3 through
5, and 4 through 6).
(iv) Set the operating limit at the lowest 3-hour average
temperature determined in paragraph (c)(8)(iii) of this section. New
operating limits become effective on the date that the performance test
report is submitted to the U.S. Environmental Protection Agency (EPA)
Compliance and Emissions Data Reporting Interface (CEDRI), per the
requirements of Sec. 60.505a(b).
(d) Performance evaluation requirements for concentration emission
limit. The owner or operator shall conduct
[[Page 48]]
performance evaluations of the CEMS for vapor collection and processing
systems subject to the emission limits in Sec. 60.502a(b)(2) or (c)(2)
as specified in paragraph (d)(1) or (2) of this section, as applicable.
(1) If the CEMS uses a nondispersive infrared analyzer, the CEMS
must be installed, evaluated, and operated according to the requirements
of Performance Specification 8 of appendix B to this part. Method 25B in
appendix A-7 to this part must be used as the reference method, and the
calibration gas must be propane. The owner or operator may request an
alternative test method under Sec. 60.8(b) to use a CEMS that excludes
the methane content in the exhaust vent.
(2) If the CEMS uses a flame ionization detector, the CEMS must be
installed, evaluated, and operated according to the requirements of
Performance Specification 8A of appendix B to this part. As part of the
performance evaluation, conduct a relative accuracy test audit (RATA)
following the procedures in Performance Specification 2, section 8.4, of
appendix B to this part; the relative accuracy must meet the criteria of
Performance Specification 8, section 13.2, of appendix B to this part.
Method 25A in appendix A-7 to this part must be used as the reference
method, and the calibration gas must be propane. The owner or operator
may exclude the methane content in the exhaust following the procedures
in paragraphs (d)(2)(i) through (iv) of this section.
(i) Methane must be separated using a chromatographic column and
measured by the flame ionization detector, followed by a back-flush of
the chromatographic column to directly measure TOC concentration minus
methane.
(ii) The CEMS must be installed, evaluated, and operated according
to the requirements of Performance Specification 8A of appendix B to
this part, except the target compound is TOC minus methane. As part of
the performance evaluation, conduct a RATA following the procedures in
Performance Specification 2, section 8.4, of appendix B to this part;
the relative accuracy must meet the criteria of Performance
Specification 8, section 13.2, of appendix B to this part.
(iii) If the concentration of TOC minus methane in the exhaust
stream is greater than 50 ppmv, Method 25 in appendix A-7 to this part
must be used as the reference method, and the calibration gas must be
propane. If the concentration of TOC minus methane in the exhaust stream
is 50 ppmv or less, Method 25A in appendix A-7 to this part must be used
as the reference method, and the calibration gas must be propane. If
Method 25A is the reference method, the procedures in paragraph (c)(6)
of this section may be used to subtract methane from the TOC
concentration.
(iv) The TOC concentration minus methane must be recorded at least
once every 15 minutes.
(e) Leak detection monitoring. Conduct the leak detection monitoring
specified in Sec. 60.502a(j)(1) for the collection of equipment at a
bulk gasoline terminal affected facility using one of the procedures
specified in paragraph (e)(1) or (2) of this section. Conduct the leak
detection monitoring specified in paragraph (a)(2) of this section using
the procedures specified in paragraph (e)(1) of this section, except
that the instrument reading that defines a leak is specified in
paragraph (a)(2) for all equipment, including loading arms, in the
gasoline loading rack affected facility and the calibration gas in
paragraph (e)(1)(ii) must be at a concentration of 500 ppm methane.
(1) Method 21 in appendix A-7 to this part. The instrument reading
that defines a leak is 10,000 ppmv (as methane). The instrument shall be
calibrated before use each day of its use by the procedures specified in
Method 21 of appendix A-7. The calibration gases in paragraphs (e)(1)(i)
and (ii) of this section must be used. The drift assessment specified in
paragraph (e)(1)(iii) of this section must be performed at the end of
each monitoring day.
(i) Zero air (less than 10 ppm of hydrocarbon in air); and
(ii) Methane and air at a concentration of 10,000 ppm methane.
(iii) At the end of each monitoring day, check the instrument using
the same calibration gas that was used to calibrate the instrument
before use.
[[Page 49]]
Follow the procedures specified in Method 21 of appendix A-7 to this
part, section 10.1, except do not adjust the meter readout to correspond
to the calibration gas value. If multiple scales are used, record the
instrument reading for each scale used. Divide the arithmetic difference
of the initial and post-test calibration response by the corresponding
calibration gas value for each scale and multiply by 100 to express the
calibration drift as a percentage. If a calibration drift assessment
shows a negative drift of more than 10 percent, then re-monitor all
equipment monitored since the last calibration with instrument readings
between the leak definition and the leak definition multiplied by (100
minus the percent of negative drift) divided by 100. If any calibration
drift assessment shows a positive drift of more than 10 percent from the
initial calibration value, then, at the owner/operator's discretion, all
equipment with instrument readings above the leak definition and below
the leak definition multiplied by (100 plus the percent of positive
drift) divided by 100 monitored since the last calibration may be re-
monitored.
(2) OGI according to all the requirements in appendix K to this
part. A leak is defined as any emissions plume imaged by the camera from
equipment regulated by this subpart.
(f) Annual certification test. The annual certification test for
gasoline cargo tanks shall consist of the following test methods and
procedures:
(1) Method 27 of appendix A-8 to this part. Conduct the test using a
time period (t) for the pressure and vacuum tests of 5 minutes. The
initial pressure (Pi) for the pressure test shall be 460 mm
water (H2O) (18 in. H2O), gauge. The initial
vacuum (Vi) for the vacuum test shall be 150 mm
H2O (6 in. H2O), gauge. The maximum allowable
pressure and vacuum changes ([Delta] p, [Delta] v) are as shown in table
1 to this paragraph (f)(1).
Table 1 to Paragraph (f)(1)--Allowable Gasoline Cargo Tank Test Pressure
or Vacuum Change
------------------------------------------------------------------------
Annual certification-
allowable pressure
or vacuum change
Gasoline cargo tank or compartment capacity, ([Delta] p, [Delta]
gallons (liters) v) in 5 minutes, mm
H2O (in. H2O)
------------------------------------------------------------------------
2,500 or more (9,464 or more)..................... 12.7 (0.50)
1,500 to 2,499 (5,678 to 9,463)................... 19.1 (0.75)
1,000 to 1,499 (3,785 to 5,677)................... 25.4 (1.00)
999 or less (3,784 or less)....................... 31.8 (1.25)
------------------------------------------------------------------------
(2) Pressure test of the gasoline cargo tank's internal vapor valve
as follows:
(i) After completing the tests under paragraph (f)(1) of this
section, use the procedures in Method 27 to repressurize the gasoline
cargo tank to 460 mm H2O (18 in. H2O), gauge.
Close the gasoline cargo tank's internal vapor valve(s), thereby
isolating the vapor return line and manifold from the gasoline cargo
tank.
(ii) Relieve the pressure in the vapor return line to atmospheric
pressure, then reseal the line. After 5 minutes, record the gauge
pressure in the vapor return line and manifold. The maximum allowable 5-
minute pressure increase is 65 mm H2O (2.5 in.
H2O).
(3) As an alternative to paragraph (f)(1) of this section, you may
use the procedure in Sec. 63.425(i) of this chapter.
Sec. 60.504a Monitoring requirements.
(a) Monitoring requirements for thermal oxidation systems complying
with the combustion zone temperature operating limit. Install, operate,
and maintain a CPMS for measuring the combustion zone temperature as
specified in paragraphs (a)(1) through (5) of this section.
(1) Install the temperature CPMS in the combustion (flame) zone or
in the exhaust gas stream as close as practical to the combustion
burners in a position that provides a representative temperature of the
combustion zone of the thermal oxidation system.
(2) The temperature CPMS must be capable of measuring temperature
with an accuracy of 1 percent over the normal
range of temperatures measured.
[[Page 50]]
(3) The temperature CPMS must be capable of recording the
temperature at least once every 5 minutes and calculating hourly block
averages that include only those 5-minute periods in which liquid
product was loaded into gasoline cargo tanks.
(4) At least quarterly, inspect all components for integrity and all
electrical connections for continuity, oxidation, and galvanic
corrosion, unless the CPMS has a redundant temperature sensor.
(5) Conduct calibration checks at least annually and conduct
calibration checks following any period of more than 24 hours throughout
which the temperature exceeded the manufacturer's specified maximum
rated temperature or install a new temperature sensor.
(b) Monitoring requirements for vapor recovery systems. Install,
calibrate, operate, and maintain a CEMS for measuring the concentration
of TOC in the atmospheric vent from the vapor recovery system as
specified in paragraphs (b)(1) and (2) of this section. Locate the
sampling probe or other interface at a measurement location such that
you obtain representative measurements of emissions from the vapor
recovery system.
(1) The requirements of Performance Specification 8 of appendix B to
this part, or, if the CEMS uses a flame ionization detector, Performance
Specification 8A of appendix B to this part, the quality assurance
requirements in Procedure 1 of appendix F to this part, and the
procedures under Sec. 60.13 must be followed for installation,
evaluation, and operation of the CEMS. For CEMS certified using
Performance Specification 8A of appendix B, conduct the RATA required
under Procedure 1 according to the requirements in Sec. 60.503a(d). As
required by Sec. 60.503a(b)(3), conduct annual performance evaluations
of each TOC CEMS according to the requirements in Sec. 60.503a(d).
Conduct accuracy determinations quarterly and calibration drift tests
daily in accordance with Procedure 1 in appendix F.
(2) The span value of the TOC CEMS must be approximately 2 times the
applicable emission limit.
(c) Monitoring requirements for flares and thermal oxidation systems
for which flare monitoring alternative is provided. Install, operate,
and maintain CPMS for flares used to comply with the emission
limitations in Sec. 60.502a(c)(3), including monitors used for gasoline
and total liquid product loading rates, following the requirements
specified in Sec. 63.671 of this chapter as specified in paragraphs
(c)(1) through (3) of this section and conduct visible emission
observations as specified in paragraph (c)(4) of this section.
(1) Substitute ``pilot flame or flare flame'' for each occurrence of
``pilot flame.''
(2) You may elect to determine compositional analysis for net
heating value with a continuous process mass spectrometer without the
use of a gas chromatograph. If you choose to determine compositional
analysis for net heating value with a continuous process mass
spectrometer, then you must comply with the requirements specified in
paragraphs (c)(2)(i) through (vii) of this section.
(i) You must meet the requirements in Sec. 63.671(e)(2) of this
chapter. You may augment the minimum list of calibration gas components
found in Sec. 63.671(e)(2) with compounds found during a pre-survey or
known to be in the gas through process knowledge.
(ii) Calibration gas cylinders must be certified to an accuracy of 2
percent and traceable to National Institute of Standards and Technology
(NIST) standards.
(iii) For unknown gas components that have similar analytical mass
fragments to calibration compounds, you may report the unknowns as an
increase in the overlapped calibration gas compound. For unknown
compounds that produce mass fragments that do not overlap calibration
compounds, you may use the response factor for the nearest molecular
weight hydrocarbon in the calibration mix to quantify the unknown
component's net heating value of flare vent gas (NHVvg).
(iv) You may use the response factor for n-pentane to quantify any
unknown components detected with a higher molecular weight than n-
pentane.
(v) You must perform an initial calibration to identify mass
fragment
[[Page 51]]
overlap and response factors for the target compounds.
(vi) You must meet applicable requirements in Performance
Specification 9 of appendix B to this part for continuous monitoring
system acceptance including, but not limited to, performing an initial
multi-point calibration check at three concentrations following the
procedure in section 10.1 of Performance Specification 9 and performing
the periodic calibration requirements listed for gas chromatographs in
table 13 to part 63, subpart CC, of this chapter, for the process mass
spectrometer. You may use the alternative sampling line temperature
allowed under Net Heating Value by Gas Chromatograph in table 13 to part
63, subpart CC.
(vii) The average instrument calibration error (CE) for each
calibration compound at any calibration concentration must not differ by
more than 10 percent from the certified cylinder gas value. The CE for
each component in the calibration blend must be calculated using the
following equation:
[GRAPHIC] [TIFF OMITTED] TR08MY24.016
Equation 1 to paragraph (c)(2)(vii)
Where:
Cm = Average instrument response (ppm).
Ca = Certified cylinder gas value (ppm).
(3) If you use a gas chromatograph or mass spectrometer for
compositional analysis for net heating value, then you may choose to use
the CE of net heating value (NHV) measured versus the cylinder tag value
NHV as the measure of agreement for daily calibration and quarterly
audits in lieu of determining the compound-specific CE. The CE for NHV
at any calibration level must not differ by more than 10 percent from
the certified cylinder gas value. The CE for NHV must be calculated
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR08MY24.017
Equation 2 to paragraph (c)(3)
Where:
NHVmeasured = Average instrument response (Btu/scf)
NHVa = Certified cylinder gas value (Btu/scf).
(4) If visible emissions are observed for more than one continuous
minute during normal duties, visible emissions observation using Method
22 of appendix A-7 to this part must be conducted for 2 hours or until
5-minutes of visible emissions are observed.
(d) Pressure CPMS requirements. The owner or operator shall install,
operate, and maintain a CPMS to measure the pressure of the vapor
collection system to determine compliance with the standard in Sec.
60.502a(h) as specified in paragraphs (d)(1) through (4) of this
section.
(1) Install a pressure CPMS (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 on the
terminal's vapor collection system at a pressure tap located as close as
possible to the connection with the gasoline cargo tank. If necessary to
obtain representative loading pressures, install pressure CPMS for each
loading rack.
(2) Check the calibration of the pressure CPMS at least annually.
Check the calibration of the pressure CPMS following any period of more
than 24 hours throughout which the pressure
[[Page 52]]
exceeded the manufacturer's specified maximum rated pressure or install
a new pressure sensor.
(3) At least quarterly, visually inspect components of the pressure
CPMS for integrity, oxidation and galvanic corrosion, unless the system
has a redundant pressure sensor.
(4) The output of the pressure CPMS must be reviewed each operating
day to ensure that the pressure readings fluctuate as expected during
loading of gasoline cargo tanks to verify the pressure taps are not
plugged. Plugged pressure taps must be unplugged or otherwise repaired
within 24 hours or prior to the next gasoline cargo tank loading,
whichever time period is longer.
(e) Limited alternative requirements for vapor recovery systems. If
the CEMS used for measuring the concentration of TOC in the atmospheric
vent from the vapor recovery system as specified in paragraph (b) of
this section requires maintenance such that it is off-line for more than
15 minutes, you may follow the requirements in paragraphs (e)(1) and (2)
of this section and monitor product loading quantities and regeneration
cycle parameters as an alternative to the monitoring requirement in
paragraph (b) for no more than 240 hours in a calendar year.
(1) Determine the quantity of liquid product loaded in gasoline
cargo tanks for the past 10 adsorption cycles prior to the CEMS going
off-line and select the smallest of these values as your product loading
quantity operating limit.
(2) Determine the vacuum pressure, purge gas quantities, and
duration of the vacuum/purge cycles used for the past 10 desorption
cycles prior to the CEMS going off-line. You must operate vapor recovery
system desorption cycles as specified in paragraphs (e)(2)(i) through
(iii) of this section.
(i) The vacuum pressure for each desorption cycle must be at or
above the average vacuum pressure from the past 10 desorption cycles.
Note: a higher vacuum means a lower absolute pressure.
(ii) Purge gas quantity used for each desorption cycle must be at or
above the average quantity of purge gas used from the past 10 desorption
cycles.
(iii) Duration of the vacuum/purge cycle for each desorption cycle
must be at or above the average duration of the vacuum/purge cycle used
from the past 10 desorption cycles.
Sec. 60.505a Recordkeeping and reporting.
(a) Recordkeeping requirements. For each affected facility listed
under Sec. 60.500a(a), keep records as specified in paragraphs (a)(1)
through (9) of this section, as applicable, for a minimum of five years
unless otherwise specified in this section. These recordkeeping
requirements supersede the requirements in Sec. 60.7(b).
(1) For each thermal oxidation system used to comply with the
emission limitations in Sec. 60.502a(b)(1) or (c)(1) by monitoring the
combustion zone temperature as specified in Sec. 60.502a(b)(1)(ii) or
(c)(1)(ii), for each pressure CPMS used to comply with the requirements
in Sec. 60.502a(h), and for each vapor recovery system used to comply
with the emission limitations in Sec. 60.502a(b)(2) or (c)(2), maintain
records, as applicable, of:
(i) The applicable operating or emission limit for the continuous
monitoring system (CMS). For combustion zone temperature operating
limits, include the applicable date range the limit applies based on
when the performance test was conducted.
(ii) Each 3-hour rolling average combustion zone temperature
measured by the temperature CPMS, each 5-minute average reading from the
pressure CPMS, and each 3-hour rolling average TOC concentration (as
propane) measured by the TOC CEMS.
(iii) For each deviation of the 3-hour rolling average combustion
zone temperature operating limit, maximum loading pressure specified in
Sec. 60.502a(h), or 3-hour rolling average TOC concentration (as
propane), the start date and time, duration, cause, and the corrective
action taken.
(iv) For each period when there was a CMS outage or the CMS was out
of control, the start date and time, duration, cause, and the corrective
action taken.
[[Page 53]]
For TOC CEMS outages where the limited alternative for vapor recovery
systems in Sec. 60.504a(e) is used, the corrective action taken shall
include an indication of the use of the limited alternative for vapor
recovery systems in Sec. 60.504a(e).
(v) Each inspection or calibration of the CMS including a unique
identifier, make, and model number of the CMS, and date of calibration
check. For TOC CEMS, include the type of CEMS used (i.e., flame
ionization detector, nondispersive infrared analyzer) and an indication
of whether methane is excluded from the TOC concentration reported in
paragraph (a)(1)(ii) of this section.
(vi) For TOC CEMS outages where the limited alternative for vapor
recovery systems in Sec. 60.504a(e) is used, also keep records of:
(A) The quantity of liquid product loaded in gasoline cargo tanks
for the past 10 adsorption cycles prior to the CEMS outage.
(B) The vacuum pressure, purge gas quantities, and duration of the
vacuum/purge cycles used for the past 10 desorption cycles prior to the
CEMS outage.
(C) The quantity of liquid product loaded in gasoline cargo tanks
for each adsorption cycle while using the alternative.
(D) The vacuum pressure, purge gas quantities, and duration of the
vacuum/purge cycles for each desorption cycle while using the
alternative.
(2) For each flare used to comply with the emission limitations in
Sec. 60.502a(c)(3) and for each thermal oxidation system using the
flare monitoring alternative as provided in Sec. 60.502a(c)(1)(iii),
maintain records of:
(i) The output of the monitoring device used to detect the presence
of a pilot flame as required in Sec. 63.670(b) of this chapter for a
minimum of 2 years. Retain records of each 15-minute block during which
there was at least one minute that no pilot flame was present when
gasoline vapors were routed to the flare for a minimum of 5 years. The
record must identify the start and end time and date of each 15-minute
block.
(ii) Visible emissions observations as specified in paragraphs
(a)(2)(ii)(A) and (B) of this section, as applicable, for a minimum of 3
years.
(A) If visible emissions observations are performed using Method 22
of appendix A-7 to this part, the record must identify the date, the
start and end time of the visible emissions observation, and the number
of minutes for which visible emissions were observed during the
observation. If the owner or operator performs visible emissions
observations more than one time during a day, include separate records
for each visible emissions observation performed.
(B) For each 2-hour period for which visible emissions are observed
for more than 5 minutes in 2 consecutive hours but visible emissions
observations according to Method 22 of appendix A-7 to this part were
not conducted for the full 2-hour period, the record must include the
date, the start and end time of the visible emissions observation, and
an estimate of the cumulative number of minutes in the 2-hour period for
which emissions were visible based on best information available to the
owner or operator.
(iii) Each 15-minute block period during which operating values are
outside of the applicable operating limits specified in Sec. 63.670(d)
through (f) of this chapter when liquid product is being loaded into
gasoline cargo tanks for at least 15-minutes identifying the specific
operating limit that was not met.
(iv) The 15-minute block average cumulative flows for flare vent gas
or the thermal oxidation system vent gas and, if applicable, total
steam, perimeter assist air, and premix assist air specified to be
monitored under Sec. 63.670(i) of this chapter, along with the date and
start and end time for the 15-minute block. If multiple monitoring
locations are used to determine cumulative vent gas flow, total steam,
perimeter assist air, and premix assist air, retain records of the 15-
minute block average flows for each monitoring location for a minimum of
2 years, and retain the 15-minute block average cumulative flows that
are used in subsequent calculations for a minimum of 5 years. If
pressure and temperature monitoring is used, retain records of the 15-
minute block average temperature, pressure and molecular weight of the
flare vent
[[Page 54]]
gas, thermal oxidation system vent gas, or assist gas stream for each
measurement location used to determine the 15-minute block average
cumulative flows for a minimum of 2 years, and retain the 15-minute
block average cumulative flows that are used in subsequent calculations
for a minimum of 5 years. If you use the supplemental gas flow rate
monitoring alternative in Sec. 60.502a(c)(3)(viii), the required
minimum supplemental gas flow rate (winter and summer, if applicable)
and the actual monitored supplemental gas flow rate for the 15-minute
block. Retain the supplemental gas flow rate records for a minimum of 5
years.
(v) The flare vent gas compositions or thermal oxidation system vent
gas specified to be monitored under Sec. 63.670(j) of this chapter.
Retain records of individual component concentrations from each
compositional analyses for a minimum of 2 years. If an NHVvg
analyzer is used, retain records of the 15-minute block average values
for a minimum of 5 years. If you demonstrate your gas streams have
consistent composition using the provisions in Sec. 63.670(j)(6) of
this chapter as specified in Sec. 60.502a(c)(3)(vii), retain records of
the required minimum ratio of gasoline loaded to total liquid product
loaded and the actual ratio on a 5-minute block basis. If applicable,
you must retain records of the required minimum gasoline loading rate as
specified in Sec. 60.502a(c)(3)(vii) and the actual gasoline loading
rate on a 5-minute block basis for a minimum of 5 years.
(vi) Each 15-minute block average operating parameter calculated
following the methods specified in Sec. 63.670(k) through (n) of this
chapter, as applicable.
(vii) All periods during which the owner or operator does not
perform monitoring according to the procedures in Sec. 63.670(g), (i),
and (j) of this chapter or in Sec. 60.502a(c)(3)(vii) and (viii) as
applicable. Note the start date, start time, and duration in minutes for
each period.
(viii) An indication of whether ``vapors displaced from gasoline
cargo tanks during product loading'' excludes periods when liquid
product is loaded but no gasoline cargo tanks are being loaded or if
liquid product loading is assumed to be loaded into gasoline cargo tanks
according to the provisions in Sec. 60.502a(c)(3)(i), records of all
time periods when ``vapors displaced from gasoline cargo tanks during
product loading'', and records of time periods when there were no
``vapors displaced from gasoline cargo tanks during product loading''.
(ix) If you comply with the flare tip velocity operating limit using
the one-time flare tip velocity operating limit compliance assessment as
provided in Sec. 60.502a(c)(3)(ix), maintain records of the applicable
one-time flare tip velocity operating limit compliance assessment for as
long as you use this compliance method.
(x) For each parameter monitored using a CMS, retain the records
specified in paragraphs (a)(2)(x)(A) through (C) of this section, as
applicable:
(A) For each deviation, record the start date and time, duration,
cause, and corrective action taken.
(B) For each period when there is a CMS outage or the CMS is out of
control, record the start date and time, duration, cause, and corrective
action taken.
(C) Each inspection or calibration of the CMS including a unique
identifier, make, and model number of the CMS, and date of calibration
check.
(3) The gasoline cargo tank vapor tightness documentation required
under Sec. 60.502a(e)(1) for each gasoline cargo tank loading at the
affected facility shall be kept on file at the terminal in either a
hardcopy or electronic form available for inspection. The documentation
shall include, at a minimum, the following information:
(i) Test title: Annual Certification Test--EPA Method 27 or Railcar
Bubble Leak Test Procedure.
(ii) Cargo tank owner's name and address.
(iii) Cargo tank identification number.
(iv) Test location and date.
(v) Tester name and signature.
(vi) Witnessing inspector, if any: Name, signature, and affiliation.
(vii) Vapor tightness repair: Nature of repair work and when
performed in relation to vapor tightness testing.
[[Page 55]]
(viii) Test results: Tank or compartment capacity, test pressure;
pressure or vacuum change, mm of water; time period of test; number of
leaks found with instrument; and leak definition.
(4) Records of each instance in which liquid product was loaded into
a gasoline cargo tank for which vapor tightness documentation required
under Sec. 60.502a(e)(1) was not provided or available in the
terminal's records. These records shall include, at a minimum:
(i) Cargo tank owner and address.
(ii) Cargo tank identification number.
(iii) Date and time liquid product was loaded into a gasoline cargo
tank without proper documentation.
(iv) Date proper documentation was received or statement that proper
documentation was never received.
(5) Records of each instance when liquid product was loaded into
gasoline cargo tanks not using submerged filling, as defined in Sec.
60.501a, not equipped with vapor collection equipment that is compatible
with the terminal's vapor collection system, or not properly connected
to the terminal's vapor collection system. These records shall include,
at a minimum:
(i) Date and time of liquid product loading into gasoline cargo tank
not using submerged filling, improperly equipped, or improperly
connected.
(ii) Type of deviation (e.g., not submerged filling, incompatible
equipment, not properly connected).
(iii) Cargo tank identification number.
(6) A record [list, summary description, or diagram(s) showing the
location] of all equipment in gasoline service at the collection of
equipment at a bulk gasoline terminal affected facility and at the
loading rack affected facility. A record of each leak inspection and
leak identified under Sec. Sec. 60.503a(a)(2) and 60.502a(j) as
specified in paragraphs (a)(6)(i) through (iv) of this section:
(i) For each leak inspection, keep the following records:
(A) An indication if the leak inspection was conducted under Sec.
60.502a(j) or Sec. 60.503a(a)(2).
(B) Leak determination method used for the leak inspection.
(ii) For leak inspections conducted with Method 21 of appendix A-7
to this part, keep the following additional records:
(A) Date of inspection.
(B) Inspector name.
(C) Monitoring instrument identification.
(D) Identification of all equipment surveyed and the instrument
reading for each piece of equipment.
(E) Date and time of instrument calibration and initials of operator
performing the calibration.
(F) Calibration gas cylinder identification, certification date, and
certified concentration.
(G) Instrument scale used.
(H) Results of the daily calibration drift assessment.
(iii) For leak inspections conducted with OGI, keep the records
specified in section 12 of appendix K to this part.
(iv) For each leak detected during a leak inspection or by audio/
visual/olfactory methods during normal duties, record the following
information:
(A) The equipment type and identification number.
(B) The date the leak was detected, the name of the person who found
the leak, the nature of the leak (i.e., vapor or liquid), and the method
of detection (i.e., audio/visual/olfactory, Method 21 of appendix A-7 to
this part, or OGI).
(C) The dates of each attempt to repair the leak and the repair
methods applied in each attempt to repair the leak.
(D) The date of successful repair of the leak, the method of
monitoring used to confirm the repair, and if Method 21 of appendix A-7
to this part is used to confirm the repair, the maximum instrument
reading measured by Method 21 of appendix A-7. If OGI is used to confirm
the repair, keep video footage of the repair confirmation.
(E) For each repair delayed beyond 15 calendar days after discovery
of the leak, record ``Repair delayed'', the reason for the delay, and
the expected date of successful repair. The owner or operator (or
designate) whose decision it was that repair could not be carried out in
the 15-calendar-day timeframe must sign the record.
(F) For each leak that is not repairable, the maximum instrument
reading measured by Method 21 of appendix A-7 to this part at the time
the leak is
[[Page 56]]
determined to be not repairable, a video captured by the OGI camera
showing that emissions are still visible, or a signed record that the
leak is still detectable via audio/visual/olfactory methods.
(7) Records of each performance test or performance evaluation
conducted on the affected facility and each notification and report
submitted to the Administrator. For each performance test, include an
indication of whether liquid product loading is assumed to be loaded
into gasoline cargo tanks or periods when liquid product is loaded but
no gasoline cargo tanks are being loaded are excluded in the
determination of the combustion zone temperature operating limit
according to the provision in Sec. 60.503a(c)(8)(ii).
(8) Records of all 5-minute time periods during which liquid product
is loaded into gasoline cargo tanks or assumed to be loaded into
gasoline cargo tanks and records of all 5-minute time periods when there
was no liquid product loaded into gasoline cargo tanks.
(9) Any records required to be maintained by this subpart that are
submitted electronically via the EPA's Compliance and Emissions
Reporting Interface (CEDRI) may be maintained in electronic format. This
ability to maintain electronic copies does not affect the requirement
for facilities to make records, data, and reports available upon request
to a delegated authority or the EPA as part of an on-site compliance
evaluation.
(b) Reporting requirements for performance tests and evaluations.
Within 60 days after the date of completing each performance test and
each CEMS performance evaluation required by this subpart, you must
submit the results following the procedures specified in paragraph (e)
of this section. As required by Sec. 60.8(f)(2)(iv), you must include
the value for the combustion zone temperature operating parameter limit
set based on your performance test in the performance test report. Data
collected using test methods supported by the EPA's Electronic Reporting
Tool (ERT) and performance evaluations of CEMS measuring RATA pollutants
that are supported by the EPA's ERT as listed on the EPA's ERT website
(https://www.epa.gov/electronic-reporting-air-emissions/electronic-
reporting-tool-ert) at the time of the test or performance evaluation
must be submitted in a file format generated using the EPA's ERT.
Alternatively, you may submit an electronic file consistent with the
extensible markup language (XML) schema listed on the EPA's ERT website.
Data collected using test methods that are not supported by the EPA's
ERT and performance evaluations of CEMS measuring RATA pollutants that
are not supported by the EPA's ERT as listed on the EPA's ERT website at
the time of the test or performance evaluation must be included as an
attachment in the ERT or an alternate electronic file.
(c) Reporting requirements for semiannual report. You must submit to
the Administrator semiannual reports with the applicable information in
paragraphs (c)(1) through (7) of this section by the dates specified in
paragraph (d) of this section following the procedure specified in
paragraph (e) of this section. For this subpart, the semiannual reports
supersede the excess emissions and monitoring systems performance report
and/or summary report form required under Sec. 60.7. Beginning on July
8, 2024, or once the report template for this subpart has been available
on the CEDRI website (https://www.epa.gov/electronic-reporting-air-
emissions/cedri) for one year, whichever date is later, submit all
subsequent reports using the appropriate electronic report template on
the CEDRI website for this subpart and following the procedure specified
in paragraph (e). The date report templates become available will be
listed on the CEDRI website. Unless the Administrator or delegated State
agency or other authority has approved a different schedule for
submission of reports, the report must be submitted by the deadline
specified in this subpart, regardless of the method in which the report
is submitted.
(1) Report the following general facility information:
(i) Facility name.
(ii) Facility physical address, including city, county, and State.
(iii) Latitude and longitude of facility's physical location.
Coordinates must be in decimal degrees with at least five decimal
places.
[[Page 57]]
(iv) The following information for the contact person:
(A) Name.
(B) Mailing address.
(C) Telephone number.
(D) Email address.
(v) Date of report and beginning and ending dates of the reporting
period. You are no longer required to provide the date of report when
the report is submitted via CEDRI.
(vi) Statement by a responsible official, with that official's name,
title, and signature, certifying the truth, accuracy, and completeness
of the content of the report. If your report is submitted via CEDRI, the
certifier's electronic signature during the submission process replaces
the requirement in this paragraph (c)(1)(vi).
(2) For each thermal oxidation system used to comply with the
emission limitations in Sec. 60.502a(b)(1) or (c)(1) by monitoring the
combustion zone temperature as specified in Sec. 60.502a(b)(1)(ii) or
(c)(1)(ii), for each pressure CPMS used to comply with the requirements
in Sec. 60.502a(h), and for each vapor recovery system used to comply
with the emission limitations in Sec. 60.502a(b)(2) or (c)(2) report
the following information for the CMS:
(i) For all instances when the temperature CPMS measured 3-hour
rolling averages below the established operating limit or when the vapor
collection system pressure exceeded the maximum loading pressure
specified in Sec. 60.502a(h) when liquid product was being loaded into
gasoline cargo tanks or when the TOC CEMS measured 3-hour rolling
average concentrations higher than the applicable emission limitation
when the vapor recovery system was operating:
(A) The date and start time of the deviation.
(B) The duration of the deviation in hours.
(C) Each 3-hour rolling average combustion zone temperature, average
pressure, or 3-hour rolling average TOC concentration during the
deviation. For TOC concentration, indicate whether methane is excluded
from the TOC concentration.
(D) A unique identifier for the CMS.
(E) The make, model number, and date of last calibration check of
the CMS.
(F) The cause of the deviation and the corrective action taken.
(ii) For all instances that the temperature CPMS for measuring the
combustion zone temperature or pressure CPMS was not operating or was
out of control when liquid product was loaded into gasoline cargo tanks,
or the TOC CEMS was not operating or was out of control when the vapor
recovery system was operating:
(A) The date and start time of the deviation.
(B) The duration of the deviation in hours.
(C) A unique identifier for the CMS.
(D) The make, model number, and date of last calibration check of
the CMS.
(E) The cause of the deviation and the corrective action taken. For
TOC CEMS outages where the limited alternative for vapor recovery
systems in Sec. 60.504a(e) is used, the corrective action taken shall
include an indication of the use of the limited alternative for vapor
recovery systems in Sec. 60.504a(e).
(F) For TOC CEMS outages where the limited alternative for vapor
recovery systems in Sec. 60.504a(e) is used, report either an
indication that there were no deviations from the operating limits when
using the limited alternative or report the number of each of the
following types of deviations that occurred during the use of the
limited alternative for vapor recovery systems in Sec. 60.504a(e).
(1) The number of adsorption cycles when the quantity of liquid
product loaded in gasoline cargo tanks exceeded the operating limit
established in Sec. 60.504a(e)(1). Enter 0 if no deviations of this
type.
(2) The number of desorption cycles when the vacuum pressure was
below the average vacuum pressure as specified in Sec.
60.504a(e)(2)(i). Enter 0 if no deviations of this type.
(3) The number of desorption cycles when the quantity of purge gas
used was below the average quantity of purge gas as specified in Sec.
60.504a(e)(2)(ii). Enter 0 if no deviations of this type.
[[Page 58]]
(4) The number of desorption cycles when the duration of the vacuum/
purge cycle was less than the average duration as specified in Sec.
60.504a(e)(2)(iii). Enter 0 if no deviations of this type.
(3) For each flare used to comply with the emission limitations in
Sec. 60.502a(c)(3) and for each thermal oxidation system using the
flare monitoring alternative as provided in Sec. 60.502a(c)(1)(iii),
report:
(i) The date and start and end times for each of the following
instances:
(A) Each 15-minute block during which there was at least one minute
when gasoline vapors were routed to the flare and no pilot flame was
present.
(B) Each period of 2 consecutive hours during which visible
emissions exceeded a total of 5 minutes. Additionally, report the number
of minutes for which visible emissions were observed during the
observation or an estimate of the cumulative number of minutes in the 2-
hour period for which emissions were visible based on best information
available to the owner or operator.
(C) Each 15-minute period for which the applicable operating limits
specified in Sec. 63.670(d) through (f) of this chapter were not met.
You must identify the specific operating limit that was not met.
Additionally, report the information in paragraphs (c)(3)(i)(C)(1)
through (3) of this section, as applicable.
(1) If you use the loading rate operating limits as determined in
Sec. 60.502a(c)(3)(vii) alone or in combination with the supplemental
gas flow rate monitoring alternative in Sec. 60.502a(c)(3)(viii), the
required minimum ratio and the actual ratio of gasoline loaded to total
product loaded for the rolling 15-minute period and, if applicable, the
required minimum quantity and the actual quantity of gasoline loaded, in
gallons, for the rolling 15-minute period.
(2) If you use the supplemental gas flow rate monitoring alternative
in Sec. 60.502a(c)(3)(viii), the required minimum supplemental gas flow
rate and the actual supplemental gas flow rate including units of flow
rates for the 15-minute block.
(3) If you use parameter monitoring systems other than those
specified in paragraphs (c)(3)(i)(C)(1) and (2) of this section, the
value of the net heating value operating parameter(s) during the
deviation determined following the methods in Sec. 63.670(k) through
(n) of this chapter as applicable.
(ii) The start date, start time, and duration in minutes for each
period when ``vapors displaced from gasoline cargo tanks during product
loading'' were routed to the flare or thermal oxidation system and the
applicable monitoring was not performed.
(iii) For each instance reported under paragraphs (c)(3)(i) and (ii)
of this section that involves CMS, report the following information:
(A) A unique identifier for the CMS.
(B) The make, model number, and date of last calibration check of
the CMS.
(C) The cause of the deviation or downtime and the corrective action
taken.
(4) For any instance in which liquid product was loaded into a
gasoline cargo tank for which vapor tightness documentation required
under Sec. 60.502a(e)(1) was not provided or available in the
terminal's records, report:
(i) Cargo tank owner and address.
(ii) Cargo tank identification number.
(iii) Date and time liquid product was loaded into a gasoline cargo
tank without proper documentation.
(iv) Date proper documentation was received or statement that proper
documentation was never received.
(5) For each instance when liquid product was loaded into gasoline
cargo tanks not using submerged filling, as defined in Sec. 60.501a,
not equipped with vapor collection equipment that is compatible with the
terminal's vapor collection system, or not properly connected to the
terminal's vapor collection system, report:
(i) Date and time of liquid product loading into gasoline cargo tank
not using submerged filling, improperly equipped, or improperly
connected.
(ii) Type of deviation (e.g., not submerged filling, incompatible
equipment, or not properly connected).
(iii) Cargo tank identification number.
[[Page 59]]
(6) Report the following information for each leak inspection
required under Sec. Sec. 60.502a(j)(1) and 60.503a(a)(2) and each leak
identified under Sec. 60.502a(j)(2).
(i) For each leak detected during a leak inspection required under
Sec. Sec. 60.502a(j)(1) and 60.503a(a)(2), report:
(A) The date of inspection.
(B) The leak determination method (OGI or Method 21 of appendix A-7
to this part).
(C) The total number and type of equipment for which leaks were
detected.
(D) The total number and type of equipment for which leaks were
repaired within 15 calendar days.
(E) The total number and type of equipment for which no repair
attempt was made within 5 calendar days of the leaks being identified.
(F) The total number and type of equipment placed on the delay of
repair, as specified in Sec. 60.502a(j)(8).
(ii) For leaks identified under Sec. 60.502a(j)(2), report:
(A) The total number and type of equipment for which leaks were
identified.
(B) The total number and type of equipment for which leaks were
repaired within 15 calendar days.
(C) The total number and type of equipment for which no repair
attempt was made within 5 calendar days of the leaks being identified.
(D) The total number and type of equipment placed on the delay of
repair, as specified in Sec. 60.502a(j)(8).
(iii) The total number of leaks on the delay of repair list at the
start of the reporting period.
(iv) The total number of leaks on the delay of repair list at the
end of the reporting period.
(v) For each leak that was on the delay of repair list at any time
during the reporting period, report:
(A) Unique equipment identification number.
(B) Type of equipment.
(C) Leak determination method (OGI, Method 21 of appendix A-7 to
this part, or audio, visual, or olfactory).
(D) The reason(s) why the repair was not feasible within 15 calendar
days.
(E) If applicable, the date repair was completed.
(7) If there were no deviations from the emission limitations,
operating parameters, or work practice standards, then provide a
statement that there were no deviations from the emission limitations,
operating limits, or work practice standards during the reporting
period. If there were no periods during which a CMS (including a CEMS or
CPMS) was inoperable or out-of-control, then provide a statement that
there were no periods during which a CMS was inoperable or out-of-
control during the reporting period.
(d) Timeframe for semiannual report submissions. (1) The first
semiannual report will cover the date starting with the date the source
first becomes an affected facility subject to this subpart and ending
with the last day of the month five months later. For example, if the
source becomes an affected facility on April 15, the first semiannual
report would cover the period from April 15 to September 30. The first
semiannual report must be submitted on or before the last day of the
month two months after the last date covered by the semiannual report.
In this example, the first semiannual report would be due November 30.
(2) Subsequent semiannual reports will cover subsequent 6 calendar
month periods with each report due on or before the last day of the
month two months after the last date covered by the semiannual report.
(e) Requirements for electronically submitting reports. For reports
required to be submitted following the procedures specified in this
paragraph (e), you must submit reports to the EPA via CEDRI, which can
be accessed through the EPA's Central Data Exchange (CDX) (https://
cdx.epa.gov/). The EPA will make all the information submitted through
CEDRI available to the public without further notice to you. Do not use
CEDRI to submit information you claim as confidential business
information (CBI). Although we do not expect persons to assert a claim
of CBI, if you wish to assert a CBI claim for some of the information in
the report, you must submit a complete file in the format specified in
this subpart, including information claimed to be CBI, to the EPA
following the procedures in paragraphs (e)(1) and (2) of this section.
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Clearly mark the part or all of the information that you claim to be
CBI. Information not marked as CBI may be authorized for public release
without prior notice. Information marked as CBI will not be disclosed
except in accordance with procedures set forth in 40 CFR part 2. All CBI
claims must be asserted at the time of submission. Anything submitted
using CEDRI cannot later be claimed CBI. Furthermore, under CAA section
114(c), emissions data are not entitled to confidential treatment, and
the EPA is required to make emissions data available to the public.
Thus, emissions data will not be protected as CBI and will be made
publicly available. You must submit the same file submitted to the CBI
office with the CBI omitted to the EPA via the EPA's CDX as described
earlier in this paragraph (e).
(1) The preferred method to receive CBI is for it to be transmitted
electronically using email attachments, File Transfer Protocol, or other
online file sharing services. Electronic submissions must be transmitted
directly to the OAQPS CBI Office at the email address [email protected],
and as described above, should include clear CBI markings. ERT files
should be flagged to the attention of the Group Leader, Measurement
Policy Group; all other files should be flagged to the attention of the
Gasoline Distribution Sector Lead. If assistance is needed with
submitting large electronic files that exceed the file size limit for
email attachments, and if you do not have your own file sharing service,
please email [email protected] to request a file transfer link.
(2) If you cannot transmit the file electronically, you may send CBI
information through the postal service to the following address: U.S.
EPA, Attn: OAQPS Document Control Officer, Mail Drop: C404-02, 109 T.W.
Alexander Drive, P.O. Box 12055, RTP, NC 27711. ERT files should be
flagged to the attention of the Group Leader, Measurement Policy Group,
and all other files should also be flagged to the attention of the
Gasoline Distribution Sector Lead. The mailed CBI material should be
double wrapped and clearly marked. Any CBI markings should not show
through the outer envelope.
(f) Claims of EPA system outage. If you are required to
electronically submit a report through CEDRI in the EPA's CDX, you may
assert a claim of EPA system outage for failure to timely comply with
that reporting requirement. To assert a claim of EPA system outage, you
must meet the requirements outlined in paragraphs (f)(1) through (7) of
this section.
(1) You must have been or will be precluded from accessing CEDRI and
submitting a required report within the time prescribed due to an outage
of either the EPA's CEDRI or CDX systems.
(2) The outage must have occurred within the period of time
beginning five business days prior to the date that the submission is
due.
(3) The outage may be planned or unplanned.
(4) You must submit notification to the Administrator in writing as
soon as possible following the date you first knew, or through due
diligence should have known, that the event may cause or has caused a
delay in reporting.
(5) You must provide to the Administrator a written description
identifying:
(i) The date(s) and time(s) when CDX or CEDRI was accessed and the
system was unavailable;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to EPA system outage;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which you propose to report, or if you have already
met the reporting requirement at the time of the notification, the date
you reported.
(6) The decision to accept the claim of EPA system outage and allow
an extension to the reporting deadline is solely within the discretion
of the Administrator.
(7) In any circumstance, the report must be submitted electronically
as soon as possible after the outage is resolved.
(g) Claims of force majeure. If you are required to electronically
submit a report through CEDRI in the EPA's CDX, you may assert a claim
of force majeure for failure to timely comply with that reporting
requirement. To assert a claim of force majeure, you must meet
[[Page 61]]
the requirements outlined in paragraphs (g)(1) through (5) of this
section.
(1) You may submit a claim if a force majeure event is about to
occur, occurs, or has occurred or there are lingering effects from such
an event within the period of time beginning five business days prior to
the date the submission is due. For the purposes of this section, a
force majeure event is defined as an event that will be or has been
caused by circumstances beyond the control of the affected facility, its
contractors, or any entity controlled by the affected facility that
prevents you from complying with the requirement to submit a report
electronically within the time period prescribed. Examples of such
events are acts of nature (e.g., hurricanes, earthquakes, or floods),
acts of war or terrorism, or equipment failure or safety hazard beyond
the control of the affected facility (e.g., large scale power outage).
(2) You must submit notification to the Administrator in writing as
soon as possible following the date you first knew, or through due
diligence should have known, that the event may cause or has caused a
delay in reporting.
(3) You must provide to the Administrator:
(i) A written description of the force majeure event;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to the force majeure event;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which you propose to report, or if you have already
met the reporting requirement at the time of the notification, the date
you reported.
(4) The decision to accept the claim of force majeure and allow an
extension to the reporting deadline is solely within the discretion of
the Administrator.
(5) In any circumstance, the reporting must occur as soon as
possible after the force majeure event occurs.
Subpart AAA_Standards of Performance for New Residential Wood Heaters
Source: 80 FR 13702, Mar. 16, 2015, unless otherwise noted.
Sec. 60.530 Am I subject to this subpart?
(a) You are subject to this subpart if you manufacture, sell, offer
for sale, import for sale, distribute, offer to distribute, introduce or
deliver for introduction into commerce in the United States, or install
or operate an affected wood heater specified in paragraphs (a)(1) or
(a)(2) of this section, except as provided in paragraph (c) of this
section.
(1) Each adjustable burn rate wood heater, single burn rate wood
heater and pellet stove manufactured on or after July 1, 1988, with a
current EPA certificate of compliance issued prior to May 15, 2015
according to the certification procedures in effect in this subpart at
the time of certification is an affected wood heater.
(2) All other residential wood heaters as defined in Sec. 60.531
manufactured or sold on or after May 15, 2015 are affected wood heaters,
except as provided in paragraph (c) of this section.
(b) Each affected wood heater must comply with the provisions of
this subpart unless exempted under paragraphs (b)(1) through (b)(6) of
this section. These exemptions are determined by rule applicability and
do not require EPA notification or public notice.
(1) Affected wood heaters manufactured in the United States for
export are exempt from the applicable emission limits of Sec. 60.532
and the requirements of Sec. 60.533.
(2) Affected wood heaters used for research and development purposes
that are never offered for sale or sold and that are not used for the
purpose of providing heat are 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 can be exempted for this
purpose.
(3) Appliances that do not burn wood or wood pellets (such as coal-
only heaters that meet the definition in Sec. 60.531 or corn-only
pellet stoves) are exempt from the applicable emission limits of
[[Page 62]]
Sec. 60.532 and the requirements of Sec. 60.533 provided that all
advertising and warranties exclude wood burning.
(4) Cook stoves as defined in Sec. 60.531 are exempt from the
applicable emission limits of Sec. 60.532 and the requirements of Sec.
60.533.
(5) Camp stoves as defined in Sec. 60.531 are exempt from the
applicable emission limits of Sec. 60.532 and the requirements of Sec.
60.533.
(6) Modification or reconstruction, as defined in Sec. Sec. 60.14
and 60.15 of subpart A of this part does not, by itself, make a wood
heater an affected facility under this subpart.
(c) The following are not affected wood heaters and are not subject
to this subpart:
(1) Residential hydronic heaters and residential forced-air furnaces
subject to subpart QQQQ of this part.
(2) Residential masonry heaters that meet the definition in Sec.
60.531.
(3) Appliances that are not residential heating devices (for
example, manufactured or site-built masonry fireplaces).
(4) Traditional Native American bake ovens that meet the definition
in Sec. 60.531.
Sec. 60.531 What definitions must I know?
As used in this subpart, all terms not defined herein have the
meaning given them in the Clean Air Act and subpart A of this part.
Adjustable burn rate wood heater means a wood heater that is
equipped with or installed with a damper or other mechanism to allow the
operator to vary burn rate conditions, regardless of whether it is
internal or external to the appliance. This definition does not
distinguish between heaters that are free standing, built-in or
fireplace inserts.
Approved test laboratory means a test laboratory that is approved
for wood heater certification testing under Sec. 60.535 or is an
independent third-party test laboratory that is accredited under ISO-IEC
Standard 17025 to perform testing using the test methods specified in
Sec. 60.534 by an accreditation body that is a full member signatory to
the International Laboratory Accreditation Cooperation Mutual
Recognition Arrangement and approved by the EPA for conducting testing
under this subpart.
Camp stove (sometimes also called cylinder stove or wall tent stove)
means a portable stove equipped with a pipe or chimney exhaust capable
of burning wood or coal intended for use in a tent or other temporary
structure used for hunting, camping, fishing or other outdoor
recreation. The primary purpose of the stove is to provide space
heating, although cooking and heating water may be additional functions.
Catalytic combustor means a device coated with a noble metal used in
a wood heater to lower the temperature required for combustion.
Chip wood fuel means wood chipped into small pieces that are uniform
in size, shape, moisture, density and energy content.
Coal-only heater means an enclosed, coal-burning appliance capable
of space heating or space heating and domestic water heating, which is
marketed and warranted solely as a coal-only heater and has all of the
following characteristics:
(1) An opening for emptying ash that is located near the bottom or
the side of the appliance;
(2) A system that admits air primarily up and through the fuel bed;
(3) A grate or other similar device for shaking or disturbing the
fuel bed or a power-driven or mechanical stoker;
(4) Installation instructions, owner's manual and marketing
information that state that the use of wood in the stove, except for
coal ignition purposes, is prohibited by law; and
(5) A safety listing as a coal-only heater, except for coal ignition
purposes, under accepted American or Canadian safety codes, as
documented by a permanent label from a nationally recognized
certification body.
Commercial owner means any person who owns or controls a wood heater
in the course of the business of the manufacture, importation,
distribution (including shipping and storage), or sale of the wood
heater.
Cook stove means a wood-fired appliance that is designed, marketed
and warranted primarily for cooking food and that has the following
characteristics:
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(1) An oven, with volume of 0.028 cubic meters (1 cubic foot) or
greater, and an oven rack;
(2) A device for measuring oven temperatures;
(3) A flame path that is routed around the oven;
(4) An ash pan;
(5) An ash clean-out door below the oven;
(6) The absence of a fan or heat channels to dissipate heat from the
appliance;
(7) A cooking surface with an area measured in square inches or
square feet that is at least 1.5 times greater than the volume of
firebox measured in cubic inches or cubic feet. Example: A cook stove
with a firebox of 2 cubic feet must have a cooking surface of at least 3
square feet;
(8) A portion of at least four sides of the oven (which may include
the bottom and/or top) is exposed to the flame path during the heating
cycle of the oven. A flue gas bypass may exist for temperature control.
Fireplace means a wood-burning appliance intended to be used
primarily for aesthetic enjoyment and not as a space heater. An
appliance is a fireplace if it is in a model line that satisfies the
requirements in paragraphs (1), (2) or (3) of this definition.
(1) The model line includes a safety listing under recognized
American or Canadian safety standards, as documented by a permanent
label from a nationally recognized certification body affixed on each
unit sold, and that said safety listing only allows operation of the
fireplace with doors fully open. Operation with any required safety
screen satisfies this requirement.
(2) The model line has a safety listing that allows operation with
doors closed, has no user-operated controls other than flue or outside
air dampers that can only be adjusted to either a fully closed or fully
opened position, and the requirements in either paragraph (2)(i) or
(2)(ii) of this definition are satisfied.
(i) Appliances are sold with tempered glass panel doors only (either
as standard or optional equipment), or
(ii) The fire viewing area is equal to or greater than 500 square
inches.
(3)(i) A model line that is clearly positioned in the marketplace as
intended to be used primarily for aesthetic enjoyment and not as a room
heater, as demonstrated by product literature (including owner's
manuals), advertising targeted at the trade or public (including web-
based promotional materials) or training materials is presumptively a
fireplace model line.
(ii) The presumption in paragraph (3)(i) of this definition can be
rebutted by test data from an EPA-approved test laboratory reviewed by
an EPA-approved third-party certifier that were generated when operating
the appliance with the door(s) closed, and that demonstrate an average
stack gas carbon dioxide (CO2) concentration over the
duration of the test run equal to or less than 5.00 percent and a ratio
of the average stack gas CO2 to the average stack gas carbon
monoxide (CO) equal to or greater than 15:1. The stack gas average
CO2 and CO concentrations for the test run shall be
determined in accordance with the requirements in CSA B415.1-10 (IBR,
see Sec. 60.17), clause 6.3, using a sampling interval no greater than
1 minute. The average stack gas CO2 and CO concentrations for
purposes of this determination shall be the average of the stack gas
concentrations from all sampling intervals over the full test run.
Manufactured means completed and ready for shipment (whether or not
assembled or packaged) for purposes of determining the date of
manufacture.
Manufacturer means any entity that constructs or imports into the
United States a wood heater.
Model line means all wood heaters offered for sale by a single
manufacturer that are similar in all material respects that would affect
emissions as defined in this section.
Particulate matter (PM) means total particulate matter including
coarse particulate (PM10) and fine particulate
(PM2.5).
Pellet fuel means refined and densified fuel shaped into small
pellets or briquettes that are uniform in size, shape, moisture, density
and energy content.
Pellet stove (sometimes called pellet heater or pellet space heater)
means an
[[Page 64]]
enclosed, pellet or chip fuel-burning device capable of and intended for
residential space heating or space heating and domestic water heating.
Pellet stoves include a fuel storage hopper or bin and a fuel feed
system. Pellet stoves include, but are not limited to:
(1) Free-standing pellet stoves--pellet stoves that are installed on
legs or on a pedestal or other supporting base. These stoves generally
are safety listed under ASTM E1509, UL-1482, ULC S627 or ULC-ORD C1482.
(2) Pellet stove fireplace inserts--pellet stoves intended to be
installed in masonry fireplace cavities or in other enclosures. These
stoves generally are safety listed under ASTM E1509, UL-1482, ULC-S628
or ULC-ORD C1482.
(3) Built-in pellet stoves--pellet stoves intended to be recessed
into the wall. These stoves generally are safety listed under ASTM
E1509, UL-127, ULC-S610 or ULC-ORD C1482.
Representative affected wood heater means an individual wood heater
that is similar in all material respects that would affect emissions to
other wood heaters within the model line it represents.
Residential masonry heater means a factory-built or site-built wood-
burning device in which the heat from intermittent fires burned rapidly
in the firebox is stored in the refractory mass for slow release to
building spaces. Masonry heaters are site-built (using local materials
or a combination of local materials and manufactured components) or
site-assembled (using factory-built components), solid fuel-burning
heating appliances constructed mainly of refractory materials (e.g.,
masonry materials or soapstone. They typically have an interior
construction consisting of a firebox and heat exchange channels built
from refractory components, through which flue gases are routed. ASTM E-
1602 ``Standard Guide for Construction of Solid Fuel Burning Masonry
Heaters'' provides design and construction information for the range of
masonry heaters most commonly built in the United States. The site-
assembled models are generally listed to UL-1482.
Sale means the transfer of ownership or control, except that a
transfer of control of an affected wood heater for research and
development purposes within the scope of Sec. 60.530(b)(2) is not a
sale.
Similar in all material respects that would affect emissions means
that the construction materials, exhaust and inlet air systems and other
design features are within the allowed tolerances for components
identified in Sec. 60.533(k)(2), (3) and (4).
Single burn rate wood heater means a wood heater that is not
equipped with or installed with a burn control device to allow the
operator to vary burn rate conditions. Burn rate control devices include
stack dampers that control the outflow of flue gases from the heater to
the chimney, whether built into the appliance, sold with it, or
recommended for use with the heater by the manufacturer, retailer or
installer; and air control slides, gates or any other type of mechanisms
that control combustion air flow into the heater.
Sold at retail means the sale by a commercial owner of a wood heater
to the ultimate purchaser/user or noncommercial purchaser.
Third-party certifier (sometimes called third-party certifying body
or product certifying body) means an independent third party that is
accredited under ISO-IEC Standards 17025 and 17065 to perform
certifications, inspections and audits by an accreditation body that is
a full member signatory to the International Laboratory Accreditation
Cooperation Mutual Recognition Arrangement and approved by the EPA for
conducting certifications, inspections and audits under this subpart.
Traditional Native American bake oven means a wood or other solid
fuel burning appliance that is designed primarily for use by Native
Americans for food preparation, cooking, warming or for instructional,
recreational, cultural or ceremonial purposes.
Unseasoned wood means wood with an average moisture content of 20
percent or more.
Valid certification test means a test that meets the following
criteria:
(1) The Administrator was notified about the test in accordance with
Sec. 60.534(g);
(2) The test was conducted by an approved test laboratory as defined
in this section;
[[Page 65]]
(3) The test was conducted on a wood heater similar in all material
respects that would affect emissions to other wood heaters of the model
line that is to be certified; and
(4) The test was conducted in accordance with the test methods and
procedures specified in Sec. 60.534.
Wood heater means an enclosed, wood burning-appliance capable of and
intended for residential space heating or space heating and domestic
water heating. These devices include, but are not limited to, adjustable
burn rate wood heaters, single burn rate wood heaters and pellet stoves.
Wood heaters may or may not include air ducts to deliver some portion of
the heat produced to areas other than the space where the wood heater is
located. Wood heaters include, but are not limited to:
(1) Free-standing wood heaters--Wood heaters that are installed on
legs, on a pedestal or suspended from the ceiling. These products
generally are safety listed under UL-1482, UL-737 or ULC-S627.
(2) Fireplace insert wood heaters--Wood heaters intended to be
installed in masonry fireplace cavities or in other enclosures. These
appliances generally are safety listed under UL-1482, UL-737 or ULC-
S628.
(3) Built-in wood heaters--Wood heaters that are intended to be
recessed into the wall. These appliances generally are safety listed
under UL-1482, UL-737, UL-127 or ULC-S610.
Sec. 60.532 What standards and associated requirements must I meet and by when?
(a) 2015 particulate matter emission standards. Unless exempted
under Sec. 60.530(b), each affected wood heater manufactured, imported
into the United States, and/or sold at retail on or after May 15, 2015
must be certified to not discharge into the atmosphere any gases that
contain particulate matter in excess of a weighted average of 4.5 g/hr
(0.010 lb/hr), except that a wood heater manufactured before May 15,
2015 may be imported into the United States and/or sold at retail on or
before December 31, 2015. Compliance for all heaters must be determined
by the test methods and procedures in Sec. 60.534.
(b) 2020 particulate matter emission standards. Unless exempted
under Sec. 60.530(b) or electing to use the cord wood alternative means
of compliance option in paragraph (c) of the section, each affected wood
heater manufactured or sold at retail for use in the United States on or
after May 15, 2020 must not discharge into the atmosphere any gases that
contain particulate matter in excess of a weighted average of 2.0 g/hr
(0.0044 lb/hr). Compliance for all heaters must be determined by the
test methods and procedures in Sec. 60.534.
(c) 2020 cord wood alternative compliance option. Each affected wood
heater manufactured or sold at retail for use in the United States on or
after May 15, 2020 must not discharge into the atmosphere any gases that
contain particulate matter in excess of a weighted average of 2.5 g/hr
(0.0055 lb/hr). Compliance must be determined by a cord wood test method
approved by the Administrator and the procedures in Sec. 60.534.
(d) Chip wood fuel requirements. Operators of wood heaters that are
certified to burn chip wood fuels must only burn chip wood fuels that
have been specified in the owner's manual. The chip wood fuel must meet
the following minimum requirements:
(1) Moisture content: less than 35 percent;
(2) Inorganic fines: less than or equal to 1 percent;
(3) Chlorides: less than or equal to 300 parts per million by
weight;
(4) Ash content: no more than 2 percent;
(5) No demolition or construction waste; and
(6) Trace metals: less than 100 mg/kg.
(e) Pellet fuel requirements. Operators of wood heaters that are
certified to burn pellet fuels may burn only pellets that have been
specified in the owner's manual and graded under a licensing agreement
with a third-party organization approved by the EPA (including a
certification by the third-party organization that the pellets do not
contain, and are not manufactured from, any of the prohibited fuels in
paragraph (f) of this section). The Pellet Fuels Institute, ENplus, and
CANplus are initially
[[Page 66]]
deemed to be approved third-party organizations for this purpose, and
additional organizations may apply to the Administrator for approval.
(f) Prohibited fuel types. No person is permitted to burn any of the
following materials in an affected wood heater:
(1) Residential or commercial garbage;
(2) Lawn clippings or yard waste;
(3) Materials containing rubber, including tires;
(4) Materials containing plastic;
(5) Waste petroleum products, paints or paint thinners, or asphalt
products;
(6) Materials containing asbestos;
(7) Construction or demolition debris;
(8) Paper products, cardboard, plywood, or particleboard. The
prohibition against burning these materials does not prohibit the use of
fire starters made from paper, cardboard, sawdust, wax and similar
substances for the purpose of starting a fire in an affected wood
heater;
(9) Railroad ties, pressure-treated wood or pallets;
(10) Manure or animal remains;
(11) Salt water driftwood or other previously salt water saturated
materials;
(12) Unseasoned wood;
(13) Any materials that are not included in the warranty and owner's
manual for the subject wood heater; or
(14) Any materials that were not included in the certification tests
for the subject wood heater.
(g) Operation of affected wood heaters. The user of an affected
residential wood heater must operate the heater in a manner consistent
with the owner's manual. The owner's manual must clearly specify that
operation in a manner inconsistent with the owner's manual would void
the warranty.
(h) Temperature sensor requirement. An affected wood heater equipped
with a catalytic combustor must be equipped with a temperature sensor
that can monitor combustor gas stream temperatures within or immediately
downstream [within 2.54 centimeters (1 inch)] of the catalytic combustor
surface.
[80 FR 13702, Mar. 16, 2015, as amended at 85 FR 18455, Apr. 2, 2020]
Sec. 60.533 What compliance and certification requirements
must I meet and by when?
(a) Certification requirement. Each affected wood heater must be
certified to be in compliance with the applicable emission standards and
other requirements of this subpart. For each model line manufactured or
sold by a single entity (e.g., company or manufacturer), compliance with
applicable emission standards of Sec. 60.532 must be determined based
on testing of representative affected wood heaters within the model
line. If one entity licenses a model line to another entity, each
entity's model line must be certified. If an entity intends to change
the name of the entity or the name of the model, the manufacturer must
apply for a new certification 60 days before the intended name change.
(1) Except for model lines meeting the requirements of paragraph
(h)(1) of this section, on or after May 15, 2015, the manufacturer must
submit to the Administrator the information required in paragraph (b) of
this section and follow either the certification process in paragraphs
(c) through (e) of this section or the third-party certifier-based
application process specified in paragraph (f) of this section.
(2) On or after May 16, 2016, the manufacturer must submit the
information required in paragraph (b) of this section and follow the
third-party certifier-based application process specified in paragraph
(f) of this section.
(b) Application for a certificate of compliance. Any manufacturer of
an affected wood heater must apply to the Administrator for a
certificate of compliance for each model line. The application must be
submitted to: [email protected]. The application must be signed
by a responsible representative of the manufacturer or an authorized
representative and must contain the following:
(1) The model name and design number. The model name and design
number must clearly distinguish one model from another. The name and
design number cannot include the EPA symbol or logo or name or
derivatives such as ``EPA.''
[[Page 67]]
(2) Engineering drawings and specifications of components that may
affect emissions (including specifications for each component listed in
paragraph (k)(2), (3) and (4) of this section). Manufacturers may use
assembly or design drawings that have been prepared for other purposes,
but must designate on the drawings the dimensions of each component
listed in paragraph (k) of this section. Manufacturers must identify
tolerances of components listed in paragraph (k)(2) of this section that
are different from those specified in that paragraph, and show that such
tolerances cannot reasonably be anticipated to cause wood heaters in the
model line to exceed the applicable emission limits. The drawings must
identify how the emission-critical parts, such as air tubes and
catalyst, can be readily inspected and replaced.
(3) A statement whether the firebox or any firebox component
(including the materials listed in paragraph (k)(3) of this section)
will be composed of material different from the material used for the
firebox or firebox component in the wood heater on which certification
testing was performed, a description of any such differences and
demonstration that any such differences may not reasonably be
anticipated to adversely affect emissions or efficiency.
(4) Clear identification of any claimed confidential business
information (CBI). Submit such information under separate cover to the
EPA CBI Office; Attn: Residential Wood Heater Compliance Program Lead,
1200 Pennsylvania Ave. NW., Washington, DC 20004. Note that all
emissions data, including all information necessary to determine
emission rates in the format of the standard, cannot be claimed as CBI.
(5) 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 must include the items specified in the applicable test
methods. Documentation must include discussion of each test run and its
appropriateness and validity, and must include detailed discussion of
all anomalies, whether all burn rate categories were achieved, any data
not used in the calculations and, for any test runs not completed, the
data collected during the test run and the reason(s) that the test run
was not completed and why. The burn rate for the low burn rate category
must be no greater than the rate that an operator can achieve in home
use and no greater than is advertised by the manufacturer or retailer.
The test report must include a summary table that clearly presents the
individual and overall emission rates, efficiencies and heat outputs.
Submit the test report and all associated required information,
according to the procedures for electronic reporting specified in Sec.
60.537(f).
(6) A copy of the warranties for the model line, which must include
a statement that the warranties are void if the unit is used to burn
materials for which the unit is not certified by the EPA and void if not
operated according to the owner's manual.
(7) A statement that the manufacturer will conduct a quality
assurance program for the model line that satisfies the requirements of
paragraph (m) of this section.
(8) A statement describing how the tested unit was sealed by the
laboratory after the completion of certification testing and asserting
that such unit will be stored by the manufacturer in the sealed state
until 5 years after the certification test.
(9) Statements that the wood heaters manufactured under this
certificate will be--
(i) Similar in all material respects that would affect emissions as
defined in Sec. 60.531 to the wood heater submitted for certification
testing, and
(ii) Labeled as prescribed in Sec. 60.536.
(iii) Accompanied by an owner's manual that meets the requirements
in Sec. 60.536. In addition, a copy of the owner's manual must be
submitted to the Administrator and be available to the public on the
manufacturer's Web site.
(10) A statement that the manufacturer has entered into contracts
with an approved laboratory and an approved third-party certifier that
satisfy the requirements of paragraph (f) of this section.
(11) A statement that the approved laboratory and approved third-
party
[[Page 68]]
certifier are allowed to submit information on behalf of the
manufacturer, including any claimed to be CBI.
(12) A statement that the manufacturer will place a copy of the
certification test report and summary on the manufacturer's Web site
available to the public within 30 days after the Administrator issues a
certificate of compliance.
(13) A statement of acknowledgment that the certificate of
compliance cannot be transferred to another manufacturer or model line
without written approval by the Administrator.
(14) A statement acknowledging that it is unlawful to sell,
distribute or offer to sell or distribute an affected wood heater
without a valid certificate of compliance.
(15) Contact information for the responsible representative of the
manufacturer and all authorized representatives, including name,
affiliation, physical address, telephone number and email address.
(c) Administrator approval process. (1) The Administrator may issue
a certificate of compliance for a model line if the Administrator
determines, based on all information submitted by the applicant and any
other relevant information available, that:
(i) A valid certification test demonstrates that the representative
affected wood heater complies with the applicable emission standards 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 paragraph (b) of this section have been
met.
(2) The Administrator will deny certification if the Administrator
determines that the criteria in paragraph (c)(1) of this section have
not been satisfied. Upon denying certification under this paragraph, the
Administrator will give written notice to the manufacturer setting forth
the basis for this determination.
(d) Level of compliance certification. The Administrator will issue
the certificate of compliance for the most stringent particulate matter
emission standard that the tested representative wood heater meets under
Sec. 60.532.
(e) Conditional, temporary certificate of compliance. A conditional,
temporary certificate of compliance may be granted by the Administrator
until May 16, 2016 based on the manufacturer's submittal of a complete
certification application meeting all the requirements in Sec.
60.533(b). The application must include the full test report by an EPA-
approved laboratory and all required compliance statements by the
manufacturer with the exception of a certificate of conformity by an
EPA-approved third-party certifier. The conditional, temporary
certificate of compliance would allow manufacture and sales of the
affected wood heater model line until May 16, 2016 or until the
Administrator completes the review of the application, whichever is
earlier. By May 16, 2016, the manufacturer must submit a certificate of
conformity by an EPA-approved third-party certifier.
(f) Third-party certifier-based application process. (1) Any
manufacturer of an affected wood heater must apply to the Administrator
for a certificate of compliance for each model line. The manufacturer
must meet the following requirements:
(i) The manufacturer must contract with a third-party certifier for
certification services. The contract must include regular (at least
annual) unannounced audits under ISO-IEC Standard 17065 to ensure that
the manufacturer's quality assurance plan is being implemented. The
contract must also include a report for each audit under ISO-IEC
Standard 17065 that fully documents the results of the audit. The
contract must include authorization and requirement for the third-party
certifier to submit all such reports to the Administrator and the
manufacturer within 30 days of the audit. The audit report must identify
deviations from the manufacturer's quality assurance plan and specify
the corrective actions that need to be taken to address each identified
deficiency.
(ii) The manufacturer must submit the materials specified in
paragraph (b) of this section and a quality assurance plan that meets
the requirements of
[[Page 69]]
paragraph (m) of this section to the third-party certifier. The quality
assurance plan must ensure that units within a model line will be
similar in all material respects that would affect emissions to the wood
heater submitted for certification testing, and it must include design
drawings for the model line.
(iii) The manufacturer must apply to the third-party certifier for a
certification of conformity with the applicable requirements of this
subpart for the model line.
(A) After testing by an approved test laboratory is complete,
certification of conformity with the emission standards in Sec. 60.532
must be performed by the manufacturer's contracted third-party
certifier.
(B) The third-party certifier may certify conformity if the emission
tests have been conducted per the appropriate guidelines; the test
report is complete and accurate; the instrumentation used for the test
was properly calibrated; the test report shows that the representative
affected wood heater meets the applicable emission limits specified in
Sec. 60.532; the quality assurance plan is adequate to ensure that
units within the model line will be similar in all material respects
that would affect emissions to the wood heater submitted for
certification testing; and that the affected heaters would meet all
applicable requirements of this subpart.
(iv) The manufacturer must then submit to the Administrator an
application for a certificate of compliance that includes the
certification of conformity, quality assurance plan, test report and all
supporting documentation specified in paragraph (b) of this section.
(v) The submission also must include a statement signed by a
responsible official of the manufacturer or authorized representative
that the manufacturer has complied with and will continue to comply with
all requirements of this subpart for certificate of compliance and that
the manufacturer remains responsible for compliance regardless of any
error by the test laboratory or third-party certifier.
(2) The Administrator will issue to the manufacturer a certificate
of compliance for a model line if it is determined, based on all of the
information submitted in the application for certification and any other
relevant information, that:
(i) A valid certification of conformity has demonstrated that the
representative affected wood heater complies with the applicable
emission standards 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 be reasonably anticipated to cause wood heaters
in the model line to exceed the applicable emission limits;
(iii) The requirements of paragraph (b) of this section have been
met; and
(iv) A valid certificate of conformity for the model line has been
prepared and submitted.
(3) The Administrator will deny certification if the Administrator
determines that the criteria in paragraph (f)(2) of this section have
not been satisfied. Upon denying certification under this paragraph, the
Administrator will give written notice to the manufacturer setting forth
the basis for the determination.
(g) Waiver from submitting test results. An applicant for
certification may apply for a potential waiver of the requirement to
submit the results of a certification test pursuant to paragraph (b)(5)
of this section, if the wood heater meets either of the following
conditions:
(1) The wood heaters of the model line are similar in all material
respects that would affect emissions, as defined in Sec. 60.531, 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.
(2) The manufacturer has previously conducted a valid certification
test to demonstrate that the wood heaters of the model line meet the
applicable standard specified in Sec. 60.532.
(h) Certification period. Unless revoked sooner by the
Administrator, a
[[Page 70]]
certificate of compliance will be valid for the following periods as
applicable:
(1) For a model line that was previously certified as meeting the
1990 Phase II emission standards under the 1988 NSPS, in effect prior to
May 15, 2015, at an emission level equal to or less than the 2015
emission standards in Sec. 60.532(a), the model line is deemed to have
a certificate of compliance for the 2015 emission standards in Sec.
60.532(a), which is valid until the effective date for the 2020
standards in Sec. 60.532(b) (i.e., until May 15, 2020).
(2) For a model line certified as meeting emission standards in
Sec. 60.532, a certificate of compliance will be valid for 5 years from
the date of issuance or until a more stringent standard comes into
effect, whichever is sooner.
(i) Renewal of certification. (1) The manufacturer must request
renewal of a model line's certificate of compliance or recertify the
model line every 5 years, or the manufacturer may choose to no longer
manufacture or sell that model line after the expiration date. If the
manufacturer chooses to no longer manufacture that model line, then the
manufacturer must submit a statement to the Administrator to that
effect.
(2) A manufacturer of an affected wood heater model line may apply
to the Administrator for potential renewal of its certificate of
compliance by submitting the material specified in paragraph (b) and
following the procedures specified in paragraph (f) of this section, or
by affirming in writing that the wood heaters in the model line continue
to be similar in all material respects that would affect emissions to
the representative wood heater submitted for testing on which the
original certificate of compliance was based and requesting a potential
waiver from certification testing. The application must include a copy
of the review of the draft application and approval by the third-party
certifier.
(3) If the Administrator grants a renewal of certification, the
Administrator will give written notice to the manufacturer setting forth
the basis for the determination and issue a certification renewal.
(4) If the Administrator denies the request for a renewal of
certification, the Administrator will give written notice to the
manufacturer setting forth the basis for the determination.
(5) If the Administrator denies the request for a renewal of
certification, the manufacturer and retailer must not manufacture or
sell the previously-certified wood heaters after the expiration date of
the certificate of compliance.
(j) [Reserved]
(k) Recertification. (1) The manufacturer must recertify a model
line whenever any change is made in the design submitted pursuant to
paragraph (b)(2) of this section that affects or is presumed to affect
the particulate matter emission rate for that model line. The
manufacturer of an affected wood heater must apply to the Administrator
for potential recertification by submitting the material specified in
paragraph (b) and following the procedures specified in paragraph (f) of
this section, or by affirming in writing that the change will not cause
wood heaters in the model line to exceed applicable emission limits and
requesting a potential waiver from certification testing. The
application for recertification must be reviewed and approved by the
contracted third-party certifier and a copy of the review and approval
must be included. The Administrator may waive this requirement upon
written request by the manufacturer, if the manufacturer presents
adequate rationale and the Administrator determines that the change may
not reasonably be anticipated to cause wood heaters in the model line to
exceed the applicable emission limits. The granting of such a waiver
does not relieve the manufacturer of any compliance obligations under
this subpart.
(2) Any change in the design tolerances or actual dimensions of any
of the following components (where such components are applicable) is
presumed to affect particulate matter and carbon monoxide emissions and
efficiency if that change exceeds 0.64 cm (\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 (c)(1)(ii) of this section:
(i) Firebox: Dimensions;
[[Page 71]]
(ii) Air introduction systems: Cross-sectional area of restrictive
air inlets and outlets, 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 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 thermal shielding and thermal coverings: Dimensions and
location;
(x) Fuel feed system: For wood heaters that are designed primarily
to burn pellet fuel or wood chips 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 particulate matter emissions and efficiency:
(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 particulate matter and carbon monoxide emissions and
efficiency, unless the change has been requested by the heater
manufacturer and 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 matter emission reduction.
(l) Criteria for revocation of certification. (1) The Administrator
may revoke certification if it is determined that the wood heaters being
manufactured or sold in that model line do not comply with the
requirements of this subpart. Such a determination will be based on all
available evidence, including but not limited to:
(i) Test data from a retesting of the original unit on which the
certification test was conducted or a unit that is similar in all
material respects that would affect emissions;
(ii) A finding that the certification test was not valid. The
finding will 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 model line, the
owner's manual or the associated marketing information 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 (as
defined in the quality assurance plan approved pursuant to paragraph (m)
of this section, but no larger than 1 percent) of production units
inspected is not similar in all material respects that would affect
emissions to the representative affected wood heater submitted for
certification testing;
(vi) Failure of the manufacturer to conduct a quality assurance
program in conformity with paragraph (m) of this section; or
(vii) Failure of the approved laboratory to test the wood heater
using the methods specified in Sec. 60.534.
(2) Revocation of certification under this paragraph (l) will 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.
(m) Quality assurance program. On or after May 16, 2016, for each
certified model line, the manufacturer must conduct a quality assurance
program that satisfies the requirements of paragraphs (m)(1) through (5)
of this section. The quality assurance program requirements of this
paragraph (m) supersede the quality assurance plan requirements
previously specified in Sec. 60.533(o) that was in effect prior to May
15, 2015. The manufacturer of a
[[Page 72]]
model line with a compliance certification under paragraph (h)(1) of
this section must conduct a quality assurance program that satisfies the
requirements of this paragraph (m) by May 16, 2016.
(1) The manufacturer must prepare and operate according to a quality
assurance plan for each certified model line that includes specific
inspection and testing requirements for ensuring that all units within a
model line are similar in all material respects that would affect
emissions to the wood heater submitted for certification testing and
meet the emissions standards in Sec. 60.532.
(2) The quality assurance plan must be approved by the third-party
certifier as part of the certification of conformity process specified
in paragraph (f) of this section.
(3) The quality assurance plan must include regular (at least
annual) unannounced audits by the third-party certifier under ISO-IEC
Standard 17065 to ensure that the manufacturer's quality assurance plan
is being implemented.
(4) The quality assurance plan must include a report for each audit
under ISO-IEC Standard 17065 that fully documents the results of the
audit. The third-party certifier must be authorized and required to
submit all such reports to the Administrator and the manufacturer within
30 days of the audit. The audit report must identify deviations from the
manufacturer's quality assurance plan and specify the corrective actions
that need to be taken to address each identified deficiency.
(5) Within 30 days after receiving each audit report, the
manufacturer must report to the third-party certifier and to the
Administrator its corrective actions and responses to any deficiencies
identified in the audit report. No such report is required if an audit
report did not identify any deficiencies.
(n) EPA compliance audit testing. (1)(i) The Administrator may
select by written notice wood heaters or model lines for compliance
audit testing to determine compliance with the emission standards in
Sec. 60.532.
(ii) The Administrator will transmit a written notification of the
selected wood heaters or model line(s) to the manufacturer, which will
include the name and address of the laboratory selected to perform the
audit test and the model name and serial number of the wood heater(s) or
model line(s) selected to undergo audit testing.
(2)(i) The Administrator may test, or direct the manufacturer to
have tested, a wood heater or a wood heater from the model line(s)
selected under paragraph (n)(1)(i) of this section in a laboratory
approved under Sec. 60.535. The Administrator may select any approved
test laboratory or federal laboratory for this audit testing.
(ii) The expense of the compliance audit test is the responsibility
of the wood heater manufacturer.
(iii) The test must be conducted using the same test method used to
obtain certification. If the certification test consisted of more than
one particulate matter sampling test method, the Administrator may
direct the manufacturer and test laboratory as to which of these methods
to use for the purpose of audit testing. The Administrator will notify
the manufacturer at least 30 days prior to any test under this
paragraph, and allow the manufacturer and/or his authorized
representatives to observe the test.
(3) Revocation of certification. (i) If emissions from a wood heater
tested under paragraph (n)(2) of this section exceed the applicable
emission standard by more than 50 percent using the same test method
used to obtain certification, the Administrator will 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 will remain in
effect until withdrawn by the Administrator, or the date 30 days from
its effective date if a revocation notice under paragraph (n)(3)(ii) of
this section is not issued within that period, or the date of final
agency action on revocation, whichever occurs earliest.
(ii)(A) If emissions from a wood heater tested under paragraph
(n)(2) of this section exceed the applicable emission limit, the
Administrator will notify the manufacturer that certification is revoked
for that model line.
[[Page 73]]
(B) A revocation notice under paragraph (n)(3)(ii)(A) of this
section will become final and effective 60 days after the date of
written notification to the manufacturer, unless it is withdrawn, a
hearing is requested under Sec. 60.539(a)(2), 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 6 months, by agreeing to a voluntary suspension of
certification.
(iii) Any notification under paragraph (n)(3)(i) or (n)(3)(ii) of
this section will include a copy of a preliminary test report from the
approved test laboratory or federal test laboratory. The test laboratory
must provide a preliminary test report to the Administrator within 14
days of the completion of testing, if a wood heater exceeds the
applicable emission limit in Sec. 60.532. The test laboratory must
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
(n)(3)(ii) of this section, the manufacturer may request that up to four
additional wood heaters from the same model line be tested at the
manufacturer's expense, at the test laboratory that performed the
emissions test for the Administrator.
(v) Whether or not the manufacturer proceeds under paragraph
(n)(3)(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 must bear the
expense of any additional testing.
(vi) The Administrator will withdraw any notice issued under
paragraph (n)(3)(ii) of this section if tests under paragraph (n)(3)(iv)
of this section show either--
(A) That exactly four additional wood heaters were tested for the
manufacturer and all four met the applicable emission limits; or
(B) That exactly two additional wood heaters were tested for the
manufacturer and each of them met the applicable emission limits and the
average emissions of all three tested heaters (the original audit heater
and the two additional heaters) met the applicable emission limits.
(vii) If the Administrator withdraws a notice pursuant to paragraph
(n)(3)(vi) of this section, the Administrator will revise the
certification values for the model line based on the test data and other
relevant information. The manufacturer must then revise the model line's
labels and marketing information accordingly.
(viii) 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 (n)(3)(iv) of
this section and/or (n)(3)(v) of this section or by any other relevant
information available to the Administrator.
Sec. 60.534 What test methods and procedures must I use to
determine compliance with the standards and requirements for
certification?
Test methods and procedures specified in this section or in
appendices of this part, except as provided under Sec. 60.8(b), must be
used to determine compliance with the standards and requirements for
certification under Sec. Sec. 60.532 and 60.533 and for reporting
carbon monoxide emissions and efficiency as follows:
(a)(1) For affected wood heaters subject to the 2015 and 2020
particulate matter emission standards of Sec. Sec. 60.532(a) and (b),
the manufacturer must have an EPA-approved test laboratory conduct
testing according to paragraphs (a)(1)(i) or (ii) of this section. The
manufacturer or manufacturer's authorized representative must submit a
summary and the full test reports with all supporting information,
including detailed discussion of all anomalies, whether all burn rate
categories were properly achieved, any data not used in the calculations
and, for any test runs not completed, the data that were collected and
the reason that the test run was not completed. The burn rate for the
low burn rate
[[Page 74]]
category must be no greater than the rate that an operator can achieve
in home use and no greater than is advertised by the manufacturer or
retailer. The manufacturer has the option of submitting test results
obtained pursuant to either paragraph (a)(1)(i) or (ii) of this section
to the Administrator as specified under Sec. 60.537 as part of a
request for a certification of compliance.
(i) Conduct testing with crib wood using EPA Method 28R of appendix
A-8 of this part or an alternative crib wood test method approved by the
Administrator or the ASTM E2779-10 (IBR, see Sec. 60.17) pellet heater
test method to establish the certification test conditions and the
particulate matter emission values.
(ii) Conduct testing with cord wood using an alternative cord wood
test method approved by the Administrator to establish the certification
test conditions and the particulate matter emission values.
(2) For the 2020 cord wood alternative means of compliance option
specified in Sec. 60.532(c), the manufacturer must have an EPA-approved
test laboratory conduct testing with cord wood using an alternative cord
wood test method approved by the Administrator to establish the
certification test conditions and the particulate matter emission
values.
(b) [Reserved]
(c) For affected wood heaters subject to the 2015 and 2020
particulate matter emission standards specified in Sec. 60.532(a)
through (c), particulate matter emission concentrations must be measured
with ASTM E2515-11 (IBR, see Sec. 60.17) with the following exceptions:
eliminate section 9.6.5.1 of ASTM E2515-11 and perform the post-test
leak checks as described in paragraph (c)(1) of this section.
Additionally, if a component change of either sampling train is needed
during sampling, then perform the leak check specified in paragraph
(c)(2) of this section. Four-inch filters and Teflon membrane filters or
Teflon-coated glass fiber filters may be used in ASTM E2515-11.
(1) Post-test leak check. A leak check of each sampling train is
mandatory at the conclusion of each sampling run before sample recovery.
The leak check must be performed in accordance with the procedures of
ASTM E2515-11, section 9.6.4.1 (IBR, see Sec. 60.17), except that it
must 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 0.0003 m\3\/min (0.01 cfm) or 4% of the average sampling
rate (whichever is less), the leak check results are acceptable. If a
higher leakage rate is obtained, the sampling run is invalid.
(2) Leak checks during sample run. If, during a sampling run, a
component (e.g., filter assembly) change becomes necessary, a leak check
must be conducted immediately before the change is made. Record the
sample volume before and after the leak test. The sample volume
collected during any leak checks must not be included in the total
sample volume for the test run. The leak check must be done according to
the procedure outlined in ASTM E2515-11, section 9.6.4.1 (IBR, see Sec.
60.17), except that it must be done at a vacuum equal to or greater than
the maximum value recorded up to that point in the sampling run. If the
leakage rate is found to be no greater than 0.0003 m\3\/min (0.01 cfm)
or 4% of the average sampling rate (whichever is less), the leak check
results are acceptable. If a higher leakage rate is obtained, the
sampling run is invalid.
Note 1 to paragraph (c):
Immediately after component changes, leak checks are optional but
highly recommended. If such leak checks are done, the procedure in
paragraph (c)(1) of this section should be used.
(d) For all tests conducted using ASTM E2515-11 (IBR, see Sec.
60.17), with the exceptions described in paragraphs (c)(1) and (2) of
this section, and pursuant to this section, the manufacturer and
approved test laboratory must also measure the first hour of particulate
matter emissions for each test run by sampling with a third, identical
and independent sampling train operated concurrently for the first hour
of PM paired train compliance testing according to paragraph (c) of this
section. The manufacturer and approved test laboratory must report the
test results from this third train separately as the first hour
emissions.
(e) The manufacturer must have the approved test laboratory measure
the
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efficiency, heat output and carbon monoxide emissions of the tested wood
heater using Canadian Standards Administration (CSA) Method B415.1-10
(IBR, see Sec. 60.17), section 13.7.
(f) Douglas fir may be used in ASTM E2779-10, ASTM E2780-10 and CSA
B415.1-10 (IBR, see Sec. 60.17).
(g) The manufacturer of an affected wood heater model line must
notify the Administrator of the date that certification testing is
scheduled to begin by email to [email protected]. This notice
must be received by the EPA at least 30 days before the start of
testing. The notification of testing must include the manufacturer's
name and physical and email addresses, the approved test laboratory's
name and physical and email addresses, the third-party certifier name,
the model name and number (or, if unavailable, some other way to
distinguish between models), and the dates of testing. The laboratory
may substitute certification testing of another affected wood heater on
the original date in order to ensure regular laboratory testing
operations.
(h) The approved test laboratory must allow the manufacturer, the
manufacturer's approved third-party certifier, the EPA and delegated
state regulatory agencies to observe certification testing. However,
manufacturers must not involve themselves in the conduct of the test
after the pretest burn has begun. Communications between the
manufacturer and laboratory or third-party certifier personnel regarding
operation of the wood heater must be limited to written communications
transmitted prior to the first pretest burn of the certification test
series. During certification tests, the manufacturer may communicate
with the third-party certifier, and only in writing, to notify them that
the manufacturer has observed a deviation from proper test procedures by
the laboratory. All communications must be included in the test
documentation required to be submitted pursuant to Sec. 60.533(b)(5)
and must be consistent with instructions provided in the owner's manual
required under Sec. 60.536(g).
[80 FR 13702, Mar. 16, 2015, as amended at 85 FR 63403, Oct. 7, 2020; 88
FR 18402, Mar. 29, 2023]
Sec. 60.535 What procedures must I use for EPA approval of a
test laboratory or EPA approval of a third-party certifier?
(a) Test laboratory approval. (1) A laboratory must apply to the
Administrator for approval to test under this rule by submitting
documentation that the laboratory is accredited by a nationally
recognized accrediting entity under ISO-IEC Standard 17025 to perform
testing using the test methods specified under Sec. 60.534.
Laboratories accredited by EPA prior to May 15, 2015 may have until
March 16, 2018 to submit documentation that they have accreditation
under ISO-IEC Standard 17025 to perform testing using the test methods
specified under Sec. 60.534. ISO accreditation is required for all
other laboratories performing testing beginning on November 16, 2015.
(2) As part of the application, the test laboratory must:
(i) Agree to participate biennially in an independently operated
proficiency testing program with no direct ties to the participating
laboratories;
(ii) Agree to allow the Administrator, regulatory agencies and
third-party certifiers access to observe certification testing;
(iii) Agree to comply with calibration, reporting and recordkeeping
requirements that affect testing laboratories; and
(iv) Agree to perform a compliance audit test at the manufacturer's
expense at the testing cost normally charged to such manufacturer if the
laboratory is selected by the Administrator to conduct the compliance
audit test of the manufacturer's model line. The test laboratory must
provide a preliminary audit test report to the Administrator within 14
days of the completion of testing, if the tested wood heater exceeds the
applicable emission limit in Sec. 60.532. The test laboratory must
provide the Administrator and the manufacturer, within 30 days of the
completion of audit 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.
(v) Have no conflict of interest and receive no financial benefit
from the
[[Page 76]]
outcome of certification testing conducted pursuant to Sec. 60.533.
(vi) Agree to not perform initial certification tests on any models
manufactured by a manufacturer for which the laboratory has conducted
research and development design services within the last 5 years.
(vii) Agree to seal any wood heater on which it performed
certification tests, immediately upon completion or suspension of
certification testing, by using a laboratory-specific seal.
(viii) Agree to immediately notify the Administrator of any
suspended tests through email and in writing, giving the date suspended,
the reason(s) why, and the projected date for restarting. The laboratory
must submit the operation and test data obtained, even if the test is
not completed.
(3) If the EPA approves the laboratory, the Administrator will
provide the test laboratory with a certificate of approval for testing
under this rule. If the EPA does not approve the laboratory, the
Administrator will give written notice to the laboratory setting forth
the basis for the determination.
(b) Revocation of test laboratory approval. (1) The Administrator
may revoke the EPA laboratory approval if it is determined that the
laboratory:
(i) Is no longer accredited by the accreditation body;
(ii) Does not follow required procedures or practices;
(iii) Has falsified data or otherwise misrepresented emission data;
(iv) Has failed to participate in a proficiency testing program, in
accordance with its commitment under paragraph (a)(2)(i) of this
section; or
(v) Has failed to seal a wood heater in accordance with paragraph
(a)(2)(vii) of this section.
(2) Revocation of approval under this paragraph (b) will 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 will, at the discretion of the
Administrator, be declared invalid.
(c) Period of test laboratory approval (1) With the exception of
laboratories meeting the provisions of paragraph (c)(2) of this section,
and unless revoked sooner, a certificate of approval for testing under
this rule is valid for 5 years from the date of issuance.
(2) Laboratories accredited by the EPA by May 15, 2015, under the
provisions of Sec. 60.535 as in effect prior to that date may continue
to be EPA accredited and deemed EPA approved for testing under this
subpart until May 15, 2018, at which time the EPA accreditation and
approval ends unless the laboratory has obtained accreditation under
Sec. 60.535 as in effect on that date.
(d) Third-party certifier approval. (1) A third-party certifier may
apply to the Administrator for approval to be an EPA-approved third-
party certifier by submitting credentials demonstrating that it has been
accredited by a nationally recognized accrediting entity to perform
certifications and inspections under ISO-IEC Standard 17025, ISO-IEC
Standard 17065 and ISO-IEC Standard 17020.
(2) As part of the application, the third-party certifier must:
(i) Agree to offer to contract with wood heater manufacturers to
perform third-party certification activities according to the
requirements of this subpart;
(ii) Agree to periodically conduct audits as described in Sec.
60.533(m) and the manufacturer's quality assurance program;
(iii) Agree to comply with reporting and recordkeeping requirements
that affect approved wood heater testing laboratories and third-party
certifiers;
(iv) Have no conflict of interest and receive no financial benefit
from the outcome of certification testing conducted pursuant to Sec.
60.533;
(v) Agree to make available to the Administrator supporting
documentation for each wood heater certification and audit; and
(vi) Agree to not perform initial certification reviews on any
models manufactured by a manufacturer for which the third-party
certifier has conducted research and development design services within
the last 5 years.
(3) If approved, the Administrator will provide the third-party
certifier
[[Page 77]]
with a certificate of approval. The approval will expire 5 years after
being issued unless renewed by the third-party certifier. If the EPA
denies the approval, the Administrator will give written notice to the
third-party certifier for the basis for the determination.
(e) Revocation of third-party certifier approval. (1) The
Administrator will revoke a third-party certifier's EPA approval if it
is determined that the certifier;
(i) Is no longer accredited by the accreditation body;
(ii) Does not follow required procedures or practices; or
(iii) Has falsified certification data or otherwise misrepresented
emission data.
(2) Revocation of approval under this paragraph (e) will not take
effect until the certifier concerned is 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 upheld, all certifications by the certifier after written notice was
given will, at the discretion of the Administrator, be declared invalid.
Sec. 60.536 What requirements must I meet for permanent labels,
temporary labels (hangtags), and owner's manuals?
(a) General permanent label requirements. (1) Each affected wood
heater manufactured on or after the date the applicable standards come
into effect as specified in Sec. 60.532, must have a permanent label
affixed to it that meets the requirements of this section.
(2) Except for wood heaters subject to Sec. 60.530(b)(1) through
(5), the permanent label must contain the following information:
(i) Month and year of manufacture of the individual unit;
(ii) Model name or number;
(iii) Certification test emission value, test method and standard
met (e.g., 2015, 2020 crib wood, or 2020 cord wood); and
(iv) Serial number.
(3) The permanent label must:
(i) Be affixed in a readily visible or readily accessible location
in such a manner that it can be easily viewed before and after the
appliance is installed (an easily-removable facade may be used for
aesthetic purposes, however the bottom of a free-standing heater is not
considered to be readily visible or readily accessible);
(ii) Be at least 8.9 cm long and 5.1 cm wide (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 the 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, the integrity of the
permanent label is not compromised, and the permanent label meets the
requirements in Sec. 60.536(a)(3).
(5) 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:
(i) That a certification of compliance was in effect at the time the
wood heater left the possession of the manufacturer;
(ii) That the manufacturer was, at the time the label was affixed,
conducting a quality assurance program in conformity with Sec.
60.533(m); and
(iii) That all wood heaters individually tested for emissions by the
manufacturer under its quality assurance program pursuant to Sec.
60.533(m) met the applicable emissions limits.
(b) Permanent label requirements for adjustable burn rate wood
heaters and pellet stoves. If an adjustable burn rate wood heater or
pellet stove belongs to a model line certified under Sec. 60.533, and
no wood heater in the model line has been found to exceed the applicable
emission limits or tolerances through quality assurance testing, one of
the following statements, as appropriate, must appear on the permanent
label:
``U.S. ENVIRONMENTAL PROTECTION AGENCY Certified to comply with 2015
particulate emission standards. Not approved for sale after May 15,
2020.'' or
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``U.S. ENVIRONMENTAL PROTECTION AGENCY Certified to comply with 2020
particulate emission standards using crib wood.'' or
``U.S. ENVIRONMENTAL PROTECTION AGENCY Certified to comply with 2020
particulate emission standards using cord wood.''
(c) Permanent label requirements for single burn rate wood heaters.
If the single burn rate wood heater belongs to a model line certified
under Sec. 60.533, and no heater in the model line has been found to
exceed the applicable emission limits or tolerances through quality
assurance testing, one of the following statements, as appropriate, must
appear on the permanent label:
``U.S. ENVIRONMENTAL PROTECTION AGENCY Certified to comply with 2015
particulate emission standards for single burn rate heaters. Not
approved for sale after May 15, 2020. This single burn rate wood heater
is not approved for use with a flue damper.'' or
``U.S. ENVIRONMENTAL PROTECTION AGENCY Certified to comply with 2020
particulate emission standards for single burn rate heaters. This single
burn rate wood heater is not approved for use with a flue damper.''
(d) Additional permanent label content. The permanent label for all
certified wood heaters must also contain the following statement:
``This wood heater needs periodic inspection and repair for proper
operation. Consult the owner's manual for further information. It is
against federal regulations to operate this wood heater in a manner
inconsistent with the operating instructions in the owner's manual.''
(e) Permanent label requirements for affected wood heaters with
exemptions under Sec. 60.530(b). (1) If an affected wood heater is
manufactured in the United States for export as provided in Sec.
60.530(b)(1), the following statement must appear on the permanent
label:
``U.S. ENVIRONMENTAL PROTECTION AGENCY Export stove. May not be sold or
operated within the United States.''
(2) If an affected wood heater is manufactured for use for research
and development purposes as provided in Sec. 60.530(b)(2), the
following statement must appear on the permanent label:
``U.S. ENVIRONMENTAL PROTECTION AGENCY Not certified. Research Stove.
Not approved for sale or for operation other than for research.''
(3) If a wood heater is exclusively a non-wood-burning heater as
provided Sec. 60.530(b)(3), the following statement must appear on the
permanent label:
``U.S. ENVIRONMENTAL PROTECTION AGENCY This heater is not certified for
wood burning. Use of any wood fuel is a violation of federal
regulations.''
(4) If an affected wood heater is a cook stove that meets the
definition in Sec. 60.531, the following statement must appear on the
permanent label:
``U.S. ENVIRONMENTAL PROTECTION AGENCY This unit is not a certified
residential wood heater. The primary use for this unit is for cooking or
baking.''
(5) If an affected wood heater is a camp stove that meets the
definition in Sec. 60.531, the following statement must appear on the
permanent label:
``U.S. ENVIRONMENTAL PROTECTION AGENCY This unit is not a certified
residential wood heater. For portable and temporary use only.''
(f) Temporary label (hangtag) voluntary option. (1) Each model
certified to meet the 2020 particulate matter emission standards of
Sec. 60.532(b) prior May 15, 2020 may display the temporary labels
(hangtags) specified in section 3 of appendix I of this part. The
electronic template will be provided by the Administrator upon approval
of the certification.
(2) The hangtags in paragraph (f)(1) of this section end on May 15,
2020.
(3) Each model certified to meet the 2020 Cord Wood Alternative
Compliance Option of Sec. 60.532(c) may display the cord wood temporary
label specified in section 3 of appendix I of this part. The electronic
template will be provided by the Administrator upon approval of the
certification.
(g) Owner's manual requirements. (1) Each affected wood heater
offered for sale by a commercial owner must be accompanied by an owner's
manual that must contain the information listed in paragraph (g)(2) of
this section (pertaining to installation) and paragraph (g)(3) of this
section (pertaining to operation and maintenance). Such information must
be adequate to enable consumers to achieve optimal
[[Page 79]]
emissions performance. Such information must be consistent with the
operating instructions provided by the manufacturer to the approved test
laboratory for operating the wood heater during certification testing,
except for details of the certification test that would not be relevant
to the user. The commercial owner must also make current and historical
owner's manuals available on the company Web site and upon request to
the EPA.
(2) Guidance on proper installation, include stack height, location
and achieving proper draft.
(3) Proper operation and maintenance information, including
minimizing visible emissions:
(i) Fuel loading and re-loading procedures; recommendations on fuel
selection and warnings on what fuels not to use, such as unseasoned
wood, treated wood, colored paper, cardboard, solvents, trash and
garbage;
(ii) Fire starting procedures;
(iii) Proper use of air controls, including how to establish good
combustion and how to ensure good combustion at the lowest burn rate for
which the heater is warranted;
(iv) Ash removal procedures;
(v) Instructions for replacement of gaskets, air tubes and other
parts that are critical to the emissions performance of the unit, and
other maintenance and repair instructions;
(vi) For catalytic or hybrid 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;
(vii) For catalytic or hybrid models, the following statement--
``This wood heater contains a catalytic combustor, which needs periodic
inspection and replacement for proper operation. It is against federal
regulations to operate this wood heater in a manner inconsistent with
operating instructions in this manual, or if the catalytic element is
deactivated or removed.''
(viii) For noncatalytic models, the following statement--
``This wood heater needs periodic inspection and repair for proper
operation. It is against federal regulations to operate this wood heater
in a manner inconsistent with operating instructions in this manual.''
(4) Any manufacturer using the EPA-recommended language contained in
appendix I of this part to satisfy any requirement of this paragraph (g)
will be considered to be in compliance with that requirement, provided
that the particular language is printed in full, with only such changes
as are necessary to ensure accuracy for the particular wood heater model
line.
(h) Wood heaters that are affected by this subpart, but that have
been owned and operated by a noncommercial owner, are not subject to
paragraphs (f) and (g) of this section when offered for resale.
Sec. 60.537 What records must I keep and what reports must I submit?
(a)(1) Each manufacturer who holds a certificate of compliance
pursuant to Sec. 60.533(c), (e) or (f) for a model line must maintain
records containing the information required by paragraph (a)(2) through
(4) of this section with respect to that model line for at least 5
years.
(2) All documentation pertaining to the certification test used to
obtain certification, including the full test report and raw data
sheets, laboratory technician notes, calculations, the test results for
all test runs, and discussions of the appropriateness and validity of
all test runs, including runs attempted but not completed. The retained
certification test documentation must include, as applicable, detailed
discussion of all anomalies, whether all burn rate categories were
properly achieved, any data not used in the calculations and, for any
test runs not completed, the data that were collected and the reason
that the test run was not completed. The retained certification test
also must include documentation that the burn rate for the low burn rate
category was no greater than the rate that an operator can achieve in
home use and no greater than is advertised by the manufacturer or
retailer.
(3) Results of the quality assurance program inspections pursuant to
Sec. 60.533(m).
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(4) For emissions tests conducted pursuant to the quality assurance
program required by Sec. 60.533(m), all test reports, data sheets,
laboratory technician notes, calculations, and test results for all test
runs, the corrective actions taken, if any, and any follow-up actions
such as additional testing.
(b) Each approved test laboratory and third-party certifier must
maintain records consisting of all documentation pertaining to each
certification test, quality assurance program inspection and audit test,
including the full test report and raw data sheets, technician notes,
calculations, and the test results for all test runs. Each approved test
laboratory must submit accreditation credentials and all proficiency
test results to the Administrator. Each third-party certifier must
submit each certification test, quality assurance program inspection
report and ISO IEC accreditation credentials to the Administrator.
(c) Each manufacturer must retain each wood heater upon which
certification tests were performed based upon which certification was
granted under Sec. 60.533(c) or (f) at the manufacturer's facility for
a minimum of 5 years after the certification test. Each wood heater must
remain sealed and unaltered. Any such wood heater must be made available
to the Administrator upon request for inspection and testing.
(d) Each manufacturer of an affected wood heater model line
certified under Sec. 60.533(c) or (f) must submit a report to the
Administrator every 2 years following issuance of a certificate of
compliance for each model line. This report must include the sales for
each model by state and certify that no changes in the design or
manufacture of this model line have been made that require
recertification under Sec. 60.533(k).
(e)(1) Unless otherwise specified, all records required under this
section must be maintained by the manufacturer, commercial owner of the
affected wood heater, approved test laboratory or third-party certifier
for a period of no less than 5 years.
(2) Unless otherwise specified, all reports to the Administrator
required under this subpart must be made to: [email protected].
(f) Within 60 days after the date of completing each performance
test, e.g., initial certification test, tests conducted for quality
assurance, and tests for renewal or recertification, each manufacturer
must submit the performance test data electronically to
[email protected]. Owners or operators who claim that some of
the information being submitted is CBI (e.g., design drawings) must
submit a complete file, including the information claimed to be CBI, on
a compact disk or other commonly used electronic storage media
(including, but not limited to, flash drives) by mail, and the same
file, with the CBI omitted, electronically. The compact disk must be
clearly marked as CBI and mailed to U.S. EPA, OECA CBI Office,
Attention: Residential Wood Heater Compliance Program Lead, 1200
Pennsylvania Avenue NW., Washington, DC 20004. Emission data, including
all information necessary to determine compliance, except sensitive
engineering drawings and sensitive detailed material specifications, may
not be claimed as CBI.
(g) Within 30 days of receiving a certification of compliance for a
model line, the manufacturer must make the full non-CBI test report and
the summary of the test report available to the public on the
manufacturer's Web site.
(h) Each manufacturer who uses the exemption for R&D heaters under
Sec. 60.530(b)(2) must maintain records for at least 5 years
documenting where the heaters were located, that the heaters were never
offered for sale or sold and that the heaters were not used for the
purpose of heating.
Sec. 60.538 What activities are prohibited under this subpart?
(a) No person is permitted to advertise for sale, offer for sale,
sell or operate an affected wood heater that does not have affixed to it
a permanent label pursuant to Sec. 60.536 (b) through (e), as
applicable.
(b) No person is permitted to advertise for sale, offer for sale, or
sell an affected wood heater labeled under Sec. 60.536(e)(1) except for
export. No person is permitted to operate an affected wood heater in the
United States if it is labeled under Sec. 60.536(e)(1).
[[Page 81]]
(c)(1) No commercial owner is permitted to advertise for sale, offer
for sale or sell an affected wood heater permanently labeled under Sec.
60.536 (b) through (d), as applicable, unless:
(i) The affected wood heater has been certified to comply with the
2015 or 2020 particulate matter emission standards pursuant to Sec.
60.532, as applicable. This prohibition does not apply to wood heaters
affected by this subpart that have been previously owned and operated by
a noncommercial owner; and
(ii) The commercial owner provides any purchaser or transferee with
an owner's manual that meets the requirements of Sec. 60.536(g) and a
copy of the warranty.
(2) No commercial owner is permitted to advertise for sale, offer
for sale, or sell an affected wood heater permanently labeled under
Sec. 60.536(b) and (c), unless the affected wood heater has been
certified to comply with the 2015 or 2020 particulate matter emission
standards of Sec. 60.532, as applicable.
(3) A commercial owner other than a manufacturer complies with the
requirements of paragraph (c)(1) of this section if the commercial
owner--
(i) Receives the required documentation from the manufacturer or a
previous commercial owner; and
(ii) Provides that documentation unaltered to any person to whom the
wood heater that it covers is sold or transferred.
(d)(1) In any case in which the Administrator revokes a certificate
of compliance either for the 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, the
Administrator may give notice of that revocation and the grounds for it
to all commercial owners.
(2) On and after the date of receipt of the notice given under
paragraph (d)(1) of this section, no commercial owner is permitted to
sell any wood heater covered by the revoked certificate (other than to
the manufacturer) unless the model line has been recertified in
accordance with this subpart.
(e) No person is permitted to install or operate an affected wood
heater except in a manner consistent with the instructions on its
permanent label and in the owner's manual pursuant to Sec. 60.536(g),
including only using fuels for which the unit is certified.
(f) No person is permitted to operate, sell or offer for sale an
affected wood heater that was originally equipped with a catalytic
combustor if the catalytic element is deactivated or removed.
(g) No person is permitted to operate, sell or offer for sale an
affected wood heater that has been physically altered to exceed the
tolerance limits of its certificate of compliance, pursuant to Sec.
60.533(k).
(h) No person is permitted to alter, deface, or remove any permanent
label required to be affixed pursuant to Sec. 60.536(a) through (e), as
applicable.
(i) If a temporary label is affixed to the wood heater, retailers
may not sell or offer for sale that wood heater unless the temporary
label affixed is in accordance with Sec. 60.536(f), as applicable.
Sec. 60.539 What hearing and appeal procedures apply to me?
(a)(1) The affected manufacturer, laboratory or third-party
certifier may request a hearing under this section within 30 days
following receipt of the required notification in any case where the
Administrator--
(i) Denies an application for a certificate of compliance under
Sec. 60.533(c) or Sec. 60.533(f);
(ii) Denies an application for a renewal of certification under
Sec. 60.533(i);
(iii) Issues a notice of revocation of certification under Sec.
60.533(1);
(iv) Denies an application for laboratory approval under Sec.
60.535(a);
(v) Issues a notice of revocation of laboratory approval under Sec.
60.535(b);
(vi) Denies an application for third-party certifier approval under
Sec. 60.535(d); or
(vii) Issues a notice of revocation of third-party certifier
approval under Sec. 60.535(e).
(2) In any case where the Administrator issues a notice of
revocation under Sec. 60.533(n)(3)(ii), the manufacturer may request a
hearing under this section with the time limits set out in Sec.
60.533(n)(3)(ii).
[[Page 82]]
(b) Any hearing request must be in writing, must be signed by an
authorized representative of the petitioning manufacturer or laboratory
and must 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 will 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 will 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 will 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 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 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
intervener 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 intervener will 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 must state his interest and the
reasons why the proposed amicus brief is desirable. If the motion is
granted, the Presiding Officer or Administrator will issue an order
setting the time for filing such brief. An amicus curia may participate
in any briefing after his motion is granted, and will 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 will not be included. Saturdays, Sundays and federal legal holidays
will be included. When a stated time expires on a Saturday, Sunday or
legal holiday, the stated time period will be extended to include the
next business day.
(d)(l) Upon his appointment, the Presiding Officer must establish a
hearing file. The file will consist of the notice issued by the
Administrator under Sec. 60.533(c)(2), Sec. 60.533(f)(3), Sec.
60.533(i)(4), Sec. 60.533(l)(2), Sec. 60.533(n)(3)(ii)(A), Sec.
60.535(a)(3), Sec. 60.535(b)(2), Sec. 60.535(d)(3) or Sec.
60.535(e)(2) 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 approval or the proposed
revocation of either.
(2) The hearing file must 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:
[[Page 83]]
(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 must be reduced to writing by the
Presiding Officer and made part of the record.
(g)(1) Hearings will 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 will 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 must 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 must, upon a showing satisfactory to
the Presiding Officer of their authenticity, relevancy and materiality,
be received in evidence and will constitute a part of the record.
(h)(1) The Presiding Officer will make an initial decision which
must 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 must be
provided to the parties and made a part of the record. The initial
decision will become the decision of the Administrator without further
proceedings unless there is an appeal to the Administrator or motion for
review by the Administrator. Except as provided in paragraph (h)(3) of
this section, any such appeal must be taken within 20 days of the date
the initial decision was filed.
(2) On appeal from or review of the initial decision, the
Administrator will have all the powers which he 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
Administrator must 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 must render the initial decision within 60 days of
that request. Any appeal to the Administrator must be taken within 10
days of the initial decision, and the Administrator must render a
decision in that appeal within 30 days of the filing of the appeal.
Sec. 60.539a Who implements and enforces this subpart?
(a) Under section 111(c) of the Clean Air Act, the Administrator may
delegate the following implementation and enforcement authority to a
state, local or tribal authority upon request:
(1) Enforcement of prohibitions on the installation and operation of
affected wood heaters in a manner inconsistent with the installation and
owner's manual;
(2) Enforcement of prohibitions on operation of catalytic wood
heaters where the catalyst has been deactivated or removed;
(3) Enforcement of prohibitions on advertisement and/or sale of
uncertified model lines;
(4) Enforcement of prohibitions on advertisement and/or sale of
affected heaters that do not have required permanent label;
(5) Enforcement of proper labeling of affected wood heaters; and
[[Page 84]]
(6) Enforcement of compliance with other labeling requirements for
affected wood heaters.
(7) Enforcement of certification testing procedures;
(8) Enforcement of requirements for sealing of the tested heaters
and meeting parameter limits; and
(9) Enforcement of compliance requirements of EPA-approved
laboratories.
(b) Delegations shall not include:
(1) Decisions on certification;
(2) Revocation of certification;
(3) Establishment or revision of standards;
(4) Establishment or revision of test methods;
(5) Laboratory and third-party certifier approvals and revocations;
(6) Enforcing provisions governing content of owner's manuals; and
(7) Hearings and appeals procedures.
(c) Nothing in these delegations will prohibit the Administrator
from enforcing any applicable requirements.
(d) Nothing in these delegations will limit delegated entities from
using their authority under section 116 of the Clean Air Act to adopt or
enforce more restrictive requirements.
Sec. 60.539b What parts of the General Provisions do not apply to me?
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), (f)(1), and (g);
(c) Section 60.14; and
(c) Section 60.15(d).
[80 FR 13702, Mar. 16, 2015, as amended at 88 FR 18402, Mar. 29, 2023]
Subpart BBB_Standards of Performance for the Rubber Tire Manufacturing
Industry
Source: 52 FR 34874, Sept. 15, 1987, unless otherwise noted.
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
[[Page 85]]
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 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
[[Page 86]]
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 (lb
per gallon))
Dr = density of VOC recovered by an emission control device
(grams per liter (lb per gallon))
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 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 (lb) per tire)
Gb = monthly average mass of VOC used per bead cemented for a
particular bead cementing affected facility (grams (lb) per
bead)
Lc = volume of cement or spray material used for a month
(liters (gallons))
Lr = volume of VOC recovered by an emission control device
for a month (liters (gallons))
M = total mass of VOC used for a month by all facilities served by a
common cement or spray material distribution system (grams
(lb))
Mo = total mass of VOC used at an affected facility for a
month (grams (lb))
Mr = mass of VOC recovered by an emission control device for
a month (grams (lb))
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 (lb) per tire)
Nb = mass of VOC emitted per bead cemented for an affected
facility for a month (grams (lb) per bead)
Qa = volumetric flow rate in vents after a control device
(dry standard cubic meters (dry standard cubic feet) per hour)
Qb = volumetric flow rate in vents before a control device
(dry standard cubic meters (dry standard cubic feet) 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 (dry standard cubic feet) 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.
[52 FR 34874, Sept. 15, 1987, as amended at 65 FR 61764, Oct. 17, 2000]
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
[[Page 87]]
(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 kg (8,531 lb) of VOC per 28 days,
(B) 4,010 kg (8,846 lb) of VOC per 29 days,
(C) 4,150 kg (9,149 lb) of VOC per 30 days,
(D) 4,280 kg (9,436 lb) of VOC per 31 days, or
(E) 4,840 kg (10,670 lb) 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 kg (7,099 lb) of VOC per 28 days,
(B) 3,340 kg (7,363 lb) of VOC per 29 days,
(C) 3,450 kg (7,606 lb) of VOC per 30 days,
(D) 3,570 kg (7,870 lb) of VOC per 31 days, or
(E) 4,030 kg (8,885 lb) of VOC per 35 days.
(3) For each tread end cementing operation: Discharge into the
atmosphere no more than 10 grams (0.022 lb) of VOC per tire cemented for
each month.
(4) For each bead cementing operation: Discharge into the atmosphere
no more than 5 grams (0.011 lb) of VOC per 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 (0.0026 lb)
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 (0.021 lb)
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:
(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 kg (7,099 lb) of VOC per 28 days,
(B) 3,340 kg (7,363 lb) of VOC per 29 days,
(C) 3,450 kg (7,606 lb) of VOC per 30 days,
(D) 3,570 kg (7,870 lb) of VOC per 31 days, or
(E) 4,030 kg (8,885 lb) 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 (0.0026 lb)
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 (0.021 lb)
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) 1,570 kg (3,461 lb) of VOC per 28 days,
(B) 1,630 kg (3,593 lb) of VOC per 29 days,
(C) 1,690 kg (3,726 lb) of VOC per 30 days,
(D) 1,740 kg (3,836 lb) of VOC per 31 days, or
(E) 1,970 kg (4,343 lb) of VOC per 35 days.
(9) For each Michelin-B operation:
[[Page 88]]
(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) 1,310 kg (2,888 lb) of VOC per 28 days,
(B) 1,360 kg (2,998 lb) of VOC per 29 days,
(C) 1,400 kg (3,086 lb) of VOC per 30 days,
(D) 1,450 kg (3,197 lb) of VOC per 31 days, or
(E) 1,640 kg (3,616 lb) 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.
[52 FR 34874, Sept. 15, 1987, as amended at 65 FR 61764, Oct. 17, 2000]
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 (0.055 lb) of VOC per tire processed for each month
if the operation uses 25 grams (0.055 lb) or less of VOC per tire
processed and does not employ a VOC emission reduction system.
(b) [Reserved]
[54 FR 38635, Sept. 19, 1989, as amended at 65 FR 61765, Oct. 17, 2000]
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:
(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
[[Page 89]]
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 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:
``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
[[Page 90]]
the VOC emission per 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 VOC emission per 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):
[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 uses 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.
[[Page 91]]
(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 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
[[Page 92]]
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 equipment 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:
[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, mg/mg-mole (lb/lb-mole).
V = The volume occupied by one mole of ideal gas at standard conditions
[20 [deg]C, 760 mm Hg] on a wet basis, 2.405 x 10-5
m\3\/mg-mole (385.3 ft\3\/lb-mole).
Qi = Volumetric flow in the capture system during run i, on a
wet basis, adjusted to standard conditions, m\3\ (ft\3\) (see
Sec. 60.547(a)(5)).
10\6\ = ppm per unity.
Mi = Mass of the single VOC used during run i, mg (lb).
(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:
[[Page 93]]
[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, mg/mg-mole (lb/lb-mole).
V = The volume occupied by one mole of ideal gas at standard conditions
[20 [deg]C, 760 mm Hg] on a wet basis, 2.405 x 10-5
m\3\/mg-mole (385.3 ft\3\/lb-mole).
Qi = Volumetric flow in the capture system during run i, on a
wet basis, adjusted to standard conditions, m\3\ (ft\3\) (see
Sec. 60.547(a)(5)).
10\6\ = ppm per unity.
Mi = Mass of the single VOC used during run i, mg (lb).
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 uses 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), 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)
[[Page 94]]
(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 uses 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.
(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 30.5 meters (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
[[Page 95]]
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 30.5 meters
(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 VOC emission per 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:
[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
[[Page 96]]
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 VOC emission per 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; 65 FR 61765, Oct. 17, 2000]
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, temperature 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,
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.
[52 FR 34874, Sept. 15, 1987, as amended at 65 FR 61765, Oct. 17, 2000]
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
[[Page 97]]
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 (50 [deg]F) 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 VOC monthly usage 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;
65 FR 61765, Oct. 17, 2000]
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
written report to the Administrator declaring 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 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:
[[Page 98]]
(1) For each affected facility for which the owner or operator seeks
to comply with a VOC monthly usage limit specified under Sec.
60.542(a): The monthly mass of VOC used (Mo) and the number
of days in the compliance period (Td).
(2) For each affected facility that seeks to comply with a VOC
emission limit per tire or per bead 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 VOC emission limit per tire or per bead 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 VOC emission limit per tire or per bead 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 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 or lb/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.
[[Page 99]]
(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 VOC
emission limit per tire or per bead specified under Sec. 60.542(a), as
applicable for the affected facility.
(2) Each monthly average VOC use rate that exceeds the monthly VOC
usage 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 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
[[Page 100]]
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 of the change.
[52 FR 34874, Sept. 15, 1987; 52 FR 37874, Oct. 9, 1987, as amended at
54 FR 38637, Sept. 19, 1989; 65 FR 61765, Oct. 17, 2000]
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 at
least 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
1.0 meter (3.3 feet). The minimum sample volume shall be 0.003 dry
standard cubic meter (dscm) (0.11 dry standard cubic feet (dscf)) 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 at
least 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 1.0 meter (3.3 feet). 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.
(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)
(0.11 dry standard cubic feet (dscf)) 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
[[Page 101]]
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;
65 FR 61765, Oct. 17, 2000]
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
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 (1,102 ton/yr) shall be exempt from Sec. 60.562-2.
[[Page 102]]
(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.
----------------------------------------------------------------------------------------------------------------
Emissions
Polymer Production process(es) Process section ---------------------------------
Continuous Intermittent
----------------------------------------------------------------------------------------------------------------
Polypropylene................... Liquid Phase........... Raw Materials X
Preparation.
Polymerization X
Reaction.
Material Recovery.. X X
Product Finishing.. X
Product Storage....
Polypropylene................... Gas Phase.............. Raw Materials
Preparation.
Polymerization ............... X
Reaction.
Material Recovery.. X
Product Finishing..
Product Storage....
Low Density Polyethylene........ High Pressure.......... Raw Materials ............... X
Preparation.
Polymerization ............... X
Reaction.
Material Recovery.. ............... X
Product Finishing.. ............... X
Product Storage.... ............... X
Low Density Polyethylene........ Low Pressure........... Raw Materials X X
Preparation.
High Density Polyethylene....... Gas Phase.............. Polymerization ............... X
Reaction.
Material Recovery..
Product Finishing.. X
Product Storage....
High Density Polyethylene....... Liquid Phase Slurry.... Raw Materials ............... X
Preparation.
Polymerization
Reaction.
Material Recovery.. X
Product Finishing.. X
Product Storage....
High Density Polyethylene....... Liquid Phase Solution.. Raw Materials X X
Preparation.
Polymerization ............... X
Reaction.
Material Recovery.. X X
Product Finishing..
Product Storage.... ...............
----------------------------------------------------------------------------------------------------------------
[[Page 103]]
(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, kg
Production process Process section TOC/Mg product
(See associated
footnote)
------------------------------------------------------------------------
Polypropylene, liquid phase Raw Materials 0.15 \b\
process. Preparation.
Polymerization 0.14 \b\, 0.24
Reaction. \c\
Material Recovery.... 0.19 \b\
Product Finishing.... 1.57 \b\
Polypropylene, gas phase Polymerization 0.12 \c\
process. 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 Polythylene, low Raw Materials 0.05 \f\
pressure process. Preparation.
Polymerization 0.03 \g\
Reaction.
Product 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\
High Density Polyethylene, gas Raw Materials 0.05 \f\
phase process. Preparation.
Polymerization 0.03 \g\
Reaction.
Product Finishing.... 0.01 \b\
Polystyrene, continuous Material Recovery.... 0.05 \b h\
process.
Poly(ethylene terephalate), Material Recovery.... 0.12 \b h\
dimethyl terephthalate
process.
Polymerization 1.80 \h i j\
Reaction.
Poly(ethlyene 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.
[[Page 104]]
\j\ Applies to a process line producing low viscosity poly(ethylene
terephthlalate).
\k\ Applies to a process line producing high viscosity poly(ethylene
terephathalate).
\l\ See footnote m.
\m\ Applies to the sum of emissions to the atmosphere from the
polymerization reaction section (including emissions from the cooling
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 (1.76 ton/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 (1.76 ton/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 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.
(j) Alternative means of compliance--(1) Option to comply with part
65. Owners or operators may choose to comply with 40 CFR part 65,
subpart G, for continuous process vents that are subject to this
subpart, that choose to comply with Sec. 60.562-1(a)(1)(i)(A), (B), or
(C) as allowed in Sec. 60.562-1(a)(1) and (b)(1)(iii). The requirements
of 40 CFR part 65, subpart G, satisfy the requirements of paragraph (c)
of this section and Sec. Sec. 60.563 through 60.566, except for Sec.
60.565(g)(1). Other provisions applying to owners or operators who
choose to comply with 40 CFR part 65 are provided in 40 CFR 65.1.
(2) Part 60, subpart A. Owners or operators who choose to comply
with 40 CFR part 65, subpart G, must also comply with Sec. Sec. 60.1,
60.2, 60.5, 60.6, 60.7(a)(1) and (4), 60.14, 60.15, and 60.16 for those
process vents. All sections and paragraphs of subpart A of this part
that are not mentioned in this paragraph (j)(2) do not apply to owners
or operators of process vents complying with 40 CFR part 65, subpart G,
except that provisions required to be met prior to implementing 40 CFR
part 65 still apply. Owners and operators who choose to comply with 40
CFR part 65, subpart G, must comply with 40 CFR part 65, subpart A.
(3) Initial startup notification. Each owner or operator subject to
the provisions of this subpart that chooses to comply with 40 CFR part
65, subpart G, at initial startup shall notify the Administrator of the
specific provisions of 40 CFR part 65, subpart G, with
[[Page 105]]
which the owner or operator has elected to comply. Notification shall be
submitted with the notification of initial startup required by 40 CFR
65.5(b).
(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, as amended at
65 FR 61765, Oct. 17, 2000; 65 FR 78278, Dec. 14, 2000]
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 failure or adverse safety personnel
consequences and to minimize adverse effects of the runaway reaction.
This does not include intermittent vents
[[Page 106]]
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 mm Hg (1 in.
H2O) 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 mm Hg (3 and 5 in. H2O). 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 gm/cm\3\3 (58.7 lb/ft\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 (103,000 kPa gauge) 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 reaction mixture during the polymerization
reaction; sometimes called a particle form process.
[[Page 107]]
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\ (58.7 lb/ft\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 (2,070
kPa gauge).
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)-
terephthalate (BHET) that is subsequently polymerized to form PET.
[[Page 108]]
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) of the finished end product. If physical
[[Page 109]]
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; 65 FR 61767, Oct. 17, 2000]
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 110]]
(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 111]]
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:
------------------------------------------------------------------------
If the percent composite TOC Use this equation to calculate
concentration is threshold 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 112]]
[GRAPHIC] [TIFF OMITTED] TC16NO91.071
[[Page 113]]
[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 114]]
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 (20.1 ton/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 115]]
[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 116]]
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 (0.0072 lb TOC/ton) 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 117]]
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 (0.036 lb TOC/ton) 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 (0.04 lb TOC/ton)
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 (0.08 lb TOC/ton) 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 (0.04 lb TOC/ton)
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
[[Page 118]]
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.
(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; 65 FR 61767, Oct. 17, 2000]
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. Sec. 60.482-1 through 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. Sec. 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 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 (302 [deg]F) as
determined by ASTM Method D86-78, 82, 90, 95, or 96 (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. Sec. 60.486 and 60.487.
[55 FR 51035, Dec. 11, 1990; 56 FR 12299, Mar. 22, 1991, as amended at
65 FR 61767, Oct. 17, 2000]
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.
[[Page 119]]
(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:
(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]
[[Page 120]]
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 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.
[[Page 121]]
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.
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 (lb TOC/hr).
Eoutlet = Mass rate of TOC, discharged to the atmosphere, kg
TOC/hr (lb 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)]{time}
(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] TR17OC00.020
Where:
Eunc = uncontrolled annual emissions, Mg/yr (ton/yr)
Cj = concentration of sample component j of the gas stream,
dry basis, ppmv
[[Page 122]]
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)
K2 = 4.157 x 10-11 [(Mg)(g-mole)]/[(g)(ppm)(dscm)]
(metric units)
= 1.298 x 10-12 [(ton)(lb-mole)]/[(lb)(ppm)(dscf)] (English
units)
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] TR17OC00.021
Where:
HT = Vent stream net heating value, MJ/scm (Btu/scf), where
the net enthalpy per mole of offgas is based on combustion at
25 [deg]C and 760 mm Hg (68 [deg]F and 30 in. Hg), but the
standard temperature for determining the volume corresponding
to one mole is 20 [deg]C (68 [deg]F).
K3 = 1.74 x 10-7 (1/ppm)(g-mole/scm)(MJ/kcal)
(metric units), where standard temperature for (g-mole/scm) is
20 [deg]C.
= 4.67 x 10-6 (1/ppm)(lb-mole/scf)(Btu/kcal) (English units)
where standard temperature for (lb/mole/scf) is 68 [deg]F.
Cj = Concentration on a wet basis of compound j in ppm.
[[Page 123]]
Hj = Net heat of combustion of compound j, kcal/(g-mole)
(kcal/(lb-mole)), based on combustion at 25 [deg]C and 760 mm
Hg (77 [deg]F and 30 in. Hg).
(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 or 90
(Reapproved 1994) (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 or 88 or D4809-95 (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:
[GRAPHIC] [TIFF OMITTED] TR17OC00.022
Where:
Vmax = Maximum permitted velocity, m/sec (ft/sec)
K4 = 28.8 (metric units), 1212 (English units)
K5 = 31.7 (metric units), 850.8 (English units)
HT = The net heating value as determined in paragraph (f) of
this section, MJ/scm (Btu/scf).
(3) The maximum permitted velocity, Vmax, for air-
assisted flares shall be determined by the following equation:
[GRAPHIC] [TIFF OMITTED] TR17OC00.023
Where:
Vmax = Maximum permitted velocity, m/sec (ft/sec).
K6 = 8.706 m/sec (metric units)
= 28.56 ft/sec (English units)
K7 = 0.7084 [(m/sec)/MJ/scm)] (metric units)
= 0.00245 [(ft/sec)/Btu/scf)] (English units)
HT = The net heating value as determined in paragraph (f) of
this section, MJ/scm (Btu/scf).
(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 Sec. Sec. 60.560(d) and (e) and
in Sec. Sec. 60.562-1(b)(1)(i), (c)(1)(i)(A), (c)(1)(ii)(A), (c)(2)(i),
and (c)(2)(ii)(A).
(1) The emission rate of TOC shall be computed using the following
equation:
[GRAPHIC] [TIFF OMITTED] TR17OC00.024
Where:
ERTOC = Emission rate of total organic compounds (minus
methane and ethane), kg TOC/Mg (lb TOC/ton) product
ETOC = Emission rate of total organic compounds (minus
methane and ethane) in the sample, kg/hr (lb/hr)
Pp = The rate of polymer production, kg/hr (lb/hr)
K5 = 1,000 kg/Mg (metric units)
= 2,000 lb/ton (English units)
(2) 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 Sec. Sec.
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.
(3) The rate of polymer production, Pp, shall be
determined by dividing the weight of polymer pulled (in kg (lb)) from
the process line during the performance test by the number of hours
taken to perform the performance test. The weight of polymer pulled
shall be determined by direct measurement or,
[[Page 124]]
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 temperature requirements in Sec. Sec. 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 or 91, ``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 or 96a, ``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] TR17OC00.025
Where:
Xi = daily ethylene glycol concentration for each day used to
calculate the 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
[[Page 125]]
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 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; 65 FR 61767, Oct.
17, 2000]
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 kg TOC (minus methane and
ethane) per Mg (lb TOC/ton) 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 boilers 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
[[Page 126]]
(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), 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 Sec. Sec. 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 Sec. Sec. 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:
[[Page 127]]
(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) 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 Sec. Sec. 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, 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
[[Page 128]]
more than 6 [deg]C (10 [deg]F) above the average operating temperature
during the most recent performance test at which compliance was
demonstrated.
(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. 60.560(j) or 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 Sec. Sec.
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 Sec. Sec. 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 Sec. Sec.
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
[[Page 129]]
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.
(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; 65 FR 61768, Oct. 17, 2000; 65 FR 78278, Dec.
14, 2000]
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
Method 24, ink
[[Page 130]]
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.
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.
bthe gas stream vents entering the emission control device.
fthe 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.
Gthe 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.
Ethe VOC emission reduction efficiency (as a fraction) of the emission
control device during performance testing.
Fthe 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 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 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
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, as amended at
65 FR 61768, Oct. 17, 2000]
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) 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
[[Page 131]]
are used in the inks, standard gas chromatographic techniques may be
used to identify and quantify these solvents. The results of Method 24
may be adjusted to subtract these solvents from the measured VOC
content.
(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. 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 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
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, 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 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 Method 24.
[[Page 132]]
(4) The Administrator may require the use of 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 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, as amended at
65 FR 61768, Oct. 17, 2000]
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
[[Page 133]]
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 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, expressed in degrees Celsius, 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 (50 [deg]F) 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, expressed in degrees Celsius, 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.
[49 FR 26892, June 29, 1984, as amended at 65 FR 61768, Oct. 17, 2000]
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).
[[Page 134]]
(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, 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 for which Construction, Reconstruction, or
Modification Commenced After January 4, 1983, and on or Before November
7, 2006
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, reconstruction, or modification after January 4,
1983, and on or before November 7, 2006, 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, subpart VVa, or subpart KKK of
this part are excluded from this subpart.
(e) Stay of standards. Owners or operators are not required to
comply with the definition of ``process unit'' in Sec. 60.590 of this
subpart until the EPA takes final action to require compliance and
publishes a document in the Federal Register. While the definition of
``process unit'' is stayed, owners or operators should use the following
definition:
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.
[49 FR 22606, May 30, 1984, as amended at 72 FR 64895, Nov. 16, 2007; 73
FR 31376, June 2, 2008]
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.
Asphalt (also known as Bitumen) is a black or dark brown solid or
semi-solid thermo-plastic material possessing waterproofing and adhesive
properties. It is a complex combination of higher molecular weight
organic compounds containing a relatively high proportion of
hydrocarbons having carbon numbers greater than C25 with a high carbon
to hydrogen ratio. It is essentially non-volatile at ambient
temperatures with closed cup flash point of 445 [deg]F (230 [deg]C) or
greater.
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).
[[Page 135]]
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 the components assembled and connected by pipes
or ducts to process raw materials and 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. For the purpose of this subpart, process unit includes any
feed, intermediate and final product storage vessels (except as
specified in Sec. 60.482-1(g)), product transfer racks, and connected
ducts and piping. A process unit includes all equipment as defined in
this subpart.
[49 FR 22606, May 30, 1984, as amended at 72 FR 64895, Nov. 16, 2007]
Effective Date Note: At 73 FR 31376, June 2, 2008, Sec. 60.591, the
definition of ``process unit'' was stayed until further notice.
Sec. 60.592 Standards.
(a) Each owner or operator subject to the provisions of this subpart
shall comply with the requirements of Sec. Sec. 60.482-1 to 60.482-10
as soon as practicable, but no later than 180 days after initial
startup.
(b) For a given process unit, an owner or operator may elect to
comply with the requirements of paragraphs (b)(1), (2), or (3) of this
section as an alternative to the requirements in Sec. 60.482-7.
(1) Comply with Sec. 60.483-1.
(2) Comply with Sec. 60.483-2.
(3) Comply with the Phase III provisions in 40 CFR 63.168, except an
owner or operator may elect to follow the provisions in Sec. 60.482-
7(f) instead of 40 CFR 63.168 for any valve that is designated as being
leakless.
(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 Sec. Sec. 60.486 and 60.487.
[49 FR 22606, May 30, 1984, as amended at 72 FR 64896, Nov. 16, 2007]
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 to 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 E260-73, 91, or 96, E168-67, 77, or 92,
or E169-63, 77, or 93 (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.
[[Page 136]]
(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. 60.482-3(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. 60.482-3(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 D86-78, 82, 90, 95, or 96 (incorporated by reference as
specified in Sec. 60.17).
(e) Pumps in light liquid service and valves in gas/vapor and light
liquid service within a process unit that is located in the Alaskan
North Slope are exempt from the requirements of Sec. Sec. 60.482-2 and
60.482-7.
(f) Open-ended valves or lines containing asphalt as defined in
Sec. 60.591 are exempt from the requirements of Sec. 60.482-6(a)
through (c).
[49 FR 22606, May 30, 1984, as amended at 65 FR 61768, Oct. 17, 2000; 72
FR 64896, Nov. 16, 2007]
Subpart GGGa_Standards of Performance for Equipment Leaks of VOC in
Petroleum Refineries for Which Construction, Reconstruction, or
Modification Commenced After November 7, 2006
Source: 72 FR 64896, Nov. 16, 2007, unless otherwise noted.
Sec. 60.590a 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. 60.591a) 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 November
7, 2006, is subject to the requirements of this subpart.
(c) Addition or replacement of equipment (defined in Sec. 60.591a)
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, subpart VVa, subpart GGG, or
subpart KKK of this part are excluded from this subpart.
(e) Stay of standards. Owners or operators are not required to
comply with the definition of ``process unit'' in Sec. 60.590 of this
subpart until the EPA takes final action to require compliance and
publishes a document in the Federal Register. While the definition of
``process unit'' is stayed, owners or operators should use the following
definition:
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.
[49 FR 22606, May 30, 1984, as amended at 73 FR 31376, June 2, 2008]
Sec. 60.591a Definitions.
As used in this subpart, all terms not defined herein shall have the
meaning given them in the Clean Air Act, in subpart A of part 60, or in
subpart VVa of this part, 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.
Asphalt (also known as Bitumen) is a black or dark brown solid or
semi-solid thermo-plastic material possessing waterproofing and adhesive
properties. It is a complex combination of higher molecular weight
organic compounds containing a relatively high proportion of
[[Page 137]]
hydrocarbons having carbon numbers greater than C25 with a high carbon
to hydrogen ratio. It is essentially non-volatile at ambient
temperatures with closed cup flash point of 445 [deg]F (230 [deg]C) or
greater.
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. 60.593a(b).
In light liquid service means that the piece of equipment contains a
liquid that meets the conditions specified in Sec. 60.593a(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 the components assembled and connected by pipes
or ducts to process raw materials and 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. For the purpose of this subpart, process unit includes any
feed, intermediate and final product storage vessels (except as
specified in Sec. 60.482-1a(g)), product transfer racks, and connected
ducts and piping. A process unit includes all equipment as defined in
this subpart.
Effective Date Note: At 73 FR 31376, June 2, 2008, Sec. 60.591a,
the definition of ``process unit'' was stayed until further notice.
Sec. 60.592a Standards.
(a) Each owner or operator subject to the provisions of this subpart
shall comply with the requirements of Sec. Sec. 60.482-1a to 60.482-10a
as soon as practicable, but no later than 180 days after initial
startup.
(b) For a given process unit, an owner or operator may elect to
comply with the requirements of paragraphs (b)(1), (2), or (3) of this
section as an alternative to the requirements in Sec. 60.482-7a.
(1) Comply with Sec. 60.483-1a.
(2) Comply with Sec. 60.483-2a.
(3) Comply with the Phase III provisions in Sec. 63.168, except an
owner or operator may elect to follow the provisions in Sec. 60.482-
7a(f) instead of Sec. 63.168 for any valve that is designated as being
leakless.
(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. 60.484a.
(d) Each owner or operator subject to the provisions of this subpart
shall comply with the provisions of Sec. 60.485a except as provided in
Sec. 60.593a.
(e) Each owner or operator subject to the provisions of this subpart
shall comply with the provisions of Sec. Sec. 60.486a and 60.487a.
Sec. 60.593a Exceptions.
(a) Each owner or operator subject to the provisions of this subpart
may comply with the following exceptions to the provisions of subpart
VVa of this part.
(b)(1) Compressors in hydrogen service are exempt from the
requirements of Sec. 60.592a if an owner or operator demonstrates that
a compressor is in hydrogen service.
(2) Each compressor is presumed not to 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
[[Page 138]]
to the general method described in ASTM E260-73, 91, or 96, E168-67, 77,
or 92, or E169-63, 77, or 93 (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) of this section 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. 60.482-3a(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. 60.482-3a(a), (b), (c), (d),
(e), and (h).
(d) An owner or operator may use the following provision in addition
to Sec. 60.485a(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, 82, 90, 93, 95, or 96 (incorporated by reference as
specified in Sec. 60.17).
(e) Pumps in light liquid service and valves in gas/vapor and light
liquid service within a process unit that is located in the Alaskan
North Slope are exempt from the requirements of Sec. Sec. 60.482-2a and
60.482-7a.
(f) Open-ended valves or lines containing asphalt as defined in
Sec. 60.591a are exempt from the requirements of Sec. 60.482-6a(a)
through (c).
(g) Connectors in gas/vapor or light liquid service are exempt from
the requirements in Sec. 60.482-11a, provided the owner or operator
complies with Sec. 60.482-8a for all connectors, not just those in
heavy liquid service.
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 Mg (551
ton) 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.
[49 FR 22606, May 30, 1984, as amended at 65 FR 61768, Oct. 17, 2000]
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 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
[[Page 139]]
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.
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 the discharge into the
atmosphere from any affected facility that produces acrylic fibers, VOC
emissions that exceed 10 kg/Mg (20 lb/ton) 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/Mg (20 lb/ton) solvent feed. VOC emissions from
affected facilities that produce
[[Page 140]]
only nonacrylic fiber types shall not exceed 17 kg/Mg (34 lb/ton)
solvent feed. Compliance with the emission limitations is determined on
a 6-month rolling average basis as described in Sec. 60.603.
[49 FR 22606, May 30, 1984, as amended at 65 FR 61768, Oct. 17, 2000]
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 unit mass
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 = VOC Emissions, in kg/Mg (lb/ton) solvent;
SV = Measured or calculated volume of solvent feed, in liters
(gallons);
SW = Weight of solvent feed, in Mg (ton);
MV = Measured volume of makeup solvent, in liters (gallons);
MW = Weight of makeup, in kg (lb);
N = Allowance for nongaseous losses, 13 kg/Mg (26 lb/ton) solvent feed;
SP = Fraction of measured volume that is actual solvent
(excludes water);
D = Density of the solvent, in kg/liter (lb/gallon);
K = Conversion factor, 1,000 kg/Mg (2,000 lb/ton);
I = Allowance for solvent inventory variation or changes in the amount
of solvent contained in the affected facility, in kg/Mg (lb/
ton) solvent feed (may be positive or negative);
IS = Amount of solvent contained in the affected facility at
the beginning of the test period, as determined by the owner
or operator, in kg (lb);
IE = Amount of solvent contained in the affected facility at
the close of the test period, as determined by the owner or
operator, in kg (lb).
(3) N, as used in the equation in paragraph (b)(2) of this section,
equals 13 kg/Mg (26 lb/ton) solvent feed to the spinning solution
preparation system and precipitation bath. This value shall be used in
all cases unless an owner or
[[Page 141]]
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, as amended at 65
FR 61769, Oct. 17, 2000]
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 Mg
(551 ton) annually) shall report to the Administrator within 30 days
whenever extruded fiber for the preceding 12 calendar months exceeds 500
Mg (551 ton).
(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; 65 FR 61769, Oct. 17, 2000]
Subpart III_Standards of Performance for Volatile Organic Compound (VOC)
Emissions From the Synthetic Organic Chemical Manufacturing Industry
(SOCMI) Air Oxidation Unit Processes After October 21, 1983, and on or
Before April 25, 2023
Source: 55 FR 26922, June 29, 1990, unless otherwise noted.
Effective Date Note: At 89 FR 43086, May 16, 2024, the heading of
subpart III was revised, effective July 15, 2024.
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 Sec. Sec. 60.612, 60.614(f), 60.615(h), and
60.615(l).
(d) Alternative means of compliance--(1) Option to comply with part
65. Owners or operators of process vents that are subject to this
subpart may choose to comply with the provisions of 40 CFR part 65,
subpart D, to satisfy the requirements of Sec. Sec. 60.612 through
60.615 and 60.618. The provisions of 40 CFR part 65 also satisfy the
criteria of paragraph (c) of this section. Other provisions applying to
an owner or operator
[[Page 142]]
who chooses to comply with 40 CFR part 65 are provided in 40 CFR 65.1.
(2) Part 60, subpart A. Owners or operators who choose to comply
with 40 CFR part 65, subpart D, must also comply with Sec. Sec. 60.1,
60.2, 60.5, 60.6, 60.7(a)(1) and (4), 60.14, 60.15, and 60.16 for those
process vents. All sections and paragraphs of subpart A of this part
that are not mentioned in this paragraph (d)(2) do not apply to owners
or operators of process vents complying with 40 CFR part 65, subpart D,
except that provisions required to be met prior to implementing 40 CFR
part 65 still apply. Owners and operators who choose to comply with 40
CFR part 65, subpart D, must comply with 40 CFR part 65, subpart A.
(3) Compliance date. Owners or operators who choose to comply with
40 CFR part 65, subpart D, at initial startup shall comply with
paragraphs (d)(1) and (2) of this section for each vent stream on and
after the date on which the initial performance test 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.
(4) Initial startup notification. Each owner or operator subject to
the provisions of this subpart that chooses to comply with 40 CFR part
65, subpart D, at initial startup shall notify the Administrator of the
specific provisions of 40 CFR 65.63(a)(1), (2), or (3) with which the
owner or operator has elected to comply. Notification shall be submitted
with the notifications of initial startup required by 40 CFR 65.5(b).
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.
[55 FR 26922, June 29, 1990, as amended at 65 FR 78278, Dec. 14, 2000]
Effective Date Note: At 89 FR 43086, May 16, 2024, Sec. 60.610 was
amended by revising paragraph (b) introductory text and adding paragraph
(e), effective July 15, 2024. For the convenience of the user, the added
and revised text is set forth as follows:
Sec. 60.610 Applicability and designation of affected facility.
* * * * *
(b) The affected facility is any of the following for which
construction, modification, or reconstruction commenced after October
21, 1983, and on or before April 25, 2023:
* * * * *
(e) Owners and operators of flares that are subject to the flare
related requirements of this subpart and flare related requirements of
any other regulation in this part or 40 CFR part 61 or 63, may elect to
comply with the requirements in Sec. 60.619a in lieu of all flare
related requirements in any other regulation in this part or 40 CFR part
61 or 63.
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 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.
[[Page 143]]
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 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]
Effective Date Note: At 89 FR 43086, May 16, 2024, Sec. 60.611 was
amended by revising the definition of ``Flame zone,'' effective July 15,
2024. For the convenience of the user, the revised text is set forth as
follows:
Sec. 60.611 Definitions.
* * * * *
Flame zone means the portion of the combustion chamber in a boiler
or process heater occupied by the flame envelope.
* * * * *
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
Sec. Sec. 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:
[[Page 144]]
(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 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 44 MW (150 million Btu/hr) heat input
design capacity.
(d) 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.
(e) 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
[[Page 145]]
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.
(f) 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.
[55 FR 26922, June 29, 1990, as amended at 65 FR 61769, Oct. 17, 2000]
Effective Date Note: At 89 FR 43086, May 16, 2024, Sec. 60.613 was
amended by revising paragraphs (e)(1)(i), (e)(2)(i), and (e)(3)(i),
effective July 15, 2024. For the convenience of the user, the revised
text is set forth as follows:
Sec. 60.613 Monitoring of emissions and operations.
* * * * *
(e) * * *
(1) * * *
(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
* * * * *
(2) * * *
(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
* * * * *
(3) * * *
(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
* * * * *
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
[[Page 146]]
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. 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/hr (lb/
hr).
Eo = Mass rate of TOC discharged to the atmosphere, kg/hr
(lb/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/
min).
K2 = 2.494 x 10-6 (1/ppm)(g-mole/scm)(kg/g)(min/
hr) (metric units), where standard temperature for (g-mole/
scm) is 20 [deg]C.
= 1.557 x 10-7 (1/ppm)(lb-mole/scf)(min/hr) (English
units), where standard temperature for (lb-mole/scf) is 68 [deg]F.
(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.
(c) 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),
[[Page 147]]
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.
(d) 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.
(e) 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(e)(2) and (3) shall
be, except for the situations outlined in paragraph (e)(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 to any post-reactor
introduction of halogenated compounds into the vent stream. No
transverse site selection method is needed for vents smaller than 10
centimeters (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(e)(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) D1946-77, or 90 (Reapproved 1994) (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 (Btu/scf), where
the net enthalpy per mole of vent stream is based on
combustion at 25 [deg]C and 760 mm Hg (77 [deg]F and 30 in.
Hg), but the standard temperature for determining the volume
corresponding to one mole is 20 [deg]C (68 [deg]F).
K1 = 1.74 x 10-7 (1/ppm)(g-mole/scm)(MJ/kcal)
(metric units), where standard temperature for (g-mole/scm) is
20 [deg]C.
= 1.03 x 10-11 (1/ppm)(lb-mole/scf)(Btu/kcal) (English
units) where standard temperature for (lb/mole/scf) is 68 [deg]F.
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, 90, or 94 (incorporation
by reference as specified in Sec. 60.17 of this part) as
indicated in Sec. 60.614(e)(2).
Hj = Net heat of combustion of compound j, kcal/(g-mole)
[kcal/(lb-mole)], based on combustion at 25 [deg]C and 760 mm
Hg (77 [deg]F and 30 in. Hg).
(5) The emission rate of TOC in the process vent stream shall be
calculated using the following equation:
[GRAPHIC] [TIFF OMITTED] TC16NO91.092
where:
[[Page 148]]
ETOC = Measured emission rate of TOC, kg/hr (lb/hr).
K2 = 2.494 x 10-6 (1/ppm)(g-mole/scm)(kg/g)(min/
hr) (metric units), where standard temperature for (g-mole/
scm) is 20 [deg]C.
= 1.557 x 10-7 (1/ppm)(lb-mole/scf)(min/hr) (English
units), where standard temperature for (lb-mole/scf) is 68 [deg]F.
Cj = Concentration on a wet basis of compound j in ppm, as
measured by Method 18 as indicated in Sec. 60.614(e)(2).
Mj = Molecular weight of sample j, g/g-mole (lb/lb-mole).
Qs = Vent stream flow rate, scm/hr (scf/hr), at a temperature
of 20 [deg]C (68 [deg]F).
(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.
(f) 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 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 that is greater than or equal
to 14.2 scm/min (501 scf/min) at a standard temperature of 20 [deg]C (68
[deg]F):
TRE = TRE index value.
Qs = Vent stream flow rate, scm/min (scf/min), at a
temperature of 20 [deg]C (68 [deg]F).
HT = Vent stream net heating value, MJ/scm (Btu/scf), where
the net enthalpy per mole of vent stream is based on
combustion at 25 [deg]C and 760 mm Hg (68 [deg]F and 30 in.
Hg), but the standard temperature for determining the volume
corresponding to one mole is 20 [deg]C (68 [deg]F) 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
= QsHT/3.6.
ETOC = Hourly emissions of TOC, kg/hr (lb/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 149]]
[GRAPHIC] [TIFF OMITTED] TR17OC00.027
[[Page 150]]
[GRAPHIC] [TIFF OMITTED] TR17OC00.028
[GRAPHIC] [TIFF OMITTED] TR17OC00.029
(ii) Where for a vent stream flow rate that is less than 14.2 scm/
min (501 scf/min) at a standard temperature of 20 [deg]C (68 [deg]F):
TRE = TRE index value.
Qs = 14.2 scm/min (501 scf/min).
HT = (FLOW)(HVAL)/Qs.
Where the following inputs are used:
FLOW = Vent stream flow rate, scm/min (scf/min), at a temperature of 20
[deg]C (68 [deg]F).
HVAL = Vent stream net heating value, MJ/scm (Btu/scf), where the net
enthalpy per mole of vent stream is based on combustion at 25
[deg]C and 760 mm Hg (68 [deg]F and 30 in. Hg), but the
standard temperature for
[[Page 151]]
determining the volume corresponding to one mole is 20 [deg]C
(68 [deg]F) 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
= QsHT/3.6.
ETOC = Hourly emissions of TOC, kg/hr (lb/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 emissions of TOC, kg/hr (lb/hr).
Qs = Vent stream flow rate, scm/min (scf/min), at a standard
temperature of 20 [deg]C (68 [deg]F).
HT = Vent stream net heating value, MJ/scm (Btu/scf), where
the net enthalpy per mole of vent stream is based on
combustion at 25 [deg]C and 760 mm Hg (68 [deg]F and 30 in.
Hg), but the standard temperature for determining the volume
corresponding to one mole is 20 [deg]C (68 [deg]F) 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 < 301 Btu/scf)........................ (0.140) (0.0367) (-0.000448) (-0.0051) (4.59)
HT >= 11.2 MJ/scm......................... 0.309 0.0619 -0.0043 -0.0034 2.08
HT >= 301 Btu/scf)........................ (0.0193) (0.00788) (-0.000010) (-0.0034) (4.59)
----------------------------------------------------------------------------------------------------------------
(g) 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. Sec. 60.8 and 60.614 and shall comply with
Sec. Sec. 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, as amended at
65 FR 61769, Oct. 17, 2000]
Effective Date Note: At 89 FR 43086, May 16, 2024, Sec. 60.614 was
amended by revising paragraphs (b)(4) introductory text and (e),
effective July 15, 2024. For the convenience of the user, the revised
text is set forth as follows:
[[Page 152]]
Sec. 60.614 Test methods and procedures.
* * * * *
(b) * * *
(4) Method 18 of appendix A-6 to this part 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. ASTM D6420-18 (incorporated by reference, see Sec.
[thinsp]60.17) may be used in lieu of Method 18, if the target compounds
are all known and are all listed in Section 1.1 of ASTM D6420-18 as
measurable; ASTM D6420-18 may not be used for methane and ethane; and
ASTM D6420-18 may not be used as a total VOC method.
* * * * *
(e) The following test methods, 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 of appendix A-1 to this part, 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(e)(2) and (3) shall be, except for the situations outlined in
paragraph (e)(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 to any post-reactor introduction of halogenated compounds into the
vent stream. No transverse site selection method is needed for vents
smaller than 10 centimeters (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 of appendix A-6 to this
part, or ASTM D6420-18 (incorporated by reference, see Sec.
[thinsp]60.17) as specified in paragraph (b)(4) of this section, 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(e)(4) and (5).
(2) The molar composition of the process vent stream shall be
determined as follows:
(i) Method 18 of appendix A-6 to this part, or ASTM D6420-18
(incorporated by reference, see Sec. [thinsp]60.17) as specified in
paragraph (b)(4) of this section, to measure the concentration of TOC
including those containing halogens.
(ii) D1946-77 or 90 (Reapproved 1994) (incorporation by reference,
see Sec. 60.17) to measure the concentration of carbon monoxide and
hydrogen.
(iii) Method 4 of appendix A to this part to measure the content of
water vapor.
(3) The volumetric flow rate shall be determined using Method 2, 2A,
2C, or 2D of appendix A-1 to this part, as appropriate.
(4) The net heating value of the vent stream shall be calculated
using the following equation:
Equation 6 to Paragraph (e)(4)
[GRAPHIC] [TIFF OMITTED] TR16MY24.026
Where:
HT = Net heating value of the sample, MJ/scm (Btu/scf), where
the net enthalpy per mole of vent stream is based on
combustion at 25 [deg]C and 760 mm Hg (77 [deg]F and 30 in.
Hg), but the standard temperature for determining the volume
corresponding to one mole is 20 [deg]C (68 [deg]F).
K1 = 1.74 x 10-7 (1/ppm)(g-mole/scm)(MJ/kcal)
(metric units), where standard temperature for (g-mole/scm) is
20 [deg]C.
= 1.03 x 10-11 (1/ppm)(lb-mole/scf)(Btu/kcal) (English units)
where standard temperature for (lb/mole/scf) is 68 [deg]F.
[[Page 153]]
Cj = Concentration on a wet basis of compound j in ppm, as
measured for organics by Method 18 of appendix A-6 to this
part, or ASTM D6420-18 (incorporated by reference, see Sec.
[thinsp]60.17) as specified in paragraph (b)(4) of this
section, and measured for hydrogen and carbon monoxide by ASTM
D1946-77, 90, or 94 (incorporation by reference, see Sec.
60.17) as indicated in paragraph (e)(2) of this section.
Hj = Net heat of combustion of compound j, kcal/(g-mole)
[kcal/(lb-mole)], based on combustion at 25 [deg]C and 760 mm
Hg (77 [deg]F and 30 in. Hg).
(5) The emission rate of TOC in the process vent stream shall be
calculated using the following equation:
Equation 7 to Paragraph (e)(5)
[GRAPHIC] [TIFF OMITTED] TR16MY24.027
Where:
ETOC = Measured emission rate of TOC, kg/hr (lb/hr).
K2 = 2.494 x 10-6 (1/ppm)(g-mole/scm)(kg/g)(min/
hr) (metric units), where standard temperature for (g-mole/
scm) is 20 [deg]C.
= 1.557 x 10-7 (1/ppm)(lb-mole/scf)(min/hr) (English units),
where standard temperature for (lb-mole/scf) is 68 [deg]F.
Cj = Concentration on a wet basis of compound j in ppm, as
measured by Method 18 of appendix A-6 to this part, or ASTM
D6420-18 (incorporated by reference, see Sec. [thinsp]60.17)
as specified in paragraph (b)(4) of this section, as indicated
in paragraph (e)(2) of this section.
Mj = Molecular weight of sample j, g/g-mole (lb/lb-mole).
Qs = Vent stream flow rate, scm/hr (scf/hr), at a temperature
of 20 [deg]C (68 [deg]F).
(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 of appendix A-6 to this part, or ASTM D6420-
18 (incorporated by reference, see Sec. 60.17) as specified in
paragraph (b)(4) of this section.
* * * * *
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 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
[[Page 154]]
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 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.
[[Page 155]]
(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 (150 million Btu/hour) 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(e) 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 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.
[[Page 156]]
(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).
(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, as amended at
65 FR 61773, Oct. 17, 2000]
Effective Date Note: At 89 FR 43088, May 16, 2024, Sec. 60.615 was
amended by revising paragraphs (b) introductory text, (j) introductory
text, and (k) and adding paragraphs (m), (n), and (o), effective July
15, 2024. For the convenience of the user, the added and revised text is
set forth as follows:
Sec. 60.615 Reporting and recordkeeping requirements.
* * * * *
(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
[[Page 157]]
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. Beginning on July 15,
2024, owners and operators must submit the performance test report
following the procedures specified in paragraph (m) of this section.
Data collected using test methods that are supported by the EPA's
Electronic Reporting Tool (ERT) as listed on the EPA's ERT website
(https://www.epa.gov/electronic-reporting-air-emissions/electronic-
reporting-tool-ert) at the time of the test must be submitted in a file
format generated using the EPA's ERT. Alternatively, the owner or
operator may submit an electronic file consistent with the extensible
markup language (XML) schema listed on the EPA's ERT website. Data
collected using test methods that are not supported by the EPA's ERT as
listed on the EPA's ERT website at the time of the test must be included
as an attachment in the ERT or an alternate electronic file.
* * * * *
(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. On and after July 15, 2025 or
once the report template for this subpart has been available on the
Compliance and Emissions Data Reporting Interface (CEDRI) website
(https://www.epa.gov/electronic-reporting-air-emissions/cedri) for 1
year, whichever date is later, owners and operators must submit all
subsequent reports using the appropriate electronic report template on
the CEDRI website for this subpart and following the procedure specified
in paragraph (m) of this section. The date report templates become
available will be listed on the CEDRI website. Unless the Administrator
or delegated state agency or other authority has approved a different
schedule for submission of reports, the report must be submitted by the
deadline specified in this subpart, regardless of the method in which
the report is submitted.
* * * * *
(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. The EPA will not approve a waiver
of electronic reporting to the EPA in delegating enforcement authority.
Thus, electronic reporting to the EPA cannot be waived, and as such, the
provisions of this paragraph cannot be used to relieve owners or
operators of affected facilities of the requirement to submit the
electronic reports required in this section to the EPA.
* * * * *
(m) If an owner or operator is required to submit notifications or
reports following the procedure specified in this paragraph (m), the
owner or operator must submit notifications or reports to the EPA via
CEDRI, which can be accessed through the EPA's Central Data Exchange
(CDX) (https://cdx.epa.gov/). The EPA will make all the information
submitted through CEDRI available to the public without further notice
to the owner or operator. Do not use CEDRI to submit information the
owner or operator claims as CBI. Although the EPA does not expect
persons to assert a claim of CBI, if an owner or operator wishes to
assert a CBI claim for some of the information in the report or
notification, the owner or operator must submit a complete file in the
format specified in this subpart, including information claimed to be
CBI, to the EPA following the procedures in paragraphs (m)(1) and (2) of
this section. Clearly mark the part or all of the information claimed to
be CBI. Information not marked as CBI may be authorized for public
release without prior notice. Information marked as CBI will not be
disclosed except in accordance with procedures set forth in 40 CFR part
2. All CBI claims must be asserted at the time of submission. Anything
submitted using CEDRI cannot later be claimed CBI. Furthermore, under
CAA section 114(c), emissions data is not entitled to confidential
treatment, and the EPA is required to make emissions data available to
the public. Thus, emissions data will not be protected as CBI and will
be made publicly available. The owner or operator must submit the same
file submitted to the CBI office with the CBI omitted to the EPA via the
EPA's CDX as described earlier in this paragraph (m).
(1) The preferred method to receive CBI is for it to be transmitted
electronically using email attachments, File Transfer Protocol, or other
online file sharing services. Electronic submissions must be transmitted
directly to the OAQPS CBI Office at the email
[[Page 158]]
address [email protected], and as described above, should include clear
CBI markings. ERT files should be flagged to the attention of the Group
Leader, Measurement Policy Group; all other files should be flagged to
the attention of the SOCMI NSPS Sector Lead. Owners and operators who do
not have their own file sharing service and who require assistance with
submitting large electronic files that exceed the file size limit for
email attachments should email [email protected] to request a file
transfer link.
(2) If an owner or operator cannot transmit the file electronically,
the owner or operator may send CBI information through the postal
service to the following address: OAQPS Document Control Officer (C404-
02), OAQPS, U.S. Environmental Protection Agency, 109 T.W. Alexander
Drive, P.O. Box 12055, Research Triangle Park, North Carolina 27711. ERT
files should be sent to the attention of the Group Leader, Measurement
Policy Group, and all other files should be sent to the attention of the
SOCMI NSPS Sector Lead. The mailed CBI material should be double wrapped
and clearly marked. Any CBI markings should not show through the outer
envelope.
(n) Owners and operators required to electronically submit
notifications or reports through CEDRI in the EPA's CDX may assert a
claim of EPA system outage for failure to timely comply with the
electronic submittal requirement. To assert a claim of EPA system
outage, owners and operators must meet the requirements outlined in
paragraphs (n)(1) through (7) of this section.
(1) The owner or operator must have been or will be precluded from
accessing CEDRI and submitting a required report within the time
prescribed due to an outage of either the EPA's CEDRI or CDX systems.
(2) The outage must have occurred within the period of time
beginning five business days prior to the date that the submission is
due.
(3) The outage may be planned or unplanned.
(4) The owner or operator must submit notification to the
Administrator in writing as soon as possible following the date the
owner or operator first knew, or through due diligence should have
known, that the event may cause or has caused a delay in reporting.
(5) The owner or operator must provide to the Administrator a
written description identifying:
(i) The date(s) and time(s) when CDX or CEDRI was accessed and the
system was unavailable;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to EPA system outage;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which the owner or operator proposes to report, or
if the owner or operator has already met the reporting requirement at
the time of the notification, the date the report was submitted.
(6) The decision to accept the claim of EPA system outage and allow
an extension to the reporting deadline is solely within the discretion
of the Administrator.
(7) In any circumstance, the report must be submitted electronically
as soon as possible after the outage is resolved.
(o) Owners and operators required to electronically submit
notifications or reports through CEDRI in the EPA's CDX, owners and
operators may assert a claim of force majeure for failure to timely
comply with the electronic submittal requirement. To assert a claim of
force majeure, you must meet the requirements outlined in paragraphs
(o)(1) through (5) of this section.
(1) An owner or operator may submit a claim if a force majeure event
is about to occur, occurs, or has occurred or there are lingering
effects from such an event within the period of time beginning five
business days prior to the date the submission is due. For the purposes
of this section, a force majeure event is defined as an event that will
be or has been caused by circumstances beyond the control of the
affected facility, its contractors, or any entity controlled by the
affected facility that prevents the owner or operator from complying
with the requirement to submit a report electronically within the time
period prescribed. Examples of such events are acts of nature (e.g.,
hurricanes, earthquakes, or floods), acts of war or terrorism, or
equipment failure or safety hazard beyond the control of the affected
facility (e.g., large scale power outage).
(2) The owner or operator must submit notification to the
Administrator in writing as soon as possible following the date the
owner or operator first knew, or through due diligence should have
known, that the event may cause or has caused a delay in reporting.
(3) The owner or operator must provide to the Administrator:
(i) A written description of the force majeure event;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to the force majeure event;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which the owner or operator proposes to report, or
if the owner or operator has already met the reporting requirement at
the time of the notification, the date the report was submitted.
(4) The decision to accept the claim of force majeure and allow an
extension to the reporting deadline is solely within the discretion of
the Administrator.
[[Page 159]]
(5) In any circumstance, the reporting must occur as soon as
possible after the force majeure event occurs.
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).
Effective Date Note: At 89 FR 43089, May 16, 2024, Sec. 60.618 was
amended by revising paragraph (b), effective July 15, 2024. For the
convenience of the user, the revised text is set forth as follows:
Sec. 60.618 Delegation of authority.
* * * * *
(b) Authorities which will not be delegated to States: Sec.
60.613(e) and approval of an alternative to any electronic reporting to
the EPA required by this subpart.
Subpart IIIa_Standards of Performance for Volatile Organic Compound
(VOC) Emissions From the Synthetic Organic Chemical Manufacturing
Industry (SOCMI) Air Oxidation Unit Processes for Which Construction,
Reconstruction, or Modification Commenced After April 25, 2023
Source: 89 FR 43089, May 16, 2024, unless otherwise noted.
Effective Date Note: At 89 FR 43089, May 16, 2024, subpart IIIa was
added, effective July 15, 2024.
Sec. 60.610a Am I subject to this subpart?
(a) You are subject to this subpart if you operate an affected
facility designated in paragraph (b) of this section that produces any
of the chemicals listed in Sec. 60.617a 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 April 25,
2023:
(1) Each air oxidation reactor not discharging its vent stream into
a recovery system.
[[Page 160]]
(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) Exemptions from the provisions of paragraph (a) of this section
are as follows:
(1) Each affected facility operated with a vent stream flow rate
less than 0.001 pound per hour (lb/hr) of TOC is exempt from all
provisions of this subpart except for the test method and procedure and
the recordkeeping and reporting requirements in Sec. 60.614a(e) and
Sec. 60.615a(h), (i)(8), and (n).
(2) A vent stream going to a fuel gas system as defined in Sec.
63.611a.
Sec. 60.611a What definitions must I know?
As used in this subpart, all terms not defined herein have the
meaning given them in the Clean Air Act and subpart A of this part.
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.
Breakthrough means the time when the level of TOC, measured at the
outlet of the first bed, has been detected is at the highest
concentration allowed to be discharged from the adsorber system and
indicates that the adsorber bed should be replaced.
By Compound means by individual stream components, not carbon
equivalents.
Closed vent system means a system that is not open to the atmosphere
and is composed of piping, ductwork, connections, and, if necessary,
flow inducing devices that transport gas or vapor from an emission point
to a control device.
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
or process heater occupied by the flame envelope.
Flow indicator means a device which indicates whether gas flow is
present in a vent stream.
Fuel gas means gases that are combusted to derive useful work or
heat.
Fuel gas system means the offsite and onsite piping and flow and
pressure control system that gathers gaseous stream(s) generated by
onsite operations, may blend them with other sources of gas, and
transports the gaseous stream for use as fuel gas in combustion devices
or in in-process combustion equipment such as furnaces and gas turbines
either singly or in combination.
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.
Pressure-assisted multi-point flare means a flare system consisting
of multiple flare burners in staged arrays whereby the vent stream
pressure is used to promote mixing and smokeless operation at the flare
burner tips. Pressure-assisted multi-point flares are designed for
smokeless operation at velocities up to Mach = 1 conditions (i.e., sonic
conditions), can be elevated or at ground level, and typically use
cross-
[[Page 161]]
lighting for flame propagation to combust any flare vent gases sent to a
particular stage of flare burners.
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 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. 60.617a. 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. 60.617a 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.
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.
Total organic compounds (TOC) means those compounds measured
according to the procedures of Method 18 of appendix A-6 to this part or
ASTM D6420-18 (incorporated by reference, see Sec. [thinsp]60.17) as
specified in Sec. 60.614a(b)(4) or the concentration of organic
compounds measured according to the procedures in Method 21 or Method
25A of appendix A-7 to this part.
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 recovery train or
indirectly, after diversion through other process equipment. The vent
stream excludes equipment leaks including, but not limited to, pumps,
compressors, and valves.
Sec. 60.612a What standards and associated requirements must I meet?
(a) You must comply with the emission limits and standards specified
in Table 1 to this subpart and the requirements specified paragraphs (b)
and (c) of this section for each vent stream on and after the date on
which the initial performance test required by Sec. Sec. 60.8 and
60.614a 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. The
standards in this section apply at all times, including periods of
startup, shutdown and malfunction. As provided in Sec. 60.11(f), this
provision supersedes the exemptions for periods of startup, shutdown and
malfunction in the general provisions in subpart A of this part.
(b) The following release events from an affected facility are a
violation of the emission limits and standards specified in table 1 to
this subpart.
(1) Any relief valve discharge to the atmosphere of a vent stream.
(2) The use of a bypass line at any time on a closed vent system to
divert emissions to the atmosphere, or to a control device or recovery
device not meeting the requirements specified in Sec. 60.613a.
(c) You may designate a vent stream as a maintenance vent if the
vent is only used as a result of startup, shutdown, maintenance, or
inspection of equipment where equipment is emptied, depressurized,
degassed, or placed into service. You must comply with the applicable
requirements in paragraphs (c)(1) through (3) of this section for each
maintenance vent. Any vent stream designated as a maintenance vent is
only subject to the
[[Page 162]]
maintenance vent provisions in this paragraph (c) and the associated
recordkeeping and reporting requirements in Sec. 60.615a(g),
respectively.
(1) Prior to venting to the atmosphere, remove process liquids from
the equipment as much as practical and depressurize the equipment to
either: A flare meeting the requirements of Sec. 60.619a, as
applicable, or using any combination of a non-flare control device or
recovery device meeting the requirements in Table 1 to this subpart
until one of the following conditions, as applicable, is met.
(i) The vapor in the equipment served by the maintenance vent has a
lower explosive limit (LEL) of less than 10 percent.
(ii) If there is no ability to measure the LEL of the vapor in the
equipment based on the design of the equipment, the pressure in the
equipment served by the maintenance vent is reduced to 5 pounds per
square inch gauge (psig) or less. Upon opening the maintenance vent,
active purging of the equipment cannot be used until the LEL of the
vapors in the maintenance vent (or inside the equipment if the
maintenance is a hatch or similar type of opening) is less than 10
percent.
(iii) The equipment served by the maintenance vent contains less
than 50 pounds of total VOC.
(iv) If, after applying best practices to isolate and purge
equipment served by a maintenance vent, none of the applicable criterion
in paragraphs (c)(1)(i) through (iii) of this section can be met prior
to installing or removing a blind flange or similar equipment blind,
then the pressure in the equipment served by the maintenance vent must
be reduced to 2 psig or less before installing or removing the equipment
blind. During installation or removal of the equipment blind, active
purging of the equipment may be used provided the equipment pressure at
the location where purge gas is introduced remains at 2 psig or less.
(2) Except for maintenance vents complying with the alternative in
paragraph (c)(1)(iii) of this section, you must determine the LEL or, if
applicable, equipment pressure using process instrumentation or portable
measurement devices and follow procedures for calibration and
maintenance according to manufacturer's specifications.
(3) For maintenance vents complying with the alternative in
paragraph (c)(1)(iii) of this section, you must determine mass of VOC in
the equipment served by the maintenance vent based on the equipment size
and contents after considering any contents drained or purged from the
equipment. Equipment size may be determined from equipment design
specifications. Equipment contents may be determined using process
knowledge.
Sec. 60.613a What are my monitoring, installation, operation,
and maintenance requirements?
(a) Except as specified in paragraphs (a)(5) through (7) of this
section, if you use a non-flare control device or recovery system to
comply with the TOC emission limit specified in Table 1 to this subpart,
then you must comply with paragraphs (a)(1) through (4), (b), and (c) of
this section.
(1) Install a continuous parameter monitoring system(s) (CPMS) and
monitor the operating parameter(s) applicable to the control device or
recovery system as specified in Table 2 to this subpart or established
according to paragraph (c) of this section.
(2) Establish the applicable minimum, maximum, or range for the
operating parameter limit as specified in Table 3 to this subpart or
established according to paragraph (c) of this section by calculating
the value(s) as the arithmetic average of operating parameter
measurements recorded during the three test runs conducted for the most
recent performance test. You may operate outside of the established
operating parameter limit(s) during subsequent performance tests in
order to establish new operating limits. You must include the updated
operating limits with the performance test results submitted to the
Administrator pursuant to Sec. 60.615a(b). Upon establishment of a new
operating limit, you must thereafter operate under the new operating
limit. If the Administrator determines that you did not conduct the
performance test in accordance with the applicable requirements or that
the operating limit established during the performance test does not
correspond to
[[Page 163]]
the conditions specified in Sec. 60.614a(a), then you must conduct a
new performance test and establish a new operating limit.
(3) Monitor, record, and demonstrate continuous compliance using the
minimum frequencies specified in Table 3 to this subpart or established
according to paragraph (c) of this section.
(4) Comply with the calibration and quality control requirements as
specified in Table 4 to this subpart or established according to
paragraph (c) of this section that are applicable to the CPMS used.
(5) Any vent stream introduced with primary fuel into a boiler or
process heater is exempt from the requirements specified in paragraphs
(a)(1) through (4) of this section.
(6) If you vent emissions through a closed vent system to an
adsorber(s) that cannot be regenerated or a regenerative adsorber(s)
that is regenerated offsite, then you must install a system of two or
more adsorber units in series and comply with the requirements specified
in paragraphs (a)(6)(i) through (iii) of this section in addition to the
requirements specified in paragraphs (a)(1) through (4) of this section.
(i) Conduct an initial performance test or design evaluation of the
adsorber and establish the breakthrough limit and adsorber bed life.
(ii) Monitor the TOC concentration through a sample port at the
outlet of the first adsorber bed in series according to the schedule in
paragraph (a)(6)(iii)(B) of this section. You must measure the
concentration of TOC using either a portable analyzer, in accordance
with Method 21 of appendix A-7 of this part using methane, propane, or
isobutylene as the calibration gas or Method 25A of appendix A-7 of this
part using methane or propane as the calibration gas.
(iii) Comply with paragraph (a)(6)(iii)(A) of this section, and
comply with the monitoring frequency according to paragraph
(a)(6)(iii)(B) of this section.
(A) The first adsorber in series must be replaced immediately when
breakthrough, as defined in Sec. 60.611a, is detected between the first
and second adsorber. The original second adsorber (or a fresh canister)
will become the new first adsorber and a fresh adsorber will become the
second adsorber. For purposes of this paragraph (a)(6)(iii)(A),
``immediately'' means within 8 hours of the detection of a breakthrough
for adsorbers of 55 gallons or less, and within 24 hours of the
detection of a breakthrough for adsorbers greater than 55 gallons. You
must monitor at the outlet of the first adsorber within 3 days of
replacement to confirm it is performing properly.
(B) Based on the adsorber bed life established according to
paragraph (a)(6)(i) of this section and the date the adsorbent was last
replaced, conduct monitoring to detect breakthrough at least monthly if
the adsorbent has more than 2 months of life remaining, at least weekly
if the adsorbent has between 2 months and 2 weeks of life remaining, and
at least daily if the adsorbent has 2 weeks or less of life remaining.
(7) If you install a continuous emissions monitoring system (CEMS)
to demonstrate compliance with the TOC standard in Table 1 of this
subpart, you must comply with the requirements specified in Sec.
60.614a(f) in lieu of the requirements specified in paragraphs (a)(1)
through (4) and (c) of this section.
(b) If you vent emissions through a closed vent system to a boiler
or process heater, then the vent stream must be introduced into the
flame zone of the boiler or process heater.
(c) If you seek to demonstrate compliance with the standards
specified under Sec. 60.612a with control devices other than an
incinerator, boiler, process heater, or flare; or recovery devices other
than an absorber, condenser, or carbon adsorber, you shall provide to
the Administrator prior to conducting the initial performance test
information describing the operation of the control device or recovery
device and the parameter(s) which would indicate proper operation and
maintenance of the device and how the parameter(s) are indicative of
control of TOC emissions. The Administrator may request further
information and will specify appropriate monitoring procedures or
requirements, including operating parameters to be monitored, averaging
times for determining compliance with the operating parameter limits,
and
[[Page 164]]
ongoing calibration and quality control requirements.
Sec. 60.614a What test methods and procedures must I use to
determine compliance with the standards?
(a) For the purpose of demonstrating compliance with the emission
limits and standards specified in table 1 to this subpart, all affected
facilities must be run at full operating conditions and flow rates
during any performance test. Performance tests are not required if you
determine compliance using a CEMS that meets the requirements outlined
in paragraph (f) of this section.
(1) Conduct initial performance tests no later than the date
required by Sec. 60.8(a).
(2) Conduct subsequent performance tests no later than 60 calendar
months after the previous performance test.
(b) The following methods, except as provided in Sec. 60.8(b) must
be used as reference methods to determine compliance with the emission
limit or percent reduction efficiency specified in table 1 to this
subpart for non-flare control devices and/or recovery systems.
(1) Method 1 or 1A of appendix A-1 to this part, as appropriate, for
selection of the sampling sites. The 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 or, if equipped with a recovery system, then prior to the inlet
of the first recovery device in the recovery system.
(2) Method 2, 2A, 2C, or 2D of appendix A-1 to this part, as
appropriate, for determination of the volumetric flow rates.
(3) Method 3A of appendix A-2 to this part or the manual method in
ANSI/ASME PTC 19.10-1981 (incorporated by reference, see Sec.
[thinsp]60.17) must be used to determine the oxygen concentration (%O2d)
for the purposes of determining compliance with the 20 ppmv limit. The
sampling site must be the same as that of the TOC samples and the
samples must be taken during the same time that the TOC samples are
taken. The TOC concentration corrected to 3 percent O2
(Cc) must be computed using the following equation:
Equation 1 to Paragraph (b)(3)
[GRAPHIC] [TIFF OMITTED] TR16MY24.028
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 of appendix A-6 to this part to determine
concentration of TOC in the control device outlet or in the outlet of
the final recovery device in a recovery system, and to determine the
concentration of TOC in the inlet when the reduction efficiency of the
control device or recovery system is to be determined. ASTM D6420-18
(incorporated by reference, see Sec. 60.17) may be used in lieu of
Method 18, if the target compounds are all known and are all listed in
Section 1.1 of ASTM D6420-18 as measurable; ASTM D6420-18 must not be
used for methane and ethane; and ASTM D6420-18 may not be used as a
total VOC method.
(i) The sampling time for each run must be 1 hour in which either an
integrated sample or at least four grab samples must be taken. If grab
sampling is used then the samples must be taken at 15-minute intervals.
(ii) The emission reduction (R) of TOC (minus methane and ethane)
must be determined using the following equation:
[[Page 165]]
Equation 2 to Paragraph (b)(4)(ii)
[GRAPHIC] [TIFF OMITTED] TR16MY24.029
Where:
R = Emission reduction, percent by weight.
Ei = Mass rate of TOC entering the control device or recovery
system, kg/hr (lb/hr).
Eo = Mass rate of TOC discharged to the atmosphere, kg/hr
(lb/hr).
(iii) The mass rates of TOC (Ei, Eo) must be
computed using the following equations:
Equations 3 and 4 to Paragraph (b)(4)(iii)
[GRAPHIC] [TIFF OMITTED] TR16MY24.030
Where:
Cij, Coj = Concentration of sample component ``j''
of the gas stream at the inlet and outlet of the control
device or recovery system, 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 or recovery system, respectively, g/g-mole (lb/lb-
mole).
Qi, Qo = Flow rate of gas stream at the inlet and
outlet of the control device or recovery system, respectively,
dscm/min (dscf/min).
K2 = 2.494 x 10-6 (1/ppm)(g-mole/scm)(kg/g)(min/
hr) (metric units), where standard temperature for (g-mole/
scm) is 20 [deg]C.
= 1.557 x 10-7 (1/ppm)(lb-mole/scf)(min/hr) (English units),
where standard temperature for (lb-mole/scf) is 68 [deg]F.
(iv) The TOC concentration (CTOC) is the sum of the
individual components and must be computed for each run using the
following equation:
Equation 5 to Paragraph (b)(4)(iv)
[GRAPHIC] [TIFF OMITTED] TR16MY24.031
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.
(c) The requirement for initial and subsequent performance tests are
waived, in accordance with Sec. 60.8(b), for the following:
(1) 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 the emission limit or percent reduction efficiency
specified in table 1 to this subpart.
[[Page 166]]
(2) When a vent stream is introduced into a boiler or process heater
with the primary fuel.
(3) When a boiler or process heater burning hazardous waste is used
for which the owner or operator:
(i) Has been issued a final permit under 40 CFR part 270 and
complies with the requirements of 40 CFR part 266, subpart H;
(ii) Has certified compliance with the interim status requirements
of 40 CFR part 266, subpart H;
(iii) Has submitted a Notification of Compliance under 40 CFR
63.1207(j) and complies with the requirements of 40 CFR part 63, subpart
EEE; or
(iv) Complies with 40 CFR part 63, subpart EEE and will submit a
Notification of Compliance under 40 CFR 63.1207(j) by the date the owner
or operator would have been required to submit the initial performance
test report for this subpart.
(4) 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.
(d) For purposes of complying with the 98 weight-percent reduction
in Sec. 60.612a(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.
(e) Any owner or operator subject to the provisions of this subpart
seeking to demonstrate compliance with Sec. 60.610a(c)(1) must use the
following methods:
(1) Method 1 or 1A of appendix A-1 to this part, as appropriate.
(2) Method 2, 2A, 2C, or 2D of appendix A-1 to this part, as
appropriate, for determination of the gas volumetric flow rates.
(3) Method 18 of appendix A-6 to this part to determine the
concentration of TOC. ASTM D6420-18 (incorporated by reference, see
Sec. 60.17) may be used in lieu of Method 18, if the target compounds
are all known and are all listed in Section 1.1 of ASTM D6420-18 as
measurable; ASTM D6420-18 may not be used for methane and ethane; and
ASTM D6420-18 must not be used as a total VOC method.
(i) The sampling site must be at a location that provides a
representative sample of the vent stream.
(ii) Perform three test runs. The sampling time for each run must be
1 hour in which either an integrated sample or at least four grab
samples must be taken. If grab sampling is used then the samples must be
taken at 15-minute intervals.
(iii) The mass rate of TOC (E) must be computed using the following
equation:
Equation 6 to Paragraph (e)(3)(ii)
[GRAPHIC] [TIFF OMITTED] TR16MY24.032
Where:
Cj = Concentration of sample component ``j'' of the gas
stream at the representative sampling location, dry basis, ppm
by volume.
Mj = Molecular weight of sample component ``j'' of the gas
stream at the representative sampling location, g/g-mole (lb/
lb-mole).
Q = Flow rate of gas stream at the representative sampling location,
dscm/min (dscf/min).
K = 2.494 x 10-6 (1/ppm)(g-mole/scm) (kg/g) (min/hr) (metric
units), where standard temperature for (g-mole/scm) is 20
[deg]C.
[[Page 167]]
= 1.557 x 10-7 (1/ppm) (lb-mole/scf) (min/hr) (English
units), where standard temperature for (lb-mole/scf) is 68
[deg]F.
(f) If you use a CEMS to demonstrate initial and continuous
compliance with the TOC standard in table 1 of this subpart, each CEMS
must be installed, operated and maintained according to the requirements
in Sec. 60.13 and paragraphs (f)(1) through (5) of this section.
(1) You must use a CEMS that is capable of measuring the target
analyte(s) as demonstrated using either process knowledge of the control
device inlet stream or the screening procedures of Method 18 of appendix
A-6 to this part on the control device inlet stream. If your CEMS is
located after a combustion device and inlet stream to that device
includes methanol or formaldehyde, you must use a CEMS which meets the
requirements in Performance Specification 9 or 15 of appendix B to this
part.
(2) Each CEMS must be installed, operated, and maintained according
to the applicable performance specification of appendix B to this part
and the applicable quality assurance procedures of appendix F to this
part. Locate the sampling probe or other interface at a measurement
location such that you obtain representative measurements of emissions
from the affected facility.
(3) Conduct a performance evaluation of each CEMS within 180 days of
installation of the monitoring system. Conduct subsequent performance
evaluations of the CEMS no later than 12 calendar months after the
previous performance evaluation. The results each performance evaluation
must be submitted in accordance with Sec. 60.615a(b)(1).
(4) You must determine TOC concentration according to one of the
following options. The span value of the TOC CEMS must be approximately
2 times the emission standard specified in table 1 of this subpart.
(i) For CEMS meeting the requirements of Performance Specification
15 of appendix B to this part, determine the target analyte(s) for
calibration using either process knowledge of the control device inlet
stream or the screening procedures of Method 18 of appendix A-6 to this
part on the control device inlet stream. The individual analytes used to
quantify TOC must represent 98 percent of the expected mass of TOC
present in the stream. Report the results of TOC as equivalent to carbon
(C1).
(ii) For CEMS meeting the requirements of Performance Specification
9 of appendix B to this part, determine the target analyte(s) for
calibration using either process knowledge of the control device inlet
stream or the screening procedures of Method 18 of appendix A-6 to this
part on the control device inlet stream. The individual analytes used to
quantify TOC must represent 98 percent of the expected mass of TOC
present in the stream. Report the results of TOC as equivalent to carbon
(C1).
(iii) For CEMS meeting the requirements of Performance Specification
8 of appendix B to this part used to monitor performance of a combustion
device, calibrate the instrument on the predominant organic HAP and
report the results as carbon (C1), and use Method 25A of appendix A-7 to
this part as the reference method for the relative accuracy tests. You
must also comply with procedure 1 of appendix F to this part.
(iv) For CEMS meeting the requirements of Performance Specification
8 of appendix B to this part used to monitor performance of a
noncombustion device, determine the predominant organic compound using
either process knowledge or the screening procedures of Method 18 of
appendix A-6 to this part on the control device inlet stream. Calibrate
the monitor on the predominant organic compound and report the results
as C1. Use Method 25A of appendix A-7 to this part as the
reference method for the relative accuracy tests. You must also comply
with procedure 1 of appendix F to this part.
(5) You must determine stack oxygen concentration at the same
location where you monitor TOC concentration with a CEMS that meets the
requirements of Performance Specification 3 of appendix B to this part.
The span value of the oxygen CEMS must be approximately 25 percent
oxygen. Use Method 3A of appendix A-2 to this part as the reference
method for the relative accuracy tests.
[[Page 168]]
(6) You must maintain written procedures for your CEMS. At a
minimum, the procedures must include the information in paragraphs
(f)(6)(i) through (vi) of this section:
(i) Description of CEMS installation location.
(ii) Description of the monitoring equipment, including the
manufacturer and model number for all monitoring equipment components
and the span of the analyzer.
(iii) Routine quality control and assurance procedures.
(iv) Conditions that would trigger a CEMS performance evaluation,
which must include, at a minimum, a newly installed CEMS; a process
change that is expected to affect the performance of the CEMS; and the
Administrator's request for a performance evaluation under section 114
of the Clean Air Act.
(v) Ongoing operation and maintenance procedures.
(vi) Ongoing recordkeeping and reporting procedures.
Sec. 60.615a What records must I keep and what reports must I submit?
(a) You must notify the Administrator of the specific provisions of
table 1 to this subpart or Sec. 60.612a(c) with which you have elected
to comply. Notification must be submitted with the notification of
initial start-up required by Sec. 60.7(a)(3). If you elect at a later
date to use an alternative provision of table 1 to this subpart with
which you will comply, then you must notify the Administrator 90 days
before implementing a change and, upon implementing the change, you must
conduct a performance test as specified by Sec. 60.614a within 180
days.
(b) If you use a non-flare control device or recovery system to
comply with the TOC emission limit specified in table 1 to this subpart,
then you must keep up-to-date, readily accessible records of the data
measured during each performance test to show compliance with the TOC
emission limit. You must also include all of the data you use to comply
with Sec. 60.613a(a)(2). The same data specified in this paragraph must
also be submitted in the initial performance test required in Sec. 60.8
and the reports of all subsequently required performance tests where
either the emission reduction efficiency of a control device or recovery
system or outlet concentration of TOC is determined. Alternatively, you
must keep records of each CEMS performance evaluation.
(1) Within 60 days after the date of completing each performance
test or CEMS performance evaluation required by this subpart, you must
submit the results of the performance test or performance evaluation
following the procedures specified in paragraph (j) of this section.
Data collected using test methods and performance evaluations of CEMS
measuring relative accuracy test audit (RATA) pollutants supported by
the EPA's Electronic Reporting Tool (ERT) as listed on the EPA's ERT
website (https://www.epa.gov/electronic-reporting-air-emissions/
electronic-reporting-tool-ert) at the time of the test or performance
evaluation must be submitted in a file format generated through the use
of the EPA's ERT. Alternatively, owners and operators may submit an
electronic file consistent with the extensible markup language (XML)
schema listed on the EPA's ERT website. Data collected using test
methods and performance evaluations of CEMS measuring RATA pollutants
that are not supported by the EPA's ERT as listed on the EPA's ERT
website at the time of the test must be included as an attachment in the
ERT or alternate electronic file.
(2) If you use a boiler or process heater with a design heat input
capacity of 44 MW (150 million Btu/hour) or greater to comply with the
TOC emission limit specified in Table 1 to this subpart, then you are
not required to submit a report containing performance test data;
however, you must submit a description of the location at which the vent
stream is introduced into the boiler or process heater.
(c) If you use a non-flare control device or recovery system to
comply with the TOC emission limit specified in table 1 to this subpart,
then you must keep up-to-date, readily accessible records of periods of
operation during which the operating parameter limits established during
the most recent performance test are exceeded or periods of operation
where the TOC CEMS,
[[Page 169]]
averaged on a 3-hour block basis, indicate an exceedance of the emission
standard in table 1 of this subpart. Additionally, you must record all
periods when the TOC CEMS is inoperable. The Administrator may at any
time require a report of these data. Periods of operation during which
the operating parameter limits established during the most recent
performance tests are exceeded are defined as follows:
(1) For absorbers:
(i) All 3-hour periods of operation during which the average
absorbing liquid temperature was above the maximum absorbing liquid
temperature established during the most recent performance test.
(ii) All 3-hour periods of operation during which the average
absorbing liquid specific gravity was outside the exit specific gravity
range (i.e., more than 0.1 unit above, or more than 0.1 unit below, the
average absorbing liquid specific gravity) established during the most
recent performance test.
(2) For boilers or process heaters:
(i) Whenever there is a change in the location at which the vent
stream is introduced into the flame zone as required under Sec.
60.613a(b).
(ii) If the boiler or process heater has a design heat input
capacity of less than 44 MW (150 million Btu/hr), then all 3-hour
periods of operation during which the average firebox temperature was
below the minimum firebox temperature during the most recent performance
test.
(3) For catalytic incinerators:
(i) All 3-hour periods of operation during which the average
temperature of the vent stream immediately before the catalyst bed is
below the minimum temperature of the vent stream established during the
most recent performance test.
(ii) All 3-hour periods of operation during which the average
temperature difference across the catalyst bed is less than the average
temperature difference of the device established during the most recent
performance test.
(4) For carbon adsorbers:
(i) All carbon bed regeneration cycles during which the total mass
stream flow or the total volumetric stream flow was below the minimum
flow established during the most recent performance test.
(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 greater than the maximum carbon bed temperature
(in degrees Celsius) established during the most recent performance
test.
(5) For condensers, all 3-hour periods of operation during which the
average exit (product side) condenser operating temperature was above
the maximum exit (product side) operating temperature established during
the most recent performance test.
(6) For scrubbers used to control halogenated vent streams:
(i) All 3-hour periods of operation during which the average pH of
the scrubber effluent is below the minimum pH of the scrubber effluent
established during the most recent performance test.
(ii) All 3-hour periods of operation during which the average
influent liquid flow to the scrubber is below the minimum influent
liquid flow to the scrubber established during the most recent
performance test.
(iii) All 3-hour periods of operation during which the average
liquid-to-gas ratio flow of the scrubber is below the minimum liquid-to-
gas ratio of the scrubber established during the most recent performance
test.
(7) For thermal incinerators, all 3-hour periods of operation during
which the average firebox temperature was below the minimum firebox
temperature established during the most recent performance test.
(8) For all other control devices, all periods (for the averaging
time specified by the Administrator) when the operating parameter(s)
established under Sec. 60.613a(c) exceeded the operating limit
established during the most recent performance test.
(d) You must keep up-to-date, readily accessible continuous records
of the flow indication specified in Table 2 to this subpart, as well as
up-to-date, readily accessible records of all periods when the vent
stream is diverted from the control device or recovery device or has no
flow rate, including the
[[Page 170]]
records as specified in paragraphs (d)(1) and (2) of this section.
(1) For each flow event from a relief valve discharge subject to the
requirements in Sec. 60.612a(b)(1), you must include an estimate of the
volume of gas, the concentration of TOC in the gas and the resulting
emissions of TOC that released to the atmosphere using process knowledge
and engineering estimates.
(2) For each flow event from a bypass line subject to the
requirements in Sec. Sec. 60.612a(b)(2) and 60.620a(e), you must
maintain records sufficient to determine whether or not the detected
flow included flow requiring control. For each flow event from a bypass
line requiring control that is released either directly to the
atmosphere or to a control device or recovery device not meeting the
requirements in this subpart, you must include an estimate of the volume
of gas, the concentration of TOC in the gas and the resulting emissions
of TOC that bypassed the control device or recovery device using process
knowledge and engineering estimates.
(e) If you use a boiler or process heater with a design heat input
capacity of 44 MW (150 million Btu/hour) or greater to comply with the
TOC emission limit specified in Table 1 to this subpart, then you must
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) If you use a flare to comply with the TOC emission standard
specified in Table 1 to this subpart, then you must keep up-to-date,
readily accessible records of all visible emission readings, heat
content determinations, flow rate measurements, and exit velocity
determinations made during the initial visible emissions demonstration
required by Sec. 63.670(h) of this chapter, as applicable; and all
periods during the compliance determination when the pilot flame or
flare flame is absent.
(g) For each maintenance vent opening subject to the requirements of
Sec. 60.612a(c), you must keep the applicable records specified in
paragraphs (g)(1) through (5) of this section.
(1) You must maintain standard site procedures used to deinventory
equipment for safety purposes (e.g., hot work or vessel entry
procedures) to document the procedures used to meet the requirements in
Sec. 60.612a(c). The current copy of the procedures must be retained
and available on-site at all times. Previous versions of the standard
site procedures, as applicable, must be retained for five years.
(2) If complying with the requirements of Sec. 60.612a(c)(1)(i),
and the lower explosive limit at the time of the vessel opening exceeds
10 percent, identification of the maintenance vent, the process units or
equipment associated with the maintenance vent, the date of maintenance
vent opening, and the lower explosive limit at the time of the vessel
opening.
(3) If complying with the requirements of Sec. 60.612a(c)(1)(ii),
and either the vessel pressure at the time of the vessel opening exceeds
5 psig or the lower explosive limit at the time of the active purging
was initiated exceeds 10 percent, identification of the maintenance
vent, the process units or equipment associated with the maintenance
vent, the date of maintenance vent opening, the pressure of the vessel
or equipment at the time of discharge to the atmosphere and, if
applicable, the lower explosive limit of the vapors in the equipment
when active purging was initiated.
(4) If complying with the requirements of Sec. 60.612a(c)(1)(iii),
records of the estimating procedures used to determine the total
quantity of VOC in the equipment and the type and size limits of
equipment that contain less than 50 pounds of VOC at the time of
maintenance vent opening. For each maintenance vent opening that
contains greater than 50 pounds of VOC for which the deinventory
procedures specified in paragraph (g)(1) of this section are not
followed or for which the equipment opened exceeds the type and size
limits established in the records specified in this paragraph (g)(4),
records that identify the maintenance vent, the process units or
equipment associated with the maintenance vent, the date of maintenance
vent opening, and records used to estimate the total quantity of VOC in
the equipment at
[[Page 171]]
the time the maintenance vent was opened to the atmosphere.
(5) If complying with the requirements of Sec. 60.612a(c)(1)(iv),
identification of the maintenance vent, the process units or equipment
associated with the maintenance vent, records documenting actions taken
to comply with other applicable alternatives and why utilization of this
alternative was required, the date of maintenance vent opening, the
equipment pressure and lower explosive limit of the vapors in the
equipment at the time of discharge, an indication of whether active
purging was performed and the pressure of the equipment during the
installation or removal of the blind if active purging was used, the
duration the maintenance vent was open during the blind installation or
removal process, and records used to estimate the total quantity of VOC
in the equipment at the time the maintenance vent was opened to the
atmosphere for each applicable maintenance vent opening.
(h) If you seek to comply with the requirements of this subpart by
complying with the flow rate cutoff in Sec. 60.610a(c)(1) you must keep
up-to-date, readily accessible records to indicate that the vent stream
flow rate is less than 0.001 lb/hr, 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) You must submit to the Administrator semiannual reports of the
information specified in paragraphs (i)(1) through (7) of this section.
You are exempt from the reporting requirements specified in Sec.
60.7(c). If there are no exceedances, periods, or events specified in
paragraphs (i)(1) through (7) of this section that occurred during the
reporting period, then you must include a statement in your report that
no exceedances, periods, and events specified in paragraphs (i)(1)
through (7) of this section occurred during the reporting period. The
initial report must be submitted within 6 months after the initial
start-up-date. On and after July 15, 2024 or once the report template
for this subpart has been available on the Compliance and Emissions Data
Reporting Interface (CEDRI) website (https://www.epa.gov/electronic-
reporting-air-emissions/cedri) for 1 year, whichever date is later, you
must submit all subsequent reports using the appropriate electronic
report template on the CEDRI website for this subpart and following the
procedure specified in paragraph (j) of this section. The date report
templates become available will be listed on the CEDRI website. Unless
the Administrator or delegated state agency or other authority has
approved a different schedule for submission of reports, the report must
be submitted by the deadline specified in this subpart, regardless of
the method in which the report is submitted. All semiannual reports must
include the following general information: company name, address
(including county), and beginning and ending dates of the reporting
period.
(1) Exceedances of monitored parameters recorded under paragraph (c)
of this section. For each exceedance, the report must include a list of
the affected facilities or equipment, the monitored parameter that was
exceeded, the start date and time of the exceedance, the duration (in
hours) of the exceedance, an estimate of the quantity in pounds of each
regulated pollutant emitted over any emission limit, a description of
the method used to estimate the emissions, the cause of the exceedance
(including unknown cause, if applicable), as applicable, and the
corrective action taken.
(2) All periods recorded under paragraph (d) of this section when
the vent stream is diverted from the control device or recovery device,
or has no flow rate, including the information specified in paragraphs
(i)(2)(i) through (iii) of this section.
(i) For periods when the flow indicator is not operating, the
identification of the flow indicator and report the start date, start
time, and duration in hours.
(ii) For each flow event from a relief valve discharge subject to
the requirements in Sec. 60.612a(b)(1), the semiannual report must
include the identification of the relief valve, the start date, start
time, duration in hours, estimate of the volume of gas in standard cubic
feet, the concentration of TOC in the gas in parts per million by volume
and the resulting mass emissions of TOC in
[[Page 172]]
pounds that released to the atmosphere.
(iii) For each flow event from a bypass line subject to the
requirements in Sec. 60.612a(b)(2) and Sec. 620a(e)(2), the semiannual
report must include the identification of the bypass line, the start
date, start time, duration in hours, estimate of the volume of gas in
standard cubic feet, the concentration of TOC in the gas in parts per
million by volume and the resulting mass emissions of TOC in pounds that
bypass a control device or recovery device.
(3) All periods when a boiler or process heater was not operating
(considering the records recorded under paragraph (e) of this section),
including the start date, start time, and duration in hours of each
period.
(4) For each flare subject to the requirements in Sec. 60.619a, the
semiannual report must include an identification of the flare and the
items specified in Sec. 60.619a(l)(2).
(5) For each closed vent system subject to the requirements in Sec.
60.620a, the semiannual report must include an identification of the
closed vent system and the items specified in Sec. 60.620a(i).
(6) Exceedances of the emission standard in table 1 to this subpart
as indicated by a 3-hour average of the TOC CEMS and recorded under
paragraph (c) of this section. For each exceedance, the report must
include a list of the affected facilities or equipment, the start date
and time of the exceedance, the duration (in hours) of the exceedance,
an estimate of the quantity in pounds of each regulated pollutant
emitted over the emission limit, a description of the method used to
estimate the emissions, the cause of the exceedance (including unknown
cause, if applicable), as applicable, and the corrective action taken.
(7) Periods when the TOC CEMS was inoperative. For each period, the
report must include a list of the affected facilities or equipment, the
start date and time of the period, the duration (in hours) of the
period, the cause of the inoperability (including unknown cause, if
applicable), as applicable, and the corrective action taken.
(8) Any change in equipment or process operation that increases the
operating vent stream flow rate above the low flow exemption level in
Sec. 60.610a(c)(1), including a measurement of the new vent stream flow
rate, as recorded under paragraph (h) of this section. 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. The performance test is subject to the
requirements of Sec. 60.8 of the General Provisions and must be
submitted according to paragraph (b)(1) of this section. Unless the
facility qualifies for an exemption under Sec. 60.610a(c), the facility
must begin compliance with the requirements set forth in Sec. 60.612a.
(j) If you are required to submit notifications or reports following
the procedure specified in this paragraph (j), you must submit
notifications or reports to the EPA via the CEDRI, which can be accessed
through the EPA's Central Data Exchange (CDX) (https://cdx.epa.gov/).
The EPA will make all the information submitted through CEDRI available
to the public without further notice to you. Do not use CEDRI to submit
information you claim as CBI. Although we do not expect persons to
assert a claim of CBI, if you wish to assert a CBI claim for some of the
information in the report or notification, you must submit a complete
file in the format specified in this subpart, including information
claimed to be CBI, to the EPA following the procedures in paragraphs
(j)(1) and (2) of this section. Clearly mark the part or all of the
information that you claim to be CBI. Information not marked as CBI may
be authorized for public release without prior notice. Information
marked as CBI will not be disclosed except in accordance with procedures
set forth in 40 CFR part 2. All CBI claims must be asserted at the time
of submission. Anything submitted using CEDRI cannot later be claimed
CBI. Furthermore, under CAA section 114(c), emissions data is not
entitled to confidential treatment, and the EPA is required to make
emissions data available to the public. Thus,
[[Page 173]]
emissions data will not be protected as CBI and will be made publicly
available. You must submit the same file submitted to the CBI office
with the CBI omitted to the EPA via the EPA's CDX as described earlier
in this paragraph (j).
(1) The preferred method to receive CBI is for it to be transmitted
electronically using email attachments, File Transfer Protocol, or other
online file sharing services. Electronic submissions must be transmitted
directly to the OAQPS CBI Office at the email address [email protected],
and as described above, should include clear CBI markings. ERT files
should be flagged to the attention of the Group Leader, Measurement
Policy Group; all other files should be flagged to the attention of the
SOCMI NSPS Sector Lead. If assistance is needed with submitting large
electronic files that exceed the file size limit for email attachments,
and if you do not have your own file sharing service, please email
[email protected] to request a file transfer link.
(2) If you cannot transmit the file electronically, you may send CBI
information through the postal service to the following address: OAQPS
Document Control Officer (C404-02), OAQPS, U.S. Environmental Protection
Agency, 109 T.W. Alexander Drive, P.O. Box 12055, Research Triangle
Park, North Carolina 27711. ERT files should be sent to the attention of
the Group Leader, Measurement Policy Group, and all other files should
be sent to the attention of the SOCMI NSPS Sector Lead. The mailed CBI
material should be double wrapped and clearly marked. Any CBI markings
should not show through the outer envelope.
(k) If you are required to electronically submit notifications or
reports through CEDRI in the EPA's CDX, you may assert a claim of EPA
system outage for failure to timely comply with the electronic submittal
requirement. To assert a claim of EPA system outage, you must meet the
requirements outlined in paragraphs (k)(1) through (7) of this section.
(1) You must have been or will be precluded from accessing CEDRI and
submitting a required report within the time prescribed due to an outage
of either the EPA's CEDRI or CDX systems.
(2) The outage must have occurred within the period of time
beginning five business days prior to the date that the submission is
due.
(3) The outage may be planned or unplanned.
(4) You must submit notification to the Administrator in writing as
soon as possible following the date you first knew, or through due
diligence should have known, that the event may cause or has caused a
delay in reporting.
(5) You must provide to the Administrator a written description
identifying:
(i) The date(s) and time(s) when CDX or CEDRI was accessed and the
system was unavailable;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to EPA system outage;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which you propose to report, or if you have already
met the reporting requirement at the time of the notification, the date
you reported.
(6) The decision to accept the claim of EPA system outage and allow
an extension to the reporting deadline is solely within the discretion
of the Administrator.
(7) In any circumstance, the report must be submitted electronically
as soon as possible after the outage is resolved.
(l) If you are required to electronically submit notifications or
reports through CEDRI in the EPA's CDX, you may assert a claim of force
majeure for failure to timely comply with the electronic submittal
requirement. To assert a claim of force majeure, you must meet the
requirements outlined in paragraphs (l)(1) through (5) of this section.
(1) You may submit a claim if a force majeure event is about to
occur, occurs, or has occurred or there are lingering effects from such
an event within the period of time beginning five business days prior to
the date the submission is due. For the purposes of this section, a
force majeure event is defined as an event that will be or has been
caused by circumstances beyond the control of
[[Page 174]]
the affected facility, its contractors, or any entity controlled by the
affected facility that prevents you from complying with the requirement
to submit a report electronically within the time period prescribed.
Examples of such events are acts of nature (e.g., hurricanes,
earthquakes, or floods), acts of war or terrorism, or equipment failure
or safety hazard beyond the control of the affected facility (e.g.,
large scale power outage).
(2) You must submit notification to the Administrator in writing as
soon as possible following the date you first knew, or through due
diligence should have known, that the event may cause or has caused a
delay in reporting.
(3) You must provide to the Administrator:
(i) A written description of the force majeure event;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to the force majeure event;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which you propose to report, or if you have already
met the reporting requirement at the time of the notification, the date
you reported.
(4) The decision to accept the claim of force majeure and allow an
extension to the reporting deadline is solely within the discretion of
the Administrator.
(5) In any circumstance, the reporting must occur as soon as
possible after the force majeure event occurs.
(m) The requirements of paragraph (i) 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 paragraph (i) of this section, provided
that they comply with the requirements established by the State. The EPA
will not approve a waiver of electronic reporting to the EPA in
delegating enforcement authority. Thus, electronic reporting to the EPA
cannot be waived, and as such, the provisions of this paragraph cannot
be used to relieve owners or operators of affected facilities of the
requirement to submit the electronic reports required in this section to
the EPA.
(n) If you seek to demonstrate compliance with Sec. 60.610(c)(1),
then you must submit to the Administrator, following the procedures in
paragraph (b)(1) of this section, an initial report including a flow
rate measurement using the test methods specified in Sec. 60.614a.
(o) 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. 60.612a other than as provided under Sec. 60.613a.
(p) Any records required to be maintained by this subpart that are
submitted electronically via the EPA's CEDRI may be maintained in
electronic format. This ability to maintain electronic copies does not
affect the requirement for facilities to make records, data, and reports
available upon request to a delegated air agency or the EPA as part of
an on-site compliance evaluation.
Sec. 60.616a What do the terms associated with reconstruction mean
for this subpart?
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 April 25, 2023. For purposes of this
section, ``commenced'' means that you have undertaken a continuous
program of component replacement or that you have entered into a
contractual obligation to undertake and complete, within a reasonable
time, a continuous program of component replacement.
Sec. 60.617a What are the chemicals that I must produce to be
affected by subpart IIIa?
------------------------------------------------------------------------
Chemical name CAS No.*
------------------------------------------------------------------------
Acetaldehyde............................................... 75-07-0
Acetic acid................................................ 64-19-7
[[Page 175]]
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. 60.618a [Reserved]
Sec. 60.619a What are my requirements if I use a flare to comply
+with this subpart?
(a) If you use a flare to comply with the TOC emission standard
specified in Table 1 to this subpart, then you must meet the applicable
requirements for flares as specified in Sec. Sec. 63.670 and 63.671 of
this chapter, including the provisions in tables 12 and 13 to part 63,
subpart CC, of this chapter, except as specified in paragraphs (b)
through (o) of this section. This requirement also applies to any flare
using fuel gas from a fuel gas system, of which 50 percent or more of
the fuel gas is derived from an affected facility, as determined on an
annual average basis. For purposes of compliance with this paragraph
(a), the following terms are defined in Sec. 63.641 of this chapter:
Assist air, assist steam, center steam, combustion zone, combustion zone
gas, flare, flare purge gas, flare supplemental gas, flare sweep gas,
flare vent gas, lower steam, net heating value, perimeter assist air,
pilot gas, premix assist air, total steam, and upper steam.
(b) When determining compliance with the pilot flame requirements
specified in Sec. 63.670(b) and (g) of this chapter, substitute ``pilot
flame or flare flame'' for each occurrence of ``pilot flame.''
(c) When determining compliance with the flare tip velocity and
combustion zone operating limits specified in Sec. 63.670(d) and (e) of
this chapter, the requirement effectively applies starting with the 15-
minute block that includes a full 15 minutes of the flaring event. You
are required to demonstrate compliance with the velocity and NHVcz
requirements starting with the block that contains the fifteenth minute
of a flaring event. You are not required to demonstrate compliance for
the previous 15-minute block in which the event started and contained
only a fraction of flow.
(d) Instead of complying with Sec. 63.670(o)(2)(i) of this chapter,
you must develop and implement the flare management plan no later than
startup for a new flare that commenced construction on or after April
25, 2023.
(e) Instead of complying with Sec. 63.670(o)(2)(iii) of this
chapter, if required to develop a flare management plan and submit it to
the Administrator, then you must also submit all versions of the plan in
portable document format (PDF) following the procedures specified in
Sec. 60.615a(j).
(f) Section 63.670(o)(3)(ii) of this chapter and all references to
it do not apply. Instead, you must comply with the maximum flare tip
velocity operating limit at all times.
(g) Substitute ``affected facility'' for each occurrence of
``petroleum refinery.''
(h) Each occurrence of ``refinery'' does not apply.
(i) If a pressure-assisted multi-point flare is used as a control
device, then you must meet the following conditions:
(1) You are not required to comply with the flare tip velocity
requirements in of Sec. 63.670(d) and (k) of this chapter;
[[Page 176]]
(2) The NHVcz for pressure-assisted mulit-point flares is 800 Btu/
scf;
(3) You must determine the 15-minute block average NHVvg using only
the direct calculation method specified in in Sec. 63.670 (l)(5)(ii) of
this chapter;
(4) Instead of complying with Sec. 63.670(b) and (g) of this
chapter, if a pressure-assisted multi-point flare uses cross-lighting on
a stage of burners rather than having an individual pilot flame on each
burner, then you must operate each stage of the pressure-assisted multi-
point flare with a flame present at all times when regulated material is
routed to that stage of burners. Each stage of burners that cross-lights
in the pressure-assisted multi-point flare must have at least two pilots
with at least one continuously lit and capable of igniting all regulated
material that is routed to that stage of burners. Each 15-minute block
during which there is at least one minute where no pilot flame is
present on a stage of burners when regulated material is routed to the
flare is a deviation of the standard. Deviations in different 15-minute
blocks from the same event are considered separate deviations. The pilot
flame(s) on each stage of burners that use cross-lighting must be
continuously monitored by a thermocouple or any other equivalent device
used to detect the presence of a flame;
(5) Unless you choose to conduct a cross-light performance
demonstration as specified in this paragraph (i)(5), you must ensure
that if a stage of burners on the flare uses cross-lighting, that the
distance between any two burners in series on that stage is no more than
6 feet when measured from the center of one burner to the next burner. A
distance greater than 6 feet between any two burners in series may be
used provided you conduct a performance demonstration that confirms the
pressure-assisted multi-point flare will cross-light a minimum of three
burners and the spacing between the burners and location of the pilot
flame must be representative of the projected installation. The
compliance demonstration must be approved by the permitting authority
and a copy of this approval must be maintained onsite. The compliance
demonstration report must include: a protocol describing the test
methodology used, associated test method QA/QC parameters, the waste gas
composition and NHVcz of the gas tested, the velocity of the waste gas
tested, the pressure-assisted multi-point flare burner tip pressure, the
time, length, and duration of the test, records of whether a successful
cross-light was observed over all of the burners and the length of time
it took for the burners to cross-light, records of maintaining a stable
flame after a successful cross-light and the duration for which this was
observed, records of any smoking events during the cross-light, waste
gas temperature, meteorological conditions (e.g., ambient temperature,
barometric pressure, wind speed and direction, and relative humidity),
and whether there were any observed flare flameouts; and
(6) You must install and operate pressure monitor(s) on the main
flare header, as well as a valve position indicator monitoring system
for each staging valve to ensure that the flare operates within the
proper range of conditions as specified by the manufacturer. The
pressure monitor must meet the requirements in table 13 to part 63,
subpart CC of this chapter.
(7) If a pressure-assisted multi-point flare is operating under the
requirements of an approved alternative means of emission limitations,
you must either continue to comply with the terms of the alternative
means of emission limitations or comply with the provisions in
paragraphs (i)(1) through (6) of this section.
(j) If you choose to determine compositional analysis for net
heating value with a continuous process mass spectrometer, then you must
comply with the requirements specified in paragraphs (j)(1) through (7)
of this section.
(1) You must meet the requirements in Sec. 63.671(e)(2) of this
chapter. You may augment the minimum list of calibration gas components
found in Sec. 63.671(e)(2) with compounds found during a pre-survey or
known to be in the gas through process knowledge.
(2) Calibration gas cylinders must be certified to an accuracy of 2
percent and traceable to National Institute of
[[Page 177]]
Standards and Technology (NIST) standards.
(3) For unknown gas components that have similar analytical mass
fragments to calibration compounds, you may report the unknowns as an
increase in the overlapped calibration gas compound. For unknown
compounds that produce mass fragments that do not overlap calibration
compounds, you may use the response factor for the nearest molecular
weight hydrocarbon in the calibration mix to quantify the unknown
component's NHVvg.
(4) You may use the response factor for n-pentane to quantify any
unknown components detected with a higher molecular weight than n-
pentane.
(5) You must perform an initial calibration to identify mass
fragment overlap and response factors for the target compounds.
(6) You must meet applicable requirements in Performance
Specification 9 of appendix B of this part, for continuous monitoring
system acceptance including, but not limited to, performing an initial
multi-point calibration check at three concentrations following the
procedure in section 10.1 and performing the periodic calibration
requirements listed for gas chromatographs in table 13 to part 63,
subpart CC of this chapter, for the process mass spectrometer. You may
use the alternative sampling line temperature allowed under Net Heating
Value by Gas Chromatograph in table 13 to part 63, subpart CC.
(7) The average instrument calibration error (CE) for each
calibration compound at any calibration concentration must not differ by
more than 10 percent from the certified cylinder gas value. The CE for
each component in the calibration blend must be calculated using
equation 1 to this paragraph (j)(7).
Equation 1 to Paragraph (j)(7)
[GRAPHIC] [TIFF OMITTED] TR16MY24.033
Where:
Cm = Average instrument response (ppm)
Ca = Certified cylinder gas value (ppm)
(k) If you use a gas chromatograph or mass spectrometer for
compositional analysis for net heating value, then you may choose to use
the CE of NHVmeasured versus the cylinder tag value NHV as
the measure of agreement for daily calibration and quarterly audits in
lieu of determining the compound-specific CE. The CE for NHV at any
calibration level must not differ by more than 10 percent from the
certified cylinder gas value. The CE must be calculated using equation 2
to this paragraph (k).
Equation 2 to Paragraph (k)
[GRAPHIC] [TIFF OMITTED] TR16MY24.034
Where:
NHVmeasured = Average instrument response (Btu/scf)
NHVa = Certified cylinder gas value (Btu/scf)
(l) Instead of complying with Sec. 63.670(q) of this chapter, you
must comply with the reporting requirements specified in paragraphs
(l)(1) and (2) of this section.
(1) The notification requirements specified in Sec. 60.615a(a).
[[Page 178]]
(2) The semiannual report specified in Sec. 60.615a(i)(4) must
include the items specified in paragraphs (l)(2)(i) through (vi) of this
section.
(i) Records as specified in paragraph (m)(1) of this section for
each 15-minute block during which there was at least one minute when
regulated material is routed to a flare and no pilot flame or flare
flame is present. Include the start and stop time and date of each 15-
minute block.
(ii) Visible emission records as specified in paragraph (m)(2)(iv)
of this section for each period of 2 consecutive hours during which
visible emissions exceeded a total of 5 minutes.
(iii) The periods specified in paragraph (m)(6) of this section.
Indicate the date and start and end times for each period, and the net
heating value operating parameter(s) determined following the methods in
Sec. 63.670(k) through (n) of part 63, subpart CC of this chapter as
applicable.
(iv) For flaring events meeting the criteria in Sec. 63.670(o)(3)
of this chapter and paragraph (f) of this section:
(A) The start and stop time and date of the flaring event.
(B) The length of time in minutes for which emissions were visible
from the flare during the event.
(C) For steam-assisted, air-assisted, and non-assisted flares, the
start date, start time, and duration in minutes for periods of time that
the flare tip velocity exceeds the maximum flare tip velocity determined
using the methods in Sec. 63.670(d)(2) of this chapter and the maximum
15-minute block average flare tip velocity in ft/sec recorded during the
event.
(D) Results of the root cause and corrective actions analysis
completed during the reporting period, including the corrective actions
implemented during the reporting period and, if applicable, the
implementation schedule for planned corrective actions to be implemented
subsequent to the reporting period.
(v) For pressure-assisted multi-point flares, the periods of time
when the pressure monitor(s) on the main flare header show the burners
operating outside the range of the manufacturer's specifications.
Indicate the date and start and end times for each period.
(vi) For pressure-assisted multi-point flares, the periods of time
when the staging valve position indicator monitoring system indicates a
stage should not be in operation and is or when a stage should be in
operation and is not. Indicate the date and start and end times for each
period.
(m) Instead of complying with Sec. 63.670(p) of this chapter, you
must keep the flare monitoring records specified in paragraphs (m)(1)
through (14) of this section.
(1) Retain records of the output of the monitoring device used to
detect the presence of a pilot flame or flare flame as required in Sec.
63.670(b) of this chapter and the presence of a pilot flame as required
in paragraph (i)(4) of this section for a minimum of 2 years. Retain
records of each 15-minute block during which there was at least one
minute that no pilot flame or flare flame is present when regulated
material is routed to a flare for a minimum of 5 years. For a pressure-
assisted multi-point flare that uses cross-lighting, retain records of
each 15-minute block during which there was at least one minute that no
pilot flame is present on each stage when regulated material is routed
to a flare for a minimum of 5 years. You may reduce the collected
minute-by-minute data to a 15-minute block basis with an indication of
whether there was at least one minute where no pilot flame or flare
flame was present.
(2) Retain records of daily visible emissions observations as
specified in paragraphs (m)(2)(i) through (iv) of this section, as
applicable, for a minimum of 3 years.
(i) To determine when visible emissions observations are required,
the record must identify all periods when regulated material is vented
to the flare.
(ii) If visible emissions observations are performed using Method 22
of appendix A-7 of this part, then the record must identify whether the
visible emissions observation was performed, the results of each
observation, total duration of observed visible emissions, and whether
it was a 5-minute or 2-hour observation. Record the date and start time
of each visible emissions observation.
[[Page 179]]
(iii) If a video surveillance camera is used pursuant to Sec.
63.670(h)(2) of this chapter, then the record must include all video
surveillance images recorded, with time and date stamps.
(iv) For each 2-hour period for which visible emissions are observed
for more than 5 minutes in 2 consecutive hours, then the record must
include the date and start and end time of the 2-hour period and an
estimate of the cumulative number of minutes in the 2 hour period for
which emissions were visible.
(3) The 15-minute block average cumulative flows for flare vent gas
and, if applicable, total steam, perimeter assist air, and premix assist
air specified to be monitored under Sec. 63.670(i) of this chapter,
along with the date and time interval for the 15-minute block. If
multiple monitoring locations are used to determine cumulative vent gas
flow, total steam, perimeter assist air, and premix assist air, then
retain records of the 15-minute block average flows for each monitoring
location for a minimum of 2 years and retain the 15-minute block average
cumulative flows that are used in subsequent calculations for a minimum
of 5 years. If pressure and temperature monitoring is used, then retain
records of the 15-minute block average temperature, pressure, and
molecular weight of the flare vent gas or assist gas stream for each
measurement location used to determine the 15-minute block average
cumulative flows for a minimum of 2 years, and retain the 15-minute
block average cumulative flows that are used in subsequent calculations
for a minimum of 5 years.
(4) The flare vent gas compositions specified to be monitored under
Sec. 63.670(j) of this chapter. Retain records of individual component
concentrations from each compositional analysis for a minimum of 2
years. If an NHVvg analyzer is used, retain records of the 15-minute
block average values for a minimum of 5 years.
(5) Each 15-minute block average operating parameter calculated
following the methods specified in Sec. 63.670(k) through (n) of this
chapter, as applicable.
(6) All periods during which operating values are outside of the
applicable operating limits specified in Sec. 63.670(d) through (f) of
this chapter and paragraph (i) of this section when regulated material
is being routed to the flare.
(7) All periods during which you do not perform flare monitoring
according to the procedures in Sec. 63.670(g) through (j) of this
chapter.
(8) For pressure-assisted multi-point flares, if a stage of burners
on the flare uses cross-lighting, then a record of any changes made to
the distance between burners.
(9) For pressure-assisted multi-point flares, all periods when the
pressure monitor(s) on the main flare header show burners are operating
outside the range of the manufacturer's specifications. Indicate the
date and time for each period, the pressure measurement, the stage(s)
and number of burners affected, and the range of manufacturer's
specifications.
(10) For pressure-assisted multi-point flares, all periods when the
staging valve position indicator monitoring system indicates a stage of
the pressure-assisted multi-point flare should not be in operation and
when a stage of the pressure-assisted multi-point flare should be in
operation and is not. Indicate the date and time for each period,
whether the stage was supposed to be open, but was closed or vice versa,
and the stage(s) and number of burners affected.
(11) Records of periods when there is flow of vent gas to the flare,
but when there is no flow of regulated material to the flare, including
the start and stop time and dates of periods of no regulated material
flow.
(12) Records when the flow of vent gas exceeds the smokeless
capacity of the flare, including start and stop time and dates of the
flaring event.
(13) Records of the root cause analysis and corrective action
analysis conducted as required in Sec. 63.670(o)(3) of this chapter and
paragraph (f) of this section, including an identification of the
affected flare, the date and duration of the event, a statement noting
whether the event resulted from the same root cause(s) identified in a
previous analysis and either a description
[[Page 180]]
of the recommended corrective action(s) or an explanation of why
corrective action is not necessary under Sec. 63.670(o)(5)(i) of this
chapter.
(14) For any corrective action analysis for which implementation of
corrective actions are required in Sec. 63.670(o)(5) of this chapter, a
description of the corrective action(s) completed within the first 45
days following the discharge and, for action(s) not already completed, a
schedule for implementation, including proposed commencement and
completion dates.
(n) You may elect to comply with the alternative means of emissions
limitation requirements specified in paragraph (r) of Sec. 63.670 of
this chapter in lieu of the requirements in Sec. 63.670(d) through (f)
of this chapter, as applicable. However, instead of complying with Sec.
63.670(r)(3)(iii) of this chapter, you must also submit the alternative
means of emissions limitation request to the following address: U.S.
Environmental Protection Agency, Office of Air Quality Planning and
Standards, Sector Policies and Programs Division, U.S. EPA Mailroom
(C404-02), Attention: SOCMI NSPS Sector Lead, 4930 Old Page Rd., Durham,
NC 27703.
(o) The referenced provisions specified in paragraphs (o)(1) through
(4) of this section do not apply when demonstrating compliance with this
section.
(1) Section 63.670(o)(4)(iv) of this chapter.
(2) The last sentence of Sec. 63.670(o)(6) of this chapter.
(3) The phrase ``that were not caused by a force majeure event'' in
Sec. 63.670(o)(7)(ii) of this chapter.
(4) The phrase ``that were not caused by a force majeure event'' in
Sec. 63.670(o)(7)(iv) of this chapter.
Sec. 60.620a What are my requirements for closed vent systems?
(a) Except as provided in paragraphs (f) and (g) of this section,
you must inspect each closed vent system according to the procedures and
schedule specified in paragraphs (a)(1) through (3) of this section.
(1) Conduct an initial inspection according to the procedures in
paragraph (b) of this section unless the closed vent system is operated
and maintained under negative pressure,
(2) Conduct annual inspections according to the procedures in
paragraph (b) of this section unless the closed vent system is operated
and maintained under negative pressure, and
(3) Conduct annual inspections for visible, audible, or olfactory
indications of leaks.
(b) You must inspect each closed vent system according to the
procedures specified in paragraphs (b)(1) through (6) of this section.
(1) Inspections must be conducted in accordance with Method 21 of
appendix A of this part.
(2)(i) Except as provided in paragraph (b)(2)(ii) of this section,
the detection instrument must meet the performance criteria of Method 21
of appendix A of this part, except the instrument response factor
criteria in section 3.1.2(a) of Method 21 must be for the average
composition of the process fluid not each individual volatile organic
compound in the stream. For process streams that contain nitrogen, air,
or other inerts which are not organic hazardous air pollutants or
volatile organic compounds, the average stream response factor must be
calculated on an inert-free basis.
(ii) If no instrument is available at the plant site that will meet
the performance criteria specified in paragraph (b)(2)(i) of this
section, the instrument readings may be adjusted by multiplying by the
average response factor of the process fluid, calculated on an inert-
free basis as described in paragraph (b)(2)(i) of this section.
(3) The detection instrument must be calibrated before use on each
day of its use by the procedures specified in Method 21 of appendix A of
this part.
(4) Calibration gases must be as follows:
(i) Zero air (less than 10 parts per million hydrocarbon in air);
and
(ii) Mixtures of methane in air at a concentration less than 2,000
parts per million. A calibration gas other than methane in air may be
used if the instrument does not respond to methane or if the instrument
does not meet the performance criteria specified in paragraph (b)(2)(i)
of this section. In such cases, the calibration gas may be a
[[Page 181]]
mixture of one or more of the compounds to be measured in air.
(5) You may elect to adjust or not adjust instrument readings for
background. If you elect to not adjust readings for background, all such
instrument readings must be compared directly to the applicable leak
definition to determine whether there is a leak.
(6) If you elect to adjust instrument readings for background, you
must determine the background concentration using Method 21 of appendix
A of this part. After monitoring each potential leak interface, subtract
the background reading from the maximum concentration indicated by the
instrument. The arithmetic difference between the maximum concentration
indicated by the instrument and the background level must be compared
with 500 parts per million for determining compliance.
(c) Leaks, as indicated by an instrument reading greater than 500
parts per million above background or by visual, audio, or olfactory
inspections, must be repaired as soon as practicable, except as provided
in paragraph (d) of this section.
(1) A first attempt at repair must be made no later than 5 calendar
days after the leak is detected.
(2) Repair must be completed no later than 15 calendar days after
the leak is detected.
(d) Delay of repair of a closed vent system for which leaks have
been detected is allowed if the repair is technically infeasible without
a shutdown, as defined in Sec. 60.2, or if you determine that emissions
resulting from immediate repair would be greater than the fugitive
emissions likely to result from delay of repair. Repair of such
equipment must be complete by the end of the next shutdown.
(e) For each closed vent system that contains bypass lines that
could divert a vent stream away from the control device and to the
atmosphere, you must comply with the provisions of either paragraph
(e)(1) or (2), except as specified in paragraph (e)(3) of this section.
(1) Install, calibrate, maintain, and operate a flow indicator that
determines whether vent stream flow is present at least once every 15
minutes. You must keep hourly records of whether the flow indicator was
operating and whether a diversion was detected at any time during the
hour, as well as records of the times and durations of all periods when
the vent stream is diverted to the atmosphere or the flow indicator is
not operating. The flow indicator must be installed at the entrance to
any bypass line; or
(2) 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 must be performed at least once every month to
ensure the valve is maintained in the closed position and the vent
stream is not diverted through the bypass line.
(3) Open-ended valves or lines that use a cap, blind flange, plug,
or second valve and follow the requirements specified in Sec. 60.482-
6(a)(2), (b), and (c) or follow requirements codified in another
regulation that are the same as Sec. 60.482-6(a)(2), (b), and (c) are
not subject to this paragraph (e).
(f) Any parts of the closed vent system that are designated, as
described in paragraph (h)(1) of this section, as unsafe to inspect are
exempt from the inspection requirements of paragraphs (a)(1) and (2) of
this section if:
(1) You determine that the equipment is unsafe to inspect because
inspecting personnel would be exposed to an imminent or potential danger
as a consequence of complying with paragraphs (a)(1) and (2) of this
section; and
(2) You have a written plan that requires inspection of the
equipment as frequently as practicable during safe-to-inspect times.
(g) Any parts of the closed vent system are designated, as described
in paragraph (h)(2) of this section, as difficult to inspect are exempt
from the inspection requirements of paragraphs (a)(1) and (2) of this
section if:
(1) You determine that the equipment cannot be inspected without
elevating the inspecting personnel more than 2 meters above a support
surface; and
(2) You have a written plan that requires inspection of the
equipment at least once every 5 years.
[[Page 182]]
(h) You must record the information specified in paragraphs (h)(1)
through (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 closed vent system that contains bypass lines that
could divert a vent stream away from the control device and to the
atmosphere, you must keep a record of the information specified in
either paragraph (h)(3)(i) or (ii) of this section in addition to the
information specified in paragraph (h)(3)(iii) of this section.
(i) Hourly records of whether the flow indicator specified under
paragraph (e)(1) of this section was operating and whether a diversion
was detected at any time during the hour, as well as records of the
times of all periods when the vent stream is diverted from the control
device or the flow indicator is not operating.
(ii) Where a seal mechanism is used to comply with paragraph (e)(2)
of this section, hourly records of flow are not required. In such cases,
you must record whether the monthly visual inspection of the seals or
closure mechanisms has been done, and you must record the occurrence of
all periods when the seal mechanism is broken, the bypass line valve
position has changed, or the key for a lock-and-key type configuration
has been checked out, and records of any car-seal that has broken.
(iii) For each flow event from a bypass line subject to the
requirements in paragraph (e) of this section, you must maintain records
sufficient to determine whether or not the detected flow included flow
requiring control. For each flow event from a bypass line requiring
control that is released either directly to the atmosphere or to a
control device not meeting the requirements in this subpart, you must
include an estimate of the volume of gas, the concentration of VOC in
the gas and the resulting emissions of VOC that bypassed the control
device using process knowledge and engineering estimates.
(4) For each inspection during which a leak is detected, a record of
the information specified in paragraphs (h)(4)(i) through (viii) of this
section.
(i) The instrument identification numbers; operator name or
initials; and identification of the equipment.
(ii) The date the leak was detected and the date of the first
attempt to repair the leak.
(iii) Maximum instrument reading measured by the method specified in
paragraph (c) of this section after the leak is successfully repaired or
determined to be nonrepairable.
(iv) ``Repair delayed'' and the reason for the delay if a leak is
not repaired within 15 calendar days after discovery of the leak.
(v) The name, initials, or other form of identification of the owner
or operator (or designee) whose decision it was that repair could not be
effected without a shutdown.
(vi) The expected date of successful repair of the leak if a leak is
not repaired within 15 calendar days.
(vii) Dates of shutdowns that occur while the equipment is
unrepaired.
(viii) The date of successful repair of the leak.
(5) For each inspection conducted in accordance with paragraph (b)
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.
(6) For each inspection conducted in accordance with paragraph
(a)(3) 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.
(i) The semiannual report specified in Sec. 60.615a(i)(5) must
include the items specified in paragraphs (i)(1) through (3) of this
section.
(1) Reports of the times of all periods recorded under paragraph
(h)(3)(i) of this section when the vent stream is diverted from the
control device through a bypass line. Include the start date,
[[Page 183]]
start time, and duration in hours of each period.
(2) Reports of all periods recorded under paragraph (h)(3)(ii) of
this section in which the seal mechanism is broken, the bypass line
valve position has changed, or the key to unlock the bypass line valve
was checked out. Include the start date, start time, and duration in
hours of each period.
(3) For bypass lines subject to the requirements in paragraph (e) of
this section, the semiannual reports must include the start date, start
time, duration in hours, estimate of the volume of gas in standard cubic
feet, the concentration of VOC in the gas in parts per million by volume
and the resulting mass emissions of VOC in pounds that bypass a control
device. For periods when the flow indicator is not operating, report the
start date, start time, and duration in hours.
Sec. Table 1 to Subpart IIIa of Part 60--Emission Limits and Standards
for Vent Streams
------------------------------------------------------------------------
For each. . . You must. . .
------------------------------------------------------------------------
1. Vent stream......................... 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 by venting
emissions through a closed
vent system to any combination
of non-flare control devices
and/or recovery system and
meet the requirements
specified in Sec. 60.613a
and Sec. 60.620a; or
b. Reduce emissions of TOC
(minus methane and ethane) by
venting emissions through a
closed vent system to a flare
and meet the requirements
specified in Sec. 60.619a
and Sec. 60.620a.
------------------------------------------------------------------------
Sec. Table 2 to Subpart IIIa of Part 60--Monitoring Requirements for
Complying With 98 Weight-Percent Reduction of Total Organic Compounds
Emissions or a Limit of 20 Parts Per Million by Volume
------------------------------------------------------------------------
Non-flare control device or recovery
device Parameters to be monitored
------------------------------------------------------------------------
1. All control and recovery devices.... a. Presence of flow diverted to
the atmosphere from the
control and recovery device;
or
b. Monthly inspections of
sealed valves.
2. Absorber............................ a. Exit temperature of the
absorbing liquid; and
b. Exit specific gravity.
3. Boiler or process heater with a Firebox temperature.\a\
design heat input capacity less than
44 megawatts and vent stream is not
introduced with or as the primary fuel.
4. Catalytic incinerator............... Temperature upstream and
downstream of the catalyst
bed.
5. Carbon adsorber, regenerative....... a. Total regeneration stream
mass or volumetric flow during
carbon bed regeneration
cycle(s); and
b. Temperature of the carbon
bed after regeneration [and
within 15 minutes of
completing any cooling
cycle(s)].
6. Carbon adsorber, non-regenerative or Breakthrough.
regenerated offsite.
7. Condenser........................... Exit (product side)
temperature.
8. Scrubber for halogenated vent a. pH of scrubber effluent; and
streams.
b. Scrubber liquid and gas flow
rates.
9. Thermal incinerator................. Firebox temperature.\a\
10. Control devices other than an As specified by the
incinerator, boiler, process heater, Administrator.
or flare; or recovery devices other
than an absorber, condenser, or carbon
adsorber.
------------------------------------------------------------------------
\a\ Monitor may be installed in the firebox or in the ductwork
immediately downstream of the firebox before any substantial heat
exchange is encountered.
[[Page 184]]
Sec. Table 3 to Subpart IIIa of Part 60--Operating Parameters, Operating
Parameter Limits and Data Monitoring, Recordkeeping and Compliance
Frequencies
----------------------------------------------------------------------------------------------------------------
You must establish And you must monitor, record, and demonstrate continuous
the following compliance using these minimum frequencies. . .
For the operating parameter operating -----------------------------------------------------------
applicable to you, as specified parameter limit. . Data averaging
in Table 2. . . . Data measurement Data recording period for
compliance
----------------------------------------------------------------------------------------------------------------
Absorbers
----------------------------------------------------------------------------------------------------------------
1. Exit temperature of the Maximum Continuous........ Every 15 minutes.. 3-hour block
absorbing liquid. temperature. average.
2. Exit specific gravity........ Exit specific Continuous........ Every 15 minutes.. 3-hour block
gravity range. average.
----------------------------------------------------------------------------------------------------------------
Boilers or process heaters
(with a design heat input capacity <44MW and vent stream is not introduced with or as the primary fuel)
----------------------------------------------------------------------------------------------------------------
3. Firebox temperature.......... Minimum firebox Continuous........ Every 15 minutes.. 3-hour block
temperature. average.
----------------------------------------------------------------------------------------------------------------
Catalytic incinerators
----------------------------------------------------------------------------------------------------------------
4. Temperature in gas stream Minimum Continuous........ Every 15 minutes.. 3-hour block
immediately before the catalyst temperature. average.
bed.
5. Temperature difference Minimum Continuous........ Every 15 minutes.. 3-hour block
between the catalyst bed inlet temperature average.
and the catalyst bed outlet. difference.
----------------------------------------------------------------------------------------------------------------
Carbon adsorbers
----------------------------------------------------------------------------------------------------------------
6. Total regeneration stream Minimum mass flow Continuously Every 15 minutes Total flow for
mass flow during carbon bed during carbon bed during during each regeneration
regeneration cycle(s). regeneration regeneration. regeneration cycle.
cycle(s). cycle.
7. Total regeneration stream Minimum volumetric Continuously Every 15 minutes Total flow for
volumetric flow during carbon flow during during during each regeneration
bed regeneration cycle(s). carbon bed regeneration. regeneration cycle.
regeneration cycle.
cycle(s).
8. Temperature of the carbon bed Maximum Continuously Every 15 minutes Average of
after regeneration [and within temperature of during during regeneration
15 minutes of completing any the carbon bed regeneration and regeneration cycle.
cooling cycle(s)]. after for 15 minutes cycle (including
regeneration. after completing any cooling
any cooling cycle).
cycle(s).
9. Breakthrough................. As defined in Sec. As required by Each monitoring N/A
60.611a. Sec. event.
60.613a(a)(6)(iii
)(B).
----------------------------------------------------------------------------------------------------------------
[[Page 185]]
Condensers
----------------------------------------------------------------------------------------------------------------
10. Exit (product side) Maximum Continuous........ Every 15 minutes.. 3-hour block
temperature. temperature. average.
----------------------------------------------------------------------------------------------------------------
Scrubbers for halogenated vent streams
----------------------------------------------------------------------------------------------------------------
11. pH of scrubber effluent..... Minimum pH........ Continuous........ Every 15 minutes.. 3-hour block
average.
12. Influent liquid flow........ Minimum inlet Continuous........ Every 15 minutes.. 3-hour block
liquid flow. average.
13. Influent liquid flow rate Minimum influent Continuous........ Every 15 minutes.. 3-hour block
and gas stream flow rate. liquid-to-gas average.
ratio.
----------------------------------------------------------------------------------------------------------------
Thermal incinerators
----------------------------------------------------------------------------------------------------------------
14. Firebox temperature......... Minimum firebox Continuous........ Every 15 minutes.. 3-hour block
temperature. average.
----------------------------------------------------------------------------------------------------------------
Control devices other than an incinerator, boiler, process heater, or flare; or recovery devices other than an
absorber, condenser, or carbon adsorber
----------------------------------------------------------------------------------------------------------------
15. As specified by the As specified by As specified by As specified by As specified by
Administrator. the Administrator. the Administrator. the Administrator. the
Administrator.
----------------------------------------------------------------------------------------------------------------
Sec. Table 4 to Subpart IIIa of Part 60--Calibration and Quality Control
Requirements for Continuous Parameter Monitoring System (CPMS)
------------------------------------------------------------------------
And your
If you monitor this parameter. . Your accuracy calibration
. requirements are. requirements are.
. . . .
------------------------------------------------------------------------
1. Temperature................... a. 1 percent evaluation
over the normal annually and
range of following any
temperature period of more
measured or 2.8 than 24 hours
degrees Celsius throughout which
(5 degrees the temperature
Fahrenheit), exceeded the
whichever is maximum rated
greater, for non- temperature of
cryogenic the sensor, or
temperature the data
ranges. recorder was off
b. 2.5 d. Visual
percent over the inspections and
normal range of checks of CPMS
temperature operation every
measured or 2.8 3 months, unless
degrees Celsius the CPMS has a
(5 degrees redundant
Fahrenheit), temperature
whichever is sensor.
greater, for e. Selection of a
cryogenic representative
temperature measurement
ranges. location.
[[Page 186]]
2. Flow Rate..................... a. 5 percent evaluation
over the normal annually and
range of flow following any
measured or 1.9 period of more
liters per minute than 24 hours
(0.5 gallons per throughout which
minute), the flow rate
whichever is exceeded the
greater, for maximum rated
liquid flow rate. flow rate of the
b. 5 percent data recorder
over the normal was off scale.
range of flow e. Checks of all
measured or 280 mechanical
liters per minute connections for
(10 cubic feet leakage monthly.
per minute), f. Visual
whichever is inspections and
greater, for gas checks of CPMS
flow rate. operation every
c. 5 percent the CPMS has a
over the normal redundant flow
range measured sensor.
for mass flow g. Selection of a
rate. representative
measurement
location where
swirling flow or
abnormal
velocity
distributions
due to upstream
and downstream
disturbances at
the point of
measurement are
minimized.
3. pH............................ a. 0.2 pH evaluation
units. annually.
Conduct a two-
point
calibration with
one of the two
buffer solutions
having a pH
within 1 of the
pH of the
operating limit.
c. Visual
inspections and
checks of CPMS
operation every
3 months, unless
the CPMS has a
redundant pH
sensor.
d. Select a
measurement
location that
provides a
representative
sample of
scrubber
effluent and
that ensures the
fluid is
properly mixed.
4. Specific Gravity.............. a. 0.02 evaluation
specific gravity annually.
units. c. Visual
inspections and
checks of CPMS
operation every
3 months, unless
the CPMS has a
redundant
specific gravity
sensor.
d. Select a
measurement
location that
provides a
representative
sample of
specific gravity
of the absorbing
liquid effluent
and that ensures
the fluid is
properly mixed.
------------------------------------------------------------------------
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 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
[[Page 187]]
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 17,791 liters
(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;
65 FR 61773, Oct. 17, 2000]
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 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
[[Page 188]]
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, 1200 Pennsylvania Ave., NW.,
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 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.
[49 FR 37331, Sept. 21, 1984, as amended at 65 FR 61773, Oct. 17, 2000]
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 for Which Construction,
Reconstruction, or Modification Commenced After January 20, 1984, and on
or Before August 23, 2011
Source: 50 FR 26124, June 24, 1985, unless otherwise noted.
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,
[[Page 189]]
and on or before August 23, 2011, 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.
(f) An affected facility must continue to comply with the
requirements of this subpart until it begins complying with a more
stringent requirement, that applies to the same affected facility, in an
approved, and effective, State or Federal plan that implements subpart
OOOOc of this part, or modifies or reconstructs after December 6, 2022,
and thus becomes subject to subpart OOOOb of this part.
[50 FR 26124, June 24, 1985, as amended at 77 FR 49542, Aug. 16, 2012;
89 FR 17034, Mar. 8, 2024]
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 Sec. Sec. 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 Sec. Sec. 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 190]]
(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 Sec. Sec. 60.486 and 60.487 except
as provided in Sec. Sec. 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 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 E169-63, 77, or 93, E168-67, 77, or 92,
or E260-73, 91, or 96 (incorporated by reference as specified in Sec.
60.17) shall be used.
[50 FR 26124, June 24, 1985, as amended at 65 FR 61773, Oct. 17, 2000]
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. Sec. 60.632(c), paragraph (b)(4) of this section, and
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. 60.482-4(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 283,200 standard cubic meters per day (scmd) (10
million standard cubic feet per day) or more of field gas are exempt
from the routine monitoring requirements of Sec. Sec. 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 Sec. Sec. 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 (302 [deg]F) as
determined by ASTM Method D86-78,
[[Page 191]]
82, 90, 95, or 96 (incorporated by reference as specified in Sec.
60.17).
(2) Equipment is in light liquid service if the weight percent
evaporated is greater than 10 percent at 150 [deg]C (302 [deg]F) as
determined by ASTM Method D86-78, 82, 90, 95, or 96 (incorporated by
reference as specified in Sec. 60.17).
[50 FR 26124, June 24, 1985, as amended at 51 FR 2702, Jan. 21, 1986; 65
FR 61773, Oct. 17, 2000]
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.
[[Page 192]]
(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 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 SO2 Emissions From Onshore
Natural Gas Processing for Which Construction, Reconstruction, or
Modification Commenced After January 20, 1984, and on or Before August
23, 2011
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 Sec. Sec. 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, and on or before August 23,
2011.
(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.
[50 FR 40160, Oct. 1, 1985, as amended at 77 FR 49542, Aug. 16, 2012]
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
[[Page 193]]
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 (lb/dscf)).
EThe sulfur emission rate expressed as elemental sulfur, kilograms per
hour (kg/hr) [pounds per hour (lb/hr)], rounded to one decimal
place.
RThe sulfur emission reduction efficiency achieved in percent, carried
to one decimal place.
SThe sulfur production rate, kilograms per hour (kg/hr) [pounds per hour
(lb/hr)], rounded to one decimal place.
XThe sulfur feed rate from the sweetening unit (i.e., the H2S
in the acid gas), expressed as sulfur, Mg/D(LT/D), rounded to
one decimal place.
YThe sulfur content of the acid gas from the sweetening unit, expressed
as mole percent H2S (dry basis) rounded to one
decimal place.
ZThe 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.
[50 FR 40160, Oct. 1, 1985, as amended at 65 FR 61773, Oct. 17, 2000]
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 194]]
[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 195]]
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:
[GRAPHIC] [TIFF OMITTED] TR17OC00.030
Where:
X = average sulfur feed rate, Mg/D (LT/D).
Qa = average volumetric flow rate of acid gas from sweetening
unit, dscm/day (dscf/day).
Y = average H2S concentration in acid gas feed from
sweetening unit, percent by volume, expressed as a decimal.
K = (32 kg S/kg-mole)/((24.04 dscm/kg-mole)(1000 kg S/ Mg)) = 1.331 x
10-3 Mg/dscm, for metric units
= (32 lb S/lb-mole)/((385.36 dscf/lb-mole)(2240 lb S/long ton))
= 3.707 x 10-5 long ton/dscf, for English units.
(2) The continuous readings from the process flowmeter shall be used
to determine the average volumetric flow rate (Qa) in dscm/
day (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 (lb/
hr) for each run.
(3) The emission rate of sulfur shall be computed for each run as
follows:
[GRAPHIC] [TIFF OMITTED] TR17OC00.031
Where:
E = emission rate of sulfur per run, kg/hr.
Ce = concentration of sulfur equivalent (SO2 +
reduced sulfur), g/dscm (lb/dscf).
Qsd = volumetric flow rate of effluent gas, dscm/hr (dscf/
hr).
K1 = conversion factor, 1000 g/kg (7000 gr/lb).
(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
[[Page 196]]
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 m\2\ (54 ft\2\) or at a point no closer to
the walls than 1 m (39 in.) if the cross-sectional area is 5 m\2\ or
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 shall be the concentration for
the run. The concentration shall be multiplied by 0.5 x 10-3
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 ft\3\/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 reduced sulfur as sulfur shall be
multiplied by 1.333 x 10-3 to convert the results to sulfur
equivalent.
(iii) Method 16A or 15 shall be used to determine the reduced sulfur
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
reduced sulfur as sulfur shall be multiplied by 1.333 x 10-3
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 (3.5 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) or (c) of this section.
[54 FR 6679, Feb. 14, 1989, as amended at 65 FR 61773, Oct. 17, 2000]
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
[[Page 197]]
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 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 (lb/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
[[Page 198]]
rate shall be expressed in terms of equivalent sulfur mass flow rates
(kg/hr (lb/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 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 152 Mg/D (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] TR17OC00.032
Where:
R = The sulfur dioxide removal efficiency achieved during the 24-hour
period, percent.
K2 = Conversion factor, 0.02400 Mg/D per kg/hr (0.01071 LT/D
per lb/hr).
S = The sulfur production rate during the 24-hour period, kg/hr (lb/hr).
X = The sulfur feed rate in the acid gas, Mg/D (LT/D).
(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; 65
FR 61774, Oct. 17, 2000]
Sec. 60.647 Recordkeeping and reporting requirements.
(a) Records of the calculations and measurements required in
Sec. Sec. 60.642 (a) and (b) and 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
[[Page 199]]
these standards, each owner or operator of a facility with a design
capacity less that 2 LT/D of H2S in the acid gas (expressed
as sulfur) shall keep, for the life of the facility, an analysis
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)
[[Page 200]]
(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 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 After December 30, 1983, and on or Before April
25, 2023
Source: 55 FR 26942, June 29, 1990, unless otherwise noted.
Effective Date Note: At 89 FR 43105, May 16, 2024, the heading of
subpart NNN was revised, effective July 15, 2024.
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 Sec. Sec. 60.662; 60.664 (e), (f), and (g); 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
[[Page 201]]
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.
(d) Alternative means of compliance--(1) Option to comply with part
65. Owners or operators of process vents that are subject to this
subpart may choose to comply with the provisions of 40 CFR part 65,
subpart D, to satisfy the requirements of Sec. Sec. 60.662 through
60.665 and 60.668. The provisions of 40 CFR part 65 also satisfy the
criteria of paragraphs (c)(4) and (6) of this section. Other provisions
applying to an owner or operator who chooses to comply with 40 CFR part
65 are provided in 40 CFR 65.1.
(2) Part 60, subpart A. Owners or operators who choose to comply
with 40 CFR part 65, subpart D, must also comply with Sec. Sec. 60.1,
60.2, 60.5, 60.6, 60.7(a)(1) and (4), 60.14, 60.15, and 60.16 for those
process vents. All sections and paragraphs of subpart A of this part
that are not mentioned in this paragraph (d)(2) do not apply to owners
or operators of process vents complying with 40 CFR part 65, subpart D,
except that provisions required to be met prior to implementing 40 CFR
part 65 still apply. Owners and operators who choose to comply with 40
CFR part 65, subpart D, must comply with 40 CFR part 65, subpart A.
(3) Compliance date. Owners or operators who choose to comply with
40 CFR part 65, subpart D, at initial startup shall comply with
paragraphs (d)(1) and (2) of this section for each vent stream on and
after the date on which the initial performance test 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.
(4) Initial startup notification. Each owner or operator subject to
the provisions of this subpart that chooses to comply with 40 CFR part
65, subpart D, at initial startup shall notify the Administrator of the
specific provisions of 40 CFR 65.63(a)(1), (2), or (3), with which the
owner or operator has elected to comply. Notification shall be submitted
with the notifications of initial startup required by 40 CFR 65.5(b).
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 TOC less methane and ethane.
This emission limit reflects the performance of BDT.
[55 FR 26942, June 29, 1990, as amended at 65 FR 78279, Dec. 14, 2000;
79 FR 11251, Feb. 27, 2014]
Effective Date Note: At 89 FR 43105, May 16, 2024, Sec. 60.660 was
amended by revising paragraphs (b) introductory text and (c)(6) and
adding paragraph (e), effective July 15, 2024. For the convenience of
the user, the added and revised text is set forth as follows:
Sec. 60.660 Applicability and designation of affected facility.
* * * * *
(b) The affected facility is any of the following for which
construction, modification, or reconstruction commenced after December
30, 1983, and on or before April 25, 2023:
* * * * *
(c) * * *
(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. Sec. 60.664(h) and 60.665(i), (l)(5),
and (o).
* * * * *
(e) Owners and operators of flares that are subject to the flare
related requirements of this subpart and flare related requirements of
any other regulation in this part or 40 CFR part 61 or 63, may elect to
comply with the requirements in Sec. 60.669a in lieu of all flare
related requirements in any other regulation in this part or 40 CFR part
61 or 63.
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
[[Page 202]]
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 (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.
Effective Date Note: At 89 FR 43105, May 16, 2024, Sec. 60.661 was
amended by revising the definition of ``Flame zone,'' effective July 15,
2024. For the convenience of the user, the revised text is set forth as
follows:
[[Page 203]]
Sec. 60.661 Definitions.
* * * * *
Flame zone means the portion of the combustion chamber in a boiler
or process heater occupied by the flame envelope.
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. Sec. 60.8 and 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 an 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 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 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.
[[Page 204]]
(d) 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.
(e) 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.
(f) 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
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.
[55 FR 26942, June 29, 1990, as amended at 65 FR 61774, Oct. 17, 2000]
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.
(3) The emission rate correction factor, integrated sampling and
analysis
[[Page 205]]
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/hr (lb/
hr).
Eo = Mass rate of TOC discharged to the atmosphere, kg/hr
(lb/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/
min).
K2 = 2.494 x 10-6 (1/ppm)(g-mole/scm) (kg/g) (min/
hr) (metric units), where standard temperature for (g-mole/
scm) is 20 [deg]C.
= 1.557 x 10-7 (1/ppm) (lb-mole/scf) (min/hr) (English
units), where standard temperature for (lb-mole/scf) is 68 [deg]F.
(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.
(c) 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.
(d) 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.
(e) 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 206]]
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(e)(2) and (3) shall
be, except for the situations outlined in paragraph (e)(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 10 centimeters (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(e)(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 or 90 (Reapproved 1994) (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 (Btu/scf), where
the net enthalpy per mole of vent stream is based on
combustion at 25 [deg]C and 760 mm Hg (77 [deg]F and 30 in.
Hg), but the standard temperature for determining the volume
corresponding to one mole is 20 [deg]C (68 [deg]F).
K1 = 1.74 x 10-7 (1/ppm) (g-mole/scm) (MJ/kcal)
(metric units), where standard temperature for (g-mole/scm) is
20 [deg]C.
= 1.03 x 10-11 (1/ppm) (lb-mole/scf) (Btu/kcal) (English
units) where standard temperature for (lb/mole/scf) is 68 [deg]F.
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 or 90 (Reapproved 1994)
(incorporation by reference as specified in Sec. 60.17 of
this part) as indicated in Sec. 60.664(e)(2).
Hj = Net heat of combustion of compound j, kcal/(g-mole)
[kcal/(lb-mole)], based on combustion at 25 [deg]C and 760 mm
Hg (77 [deg]F and 30 in. 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 = Measured emission rate of TOC, kg/hr (lb/hr).
K2 = 2.494 x 10-6 (1/ppm) (g-mole/scm) (kg/g)
(min/hr) (metric units), where standard temperature for (g-
mole/scm) is 20 [deg]C.
= 1.557 x 10-7 (1/ppm) (lb-mole/scf) (min/hr) (English
units), where standard temperature for (lb-mole/scf) is 68
[deg]F.
[[Page 207]]
Cj = Concentration on a wet basis of compound j in ppm, as
measured by Method 18 as indicated in Sec. 60.664(e)(2).
Mj = Molecular weight of sample j, g/g-mole (lb/lb-mole).
Qs = Vent stream flow rate, scm/min (scf/min), at a
temperature of 20 [deg]C (68 [deg]F).
(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.
(f) 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 that is greater than or equal
to 14.2 scm/min (501 scf/min) at a standard temperature of 20 [deg]C (68
[deg]F):
TRE = TRE index value.
Qs = Vent stream flow rate, scm/min (scf/min), at a
temperature of 20 [deg]C (68 [deg]F).
HT = Vent stream net heating value, MJ/scm (Btu/scf), where
the net enthalpy per mole of vent stream is based on
combustion at 25 [deg]C and 760 mm Hg (68 [deg]F and 30 in.
Hg), but the standard temperature for determining the volume
corresponding to one mole is 20 [deg]C (68 [deg]F) 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
= QsHT/3.6.
ETOC = Hourly emissions of TOC, kg/hr (lb/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 208]]
[GRAPHIC] [TIFF OMITTED] TR17OC00.033
[GRAPHIC] [TIFF OMITTED] TR17OC00.034
[[Page 209]]
[GRAPHIC] [TIFF OMITTED] TR17OC00.035
[GRAPHIC] [TIFF OMITTED] TR17OC00.036
(ii) Where for a vent stream flow rate that is less than 14.2 scm/
min (501 scf/min) at a standard temperature of 20 [deg]C (68 [deg]F):
TRE = TRE index value.
Qs = 14.2 scm/min (501 scf/min).
HT = (FLOW) (HVAL)/Qs.
Where the following inputs are used:
FLOW = Vent stream flow rate, scm/min (scf/min), at a temperature of 20
[deg]C (68 [deg]F).
HVAL = Vent stream net heating value, MJ/scm (Btu/scf), where the net
enthalpy per mole of vent stream is based on combustion at 25
[deg]C and 760 mm Hg (68 [deg]F and 30 in. Hg), but the
standard temperature for determining the volume corresponding
to one mole is 20 [deg]C (68 [deg]F) 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
= QsHT/3.6.
ETOC = Hourly emissions of TOC, kg/hr (lb/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 210]]
(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 emissions of TOC, kg/hr (lb/hr).
Qs = Vent stream flow rate, scm/min (scf/min), at a standard
temperature of 20 [deg]C (68 [deg]F).
HT = Vent stream net heating value, MJ/scm (Btu/scf), where
the net enthalpy per mole of vent stream is based on
combustion at 25 [deg]C and 760 mm Hg (68 [deg]F and 30 in.
Hg), but the standard temperature for determining the volume
corresponding to one mole is 20 [deg]C (68 [deg]F) 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 < 301 Btu/scf).............. (0.140) (0.0367) (-0.000448) (-0.0051) (4.59)
HT >= 11.2 MJ/scm............... 0.309 0.0619 -0.0043 -0.0034 2.08
(HT >= 301 Btu/scf)............. (0.0193) (0.00788) (-0.0000010) (-0.0034) (4.59)
----------------------------------------------------------------------------------------------------------------
(g) 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 Sec. Sec. 60.8 and 60.664 and shall comply with
Sec. Sec. 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.
(h) 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.
[55 FR 26942, June 29, 1990, as amended at 65 FR 61774, Oct. 17, 2000]
Effective Date Note: At 89 FR 43105, May 16, 2024, Sec. 60.664 was
amended by revising paragraphs (b)(4) introductory text and (e),
effective July 15, 2024. For the convenience of the user, the revised
text is set forth as follows:
Sec. 60.664 Test methods and procedures.
* * * * *
(b) * * *
[[Page 211]]
(4) Method 18 of appendix A-6 to this part 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. ASTM D6420-18 (incorporated by reference, see Sec.
[thinsp]60.17) may be used in lieu of Method 18, if the target compounds
are all known and are all listed in Section 1.1 of ASTM D6420-18 as
measurable; ASTM D6420-18 may not be used for methane and ethane; and
ASTM D6420-18 may not be used as a total VOC method.
* * * * *
(e) The following test methods, 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. 60.662(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 of appendix A-1 to this part, as appropriate,
for selection of the sampling site. The sampling site for the vent
stream flow rate and molar composition determination prescribed in
paragraphs (e)(2) and (3) of this section shall be, except for the
situations outlined in paragraph (e)(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 10 centimeters (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 of appendix A-6 to this
part, or ASTM D6420-18 (incorporated by reference, see Sec.
[thinsp]60.17) as specified in paragraph (b)(4) of this section, 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(e)(4) and (5).
(2) The molar composition of the process vent stream shall be
determined as follows:
(i) Method 18 of appendix A-6 to this part, or ASTM D6420-18
(incorporated by reference, see Sec. [thinsp]60.17) as specified in
paragraph (b)(4) of this section, to measure the concentration of TOC
including those containing halogens.
(ii) ASTM D1946-77 or 90 (Reapproved 1994) (incorporation by
reference as specified in Sec. 60.17 of this part) to measure the
concentration of carbon monoxide and hydrogen.
(iii) Method 4 of appendix A-3 to this part to measure the content
of water vapor.
(3) The volumetric flow rate shall be determined using Method 2, 2A,
2C, or 2D of appendix A-1 to this part, as appropriate.
(4)(i) The net heating value of the vent stream shall be calculated
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR16MY24.035
Where:
HT = Net heating value of the sample, MJ/scm (Btu/scf), where
the net enthalpy per mole of vent stream is based on
combustion at 25 [deg]C and 760 mm Hg (77 [deg]F and 30 in.
Hg), but the standard temperature for determining the volume
corresponding to one mole is 20 [deg]C (68 [deg]F).
K1 = 1.74 x 10-7 (1/ppm) (g-mole/scm) (MJ/kcal)
(metric units), where standard temperature for (g-mole/scm) is
20 [deg]C.
= 1.03 x 10-11 (1/ppm) (lb-mole/scf) (Btu/kcal) (English
units) where standard temperature for (lb/mole/scf) is 68
[deg]F.
[[Page 212]]
Cj = Concentration on a wet basis of compound j in ppm, as
measured for organics by Method 18 of appendix A-6 to this
part, or ASTM D6420-18 (incorporated by reference, see Sec.
[thinsp]60.17) as specified in paragraph (b)(4) of this
section, and measured for hydrogen and carbon monoxide by ASTM
D1946-77 or 90 (Reapproved 1994) (incorporated by reference,
see Sec. 60.17) as indicated in paragraph (e)(2) of this
section.
Hj = Net heat of combustion of compound j, kcal/(g-mole)
[kcal/(lb-mole)], based on combustion at 25 [deg]C and 760 mm
Hg (77 [deg]F and 30 in. Hg).
(ii) The heats of combustion of vent stream components would be
required to 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.
(5) The emission rate of TOC in the vent stream shall be calculated
using the following equation:
[GRAPHIC] [TIFF OMITTED] TR16MY24.036
Where:
ETOC = Measured emission rate of TOC, kg/hr (lb/hr).
K2 = 2.494 x 10-6 (1/ppm) (g-mole/scm) (kg/g)
(min/hr) (metric units), where standard temperature for (g-
mole/scm) is 20 [deg]C.
= 1.557 x 10-7 (1/ppm) (lb-mole/scf) (min/hr) (English
units), where standard temperature for (lb-mole/scf) is 68
[deg]F.
Cj = Concentration on a wet basis of compound j in ppm, as
measured by Method 18 of appendix A-6 to this part, or ASTM
D6420-18 (incorporated by reference, see Sec. [thinsp]60.17)
as specified in paragraph (b)(4) of this section, as indicated
in paragraph (e)(2) of this section.
Mj = Molecular weight of sample j, g/g-mole (lb/lb-mole).
Qs = Vent stream flow rate, scm/min (scf/min), at a
temperature of 20 [deg]C (68 [deg]F).
(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 of appendix A-6 to this part, or ASTM D6420-
18 (incorporated by reference, see Sec. [thinsp]60.17) as specified in
paragraph (b)(4) of this section.
* * * * *
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:
[[Page 213]]
(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 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. 60.665(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
[[Page 214]]
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 (150 million Btu/hour) 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 keep up-to-date, readily accessible continuous records of the
equipment operating parameters specified to be monitored under Sec.
60.663(e), 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)
[[Page 215]]
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(g); and
(3) The results of any performance test performed pursuant to the
methods and procedures required by Sec. 60.664(e).
(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 scm/min (0.3 scf/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) 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
[[Page 216]]
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
paragraph (j) of this section, 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 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 to the requirements of Sec. 60.8. The facility must begin
compliance with the requirements set forth in Sec. 60.660(d) or Sec.
60.662. If the facility chooses to comply with Sec. 60.662, the
facility may qualify for an exemption in Sec. 60.660(c)(4) or (6).
(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 capacity 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 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; 65 FR 61778, Oct. 17, 2000; 65 FR 78279,
Dec. 14, 2000; 79 FR 11251, Feb. 27, 2014]
Effective Date Note: At 89 FR 43106, May 16, 2024, Sec. 60.665 was
amended by revising paragraphs (b) introductory text, (l) introductory
text, (l)(5) and (6), and (m) and adding paragraphs (q), (r), and (s),
effective July 15, 2024. For the convenience of the user, the added and
revised text is set forth as follows:
Sec. 60.665 Reporting and recordkeeping requirements.
* * * * *
(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. Beginning on July 15,
2024, owners and operators must submit the performance test report
following the procedures specified in paragraph (q) of this section.
Data collected using test methods that are supported by the EPA's
Electronic Reporting Tool (ERT) as listed on the EPA's ERT website
(https://www.epa.gov/electronic-reporting-air-emissions/electronic-
reporting-tool-ert) at the time of the test must be submitted in a file
format generated using the EPA's ERT. Alternatively, the owner or
operator may submit an electronic file consistent with the extensible
markup language (XML) schema listed on the EPA's ERT website. Data
collected using test methods that are not supported by the EPA's ERT as
listed on the EPA's ERT website at the time
[[Page 217]]
of the test must be included as an attachment in the ERT or an alternate
electronic file.
* * * * *
(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. On and after July 15, 2025 or once the report template
for this subpart has been available on the Compliance and Emissions Data
Reporting Interface (CEDRI) website (https://www.epa.gov/electronic-
reporting-air-emissions/cedri) for 1 year, whichever date is later,
owners and operators must submit all subsequent reports using the
appropriate electronic report template on the CEDRI website for this
subpart and following the procedure specified in paragraph (q) of this
section. The date report templates become available will be listed on
the CEDRI website. Unless the Administrator or delegated state agency or
other authority has approved a different schedule for submission of
reports, the report must be submitted by the deadline specified in this
subpart, regardless of the method in which the report is submitted.
* * * * *
(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, and the performance test must be reported
according to paragraph (b) of this section. 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
paragraph (j) of this section, 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 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 to the requirements of Sec. 60.8, and the performance test must
be reported according to paragraph (b) of this section. The facility
must begin compliance with the requirements set forth in Sec. 60.660(d)
or Sec. 60.662. If the facility chooses to comply with Sec. 60.662,
the facility may qualify for an exemption in Sec. 60.660(c)(4) or (6).
* * * * *
(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. The EPA will not approve a waiver
of electronic reporting to the EPA in delegating enforcement authority.
Thus, electronic reporting to the EPA cannot be waived, and as such, the
provisions of this paragraph cannot be used to relieve owners or
operators of affected facilities of the requirement to submit the
electronic reports required in this section to the EPA.
* * * * *
(q) If an owner or operator is required to submit notifications or
reports following the procedure specified in this paragraph (q), the
owner or operator must submit notifications or reports to the EPA via
CEDRI, which can be accessed through the EPA's Central Data Exchange
(CDX) (https://cdx.epa.gov/). The EPA will make all the information
submitted through CEDRI available to the public without further notice
to the owner or operator. Do not use CEDRI to submit information the
owner or operator claims as CBI. Although the EPA does not expect
persons to assert a claim of CBI, if an owner or operator wishes to
assert a CBI claim for some of the information in the report or
notification, the owner or operator must submit a complete file in the
format specified in this subpart, including information claimed to be
CBI, to the EPA following the procedures in paragraphs (q)(1) and (2) of
this section. Clearly mark the part or all of the information that
claimed to be CBI. Information not marked as CBI may be authorized for
public release without prior notice. Information marked as
[[Page 218]]
CBI will not be disclosed except in accordance with procedures set forth
in 40 CFR part 2. All CBI claims must be asserted at the time of
submission. Anything submitted using CEDRI cannot later be claimed CBI.
Furthermore, under CAA section 114(c), emissions data is not entitled to
confidential treatment, and the EPA is required to make emissions data
available to the public. Thus, emissions data will not be protected as
CBI and will be made publicly available. The owner or operator must
submit the same file submitted to the CBI office with the CBI omitted to
the EPA via the EPA's CDX as described earlier in this paragraph (q).
(1) The preferred method to receive CBI is for it to be transmitted
electronically using email attachments, File Transfer Protocol, or other
online file sharing services. Electronic submissions must be transmitted
directly to the OAQPS CBI Office at the email address [email protected],
and as described above, should include clear CBI markings. ERT files
should be flagged to the attention of the Group Leader, Measurement
Policy Group; all other files should be flagged to the attention of the
SOCMI NSPS Sector Lead. Owners and operators who do not have their own
file sharing service and who require assistance with submitting large
electronic files that exceed the file size limit for email attachments
should email [email protected] to request a file transfer link.
(2) If an owner or operator cannot transmit the file electronically,
the owner or operator may send CBI information through the postal
service to the following address: OAQPS Document Control Officer (C404-
02), OAQPS, U.S. Environmental Protection Agency, 109 T.W. Alexander
Drive, P.O. Box 12055, Research Triangle Park, North Carolina 27711. ERT
files should be sent to the attention of the Group Leader, Measurement
Policy Group, and all other files should be sent to the attention of the
SOCMI NSPS Sector Lead. The mailed CBI material should be double wrapped
and clearly marked. Any CBI markings should not show through the outer
envelope.
(r) Owners and operators required to electronically submit
notifications or reports through CEDRI in the EPA's CDX may assert a
claim of EPA system outage for failure to timely comply with the
electronic submittal requirement. To assert a claim of EPA system
outage, owners and operators must meet the requirements outlined in
paragraphs (r)(1) through (7) of this section.
(1) The owner or operator must have been or will be precluded from
accessing CEDRI and submitting a required report within the time
prescribed due to an outage of either the EPA's CEDRI or CDX systems.
(2) The outage must have occurred within the period of time
beginning five business days prior to the date that the submission is
due.
(3) The outage may be planned or unplanned.
(4) The owner or operator must submit notification to the
Administrator in writing as soon as possible following the date the
owner or operator first knew, or through due diligence should have
known, that the event may cause or has caused a delay in reporting.
(5) The owner or operator must provide to the Administrator a
written description identifying:
(i) The date(s) and time(s) when CDX or CEDRI was accessed and the
system was unavailable;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to EPA system outage;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which the owner or operator proposes to report, or
if the owner or operator has already met the reporting requirement at
the time of the notification, the date the report was submitted.
(6) The decision to accept the claim of EPA system outage and allow
an extension to the reporting deadline is solely within the discretion
of the Administrator.
(7) In any circumstance, the report must be submitted electronically
as soon as possible after the outage is resolved.
(s) Owners and operators required to electronically submit
notifications or reports through CEDRI in the EPA's CDX may assert a
claim of force majeure for failure to timely comply with the electronic
submittal requirement. To assert a claim of force majeure, owners and
operators must meet the requirements outlined in paragraphs (s)(1)
through (5) of this section.
(1) An owner or operator may submit a claim if a force majeure event
is about to occur, occurs, or has occurred or there are lingering
effects from such an event within the period of time beginning five
business days prior to the date the submission is due. For the purposes
of this section, a force majeure event is defined as an event that will
be or has been caused by circumstances beyond the control of the
affected facility, its contractors, or any entity controlled by the
affected facility that prevents the owner or operator from complying
with the requirement to submit a report electronically within the time
period prescribed. Examples of such events are acts of nature (e.g.,
hurricanes, earthquakes, or floods), acts of war or terrorism, or
equipment failure or safety hazard beyond the control of the affected
facility (e.g., large scale power outage).
(2) The owner or operator must submit notification to the
Administrator in writing as soon as possible following the date the
owner or operator first knew, or through due diligence should have
known, that the event
[[Page 219]]
may cause or has caused a delay in reporting.
(3) An owner or operator must provide to the Administrator:
(i) A written description of the force majeure event;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to the force majeure event;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which the owner or operator proposes to report, or
if the owner or operator has already met the reporting requirement at
the time of the notification, the date the report was submitted.
(4) The decision to accept the claim of force majeure and allow an
extension to the reporting deadline is solely within the discretion of
the Administrator.
(5) In any circumstance, the reporting must occur as soon as
possible after the force majeure event occurs.
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
[[Page 220]]
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
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).
[[Page 221]]
Effective Date Note: At 89 FR 43108, May 16, 2024, Sec. 60.668 was
amended by revising paragraph (b), effective July 15, 2024. For the
convenience of the user, the revised text is set forth as follows:
Sec. 60.668 Delegation of authority.
* * * * *
(b) Authorities which will not be delegated to States: Sec.
60.663(e) and approval of an alternative to any electronic reporting to
the EPA required by this subpart.
Subpart NNNa_Standards of Performance for Volatile Organic Compound
(VOC) Emissions From Synthetic Organic Chemical Manufacturing Industry
(SOCMI) Distillation Operations for Which Construction, Reconstruction,
or Modification Commenced After April 25, 2023
Source: 89 FR 43108, May 16, 2024, unless otherwise noted.
Effective Date Note: At 89 FR 43108, May 16, 2024, subpart NNNa was
added, effective July 15, 2024.
Sec. 60.660a Am I subject to this subpart?
(a) You are subject to this subpart if you operate an affected
facility designated in paragraph (b) of this section that produces any
of the chemicals listed in Sec. 60.667a 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 April 25,
2023:
(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 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 Sec. 60.665a(h),
(j)(6), and (o).
(5) Each affected facility operated with a vent stream flow rate
less than 0.008 standard cubic meter per minute (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. 60.664a(e) and
Sec. 60.665a(i), (j)(7), and (p).
(6) Each affected facility operated with a vent stream flow rate
less than 0.001 pound per hour (lb/hr) of TOC is exempt from all
provisions of this subpart except for the test method and procedure and
the recordkeeping and reporting requirements in Sec. Sec. 60.664a(f)
and 60.665a(i), (j)(7), and (p).
(7) A vent stream going to a fuel gas system as defined in Sec.
63.661a.
Sec. 60.661a What definitions must I know?
As used in this subpart, all terms not defined herein have the
meaning given them in the Clean Air Act and subpart A of this part.
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.
Breakthrough means the time when the level of TOC, measured at the
outlet of the first bed, has been detected is at the highest
concentration allowed to be discharged from the adsorber system and
indicates that the adsorber bed should be replaced.
[[Page 222]]
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.
Closed vent system means a system that is not open to the atmosphere
and is composed of piping, ductwork, connections, and, if necessary,
flow inducing devices that transport gas or vapor from an emission point
to a control device.
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
or process heater occupied by the flame envelope.
Flow indicator means a device which indicates whether gas flow is
present in a vent stream.
Fuel gas means gases that are combusted to derive useful work or
heat.
Fuel gas system means the offsite and onsite piping and flow and
pressure control system that gathers gaseous stream(s) generated by
onsite operations, may blend them with other sources of gas, and
transports the gaseous stream for use as fuel gas in combustion devices
or in in-process combustion equipment such as furnaces and gas turbines
either singly or in combination.
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.
Pressure-assisted multi-point flare means a flare system consisting
of multiple flare burners in staged arrays whereby the vent stream
pressure is used to promote mixing and smokeless operation at the flare
burner tips. Pressure-assisted multi-point flares are designed for
smokeless operation at velocities up to Mach = 1 conditions (i.e., sonic
conditions), can be elevated or at ground level, and typically use
cross-lighting for flame propagation to combust any flare vent gases
sent to a particular stage of flare burners.
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 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. 60.667a. 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. 60.667a 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.
Relief valve means a valve used only to release an unplanned,
nonroutine
[[Page 223]]
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.
Total organic compounds (TOC) means those compounds measured
according to the procedures in Method 18 of appendix A-6 of this part or
the concentration of organic compounds measured according to the
procedures in Method 21 or Method 25A of appendix A-7 of this part.
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 equipment leaks including, but not limited to, pumps,
compressors, and valves.
Sec. 60.662a What standards and associated requirements must I meet?
(a) You must comply with the emission limits and standards specified
in table 1 to this subpart and the requirements specified in paragraphs
(b) and (c) of this section for each vent stream on and after the date
on which the initial performance test required by Sec. Sec. 60.8 and
60.664a 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. The
standards in this section apply at all times, including periods of
startup, shutdown and malfunction. As provided in Sec. 60.11(f), this
provision supersedes the exemptions for periods of startup, shutdown and
malfunction in the general provisions in subpart A of this part.
(b) The following release events from an affected facility are a
violation of the emission limits and standards specified in table 1 to
this subpart.
(1) Any relief valve discharge to the atmosphere of a vent stream.
(2) The use of a bypass line at any time on a closed vent system to
divert emissions to the atmosphere, or to a control device or recovery
device not meeting the requirements specified in Sec. 60.663a.
(c) You may designate a vent stream as a maintenance vent if the
vent is only used as a result of startup, shutdown, maintenance, or
inspection of equipment where equipment is emptied, depressurized,
degassed, or placed into service. You must comply with the applicable
requirements in paragraphs (c)(1) through (3) of this section for each
maintenance vent. Any vent stream designated as a maintenance vent is
only subject to the maintenance vent provisions in this paragraph (c)
and the associated recordkeeping and reporting requirements in Sec.
60.665a(g), respectively.
(1) Prior to venting to the atmosphere, remove process liquids from
the equipment as much as practical and depressurize the equipment to
either: A flare meeting the requirements of Sec. 60.669a, as
applicable, or using any combination of a non-flare control device or
recovery device meeting the requirements in table 1 to this subpart
until one of the following conditions, as applicable, is met.
(i) The vapor in the equipment served by the maintenance vent has a
lower explosive limit (LEL) of less than 10 percent.
(ii) If there is no ability to measure the LEL of the vapor in the
equipment based on the design of the equipment, the pressure in the
equipment served by the maintenance vent is reduced to 5 pounds per
square inch gauge (psig) or less. Upon opening the maintenance vent,
active purging of the equipment cannot be used until the LEL of the
vapors in the maintenance vent (or inside the equipment if the
maintenance vent is a hatch or similar type of opening) is less than 10
percent.
(iii) The equipment served by the maintenance vent contains less
than 50 pounds of total VOC.
(iv) If, after applying best practices to isolate and purge
equipment served by a maintenance vent, none of the applicable criterion
in paragraphs (c)(1)(i) through (iii) of this section can be met prior
to installing or removing a blind flange or similar equipment blind,
then the pressure in the equipment served by the maintenance vent must
be reduced to 2 psig or less before installing or removing the equipment
blind. During installation or removal of the
[[Page 224]]
equipment blind, active purging of the equipment may be used provided
the equipment pressure at the location where purge gas is introduced
remains at 2 psig or less.
(2) Except for maintenance vents complying with the alternative in
paragraph (c)(1)(iii) of this section, you must determine the LEL or, if
applicable, equipment pressure using process instrumentation or portable
measurement devices and follow procedures for calibration and
maintenance according to manufacturer's specifications.
(3) For maintenance vents complying with the alternative in
paragraph (c)(1)(iii) of this section, you must determine mass of VOC in
the equipment served by the maintenance vent based on the equipment size
and contents after considering any contents drained or purged from the
equipment. Equipment size may be determined from equipment design
specifications. Equipment contents may be determined using process
knowledge.
Sec. 60.663a What are my monitoring, installation, operation,
and maintenance requirements?
(a) Except as specified in paragraphs (a)(5) through (7) of this
section, if you use a non-flare control device or recovery system to
comply with the TOC emission limit specified in table 1 to this subpart,
then you must comply with paragraphs (a)(1) through (4), (b), and (c) of
this section.
(1) Install a continuous parameter monitoring system(s) (CPMS) and
monitor the operating parameter(s) applicable to the control device or
recovery system as specified in table 2 to this subpart or established
according to paragraph (c) of this section.
(2) Establish the applicable minimum, maximum, or range for the
operating parameter limit as specified in table 3 to this subpart or
established according to paragraph (c) of this section by calculating
the value(s) as the arithmetic average of operating parameter
measurements recorded during the three test runs conducted for the most
recent performance test. You may operate outside of the established
operating parameter limit(s) during subsequent performance tests in
order to establish new operating limits. You must include the updated
operating limits with the performance test results submitted to the
Administrator pursuant to Sec. 60.665a(b). Upon establishment of a new
operating limit, you must thereafter operate under the new operating
limit. If the Administrator determines that you did not conduct the
performance test in accordance with the applicable requirements or that
the operating limit established during the performance test does not
correspond to the conditions specified in Sec. 60.664a(a), then you
must conduct a new performance test and establish a new operating limit.
(3) Monitor, record, and demonstrate continuous compliance using the
minimum frequencies specified in table 3 to this subpart or established
according to paragraph (c) of this section.
(4) Comply with the calibration and quality control requirements as
specified in table 4 to this subpart or established according to
paragraph (c) of this section that are applicable to the CPMS used.
(5) Any vent stream introduced with primary fuel into a boiler or
process heater is exempt from the requirements specified in paragraphs
(a)(1) through (4) of this section.
(6) If you vent emissions through a closed vent system to an
adsorber(s) that cannot be regenerated or a regenerative adsorber(s)
that is regenerated offsite, then you must install a system of two or
more adsorber units in series and comply with the requirements specified
in paragraphs (a)(6)(i) through (iii) of this section in addition to the
requirements specified in paragraphs (a)(1) through (4) of this section.
(i) Conduct an initial performance test or design evaluation of the
adsorber and establish the breakthrough limit and adsorber bed life.
(ii) Monitor the TOC concentration through a sample port at the
outlet of the first adsorber bed in series according to the schedule in
paragraph (a)(6)(iii)(B) of this section. You must measure the
concentration of TOC using either a portable analyzer, in accordance
with Method 21 of appendix A-7 of this part using methane, propane, or
isobutylene as the calibration gas or Method 25A of appendix A-7 of
[[Page 225]]
this part using methane or propane as the calibration gas.
(iii) Comply with paragraph (a)(6)(iii)(A) of this section and
comply with the monitoring frequency according to paragraph
(a)(6)(iii)(B) of this section.
(A) The first adsorber in series must be replaced immediately when
breakthrough, as defined in Sec. 60.661a, is detected between the first
and second adsorber. The original second adsorber (or a fresh canister)
will become the new first adsorber and a fresh adsorber will become the
second adsorber. For purposes of this paragraph (a)(6)(iii)(A),
``immediately'' means within 8 hours of the detection of a breakthrough
for adsorbers of 55 gallons or less, and within 24 hours of the
detection of a breakthrough for adsorbers greater than 55 gallons. You
must monitor at the outlet of the first adsorber within 3 days of
replacement to confirm it is performing properly.
(B) Based on the adsorber bed life established according to
paragraph (a)(6)(i) of this section and the date the adsorbent was last
replaced, conduct monitoring to detect breakthrough at least monthly if
the adsorbent has more than 2 months of life remaining, at least weekly
if the adsorbent has between 2 months and 2 weeks of life remaining, and
at least daily if the adsorbent has 2 weeks or less of life remaining.
(7) If you install a continuous emissions monitoring system (CEMS)
to demonstrate compliance with the TOC standard in table 1 of this
subpart, you must comply with the requirements specified in Sec.
60.664a(g) in lieu of the requirements specified in paragraphs (a)(1)
through (4) and (c) of this section.
(b) If you vent emissions through a closed vent system to a boiler
or process heater, then the vent stream must be introduced into the
flame zone of the boiler or process heater.
(c) If you seek to demonstrate compliance with the standards
specified under Sec. 60.662a with control devices other than an
incinerator, boiler, process heater, or flare; or recovery devices other
than an absorber, condenser, or carbon adsorber, you shall provide to
the Administrator prior to conducting the initial performance test
information describing the operation of the control device or recovery
device and the parameter(s) which would indicate proper operation and
maintenance of the device and how the parameter(s) are indicative of
control of TOC emissions. The Administrator may request further
information and will specify appropriate monitoring procedures or
requirements, including operating parameters to be monitored, averaging
times for determining compliance with the operating parameter limits,
and ongoing calibration and quality control requirements.
Sec. 60.664a What test methods and procedures must I use to
determine compliance with the standards?
(a) For the purpose of demonstrating compliance with the emission
limits and standards specified in table 1 to this subpart, all affected
facilities must be run at full operating conditions and flow rates
during any performance test. Performance tests are not required if you
determine compliance using a CEMS that meets the requirements outlined
in paragraph (g) of this section.
(1) Conduct initial performance tests no later than the date
required by Sec. 60.8(a).
(2) Conduct subsequent performance tests no later than 60 calendar
months after the previous performance test.
(b) The following methods, except as provided in Sec. 60.8(b) must,
must be used as reference methods to determine compliance with the
emission limit or percent reduction efficiency specified in table 1 to
this subpart for non-flare control devices and/or recovery systems.
(1) Method 1 or 1A of appendix A-1 to this part, as appropriate, for
selection of the sampling sites. The 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 or, if equipped with a recovery system, then prior to the inlet
of the first recovery device in the recovery system.
(2) Method 2, 2A, 2C, or 2D of appendix A-1 to this part, as
appropriate, for determination of the gas volumetric flow rates.
[[Page 226]]
(3) Method 3A of appendix A-2 to this part or the manual method in
ANSI/ASME PTC 19.10-1981 (incorporated by reference, see Sec.
[thinsp]60.17) must be used to determine the oxygen concentration (%O2d)
for the purposes of determining compliance with the 20 ppmv limit. The
sampling site must be the same as that of the TOC samples, and the
samples must be taken during the same time that the TOC samples are
taken. The TOC concentration corrected to 3 percent O2
(Cc) must be computed using the following equation:
Equation 1 to Paragraph (b)(3)
[GRAPHIC] [TIFF OMITTED] TR16MY24.037
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 of appendix A-6 to this part to determine the
concentration of TOC in the control device outlet or in the outlet of
the final recovery device in a recovery system, and to determine the
concentration of TOC in the inlet when the reduction efficiency of the
control device or recovery system is to be determined. ASTM D6420-18
(incorporated by reference, see Sec. 60.17) may be used in lieu of
Method 18, if the target compounds are all known and are all listed in
section 1.1 of ASTM D6420-18 as measurable; ASTM D6420-18 may not be
used for methane and ethane; and ASTM D6420-18 must not be used as a
total VOC method.
(i) The sampling time for each run must be 1 hour in which either an
integrated sample or at least four grab samples must be taken. If grab
sampling is used then the samples must be taken at 15-minute intervals.
(ii) The emission reduction (R) of TOC (minus methane and ethane)
must be determined using the following equation:
Equation 2 to Paragraph (b)(4)(ii)
[GRAPHIC] [TIFF OMITTED] TR16MY24.038
Where:
R = Emission reduction, percent by weight.
Ei = Mass rate of TOC entering the control device or recovery
system, kg/hr (lb/hr).
Eo = Mass rate of TOC discharged to the atmosphere, kg/hr
(lb/hr).
(iii) The mass rates of TOC (Ei, Eo) must be
computed using the following equations:
[[Page 227]]
Equations 3 and 4 to Paragraph (b)(4)(iii)
[GRAPHIC] [TIFF OMITTED] TR16MY24.039
Where:
Cij, Coj = Concentration of sample component ``j''
of the gas stream at the inlet and outlet of the control
device or recovery system, 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 or recovery system, respectively, g/g-mole (lb/lb-
mole).
Qi, Qo = Flow rate of gas stream at the inlet and
outlet of the control device or recovery system, respectively,
dscm/min (dscf/min).
K2 = 2.494 x 10-6 (1/ppm)(g-mole/scm) (kg/g) (min/
hr) (metric units), where standard temperature for (g-mole/
scm) is 20 [deg]C.
= 1.557 x 10-7 (1/ppm) (lb-mole/scf) (min/hr) (English
units), where standard temperature for (lb-mole/scf) is 68
[deg]F.
(iv) The TOC concentration (CTOC) is the sum of the
individual components and must be computed for each run using the
following equation:
Equation 5 to Paragraph (b)(4)(iv)
[GRAPHIC] [TIFF OMITTED] TR16MY24.040
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.
(c) The requirement for initial and subsequent performance tests are
waived, in accordance with Sec. 60.8(b), for the following:
(1) 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 the emission limit or percent reduction efficiency specified
in table 1 to this subpart.
(2) When a vent stream is introduced into a boiler or process heater
with the primary fuel.
(3) When a boiler or process heater burning hazardous waste is used
for which the owner or operator:
(i) Has been issued a final permit under 40 CFR part 270 and
complies with the requirements of 40 CFR part 266, subpart H;
(ii) Has certified compliance with the interim status requirements
of 40 CFR part 266, subpart H;
(iii) Has submitted a Notification of Compliance under 40 CFR
63.1207(j) and complies with the requirements of 40 CFR part 63, subpart
EEE; or
(iv) Complies with 40 CFR part 63, subpart EEE and will submit a
Notification of Compliance under 40 CFR 63.1207(j) by the date the owner
or operator would have been required to submit the initial performance
test report for this subpart.
(4) 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.
(d) For purposes of complying with the 98 weight-percent reduction
in Sec. 60.702a(a), if the vent stream entering
[[Page 228]]
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.
(e) Any owner or operator subject to the provisions of this subpart
seeking to demonstrate compliance with Sec. 60.660a(c)(5) must use
Method 2, 2A, 2C, or 2D of appendix A-1 to this part as appropriate, for
determination of volumetric flow rate. The owner or operator must
conduct three velocity traverses and determine the volumetric flow rate
for each traverse. If the pipe or duct is smaller than four inches in
diameter, the owner operator may conduct the measurement at the centroid
of the duct instead of conducting a traverse; the measurement period
must be at least five minutes long and data must be recorded at least
once every 30 seconds. Owners and operators who conduct the
determination with Method 2A or 2D must record volumetric flow rate
every 30 seconds for at least five minutes.
(f) Any owner or operator subject to the provisions of this subpart
seeking to demonstrate compliance with Sec. 60.660a(c)(6) must use the
following methods:
(1) Method 1 or 1A of appendix A-1 to this part, as appropriate.
(2) Method 2, 2A, 2C, or 2D of appendix A-1 to this part, as
appropriate, for determination of the gas volumetric flow rates.
(3) Method 18 of appendix A-6 to this part to determine the
concentration of TOC. ASTM D6420-18 (incorporated by reference, see
Sec. 60.17) may be used in lieu of Method 18, if the target compounds
are all known and are all listed in Section 1.1 of ASTM D6420-18 as
measurable; ASTM D6420-18 may not be used for methane and ethane; and
ASTM D6420-18 must not be used as a total VOC method.
(i) The sampling site must be at a location that provides a
representative sample of the vent stream.
(ii) Perform three test runs. The sampling time for each run must be
1 hour in which either an integrated sample or at least four grab
samples must be taken. If grab sampling is used then the samples must be
taken at 15-minute intervals.
(iii) The mass rate of TOC (E) must be computed using the following
equation:
Equation 6 to Paragraph (f)(3)(iii)
[GRAPHIC] [TIFF OMITTED] TR16MY24.041
Where:
Cj = Concentration of sample component ``j'' of the gas
stream at the representative sampling location, dry basis, ppm
by volume.
Mj = Molecular weight of sample component ``j'' of the gas
stream at the representative sampling location, g/g-mole (lb/
lb-mole).
Q = Flow rate of gas stream at the representative sampling location,
dscm/min (dscf/min).
K = 2.494 x 10-6 (1/ppm)(g-mole/scm) (kg/g) (min/hr) (metric
units), where standard temperature for (g-mole/scm) is 20
[deg]C.
= 1.557 x 10-7 (1/ppm) (lb-mole/scf) (min/hr) (English
units), where standard temperature for (lb-mole/scf) is 68
[deg]F.
(g) If you use a CEMS to demonstrate initial and continuous
compliance with the TOC standard in table 1 of this subpart, each CEMS
must be installed, operated and maintained according to the
[[Page 229]]
requirements in Sec. 60.13 and paragraphs (g)(1) through (5) of this
section.
(1) You must use a CEMS that is capable of measuring the target
analyte(s) as demonstrated using either process knowledge of the control
device inlet stream or the screening procedures of Method 18 of appendix
A-6 to this part on the control device inlet stream. If your CEMS is
located after a combustion device and inlet stream to that device
includes methanol or formaldehyde, you must use a CEMS which meets the
requirements in Performance Specification 9 or 15 of appendix B to this
part.
(2) Each CEMS must be installed, operated, and maintained according
to the applicable performance specification of appendix B to this part
and the applicable quality assurance procedures of appendix F to this
part. Locate the sampling probe or other interface at a measurement
location such that you obtain representative measurements of emissions
from the affected facility.
(3) Conduct a performance evaluation of each CEMS within 180 days of
installation of the monitoring system. Conduct subsequent performance
evaluations of the CEMS no later than 12 calendar months after the
previous performance evaluation. The results each performance evaluation
must be submitted in accordance with Sec. 60.665a(b)(1).
(4) You must determine TOC concentration according to one of the
following options. The span value of the TOC CEMS must be approximately
2 times the emission standard specified in table 1 of this subpart.
(i) For CEMS meeting the requirements of Performance Specification
15 of appendix B to this part, determine the target analyte(s) for
calibration using either process knowledge of the control device inlet
stream or the screening procedures of Method 18 of appendix A-6 to this
part on the control device inlet stream. The individual analytes used to
quantify TOC must represent 98 percent of the expected mass of TOC
present in the stream. Report the results of TOC as equivalent to carbon
(C1).
(ii) For CEMS meeting the requirements of Performance Specification
9 of appendix B of this part, determine the target analyte(s) for
calibration using either process knowledge of the control device inlet
stream or the screening procedures of Method 18 of appendix A-6 to this
part on the control device inlet stream. The individual analytes used to
quantify TOC must represent 98 percent of the expected mass of TOC
present in the stream. Report the results of TOC as equivalent to carbon
(C1).
(iii) For CEMS meeting the requirements of Performance Specification
8 of appendix B to this part used to monitor performance of a combustion
device, calibrate the instrument on the predominant organic HAP and
report the results as carbon (C1), and use Method 25A of appendix A-7 to
this part as the reference method for the relative accuracy tests. You
must also comply with procedure 1 of appendix F to this part.
(iv) For CEMS meeting the requirements of Performance Specification
8 of appendix B to this part used to monitor performance of a
noncombustion device, determine the predominant organic compound using
either process knowledge or the screening procedures of Method 18 on the
control device inlet stream. Calibrate the monitor on the predominant
organic compound and report the results as C1. Use Method 25A
of appendix A-7 to this part as the reference method for the relative
accuracy tests. You must also comply with procedure 1 of appendix F to
this part.
(5) You must determine stack oxygen concentration at the same
location where you monitor TOC concentration with a CEMS that meets the
requirements of Performance Specification 3 of appendix B to this part.
The span value of the oxygen CEMS must be approximately 25 percent
oxygen. Use Method 3A of appendix A-2 to this part as the reference
method for the relative accuracy tests.
(6) You must maintain written procedures for your CEMS. At a
minimum, the procedures must include the information in paragraph
(g)(6)(i) through (vi) of this section:
(i) Description of CEMS installation location.
(ii) Description of the monitoring equipment, including the
manufacturer
[[Page 230]]
and model number for all monitoring equipment components and the span of
the analyzer.
(iii) Routine quality control and assurance procedures.
(iv) Conditions that would trigger a CEMS performance evaluation,
which must include, at a minimum, a newly installed CEMS; a process
change that is expected to affect the performance of the CEMS; and the
Administrator's request for a performance evaluation under section 114
of the Clean Air Act.
(v) Ongoing operation and maintenance procedures.
(vi) Ongoing recordkeeping and reporting procedures.
Sec. 60.665a What records must I keep and what reports
must I submit?
(a) You must notify the Administrator of the specific provisions of
table 1 of this subpart or Sec. 60.662a(c) with which you have elected
to comply. Notification must be submitted with the notification of
initial start-up required by Sec. 60.7(a)(3). If you elect at a later
date to use an alternative provision of table 1 to this subpart with
which you will comply, then you must notify the Administrator 90 days
before implementing a change and, upon implementing the change, you must
conduct a performance test as specified by Sec. 60.664a within 180
days.
(b) If you use a non-flare control device or recovery system to
comply with the TOC emission limit specified in table 1 to this subpart,
then you must keep an up-to-date, readily accessible record of the data
measured during each performance test to show compliance with the TOC
emission limit. You must also include all of the data you use to comply
with Sec. 60.663a(a)(2). The same data specified in this paragraph must
also be submitted in the initial performance test required in Sec. 60.8
and the reports of all subsequently required performance tests where
either the emission reduction efficiency of a control device or recovery
system or outlet concentration of TOC is determined. Alternatively, you
must keep records of each CEMS performance evaluation.
(1) Within 60 days after the date of completing each performance
test or CEMS performance evaluation required by this subpart, you must
submit the results of the performance test or performance evaluation
following the procedures specified in paragraph (k) of this section.
Data collected using test methods and performance evaluations of CEMS
measuring relative accuracy test audit (RATA) pollutants supported by
the EPA's Electronic Reporting Tool (ERT) as listed on the EPA's ERT
website (https://www.epa.gov/electronic-reporting-air-emissions/
electronic-reporting-tool-ert) at the time of the test or performance
evaluation must be submitted in a file format generated through the use
of the EPA's ERT. Alternatively, owners and operators may submit an
electronic file consistent with the extensible markup language (XML)
schema listed on the EPA's ERT website. Data collected using test
methods and performance evaluations of CEMS measuring RATA pollutants
that are not supported by the EPA's ERT as listed on the EPA's ERT
website at the time of the test must be included as an attachment in the
ERT or alternate electronic file.
(2) If you use a boiler or process heater with a design heat input
capacity of 44 MW (150 million Btu/hour) or greater to comply with the
TOC emission limit specified in table 1 to this subpart, then you are
not required to submit a report containing performance test data;
however, you must submit a description of the location at which the vent
stream is introduced into the boiler or process heater.
(c) If you use a non-flare control device or recovery system to
comply with the TOC emission limit specified in Table 1 to this subpart,
then you must keep up-to-date, readily accessible records of periods of
operation during which the operating parameter limits established during
the most recent performance test are exceeded or periods of operation
where the TOC CEMS, averaged on a 3-hour block basis, indicate an
exceedance of the emission standard in table 1 to this subpart.
Additionally, you must record all periods when the TOC CEMS is
inoperable. The Administrator may at any time require a report of these
data. Periods of operation during which the operating parameter limits
established during the
[[Page 231]]
most recent performance tests are exceeded are defined as follows:
(1) For absorbers:
(i) All 3-hour periods of operation during which the average
absorbing liquid temperature was above the maximum absorbing liquid
temperature established during the most recent performance test.
(ii) All 3-hour periods of operation during which the average
absorbing liquid specific gravity was outside the exit specific gravity
range (i.e., more than 0.1 unit above, or more than 0.1 unit below, the
average absorbing liquid specific gravity) established during the most
recent performance test.
(2) For boilers or process heaters:
(i) Whenever there is a change in the location at which the vent
stream is introduced into the flame zone as required under Sec.
60.663a(b).
(ii) If the boiler or process heater has a design heat input
capacity of less than 44 MW (150 million Btu/hr), then all 3-hour
periods of operation during which the average firebox temperature was
below the minimum firebox temperature during the most recent performance
test.
(3) For catalytic incinerators:
(i) All 3-hour periods of operation during which the average
temperature of the vent stream immediately before the catalyst bed is
below the minimum temperature of the vent stream established during the
most recent performance test.
(ii) All 3-hour periods of operation during which the average
temperature difference across the catalyst bed is less than the average
temperature difference of the device established during the most recent
performance test.
(4) For carbon adsorbers:
(i) All carbon bed regeneration cycles during which the total mass
stream flow or the total volumetric stream flow was below the minimum
flow established during the most recent performance test.
(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 greater than the maximum carbon bed temperature
(in degrees Celsius) established during the most recent performance
test.
(5) For condensers, all 3-hour periods of operation during which the
average exit (product side) condenser operating temperature was above
the maximum exit (product side) operating temperature established during
the most recent performance test.
(6) For scrubbers used to control halogenated vent streams:
(i) All 3-hour periods of operation during which the average pH of
the scrubber effluent is below the minimum pH of the scrubber effluent
established during the most recent performance test.
(ii) All 3-hour periods of operation during which the average
influent liquid flow to the scrubber is below the minimum influent
liquid flow to the scrubber established during the most recent
performance test.
(iii) All 3-hour periods of operation during which the average
liquid-to-gas ratio flow of the scrubber is below the minimum liquid-to-
gas ratio of the scrubber established during the most recent performance
test.
(7) For thermal incinerators, all 3-hour periods of operation during
which the average firebox temperature was below the minimum firebox
temperature established during the most recent performance test.
(8) For all other control devices, all periods (for the averaging
time specified by the Administrator) when the operating parameter(s)
established under Sec. 60.663a(c) exceeded the operating limit
established during the most recent performance test.
(d) You must keep up to date, readily accessible continuous records
of the flow indication specified in table 2 to this subpart, as well as
up-to-date, readily accessible records of all periods when the vent
stream is diverted from the control device or recovery device or has no
flow rate, including the records as specified in paragraphs (d)(1) and
(2) of this section.
(1) For each flow event from a relief valve discharge subject to the
requirements in Sec. 60.662a(b)(1), you must include an estimate of the
volume of gas, the concentration of TOC in the gas and the resulting
emissions of TOC that released to the atmosphere using process knowledge
and engineering estimates.
[[Page 232]]
(2) For each flow event from a bypass line subject to the
requirements in Sec. Sec. 60.662a(b)(2) and 60.670a(e), you must
maintain records sufficient to determine whether or not the detected
flow included flow requiring control. For each flow event from a bypass
line requiring control that is released either directly to the
atmosphere or to a control device or recovery device not meeting the
requirements in this subpart, you must include an estimate of the volume
of gas, the concentration of TOC in the gas and the resulting emissions
of TOC that bypassed the control device or recovery device using process
knowledge and engineering estimates.
(e) If you use a boiler or process heater with a design heat input
capacity of 44 MW (150 million Btu/hour) or greater to comply with the
TOC emission limit specified in Table 1 to this subpart, then you must
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) If you use a flare to comply with the TOC emission standard
specified in Table 1 to this subpart, then you must keep up-to-date,
readily accessible records of all visible emission readings, heat
content determinations, flow rate measurements, and exit velocity
determinations made during the initial visible emissions demonstration
required by Sec. 63.670(h) of this chapter, as applicable; and all
periods during the compliance determination when the pilot flame or
flare flame is absent.
(g) For each maintenance vent opening subject to the requirements of
Sec. 60.662a(c), you must keep the applicable records specified in
paragraphs (g)(1) through (5) of this section.
(1) You must maintain standard site procedures used to inventory
equipment for safety purposes (e.g., hot work or vessel entry
procedures) to document the procedures used to meet the requirements in
Sec. 60.662a(c). The current copy of the procedures must be retained
and available on-site at all times. Previous versions of the standard
site procedures, as applicable, must be retained for five years.
(2) If complying with the requirements of Sec. 60.662a(c)(1)(i),
and the lower explosive limit at the time of the vessel opening exceeds
10 percent, identification of the maintenance vent, the process units or
equipment associated with the maintenance vent, the date of maintenance
vent opening, and the lower explosive limit at the time of the vessel
opening.
(3) If complying with the requirements of Sec. 60.662a(c)(1)(ii),
and either the vessel pressure at the time of the vessel opening exceeds
5 psig or the lower explosive limit at the time of the active purging
was initiated exceeds 10 percent, identification of the maintenance
vent, the process units or equipment associated with the maintenance
vent, the date of maintenance vent opening, the pressure of the vessel
or equipment at the time of discharge to the atmosphere and, if
applicable, the lower explosive limit of the vapors in the equipment
when active purging was initiated.
(4) If complying with the requirements of Sec. 60.662a(c)(1)(iii),
records of the estimating procedures used to determine the total
quantity of VOC in the equipment and the type and size limits of
equipment that contain less than 50 pounds of VOC at the time of
maintenance vent opening. For each maintenance vent opening that
contains greater than 50 pounds of VOC for which the inventory
procedures specified in paragraph (g)(1) of this section are not
followed or for which the equipment opened exceeds the type and size
limits established in the records specified in this paragraph (g)(4),
records that identify the maintenance vent, the process units or
equipment associated with the maintenance vent, the date of maintenance
vent opening, and records used to estimate the total quantity of VOC in
the equipment at the time the maintenance vent was opened to the
atmosphere.
(5) If complying with the requirements of Sec. 60.662a(c)(1)(iv),
identification of the maintenance vent, the process units or equipment
associated with the maintenance vent, records documenting actions taken
to comply with other applicable alternatives and why utilization of this
alternative was required, the date of maintenance vent
[[Page 233]]
opening, the equipment pressure and lower explosive limit of the vapors
in the equipment at the time of discharge, an indication of whether
active purging was performed and the pressure of the equipment during
the installation or removal of the blind if active purging was used, the
duration the maintenance vent was open during the blind installation or
removal process, and records used to estimate the total quantity of VOC
in the equipment at the time the maintenance vent was opened to the
atmosphere for each applicable maintenance vent opening.
(h) If you seek to comply with the requirements of this subpart by
complying with the design production capacity provision in Sec.
60.660a(c)(4) you must 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.
(i) If you seek to comply with the requirements of this subpart by
complying with the flow rate cutoff in Sec. 60.660a(c)(5) or (6) you
must keep up-to-date, readily accessible records to indicate that the
vent stream flow rate is less than 0.008 scm/min (0.3 scf/min) or less
than 0.001 lb/hr, 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) You must submit to the Administrator semiannual reports of the
information specified in paragraphs (j)(1) through (9) of this section.
You are exempt from the reporting requirements specified in Sec.
60.7(c). If there are no exceedances, periods, or events specified in
paragraphs (j)(1) through (9) of this section that occurred during the
reporting period, then you must include a statement in your report that
no exceedances, periods, and events specified in paragraphs (j)(1)
through (9) of this section occurred during the reporting period. The
initial report must be submitted within 6 months after the initial
start-up-date. On and after July 15, 2024 or once the report template
for this subpart has been available on the Compliance and Emissions Data
Reporting Interface (CEDRI) website (https://www.epa.gov/electronic-
reporting-air-emissions/cedri) for 1 year, whichever date is later, you
must submit all subsequent reports using the appropriate electronic
report template on the CEDRI website for this subpart and following the
procedure specified in paragraph (k) of this section. The date report
templates become available will be listed on the CEDRI website. Unless
the Administrator or delegated state agency or other authority has
approved a different schedule for submission of reports, the report must
be submitted by the deadline specified in this subpart, regardless of
the method in which the report is submitted. All semiannual reports must
include the following general information: company name, address
(including county), and beginning and ending dates of the reporting
period.
(1) Exceedances of monitored parameters recorded under paragraph (c)
of this section. For each exceedance, the report must include a list of
the affected facilities or equipment, the monitored parameter that was
exceeded, the start date and time of the exceedance, the duration (in
hours) of the exceedance, an estimate of the quantity in pounds of each
regulated pollutant emitted over any emission limit, a description of
the method used to estimate the emissions, the cause of the exceedance
(including unknown cause, if applicable), as applicable, and the
corrective action taken.
(2) All periods recorded under paragraph (d) of this section when
the vent stream is diverted from the control device or recovery device,
or has no flow rate, including the information specified in paragraphs
(j)(2)(i) through (iii) of this section.
(i) For periods when the flow indicator is not operating, report the
identification of the flow indicator and the start date, start time, and
duration in hours.
(ii) For each flow event from a relief valve discharge subject to
the requirements in Sec. 60.662a(b)(1), the semiannual report must
include the identification of the relief valve, the start date, start
time, duration in hours, estimate of the volume of gas in standard cubic
feet, the concentration of TOC in the gas in parts per million by volume
and the resulting mass emissions of TOC in
[[Page 234]]
pounds that released to the atmosphere.
(iii) For each flow event from a bypass line subject to the
requirements in Sec. 60.662a(b)(2) and Sec. 670a(e)(2), the semiannual
report must include the identification of the bypass line, the start
date, start time, duration in hours, estimate of the volume of gas in
standard cubic feet, the concentration of TOC in the gas in parts per
million by volume and the resulting mass emissions of TOC in pounds that
bypass a control device or recovery device.
(3) All periods when a boiler or process heater was not operating
(considering the records recorded under paragraph (e) of this section),
including the start date, start time, and duration in hours of each
period.
(4) For each flare subject to the requirements in Sec. 60.669a, the
semiannual report must include an identification of the flare and the
items specified in Sec. 60.669a(l)(2).
(5) For each closed vent system subject to the requirements in Sec.
60.670a, the semiannual report must include an identification of the
closed vent system and the items specified in Sec. 60.670a(i).
(6) Any change in equipment or process operation, as recorded under
paragraph (h) of this section, that increases the design production
capacity above the low capacity exemption level in Sec. 60.660a(c)(4)
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 separate report. Unless the facility
qualifies for an exemption under Sec. 60.660a(c), the facility must
begin compliance with the requirements set forth in Sec. 60.662a.
(7) Any change in equipment or process operation that increases the
operating vent stream flow rate above the low flow exemption level in
Sec. 60.660a(c)(5) or (6), including a measurement of the new vent
stream flow rate, as recorded under paragraph (i) of this section. 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. The performance test is subject to the
requirements of Sec. 60.8 and must be submitted according to paragraph
(b)(1) of this section. Unless the facility qualifies for an exemption
under Sec. 60.660a(c), the facility must begin compliance with the
requirements set forth in Sec. 60.662a.
(8) Exceedances of the emission standard in Table 1 of this subpart
as indicated by a 3-hour average of the TOC CEMS and recorded under
paragraph (c) of this section. For each exceedance, the report must
include a list of the affected facilities or equipment, the start date
and time of the exceedance, the duration (in hours) of the exceedance,
an estimate of the quantity in pounds of each regulated pollutant
emitted over the emission limit, a description of the method used to
estimate the emissions, the cause of the exceedance (including unknown
cause, if applicable), as applicable, and the corrective action taken.
(9) Periods when the TOC CEMS was inoperative. For each period, the
report must include a list of the affected facilities or equipment, the
start date and time of the period, the duration (in hours) of the
period, the cause of the inoperability (including unknown cause, if
applicable), as applicable, and the corrective action taken.
(k) If you are required to submit notifications or reports following
the procedure specified in this paragraph (k), you must submit
notifications or reports to the EPA via CEDRI, which can be accessed
through the EPA's Central Data Exchange (CDX) (https://cdx.epa.gov/).
The EPA will make all the information submitted through CEDRI available
to the public without further notice to you. Do not use CEDRI to submit
information you claim as CBI. Although we do not expect persons to
assert a claim of CBI, if you wish to assert a CBI claim for some of the
information in the report or notification, you must submit a complete
file in the format specified in this subpart, including information
[[Page 235]]
claimed to be CBI, to the EPA following the procedures in paragraphs
(k)(1) and (2) of this section. Clearly mark the part or all of the
information that you claim to be CBI. Information not marked as CBI may
be authorized for public release without prior notice. Information
marked as CBI will not be disclosed except in accordance with procedures
set forth in 40 CFR part 2. All CBI claims must be asserted at the time
of submission. Anything submitted using CEDRI cannot later be claimed
CBI. Furthermore, under CAA section 114(c), emissions data is not
entitled to confidential treatment, and the EPA is required to make
emissions data available to the public. Thus, emissions data will not be
protected as CBI and will be made publicly available. You must submit
the same file submitted to the CBI office with the CBI omitted to the
EPA via the EPA's CDX as described earlier in this paragraph (k).
(1) The preferred method to receive CBI is for it to be transmitted
electronically using email attachments, File Transfer Protocol, or other
online file sharing services. Electronic submissions must be transmitted
directly to the OAQPS CBI Office at the email address [email protected],
and as described above, should include clear CBI markings. ERT files
should be flagged to the attention of the Group Leader, Measurement
Policy Group; all other files should be flagged to the attention of the
SOCMI NSPS Sector Lead. If assistance is needed with submitting large
electronic files that exceed the file size limit for email attachments,
and if you do not have your own file sharing service, please email
[email protected] to request a file transfer link.
(2) If you cannot transmit the file electronically, you may send CBI
information through the postal service to the following address: OAQPS
Document Control Officer (C404-02), OAQPS, U.S. Environmental Protection
Agency, 109 T.W. Alexander Drive, P.O. Box 12055, Research Triangle
Park, North Carolina 27711. ERT files should be sent to the attention of
the Group Leader, Measurement Policy Group, and all other files should
be sent to the attention of the SOCMI NSPS Sector Lead. The mailed CBI
material should be double wrapped and clearly marked. Any CBI markings
should not show through the outer envelope.
(l) If you are required to electronically submit notifications or
reports through CEDRI in the EPA's CDX, you may assert a claim of EPA
system outage for failure to timely comply with the electronic submittal
requirement. To assert a claim of EPA system outage, you must meet the
requirements outlined in paragraphs (l)(1) through (7) of this section.
(1) You must have been or will be precluded from accessing CEDRI and
submitting a required report within the time prescribed due to an outage
of either the EPA's CEDRI or CDX systems.
(2) The outage must have occurred within the period of time
beginning five business days prior to the date that the submission is
due.
(3) The outage may be planned or unplanned.
(4) You must submit notification to the Administrator in writing as
soon as possible following the date you first knew, or through due
diligence should have known, that the event may cause or has caused a
delay in reporting.
(5) You must provide to the Administrator a written description
identifying:
(i) The date(s) and time(s) when CDX or CEDRI was accessed and the
system was unavailable;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to EPA system outage;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which you propose to report, or if you have already
met the reporting requirement at the time of the notification, the date
you reported.
(6) The decision to accept the claim of EPA system outage and allow
an extension to the reporting deadline is solely within the discretion
of the Administrator.
(7) In any circumstance, the report must be submitted electronically
as soon as possible after the outage is resolved.
(m) If you are required to electronically submit notifications or
reports through CEDRI in the EPA's CDX, you
[[Page 236]]
may assert a claim of force majeure for failure to timely comply with
the electronic submittal requirement. To assert a claim of force
majeure, you must meet the requirements outlined in paragraphs (m)(1)
through (5) of this section.
(1) You may submit a claim if a force majeure event is about to
occur, occurs, or has occurred or there are lingering effects from such
an event within the period of time beginning five business days prior to
the date the submission is due. For the purposes of this section, a
force majeure event is defined as an event that will be or has been
caused by circumstances beyond the control of the affected facility, its
contractors, or any entity controlled by the affected facility that
prevents you from complying with the requirement to submit a report
electronically within the time period prescribed. Examples of such
events are acts of nature (e.g., hurricanes, earthquakes, or floods),
acts of war or terrorism, or equipment failure or safety hazard beyond
the control of the affected facility (e.g., large scale power outage).
(2) You must submit notification to the Administrator in writing as
soon as possible following the date you first knew, or through due
diligence should have known, that the event may cause or has caused a
delay in reporting.
(3) You must provide to the Administrator:
(i) A written description of the force majeure event;
(ii) A rationale for attributing the delay in reporting beyond the
regulatory deadline to the force majeure event;
(iii) A description of measures taken or to be taken to minimize the
delay in reporting; and
(iv) The date by which you propose to report, or if you have already
met the reporting requirement at the time of the notification, the date
you reported.
(4) The decision to accept the claim of force majeure and allow an
extension to the reporting deadline is solely within the discretion of
the Administrator.
(5) In any circumstance, the reporting must occur as soon as
possible after the force majeure event occurs.
(n) The requirements of paragraph (j) 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 paragraph (j) of this section, provided
that they comply with the requirements established by the State. The EPA
will not approve a waiver of electronic reporting to the EPA in
delegating enforcement authority. Thus, electronic reporting to the EPA
cannot be waived, and as such, the provisions of this paragraph cannot
be used to relieve owners or operators of affected facilities of the
requirement to submit the electronic reports required in this section to
the EPA.
(o) If you seek to demonstrate compliance with Sec. 60.660(c)(4),
then you must submit to the Administrator an initial report detailing
the design production capacity of the process unit.
(p) If you seek to demonstrate compliance with Sec. 60.660(c)(5) or
(6), then you must submit to the Administrator, following the procedures
in paragraph (b)(1) of this section, an initial report including a flow
rate measurement using the test methods specified in Sec. 60.664a.
(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. 60.662a other
than as provided under Sec. 60.663a.
(r) Any records required to be maintained by this subpart that are
submitted electronically via the EPA's CEDRI may be maintained in
electronic format. This ability to maintain electronic copies does not
affect the requirement for facilities to make records, data, and reports
available upon request to a delegated air agency or the EPA as part of
an on-site compliance evaluation.
[[Page 237]]
Sec. 60.666a What do the terms associated with reconstruction
mean for this subpart?
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 April 25, 2023. For purposes of this
paragraph, ``commenced'' means that you have undertaken a continuous
program of component replacement or that you have entered into a
contractual obligation to undertake and complete, within a reasonable
time, a continuous program of component replacement.
Sec. 60.667a What are the chemicals that I must produce to be affected by subpart NNNa?
------------------------------------------------------------------------
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 68081-81-2
salts...............................................
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
[[Page 238]]
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
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
[[Page 239]]
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
[[Page 240]]
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.
Sec. 60.668a [Reserved]
Sec. 60.669a What are my requirements if I use a flare to comply
with this subpart?
(a) If you use a flare to comply with the TOC emission standard
specified in Table 1 to this subpart, then you must meet the applicable
requirements for flares as specified in Sec. Sec. 63.670 and 63.671 of
this chapter, including the provisions in tables 12 and 13 to part 63,
subpart CC, of this chapter, except as specified in paragraphs (b)
through (o) of this section. This requirement also applies to any flare
using fuel gas from a fuel gas system, of which 50 percent or more of
the fuel gas is derived from an affected facility, as determined on an
annual average basis. For purposes of compliance with this paragraph
(a), the following terms are defined in Sec. 63.641 of this chapter:
Assist air, assist steam, center steam, combustion zone, combustion zone
gas, flare, flare purge gas, flare supplemental gas, flare sweep gas,
flare vent gas, lower steam, net heating value, perimeter assist air,
pilot gas, premix assist air, total steam, and upper steam.
(b) When determining compliance with the pilot flame requirements
specified in Sec. 63.670(b) and (g) of this chapter, substitute ``pilot
flame or flare flame'' for each occurrence of ``pilot flame.''
(c) When determining compliance with the flare tip velocity and
combustion zone operating limits specified in Sec. 63.670(d) and (e) of
this chapter, the requirement effectively applies starting with the 15-
minute block that includes a full 15 minutes of the flaring event. You
are required to demonstrate compliance with the velocity and NHVcz
requirements starting with the block that contains the fifteenth minute
of a flaring event. You are not required to demonstrate compliance for
the previous 15-minute block in which the event started and contained
only a fraction of flow.
(d) Instead of complying with Sec. 63.670(o)(2)(i) of this chapter,
you must develop and implement the flare management plan no later than
startup for a new flare that commenced construction on or after April
25, 2023.
(e) Instead of complying with Sec. 63.670(o)(2)(iii) of this
chapter, if required to develop a flare management plan and submit it to
the Administrator, then you must also submit all versions of the plan in
portable document format (PDF) following the procedures specified in
Sec. 60.665a(k).
(f) Section 63.670(o)(3)(ii) of this chapter and all references to
it do not apply. Instead, you must comply with the maximum flare tip
velocity operating limit at all times.
(g) Substitute ``affected facility'' for each occurrence of
``petroleum refinery.''
(h) Each occurrence of ``refinery'' does not apply.
(i) If a pressure-assisted multi-point flare is used as a control
device, then you must meet the following conditions:
(1) You are not required to comply with the flare tip velocity
requirements in Sec. 63.670(d) and (k) of this chapter;
(2) The NHVcz for pressure-assisted mulit-point flares is 800 Btu/
scf;
(3) You must determine the 15-minute block average NHVvg using only
the direct calculation method specified in in Sec. 63.670(l)(5)(ii) of
this chapter;
(4) Instead of complying with Sec. 63.670(b) and (g) of this
chapter, if a pressure-assisted multi-point flare uses cross-lighting on
a stage of burners rather than having an individual pilot
[[Page 241]]
flame on each burner, then you must operate each stage of the pressure-
assisted multi-point flare with a flame present at all times when
regulated material is routed to that stage of burners. Each stage of
burners that cross-lights in the pressure-assisted multi-point flare
must have at least two pilots with at least one continuously lit and
capable of igniting all regulated material that is routed to that stage
of burners. Each 15-minute block during which there is at least one
minute where no pilot flame is present on a stage of burners when
regulated material is routed to the flare is a deviation of the
standard. Deviations in different 15-minute blocks from the same event
are considered separate deviations. The pilot flame(s) on each stage of
burners that use cross-lighting must be continuously monitored by a
thermocouple or any other equivalent device used to detect the presence
of a flame;
(5) Unless you choose to conduct a cross-light performance
demonstration as specified in this paragraph (i)(5), you must ensure
that if a stage of burners on the flare uses cross-lighting, that the
distance between any two burners in series on that stage is no more than
6 feet when measured from the center of one burner to the next burner. A
distance greater than 6 feet between any two burners in series may be
used provided you conduct a performance demonstration that confirms the
pressure-assisted multi-point flare will cross-light a minimum of three
burners and the spacing between the burners and location of the pilot
flame must be representative of the projected installation. The
compliance demonstration must be approved by the permitting authority
and a copy of this approval must be maintained onsite. The compliance
demonstration report must include: a protocol describing the test
methodology used, associated test method QA/QC parameters, the waste gas
composition and NHVcz of the gas tested, the velocity of the waste gas
tested, the pressure-assisted multi-point flare burner tip pressure, the
time, length, and duration of the test, records of whether a successful
cross-light was observed over all of the burners and the length of time
it took for the burners to cross-light, records of maintaining a stable
flame after a successful cross-light and the duration for which this was
observed, records of any smoking events during the cross-light, waste
gas temperature, meteorological conditions (e.g., ambient temperature,
barometric pressure, wind speed and direction, and relative humidity),
and whether there were any observed flare flameouts; and
(6) You must install and operate pressure monitor(s) on the main
flare header, as well as a valve position indicator monitoring system
for each staging valve to ensure that the flare operates within the
proper range of conditions as specified by the manufacturer. The
pressure monitor must meet the requirements in table 13 to part 63,
subpart CC, of this chapter.
(7) If a pressure-assisted multi-point flare is operating under the
requirements of an approved alternative means of emission limitations,
you must either continue to comply with the terms of the alternative
means of emission limitations or comply with the provisions in
paragraphs (i)(1) through (6) of this section.
(j) If you choose to determine compositional analysis for net
heating value with a continuous process mass spectrometer, then you must
comply with the requirements specified in paragraphs (j)(1) through (7)
of this section.
(1) You must meet the requirements in Sec. 63.671(e)(2) of this
chapter. You may augment the minimum list of calibration gas components
found in Sec. 63.671(e)(2) with compounds found during a pre-survey or
known to be in the gas through process knowledge.
(2) Calibration gas cylinders must be certified to an accuracy of 2
percent and traceable to National Institute of Standards and Technology
(NIST) standards.
(3) For unknown gas components that have similar analytical mass
fragments to calibration compounds, you may report the unknowns as an
increase in the overlapped calibration gas compound. For unknown
compounds that produce mass fragments that do not overlap calibration
compounds, you may use the response factor for the nearest molecular
weight
[[Page 242]]
hydrocarbon in the calibration mix to quantify the unknown component's
NHVvg.
(4) You may use the response factor for n-pentane to quantify any
unknown components detected with a higher molecular weight than n-
pentane.
(5) You must perform an initial calibration to identify mass
fragment overlap and response factors for the target compounds.
(6) You must meet applicable requirements in Performance
Specification 9 of appendix B of this part, for continuous monitoring
system acceptance including, but not limited to, performing an initial
multi-point calibration check at three concentrations following the
procedure in Section 10.1 and performing the periodic calibration
requirements listed for gas chromatographs in table 13 to part 63,
subpart CC, of this chapter, for the process mass spectrometer. You may
use the alternative sampling line temperature allowed under Net Heating
Value by Gas Chromatograph in table 13 to part 63, subpart CC, of this
chapter.
(7) The average instrument calibration error (CE) for each
calibration compound at any calibration concentration must not differ by
more than 10 percent from the certified cylinder gas value. The CE for
each component in the calibration blend must be calculated using
equation 1 to this paragraph (j)(7).
Equation 1 to Paragraph (j)(7)
[GRAPHIC] [TIFF OMITTED] TR16MY24.042
Where:
Cm = Average instrument response (ppm)
Ca = Certified cylinder gas value (ppm)
(k) If you use a gas chromatograph or mass spectrometer for
compositional analysis for net heating value, then you may choose to use
the CE of NHVmeasured versus the cylinder tag value NHV as
the measure of agreement for daily calibration and quarterly audits in
lieu of determining the compound-specific CE. The CE for NHV at any
calibration level must not differ by more than 10 percent from the
certified cylinder gas value. The CE must be calculated using equation 2
to this paragraph (k).
Equation 2 to Paragraph (k)
[GRAPHIC] [TIFF OMITTED] TR16MY24.043
Where:
NHVmeasured = Average instrument response (Btu/scf)
NHVa = Certified cylinder gas value (Btu/scf)
(l) Instead of complying with Sec. 63.670(q) of this chapter, you
must comply with the reporting requirements specified in paragraphs
(l)(1) and (2) of this section.
(1) The notification requirements specified in Sec. 60.665a(a).
(2) The semiannual report specified in Sec. 60.665a(j)(4) must
include the items specified in paragraphs (l)(2)(i) through (vi) of this
section.
(i) Records as specified in paragraph (m)(1) of this section for
each 15-minute block during which there was at least one minute when
regulated material is routed to a flare and no pilot flame or flare
flame is present. Include the start and stop time and date of each 15-
minute block.
(ii) Visible emission records as specified in paragraph (m)(2)(iv)
of this section for each period of 2 consecutive
[[Page 243]]
hours during which visible emissions exceeded a total of 5 minutes.
(iii) The periods specified in paragraph (m)(6) of this section.
Indicate the date and start and end times for each period, and the net
heating value operating parameter(s) determined following the methods in
Sec. 63.670(k) through (n) of this chapter as applicable.
(iv) For flaring events meeting the criteria in Sec. 63.670(o)(3)
of this chapter and paragraph (f) of this section:
(A) The start and stop time and date of the flaring event.
(B) The length of time in minutes for which emissions were visible
from the flare during the event.
(C) For steam-assisted, air-assisted, and non-assisted flares, the
start date, start time, and duration in minutes for periods of time that
the flare tip velocity exceeds the maximum flare tip velocity determined
using the methods in Sec. 63.670(d)(2) of this chapter and the maximum
15-minute block average flare tip velocity in ft/sec recorded during the
event.
(D) Results of the root cause and corrective actions analysis
completed during the reporting period, including the corrective actions
implemented during the reporting period and, if applicable, the
implementation schedule for planned corrective actions to be implemented
subsequent to the reporting period.
(v) For pressure-assisted multi-point flares, the periods of time
when the pressure monitor(s) on the main flare header show the burners
operating outside the range of the manufacturer's specifications.
Indicate the date and start and end times for each period.
(vi) For pressure-assisted multi-point flares, the periods of time
when the staging valve position indicator monitoring system indicates a
stage should not be in operation and is or when a stage should be in
operation and is not. Indicate the date and start and end times for each
period.
(m) Instead of complying with Sec. 63.670(p) of this chapter, you
must keep the flare monitoring records specified in paragraphs (m)(1)
through (14) of this section.
(1) Retain records of the output of the monitoring device used to
detect the presence of a pilot flame or flare flame as required in Sec.
63.670(b) of this chapter and the presence of a pilot flame as required
in paragraph (i)(4) of this section for a minimum of 2 years. Retain
records of each 15-minute block during which there was at least one
minute that no pilot flame or flare flame is present when regulated
material is routed to a flare for a minimum of 5 years. For a pressure-
assisted multi-point flare that uses cross-lighting, retain records of
each 15-minute block during which there was at least one minute that no
pilot flame is present on each stage when regulated material is routed
to a flare for a minimum of 5 years. You may reduce the collected
minute-by-minute data to a 15-minute block basis with an indication of
whether there was at least one minute where no pilot flame or flare
flame was present.
(2) Retain records of daily visible emissions observations as
specified in paragraphs (m)(2)(i) through (iv) of this section, as
applicable, for a minimum of 3 years.
(i) To determine when visible emissions observations are required,
the record must identify all periods when regulated material is vented
to the flare.
(ii) If visible emissions observations are performed using Method 22
of appendix A-7 of this part, then the record must identify whether the
visible emissions observation was performed, the results of each
observation, total duration of observed visible emissions, and whether
it was a 5-minute or 2-hour observation. Record the date and start time
of each visible emissions observation.
(iii) If a video surveillance camera is used pursuant to Sec.
63.670(h)(2) of this chapter, then the record must include all video
surveillance images recorded, with time and date stamps.
(iv) For each 2-hour period for which visible emissions are observed
for more than 5 minutes in 2 consecutive hours, then the record must
include the date and start and end time of the 2-hour period and an
estimate of the cumulative number of minutes in the 2-hour period for
which emissions were visible.
[[Page 244]]
(3) The 15-minute block average cumulative flows for flare vent gas
and, if applicable, total steam, perimeter assist air, and premix assist
air specified to be monitored under Sec. 63.670(i) of this chapter,
along with the date and time interval for the 15-minute block. If
multiple monitoring locations are used to determine cumulative vent gas
flow, total steam, perimeter assist air, and premix assist air, then
retain records of the 15-minute block average flows for each monitoring
location for a minimum of 2 years, and retain the 15-minute block
average cumulative flows that are used in subsequent calculations for a
minimum of 5 years. If pressure and temperature monitoring is used, then
retain records of the 15-minute block average temperature, pressure, and
molecular weight of the flare vent gas or assist gas stream for each
measurement location used to determine the 15-minute block average
cumulative flows for a minimum of 2 years, and retain the 15-minute
block average cumulative flows that are used in subsequent calculations
for a minimum of 5 years.
(4) The flare vent gas compositions specified to be monitored under
Sec. 63.670(j) of this chapter. Retain records of individual component
concentrations from each compositional analysis for a minimum of 2
years. If an NHVvg analyzer is used, retain records of the 15-minute
block average values for a minimum of 5 years.
(5) Each 15-minute block average operating parameter calculated
following the methods specified in Sec. 63.670(k) through (n) this
chapter, as applicable.
(6) All periods during which operating values are outside of the
applicable operating limits specified in Sec. 63.670(d) through (f) of
this chapter and paragraph (i) of this section when regulated material
is being routed to the flare.
(7) All periods during which you do not perform flare monitoring
according to the procedures in Sec. 63.670(g) through (j) of this
chapter.
(8) For pressure-assisted multi-point flares, if a stage of burners
on the flare uses cross-lighting, then a record of any changes made to
the distance between burners.
(9) For pressure-assisted multi-point flares, all periods when the
pressure monitor(s) on the main flare header show burners are operating
outside the range of the manufacturer's specifications. Indicate the
date and time for each period, the pressure measurement, the stage(s)
and number of burners affected, and the range of manufacturer's
specifications.
(10) For pressure-assisted multi-point flares, all periods when the
staging valve position indicator monitoring system indicates a stage of
the pressure-assisted multi-point flare should not be in operation and
when a stage of the pressure-assisted multi-point flare should be in
operation and is not. Indicate the date and time for each period,
whether the stage was supposed to be open, but was closed or vice versa,
and the stage(s) and number of burners affected.
(11) Records of periods when there is flow of vent gas to the flare,
but when there is no flow of regulated material to the flare, including
the start and stop time and dates of periods of no regulated material
flow.
(12) Records when the flow of vent gas exceeds the smokeless
capacity of the flare, including start and stop time and dates of the
flaring event.
(13) Records of the root cause analysis and corrective action
analysis conducted as required in Sec. 63.670(o)(3) of this chapter and
paragraph (f) of this section, including an identification of the
affected flare, the date and duration of the event, a statement noting
whether the event resulted from the same root cause(s) identified in a
previous analysis and either a description of the recommended corrective
action(s) or an explanation of why corrective action is not necessary
under Sec. 63.670(o)(5)(i) of this chapter.
(14) For any corrective action analysis for which implementation of
corrective actions are required in Sec. 63.670(o)(5) of this chapter, a
description of the corrective action(s) completed within the first 45
days following the discharge and, for action(s) not already completed, a
schedule for implementation, including proposed commencement and
completion dates.
[[Page 245]]
(n) You may elect to comply with the alternative means of emissions
limitation requirements specified in Sec. 63.670(r) of this chapter in
lieu of the requirements in Sec. 63.670(d) through (f) of this chapter,
as applicable. However, instead of complying with Sec.
63.670(r)(3)(iii) of this chapter, you must also submit the alternative
means of emissions limitation request to the following address: U.S.
Environmental Protection Agency, Office of Air Quality Planning and
Standards, Sector Policies and Programs Division, U.S. EPA Mailroom
(C404-02), Attention: SOCMI NSPS Sector Lead, 4930 Old Page Rd., Durham,
NC 27703.
(o) The referenced provisions specified in paragraphs (o)(1) through
(4) of this section do not apply when demonstrating compliance with this
section.
(1) Section 63.670(o)(4)(iv) of this chapter.
(2) The last sentence of Sec. 63.670(o)(6) of this chapter.
(3) The phrase ``that were not caused by a force majeure event'' in
Sec. 63.670(o)(7)(ii) of this chapter.
(4) The phrase ``that were not caused by a force majeure event'' in
Sec. 63.670(o)(7)(iv) of this chapter.
Sec. 60.670a What are my requirements for closed vent systems?
(a) Except as provided in paragraphs (f) and (g) of this section,
you must inspect each closed vent system according to the procedures and
schedule specified in paragraphs (a)(1) through (3) of this section.
(1) Conduct an initial inspection according to the procedures in
paragraph (b) of this section unless the closed vent system is operated
and maintained under negative pressure;
(2) Conduct annual inspections according to the procedures in
paragraph (b) of this section unless the closed vent system is operated
and maintained under negative pressure; and
(3) Conduct annual inspections for visible, audible, or olfactory
indications of leaks.
(b) You must inspect each closed vent system according to the
procedures specified in paragraphs (b)(1) through (6) of this section.
(1) Inspections must be conducted in accordance with Method 21 of
appendix A of this part.
(2)(i) Except as provided in paragraph (b)(2)(ii) of this section,
the detection instrument must meet the performance criteria of Method 21
of appendix A of this part, except the instrument response factor
criteria in section 3.1.2(a) of Method 21 must be for the average
composition of the process fluid not each individual volatile organic
compound in the stream. For process streams that contain nitrogen, air,
or other inerts which are not organic hazardous air pollutants or
volatile organic compounds, the average stream response factor must be
calculated on an inert-free basis.
(ii) If no instrument is available at the plant site that will meet
the performance criteria specified in paragraph (b)(2)(i) of this
section, the instrument readings may be adjusted by multiplying by the
average response factor of the process fluid, calculated on an inert-
free basis as described in paragraph (b)(2)(i).
(3) The detection instrument must be calibrated before use on each
day of its use by the procedures specified in Method 21 of appendix A of
this part.
(4) Calibration gases must be as follows:
(i) Zero air (less than 10 parts per million hydrocarbon in air);
and
(ii) Mixtures of methane in air at a concentration less than 2,000
parts per million. A calibration gas other than methane in air may be
used if the instrument does not respond to methane or if the instrument
does not meet the performance criteria specified in paragraph (b)(2)(i)
of this section. In such cases, the calibration gas may be a mixture of
one or more of the compounds to be measured in air.
(5) You may elect to adjust or not adjust instrument readings for
background. If you elect to not adjust readings for background, all such
instrument readings must be compared directly to the applicable leak
definition to determine whether there is a leak.
(6) If you elect to adjust instrument readings for background, you
must determine the background concentration using Method 21 of appendix
A of this part. After monitoring each potential
[[Page 246]]
leak interface, subtract the background reading from the maximum
concentration indicated by the instrument. The arithmetic difference
between the maximum concentration indicated by the instrument and the
background level must be compared with 500 parts per million for
determining compliance.
(c) Leaks, as indicated by an instrument reading greater than 500
parts per million above background or by visual, audio, or olfactory
inspections, must be repaired as soon as practicable, except as provided
in paragraph (d) of this section.
(1) A first attempt at repair must be made no later than 5 calendar
days after the leak is detected.
(2) Repair must be completed no later than 15 calendar days after
the leak is detected.
(d) Delay of repair of a closed vent system for which leaks have
been detected is allowed if the repair is technically infeasible without
a shutdown, as defined in Sec. 60.2, or if you determine that emissions
resulting from immediate repair would be greater than the fugitive
emissions likely to result from delay of repair. Repair of such
equipment must be complete by the end of the next shutdown.
(e) For each closed vent system that contains bypass lines that
could divert a vent stream away from the control device and to the
atmosphere, you must comply with the provisions of either paragraph
(e)(1) or (2), except as specified in paragraph (e)(3) of this section.
(1) Install, calibrate, maintain, and operate a flow indicator that
determines whether vent stream flow is present at least once every 15
minutes. You must keep hourly records of whether the flow indicator was
operating and whether a diversion was detected at any time during the
hour, as well as records of the times and durations of all periods when
the vent stream is diverted to the atmosphere or the flow indicator is
not operating. The flow indicator must be installed at the entrance to
any bypass line; or
(2) 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 must be performed at least once every month to
ensure the valve is maintained in the closed position and the vent
stream is not diverted through the bypass line.
(3) Open-ended valves or lines that use a cap, blind flange, plug,
or second valve and follow the requirements specified in Sec. 60.482-
6(a)(2), (b), and (c) or follow requirements codified in another
regulation that are the same as Sec. 60.482-6(a)(2), (b), and (c) are
not subject to this paragraph (e) of this section.
(f) Any parts of the closed vent system that are designated, as
described in paragraph (h)(1) of this section, as unsafe to inspect are
exempt from the inspection requirements of paragraphs (a)(1) and (2) of
this section if:
(1) You determine that the equipment is unsafe to inspect because
inspecting personnel would be exposed to an imminent or potential danger
as a consequence of complying with paragraphs (a)(1) and (2) of this
section; and
(2) You have a written plan that requires inspection of the
equipment as frequently as practicable during safe-to-inspect times.
(g) Any parts of the closed vent system are designated, as described
in paragraph (h)(2) of this section, as difficult to inspect are exempt
from the inspection requirements of paragraphs (a)(1) and (2) of this
section if:
(1) You determine that the equipment cannot be inspected without
elevating the inspecting personnel more than 2 meters above a support
surface; and
(2) You have a written plan that requires inspection of the
equipment at least once every 5 years.
(h) You must record the information specified in paragraphs (h)(1)
through (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.
[[Page 247]]
(3) For each closed vent system that contains bypass lines that
could divert a vent stream away from the control device and to the
atmosphere, you must keep a record of the information specified in
either paragraph (h)(3)(i) or (ii) of this section in addition to the
information specified in paragraph (h)(3)(iii) of this section.
(i) Hourly records of whether the flow indicator specified under
paragraph (e)(1) of this section was operating and whether a diversion
was detected at any time during the hour, as well as records of the
times of all periods when the vent stream is diverted from the control
device or the flow indicator is not operating.
(ii) Where a seal mechanism is used to comply with paragraph (e)(2)
of this section, hourly records of flow are not required. In such cases,
you must record whether the monthly visual inspection of the seals or
closure mechanisms has been done, and you must record the occurrence of
all periods when the seal mechanism is broken, the bypass line valve
position has changed, or the key for a lock-and-key type configuration
has been checked out, and records of any car-seal that has broken.
(iii) For each flow event from a bypass line subject to the
requirements in paragraph (e) of this section, you must maintain records
sufficient to determine whether or not the detected flow included flow
requiring control. For each flow event from a bypass line requiring
control that is released either directly to the atmosphere or to a
control device not meeting the requirements in this subpart, you must
include an estimate of the volume of gas, the concentration of VOC in
the gas and the resulting emissions of VOC that bypassed the control
device using process knowledge and engineering estimates.
(4) For each inspection during which a leak is detected, a record of
the information specified in paragraphs (h)(4)(i) through (viii) of this
section.
(i) The instrument identification numbers; operator name or
initials; and identification of the equipment.
(ii) The date the leak was detected and the date of the first
attempt to repair the leak.
(iii) Maximum instrument reading measured by the method specified in
paragraph (c) of this section after the leak is successfully repaired or
determined to be nonrepairable.
(iv) ``Repair delayed'' and the reason for the delay if a leak is
not repaired within 15 calendar days after discovery of the leak.
(v) The name, initials, or other form of identification of the owner
or operator (or designee) whose decision it was that repair could not be
effected without a shutdown.
(vi) The expected date of successful repair of the leak if a leak is
not repaired within 15 calendar days.
(vii) Dates of shutdowns that occur while the equipment is
unrepaired.
(viii) The date of successful repair of the leak.
(5) For each inspection conducted in accordance with paragraph (b)
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.
(6) For each inspection conducted in accordance with paragraph
(a)(3) 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.
(i) The semiannual report specified in Sec. 60.665a(j)(5) must
include the items specified in paragraphs (i)(1) through (3) of this
section.
(1) Reports of the times of all periods recorded under paragraph
(h)(3)(i) of this section when the vent stream is diverted from the
control device through a bypass line. Include the start date, start
time, and duration in hours of each period.
(2) Reports of all periods recorded under paragraph (h)(3)(ii) of
this section in which the seal mechanism is broken, the bypass line
valve position has changed, or the key to unlock the bypass line valve
was checked out. Include the start date, start time, and duration in
hours of each period.
(3) For bypass lines subject to the requirements in paragraph (e) of
this section, the semiannual reports must include the start date, start
time, duration in hours, estimate of the volume
[[Page 248]]
of gas in standard cubic feet, the concentration of VOC in the gas in
parts per million by volume and the resulting mass emissions of VOC in
pounds that bypass a control device. For periods when the flow indicator
is not operating, report the start date, start time, and duration in
hours.
Sec. Table 1 to Subpart NNNa of Part 60--Emission Limits and Standards
for Vent Streams
------------------------------------------------------------------------
For each . . . You must . . .
------------------------------------------------------------------------
1. Vent stream.................... 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 by venting emissions
through a closed vent system to any
combination of non-flare control
devices and/or recovery system and
meet the requirements specified in
Sec. 60.663a and Sec. 60.670a;
or
b. Reduce emissions of TOC (minus
methane and ethane) by venting
emissions through a closed vent
system to a flare and meet the
requirements specified in Sec.
60.669a and Sec. 60.670a.
------------------------------------------------------------------------
Sec. Table 2 to Subpart NNNa of Part 60--Monitoring Requirements for
Complying With 98 Weight-Percent Reduction of Total Organic Compounds
Emissions or a Limit of 20 Parts per Million by Volume
------------------------------------------------------------------------
Non-flare control device or
recovery device Parameters to be monitored
------------------------------------------------------------------------
1. All control and recovery a. Presence of flow diverted to the
devices. atmosphere from the control and
recovery device; or
b. Monthly inspections of sealed
valves
2. Absorber...................... a. Exit temperature of the absorbing
liquid; and
b. Exit specific gravity
3. Boiler or process heater with Firebox temperature \a\
a design heat input capacity
less than 44 megawatts and vent
stream is not introduced with or
as the primary fuel.
4. Catalytic incinerator......... Temperature upstream and downstream
of the catalyst bed
5. Carbon adsorber, regenerative. a. Total regeneration stream mass or
volumetric flow during carbon bed
regeneration cycle(s); and
b. Temperature of the carbon bed
after regeneration [and within 15
minutes of completing any cooling
cycle(s)]
6. Carbon adsorber, non- Breakthrough
regenerative or regenerated
offsite.
7. Condenser..................... Exit (product side) temperature
8. Scrubber for halogenated vent a. pH of scrubber effluent; and
streams.
b. Scrubber liquid and gas flow rates
9. Thermal incinerator........... Firebox temperature \a\
10. Control devices other than an As specified by the Administrator
incinerator, boiler, process
heater, or flare; or recovery
devices other than an absorber,
condenser, or carbon adsorber.
------------------------------------------------------------------------
\a\ Monitor may be installed in the firebox or in the ductwork
immediately downstream of the firebox before any substantial heat
exchange is encountered.
Sec. Table 3 to Subpart NNNa of Part 60--Operating Parameters, Operating
Parameter Limits and Data Monitoring, Recordkeeping and Compliance
Frequencies
----------------------------------------------------------------------------------------------------------------
You must And you must monitor, record, and demonstrate continuous
establish the compliance using these minimum frequencies . . .
For the operating parameter following -------------------------------------------------------------
applicable to you, as specified operating Data averaging
in table 2 parameter limit . Data measurement Data recording period for
. . compliance
----------------------------------------------------------------------------------------------------------------
Absorbers
----------------------------------------------------------------------------------------------------------------
1. Exit temperature of the Maximum Continuous............ Every 15 minutes. 3-hour block
absorbing liquid. temperature. average.
2. Exit specific gravity....... Exit specific Continuous............ Every 15 minutes. 3-hour block
gravity range. average.
----------------------------------------------------------------------------------------------------------------
[[Page 249]]
Boilers or process heaters
(with a design heat input capacity <44MW and vent stream is not introduced with or as the primary fuel)
----------------------------------------------------------------------------------------------------------------
3. Firebox temperature......... Minimum firebox Continuous............ Every 15 minutes. 3-hour block
temperature. average.
----------------------------------------------------------------------------------------------------------------
Catalytic incinerators
----------------------------------------------------------------------------------------------------------------
4. Temperature in gas stream Minimum Continuous............ Every 15 minutes. 3-hour block
immediately before the temperature. average.
catalyst bed.
5. Temperature difference Minimum Continuous............ Every 15 minutes. 3-hour block
between the catalyst bed inlet temperature average.
and the catalyst bed outlet. difference.
----------------------------------------------------------------------------------------------------------------
Carbon adsorbers
----------------------------------------------------------------------------------------------------------------
6. Total regeneration stream Minimum mass flow Continuously during Every 15 minutes Total flow for
mass flow during carbon bed during carbon regeneration. during each
regeneration cycle(s). bed regeneration regeneration regeneration
cycle(s). cycle. cycle.
7. Total regeneration stream Minimum Continuously during Every 15 minutes Total flow for
volumetric flow during carbon volumetric flow regeneration. during each
bed regeneration cycle(s). during carbon regeneration regeneration
bed regeneration cycle. cycle.
cycle(s).
8. Temperature of the carbon Maximum Continuously during Every 15 minutes Average of
bed after regeneration [and temperature of regeneration and for during regeneration
within 15 minutes of the carbon bed 15 minutes after regeneration cycle.
completing any cooling after completing any cycle (including
cycle(s)]. regeneration. cooling cycle(s). any cooling
cycle).
9. Breakthrough................ As defined in As required by Sec. Each monitoring N/A.
Sec. 60.661a. 60.663a(a)(6)(iii)(B). event.
----------------------------------------------------------------------------------------------------------------
Condensers
----------------------------------------------------------------------------------------------------------------
10. Exit (product side) Maximum Continuous............ Every 15 minutes. 3-hour block
temperature. temperature. average.
----------------------------------------------------------------------------------------------------------------
Scrubbers for halogenated vent streams
----------------------------------------------------------------------------------------------------------------
11. pH of scrubber effluent.... Minimum pH....... Continuous............ Every 15 minutes. 3-hour block
average.
12. Influent liquid flow....... Minimum inlet Continuous............ Every 15 minutes. 3-hour block
liquid flow. average.
13. Influent liquid flow rate Minimum influent Continuous............ Every 15 minutes. 3-hour block
and gas stream flow rate. liquid-to-gas average.
ratio.
----------------------------------------------------------------------------------------------------------------
Thermal incinerators
----------------------------------------------------------------------------------------------------------------
14. Firebox temperature........ Minimum firebox Continuous............ Every 15 minutes. 3-hour block
temperature. average.
----------------------------------------------------------------------------------------------------------------
Control devices other than an incinerator, boiler, process heater, or flare; or recovery devices other than an
absorber, condenser, or carbon adsorber
----------------------------------------------------------------------------------------------------------------
15. As specified by the 15. As specified 15. As specified by 15. As specified 15. As specified
Administrator. by the the Administrator. by the by the
Administrator. Administrator. Administrator.
----------------------------------------------------------------------------------------------------------------
[[Page 250]]
Sec. Table 4 to Subpart NNNa of Part 60--Calibration and Quality Control
Requirements for Continuous Parameter Monitoring System (CPMS)
------------------------------------------------------------------------
And your calibration
If you monitor this Your accuracy requirements are . .
parameter . . . requirements are . . .
.
------------------------------------------------------------------------
1. Temperature.............. a. 1 percent evaluation annually
over the normal and following any
range of period of more than
temperature 24 hours throughout
measured or 2.8 which the
degrees Celsius (5 temperature
degrees exceeded the
Fahrenheit), maximum rated
whichever is temperature of the
greater, for non- sensor, or the data
cryogenic recorder was off
temperature ranges. scale.
b. 2.5 percent inspections and
over the normal checks of CPMS
range of operation every 3
temperature months, unless the
measured or 2.8 CPMS has a
degrees Celsius (5 redundant
degrees temperature sensor.
Fahrenheit), e. Selection of a
whichever is representative
greater, for measurement
cryogenic location.
temperature ranges.
2. Flow Rate................ a. 5 percent evaluation annually
over the normal and following any
range of flow period of more than
measured or 1.9 24 hours throughout
liters per minute which the flow rate
(0.5 gallons per exceeded the
minute), whichever maximum rated flow
is greater, for rate of the sensor,
liquid flow rate. or the data
b. 5 percent scale.
over the normal e. Checks of all
range of flow mechanical
measured or 280 connections for
liters per minute leakage monthly.
(10 cubic feet per f. Visual
minute), whichever inspections and
is greater, for gas checks of CPMS
flow rate. operation every 3
c. 5 percent CPMS has a
over the normal redundant flow
range measured for sensor.
mass flow rate. g. Selection of a
representative
measurement
location where
swirling flow or
abnormal velocity
distributions due
to upstream and
downstream
disturbances at the
point of
measurement are
minimized.
3. pH....................... a. 0.2 pH evaluation
units. annually. Conduct a
two-point
calibration with
one of the two
buffer solutions
having a pH within
1 of the pH of the
operating limit.
c. Visual
inspections and
checks of CPMS
operation every 3
months, unless the
CPMS has a
redundant pH
sensor.
d. Select a
measurement
location that
provides a
representative
sample of scrubber
effluent and that
ensures the fluid
is properly mixed.
4. Specific Gravity......... a. 0.02 evaluation
specific gravity annually.
units. c. Visual
inspections and
checks of CPMS
operation every 3
months, unless the
CPMS has a
redundant specific
gravity sensor.
d. Select a
measurement
location that
provides a
representative
sample of specific
gravity of the
absorbing liquid
effluent and that
ensures the fluid
is properly mixed.
------------------------------------------------------------------------
Subpart OOO_Standards of Performance for Nonmetallic Mineral Processing
Plants
Source: 74 FR 19309, Apr. 28, 2009, 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 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; plants without
crushers or grinding mills above ground; and wet material processing
operations (as defined in Sec. 60.671).
[[Page 251]]
(b) An affected facility that is subject to the provisions of
subparts F or I of this part 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, and there is no increase in the
amount of emissions, the new facility is exempt from the provisions of
Sec. Sec. 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 Sec. Sec. 60.672, 60.674 and 60.675.
(e) An affected facility under paragraph (a) of this section that
commences construction, modification, or reconstruction 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 do not apply to owners and operators of affected
facilities subject to this subpart or that apply with certain
exceptions.
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 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 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.
Crush or Crushing means to reduce the size of nonmetallic mineral
material by means of physical impaction of the crusher or grinding mill
upon the material.
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
[[Page 252]]
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:
(1) Crushed and Broken Stone, including Limestone, Dolomite,
Granite, Traprock, Sandstone, Quartz, Quartzite, Marl, Marble, Slate,
Shale, Oil Shale, and Shell.
(2) Sand and Gravel.
(3) Clay including Kaolin, Fireclay, Bentonite, Fuller's Earth, Ball
Clay, and Common Clay.
(4) Rock Salt.
(5) Gypsum (natural or synthetic).
(6) Sodium Compounds, including Sodium Carbonate, Sodium Chloride,
and Sodium Sulfate.
(7) Pumice.
(8) Gilsonite.
(9) Talc and Pyrophyllite.
(10) Boron, including Borax, Kernite, and Colemanite.
(11) Barite.
(12) Fluorospar.
(13) Feldspar.
(14) Diatomite.
(15) Perlite.
(16) Vermiculite.
(17) Mica.
(18) 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.
Saturated material means, for purposes of this subpart, mineral
material with sufficient surface moisture such that particulate matter
emissions are not generated from processing of the material through
screening operations, bucket elevators and belt conveyors. Material that
is wetted solely by wet suppression systems is not considered to be
``saturated'' for purposes of this definition.
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). Grizzly feeders associated with truck dumping and
static (non-moving) grizzlies used anywhere in the nonmetallic mineral
processing plant are not considered to be screening operations.
Seasonal shut down means shut down of an affected facility for a
period of at least 45 consecutive days due to weather or seasonal market
conditions.
Size means the rated capacity in tons per hour of a crusher,
grinding mill,
[[Page 253]]
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) of
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 material processing operation(s) means any of the following:
(1) Wet screening operations (as defined in this section) and
subsequent screening operations, bucket elevators and belt conveyors in
the production line that process saturated materials (as defined in this
section) up to the first crusher, grinding mill or storage bin in the
production line; or
(2) Screening operations, bucket elevators and belt conveyors in the
production line downstream of wet mining operations (as defined in this
section) that process saturated materials (as defined in this section)
up to the first crusher, grinding mill or storage bin in the production
line.
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.
Sec. 60.672 Standard for particulate matter (PM).
(a) Affected facilities must meet the stack emission limits and
compliance requirements in Table 2 of this subpart 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 as
required under Sec. 60.8. The requirements in Table 2 of this subpart
apply for affected facilities with capture systems used to capture and
transport particulate matter to a control device.
(b) Affected facilities must meet the fugitive emission limits and
compliance requirements in Table 3 of this subpart 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 as
required under Sec. 60.11. The requirements in Table 3 of this subpart
apply for fugitive emissions from affected facilities without capture
systems and for fugitive emissions escaping capture systems.
(c) [Reserved]
(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) and (b) of this
section, or the building enclosing the affected facility or facilities
must comply with the following emission limits:
(1) Fugitive emissions from the building openings (except for vents
as defined in Sec. 60.671) must not exceed 7 percent opacity; and
(2) Vents (as defined in Sec. 60.671) in the building must meet the
applicable stack emission limits and compliance requirements in Table 2
of this subpart.
(f) Any baghouse that controls emissions from only an individual,
enclosed
[[Page 254]]
storage bin is exempt from the applicable stack PM concentration limit
(and associated performance testing) in Table 2 of this subpart but must
meet the applicable stack opacity limit and compliance requirements in
Table 2 of this subpart. This exemption from the stack PM concentration
limit does not apply for multiple storage bins with combined stack
emissions.
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 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.
(a) 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:
(1) 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.
(2) 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.
(b) The owner or operator of any affected facility for which
construction, modification, or reconstruction commenced on or after
April 22, 2008, that uses wet suppression to control emissions from the
affected facility must perform monthly periodic inspections to check
that water is flowing to discharge spray nozzles in the wet suppression
system. The owner or operator must initiate corrective action within 24
hours and complete corrective action as expediently as practical if the
owner or operator finds that water is not flowing properly during an
inspection of the water spray nozzles. The owner or operator must record
each inspection of the water spray nozzles, including the date of each
inspection and any corrective actions taken, in the logbook required
under Sec. 60.676(b).
(1) If an affected facility relies on water carryover from upstream
water sprays to control fugitive emissions, then that affected facility
is exempt from the 5-year repeat testing requirement specified in Table
3 of this subpart provided that the affected facility meets the criteria
in paragraphs (b)(1)(i) and (ii) of this section:
(i) The owner or operator of the affected facility conducts periodic
inspections of the upstream water spray(s) that are responsible for
controlling fugitive emissions from the affected facility. These
inspections are conducted according to paragraph (b) of this section and
Sec. 60.676(b), and
(ii) The owner or operator of the affected facility designates which
upstream water spray(s) will be periodically inspected at the time of
the initial performance test required under Sec. 60.11 of this part and
Sec. 60.675 of this subpart.
(2) If an affected facility that routinely uses wet suppression
water sprays ceases operation of the water sprays or is using a control
mechanism to reduce fugitive emissions other than water sprays during
the monthly inspection (for example, water from recent rainfall), the
logbook entry required under Sec. 60.676(b) must specify the control
mechanism being used instead of the water sprays.
(c) Except as specified in paragraph (d) or (e) of this section, the
owner or operator of any affected facility for
[[Page 255]]
which construction, modification, or reconstruction commenced on or
after April 22, 2008, that uses a baghouse to control emissions must
conduct quarterly 30-minute visible emissions inspections using EPA
Method 22 (40 CFR part 60, appendix A-7). The Method 22 (40 CFR part 60,
appendix A-7) test shall be conducted while the baghouse is operating.
The test is successful if no visible emissions are observed. If any
visible emissions are observed, the owner or operator of the affected
facility must initiate corrective action within 24 hours to return the
baghouse to normal operation. The owner or operator must record each
Method 22 (40 CFR part 60, appendix A-7) test, including the date and
any corrective actions taken, in the logbook required under Sec.
60.676(b). The owner or operator of the affected facility may establish
a different baghouse-specific success level for the visible emissions
test (other than no visible emissions) by conducting a PM performance
test according to Sec. 60.675(b) simultaneously with a Method 22 (40
CFR part 60, appendix A-7) to determine what constitutes normal visible
emissions from that affected facility's baghouse when it is in
compliance with the applicable PM concentration limit in Table 2 of this
subpart. The revised visible emissions success level must be
incorporated into the permit for the affected facility.
(d) As an alternative to the periodic Method 22 (40 CFR part 60,
appendix A-7) visible emissions inspections specified in paragraph (c)
of this section, the owner or operator of any affected facility for
which construction, modification, or reconstruction commenced on or
after April 22, 2008, that uses a baghouse to control emissions may use
a bag leak detection system. The owner or operator must install,
operate, and maintain the bag leak detection system according to
paragraphs (d)(1) through (3) of this section.
(1) Each bag leak detection system must meet the specifications and
requirements in paragraphs (d)(1)(i) through (viii) of this section.
(i) The bag leak detection system must be certified by the
manufacturer to be capable of detecting PM emissions at concentrations
of 1 milligram per dry standard cubic meter (0.00044 grains per actual
cubic foot) or less.
(ii) The bag leak detection system sensor must provide output of
relative PM loadings. The owner or operator shall continuously record
the output from the bag leak detection system using electronic or other
means (e.g., using a strip chart recorder or a data logger).
(iii) The bag leak detection system must be equipped with an alarm
system that will sound when the system detects an increase in relative
particulate loading over the alarm set point established according to
paragraph (d)(1)(iv) of this section, and the alarm must be located such
that it can be heard by the appropriate plant personnel.
(iv) In the initial adjustment of the bag leak detection system, the
owner or operator must establish, at a minimum, the baseline output by
adjusting the sensitivity (range) and the averaging period of the
device, the alarm set points, and the alarm delay time.
(v) Following initial adjustment, the owner or operator shall not
adjust the averaging period, alarm set point, or alarm delay time
without approval from the Administrator or delegated authority except as
provided in paragraph (d)(1)(vi) of this section.
(vi) Once per quarter, the owner or operator may adjust the
sensitivity of the bag leak detection system to account for seasonal
effects, including temperature and humidity, according to the procedures
identified in the site-specific monitoring plan required by paragraph
(d)(2) of this section.
(vii) The owner or operator must install the bag leak detection
sensor downstream of the fabric filter.
(viii) Where multiple detectors are required, the system's
instrumentation and alarm may be shared among detectors.
(2) The owner or operator of the affected facility must develop and
submit to the Administrator or delegated authority for approval of a
site-specific monitoring plan for each bag leak detection system. The
owner or operator must operate and maintain the bag leak detection
system according to the site-specific monitoring plan at all
[[Page 256]]
times. Each monitoring plan must describe the items in paragraphs
(d)(2)(i) through (vi) of this section.
(i) Installation of the bag leak detection system;
(ii) Initial and periodic adjustment of the bag leak detection
system, including how the alarm set-point will be established;
(iii) Operation of the bag leak detection system, including quality
assurance procedures;
(iv) How the bag leak detection system will be maintained, including
a routine maintenance schedule and spare parts inventory list;
(v) How the bag leak detection system output will be recorded and
stored; and
(vi) Corrective action procedures as specified in paragraph (d)(3)
of this section. In approving the site-specific monitoring plan, the
Administrator or delegated authority may allow owners and operators more
than 3 hours to alleviate a specific condition that causes an alarm if
the owner or operator identifies in the monitoring plan this specific
condition as one that could lead to an alarm, adequately explains why it
is not feasible to alleviate this condition within 3 hours of the time
the alarm occurs, and demonstrates that the requested time will ensure
alleviation of this condition as expeditiously as practicable.
(3) For each bag leak detection system, the owner or operator must
initiate procedures to determine the cause of every alarm within 1 hour
of the alarm. Except as provided in paragraph (d)(2)(vi) of this
section, the owner or operator must alleviate the cause of the alarm
within 3 hours of the alarm by taking whatever corrective action(s) are
necessary. Corrective actions may include, but are not limited to the
following:
(i) Inspecting the fabric filter for air leaks, torn or broken bags
or filter media, or any other condition that may cause an increase in PM
emissions;
(ii) Sealing off defective bags or filter media;
(iii) Replacing defective bags or filter media or otherwise
repairing the control device;
(iv) Sealing off a defective fabric filter compartment;
(v) Cleaning the bag leak detection system probe or otherwise
repairing the bag leak detection system; or
(vi) Shutting down the process producing the PM emissions.
(e) As an alternative to the periodic Method 22 (40 CFR part 60,
appendix A-7) visible emissions inspections specified in paragraph (c)
of this section, the owner or operator of any affected facility that is
subject to the requirements for processed stone handling operations in
the Lime Manufacturing NESHAP (40 CFR part 63, subpart AAAAA) may follow
the continuous compliance requirements in row 1 items (i) through (iii)
of table 6 to subpart AAAAA of 40 CFR part 63.
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 appendices A-1 through A-7 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 PM
standards in Sec. 60.672(a) as follows:
(1) Except as specified in paragraphs (e)(3) and (4) of this
section, Method 5 of appendix A-3 of this part or Method 17 of appendix
A-6 of this part shall be used to determine the particulate matter
concentration. The sample volume shall be at least 1.70 dscm (60 dscf).
For Method 5 (40 CFR part 60, appendix A-3), 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 of appendix A-4 of this part 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) or Sec. 60.672(e)(1), the owner or
operator shall use Method 9 of appendix
[[Page 257]]
A-4 of this part 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 of
appendix A-4 of this part, 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)(i) 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 (40 CFR part 60, appendix A-4), the duration of the Method 9 (40 CFR
part 60, appendix A-4) observations shall be 1 hour (ten 6-minute
averages).
(ii) The duration of the Method 9 (40 CFR part 60, appendix A-4)
observations may be reduced to the duration the affected facility
operates (but not less than 30 minutes) for baghouses that control
storage bins or enclosed truck or railcar loading stations that operate
for less than 1 hour at a time.
(3) When determining compliance with the fugitive emissions standard
for any affected facility described under Sec. 60.672(b) or Sec.
60.672(e)(1) of this subpart, the duration of the Method 9 (40 CFR part
60, appendix A-4) observations must be 30 minutes (five 6-minute
averages). Compliance with the applicable fugitive emission limits in
Table 3 of this subpart must be based on the average of the five 6-
minute averages.
(d) To demonstrate compliance with the fugitive emission limits for
buildings specified in Sec. 60.672(e)(1), the owner or operator must
complete the testing specified in paragraph (d)(1) and (2) of this
section. Performance tests must be conducted while all affected
facilities inside the building are operating.
(1) If the building encloses any affected facility that commences
construction, modification, or reconstruction on or after April 22,
2008, the owner or operator of the affected facility must conduct an
initial Method 9 (40 CFR part 60, appendix A-4) performance test
according to this section and Sec. 60.11.
(2) If the building encloses only affected facilities that commenced
construction, modification, or reconstruction before April 22, 2008, and
the owner or operator has previously conducted an initial Method 22 (40
CFR part 60, appendix A-7) performance test showing zero visible
emissions, then the owner or operator has demonstrated compliance with
the opacity limit in Sec. 60.672(e)(1). If the owner or operator has
not conducted an initial performance test for the building before April
22, 2008, then the owner or operator must conduct an initial Method 9
(40 CFR part 60, appendix A-4) performance test according to this
section and Sec. 60.11 to show compliance with the opacity limit in
Sec. 60.672(e)(1).
(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.
(2) A single visible emission observer may conduct visible emission
observations for up to three fugitive, stack, or vent emission points
within a 15-second interval if the following conditions are met:
(i) No more than three emission points may be read concurrently.
[[Page 258]]
(ii) All three emission points must be within a 70 degree viewing
sector or angle in front of the observer such that the proper sun
position can be maintained for all three points.
(iii) If an opacity reading for any one of the three emission points
equals or exceeds the applicable standard, then the observer must stop
taking readings for the other two points and continue reading just that
single point.
(3) Method 5I of appendix A-3 of this part may be used to determine
the PM concentration as an alternative to the methods specified in
paragraph (b)(1) of this section. Method 5I (40 CFR part 60, appendix A-
3) may be useful for affected facilities that operate for less than 1
hour at a time such as (but not limited to) storage bins or enclosed
truck or railcar loading stations.
(4) In some cases, velocities of exhaust gases from building vents
may be too low to measure accurately with the type S pitot tube
specified in EPA Method 2 of appendix A-1 of this part [i.e., velocity
head <1.3 mm H2O (0.05 in. H2O)] and referred to
in EPA Method 5 of appendix A-3 of this part. For these conditions, the
owner or operator may determine the average gas flow rate produced by
the power fans (e.g., from vendor-supplied fan curves) to the building
vent. The owner or operator may calculate the average gas velocity at
the building vent measurement site using Equation 1 of this section and
use this average velocity in determining and maintaining isokinetic
sampling rates.
[GRAPHIC] [TIFF OMITTED] TR28AP09.007
Where:
Ve = average building vent velocity (feet per minute);
Qf = average fan flow rate (cubic feet per minute); and
Ae = area of building vent and measurement location (square
feet).
(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)(1) and (2) during each
particulate matter run and shall determine the averages.
(g) For performance tests involving only Method 9 (40 CFR part 60
appendix A-4) testing, the owner or operator may reduce the 30-day
advance notification of performance test in Sec. 60.7(a)(6) and 60.8(d)
to a 7-day advance notification.
(h) [Reserved]
(i) If the initial performance test date for an affected facility
falls during a seasonal shut down (as defined in Sec. 60.671 of this
subpart) of the affected facility, then with approval from the
permitting authority, the owner or operator may postpone the initial
performance test until no later than 60 calendar days after resuming
operation of the affected facility.
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 megagrams or 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 megagrams or tons of the existing storage
bin being replaced and
(ii) The rated capacity in megagrams or tons of replacement storage
bins.
(b)(1) Owners or operators of affected facilities (as defined in
Sec. Sec. 60.670 and 60.671) for which construction, modification, or
reconstruction commenced on or after April 22, 2008, must record each
periodic inspection required under
[[Page 259]]
Sec. 60.674(b) or (c), including dates and any corrective actions
taken, in a logbook (in written or electronic format). The owner or
operator must keep the logbook onsite and make hard or electronic copies
(whichever is requested) of the logbook available to the Administrator
upon request.
(2) For each bag leak detection system installed and operated
according to Sec. 60.674(d), the owner or operator must keep the
records specified in paragraphs (b)(2)(i) through (iii) of this section.
(i) Records of the bag leak detection system output;
(ii) Records of bag leak detection system adjustments, including the
date and time of the adjustment, the initial bag leak detection system
settings, and the final bag leak detection system settings; and
(iii) The date and time of all bag leak detection system alarms, the
time that procedures to determine the cause of the alarm were initiated,
the cause of the alarm, an explanation of the actions taken, the date
and time the cause of the alarm was alleviated, and whether the cause of
the alarm was alleviated within 3 hours of the alarm.
(3) The owner or operator of each affected facility demonstrating
compliance according to Sec. 60.674(e) by following the requirements
for processed stone handling operations in the Lime Manufacturing NESHAP
(40 CFR part 63, subpart AAAAA) must maintain records of visible
emissions observations required by Sec. 63.7132(a)(3) and (b) of 40 CFR
part 63, subpart AAAAA.
(c) During the initial performance test of a wet scrubber, and daily
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.
(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 and
liquid flow rate decrease by more than 30 percent from the average
determined during the most recent performance test.
(e) The reports required under paragraph (d) of this section 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 (40 CFR part 60, appendix A-4) to demonstrate compliance with
Sec. 60.672(b), (e) and (f).
(g) The owner or operator of any wet material processing operation
that processes saturated and subsequently processes unsaturated
materials, shall submit a report of this change within 30 days following
such change. At the time of such change, this screening operation,
bucket elevator, or belt conveyor becomes subject to the applicable
opacity limit in Sec. 60.672(b) and the emission test requirements of
Sec. 60.11.
(h) The subpart A requirement under Sec. 60.7(a)(1) for
notification of the date construction or reconstruction commenced is
waived for affected facilities 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
[[Page 260]]
obligation to comply with the reporting requirements of this section,
provided that they comply with requirements established by the State.
(k) Notifications and reports required under this subpart and under
subpart A of this part to demonstrate compliance with this subpart need
only to be sent to the EPA Region or the State which has been delegated
authority according to Sec. 60.4(b).
Sec. Table 1 to Subpart OOO of Part 60--Exceptions to Applicability of
Subpart A to Subpart OOO
------------------------------------------------------------------------
Applies to
Subpart A reference subpart OOO Explanation
------------------------------------------------------------------------
60.4, Address................. Yes.............. Except in Sec.
60.4(a) and (b)
submittals need not
be submitted to both
the EPA Region and
delegated State
authority (Sec.
60.676(k)).
60.7, Notification and Yes.............. Except in (a)(1)
recordkeeping. notification of the
date construction or
reconstruction
commenced (Sec.
60.676(h)).
Also, except in
(a)(6) performance
tests involving only
Method 9 (40 CFR
part 60, appendix A-
4) require a 7-day
advance notification
instead of 30 days
(Sec. 60.675(g)).
60.8, Performance tests....... Yes.............. Except in (d)
performance tests
involving only
Method 9 (40 CFR
part 60, appendix A-
4) require a 7-day
advance notification
instead of 30 days
(Sec. 60.675(g)).
60.11, Compliance with Yes.............. Except in (b) under
standards and maintenance certain conditions
requirements. (Sec. Sec.
60.675(c)), Method 9
(40 CFR part 60,
appendix A-4)
observation is
reduced from 3 hours
to 30 minutes for
fugitive emissions.
60.18, General control device. No............... Flares will not be
used to comply with
the emission limits.
------------------------------------------------------------------------
Sec. Table 2 to Subpart OOO of Part 60--Stack Emission Limits for
Affected Facilities With Capture Systems
----------------------------------------------------------------------------------------------------------------
The owner or operator
The owner or operator And the owner or must demonstrate
For * * * must meet a PM limit of operator must meet an compliance with these
* * * opacity limit of * * * limits by conducting *
* *
----------------------------------------------------------------------------------------------------------------
Affected facilities (as defined in 0.05 g/dscm (0.022 gr/ 7 percent for dry An initial performance
Sec. Sec. 60.670 and 60.671) that dscf) \a\. control devices \b\. test according to Sec.
commenced construction, 60.8 of this part
modification, or reconstruction and Sec. 60.675 of
after August 31, 1983 but before this subpart; and
April 22, 2008. Monitoring of wet
scrubber parameters
according to Sec.
60.674(a) and Sec.
60.676(c), (d), and
(e).
Affected facilities (as defined in 0.032 g/dscm (0.014 gr/ Not applicable (except An initial performance
Sec. Sec. 60.670 and 60.671) that dscf) \a\. for individual test according to Sec.
commence construction, modification, enclosed storage bins). 60.8 of this part
or reconstruction on or after April 7 percent for dry and Sec. 60.675 of
22, 2008. control devices on this subpart; and
individual enclosed Monitoring of wet
storage bins. scrubber parameters
according to Sec.
60.674(a) and Sec.
60.676(c), (d), and
(e); and
Monitoring of baghouses
according to Sec.
60.674(c), (d), or (e)
and Sec. 60.676(b).
----------------------------------------------------------------------------------------------------------------
\a\ Exceptions to the PM limit apply for individual enclosed storage bins and other equipment. See Sec.
60.672(d) through (f).
\b\ The stack opacity limit and associated opacity testing requirements do not apply for affected facilities
using wet scrubbers.
[[Page 261]]
Sec. Table 3 to Subpart OOO of Part 60--Fugitive Emission Limits
----------------------------------------------------------------------------------------------------------------
The owner or operator
must meet the following
fugitive emissions
limit for grinding
mills, screening
operations, bucket
elevators, transfer The owner or operator The owner or operator
points on belt must meet the following must demonstrate
For * * * conveyors, bagging fugitive emissions compliance with these
operations, storage limit for crushers at limits by conducting *
bins, enclosed truck or which a capture system * *
railcar loading is not used * * *
stations or from any
other affected facility
(as defined in Sec.
Sec. 60.670 and
60.671) * * *
----------------------------------------------------------------------------------------------------------------
Affected facilities (as defined in 10 percent opacity..... 15 percent opacity..... An initial performance
Sec. Sec. 60.670 and 60.671) that test according to Sec.
commenced construction, 60.11 of this part
modification, or reconstruction and Sec. 60.675 of
after August 31, 1983 but before this subpart.
April 22, 2008.
Affected facilities (as defined in 7 percent opacity...... 12 percent opacity..... An initial performance
Sec. Sec. 60.670 and 60.671) that test according to Sec.
commence construction, modification, 60.11 of this part
or reconstruction on or after April and Sec. 60.675 of
22, 2008. this subpart; and
Periodic inspections of
water sprays according
to Sec. 60.674(b)
and Sec. 60.676(b);
and
A repeat performance
test according to Sec.
60.11 of this part
and Sec. 60.675 of
this subpart within 5
years from the
previous performance
test for fugitive
emissions from
affected facilities
without water sprays.
Affected facilities
controlled by water
carryover from
upstream water sprays
that are inspected
according to the
requirements in Sec.
Sec. 60.674(b) and
60.676(b) are exempt
from this 5-year
repeat testing
requirement.
----------------------------------------------------------------------------------------------------------------
Subpart PPP_Standard of Performance for Wool Fiberglass Insulation
Manufacturing Plants
Source: 50 FR 7699, Feb. 25, 1985, unless otherwise noted.