[Federal Register Volume 68, Number 197 (Friday, October 10, 2003)]
[Proposed Rules]
[Pages 58838-58866]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 03-24909]



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Part IV





Environmental Protection Agency





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40 CFR Part 60



Update of Continuous Instrumental Test Methods; Proposed Rule

  Federal Register / Vol. 68, No. 197 / Friday, October 10, 2003 / 
Proposed Rules  

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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 60

[OAR-2002-0071; FRL-7566-8]
RIN 2060-AG21


Update of Continuous Instrumental Test Methods

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed rule.

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SUMMARY: We, the Environmental Protection Agency, are proposing to 
amend five instrumental test methods that are used to measure air 
pollutant emissions from stationary sources. The intended effect of 
this rule is to harmonize, simplify, and update the test methods. The 
methods were originally developed for specific industry applications 
but have since been adapted to general testing applications. These 
proposed revisions would remove inconsistencies in equipment and 
performance specifications so each method would be similar in these 
respects and have expanded applicability. We are also proposing to add 
helpful calculation procedures, quality assurance recommendations, and 
provisions for sampling at low concentrations. A large number of 
industries are already subject to the provisions requiring the use of 
these methods. Some of the affected industries and their Standard 
Industrial Classification codes are listed under SUPPLEMENTARY 
INFORMATION.

DATES: Comments: Submit comments on or before December 9, 2003.
    Public Hearing: If anyone contacts us requesting to speak at a 
public hearing by October 27, 2003, we will hold a public hearing on 
November 10, 2003.

ADDRESSES: Comments. Comments may be submitted electronically, by mail, 
by facsimile, or through hand delivery/courier. Follow the detailed 
instructions as provided in Unit I.C. of the SUPPLEMENTARY INFORMATION. 
By U.S. Postal Service, send comments (in duplicate, if possible) to: 
Air and Radiation Docket and Information Center (6102), Attention 
Docket Number OAR-2002-0071, U.S. Environmental Protection Agency, 1200 
Pennsylvania Avenue, NW., Washington, DC 20460. In person or by 
courier, deliver comments (in duplicate if possible) to: EPA Docket 
Center, Attention Docket ID No. OAR-2002-0071, EPA West, Room 108, 1301 
Constitution Ave., NW., Washington, DC 20460. We request that a 
separate copy also be sent to the contact person listed below (see FOR 
FURTHER INFORMATION CONTACT).
    Public Hearing. If a public hearing is held, it will be held at 10 
a.m. in the EPA Auditorium, Research Triangle Park, North Carolina, or 
at an alternate site nearby.
    Docket. Docket No. OAR-2002-0071, contains information relevant to 
this rule. You can read and copy it between 8:30 a.m. and 5:30 p.m., 
Monday through Friday, (except for Federal holidays), at the U.S. 
Environmental Protection Agency, EPA Docket Center, EPA West, Room 108, 
1301 Constitution Ave., Washington, DC 20004; telephone (202) 566-1742. 
The docket office may charge a reasonable fee for copying.

FOR FURTHER INFORMATION CONTACT: Foston Curtis or Terry Harrison, 
Emission Measurement Center, Mail Code D205-02, Emissions, Monitoring, 
and Analysis Division, U.S. Environmental Protection Agency, Research 
Triangle Park, North Carolina 27711; telephone (919) 541-1063 or 5233; 
facsimile number (919) 541-0516; electronic mail address 
[email protected] or [email protected].

SUPPLEMENTARY INFORMATION:

I. General Information

A. Affected Entities

    Entities potentially affected by this action include those listed 
in Table 1.

         Table 1.--Entities Potentially Affected by This Action
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        Examples of regulated entities           SIC codes   NAICS codes
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Fossil Fuel-Fired Steam Generators............        3569        332410
Industrial, Commercial, Institutional Steam           3569        332410
 Generating Units.............................
Municipal Waste Combustors....................        3567        562213
Hospital, Medical, Infectious Waste                   3567        562211
 Incinerators.................................
Petroleum Refineries..........................        2911        324110
Stationary Gas Turbines.......................        3511        333611
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    This table is not intended to be exhaustive, but rather provides a 
guide for readers regarding entities likely to be affected by this 
action. If you have any questions regarding the applicability of this 
action to a particular entity, consult the person listed in the 
preceding FOR FURTHER INFORMATION CONTACT section.

B. How Can I Get Copies of This Document and Other Related Information?

    1. Docket. EPA has established an official public docket for this 
action under Docket ID No. OAR-2002-0071. The official public docket 
consists of the documents specifically referenced in this action, any 
public comments received, and other information related to this action. 
Although a part of the official docket, the public docket does not 
include Confidential Business Information (CBI) or other information 
whose disclosure is restricted by statute. The official public docket 
is the collection of materials that is available for public viewing at 
the EPA Docket Center, (EPA/DC) EPA West, Room 108, 1301 Constitution 
Ave., NW., Washington, DC 20460; telephone (202) 566-1742. The EPA 
Docket Center Public Reading Room is open from 8:30 a.m. to 4:30 p.m., 
Monday through Friday, excluding legal holidays. The telephone number 
for the Reading Room is (202) 566-1742.
    2. Electronic Access. You may access this Federal Register document 
electronically through the EPA Internet under the Federal Register 
listings at http://www.epa.gov/fedrgstr/.
    An electronic version of the public docket is available through 
EPA's electronic public docket and comment system, EPA Dockets. You may 
use EPA Dockets at http://www.epa.gov/edocket/ to submit or view public 
comments, access the index listing of the contents of the official 
public docket, and to access those documents in the public docket that 
are available electronically. Once in the system, select ``search,'' 
then key in the appropriate docket identification number.
    Certain types of information will not be placed in the EPA Dockets. 
Information claimed as CBI and other information whose disclosure is 
restricted by statute, which is not included in the official public 
docket, will not be available for public viewing in EPA's electronic 
public docket. EPA's

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policy is that copyrighted material will not be placed in EPA's 
electronic public docket but will be available only in printed, paper 
form in the official public docket. To the extent feasible, publicly 
available docket materials will be made available in EPA's electronic 
public docket. When a document is selected from the index list in EPA 
Dockets, the system will identify whether the document is available for 
viewing in EPA's electronic public docket. Although not all docket 
materials may be available electronically, you may still access any of 
the publicly available docket materials through the docket facility 
identified in Unit I.B.
    For public commenters, it is important to note that EPA's policy is 
that public comments, whether submitted electronically or on paper, 
will be made available for public viewing in EPA's electronic public 
docket as EPA receives them and without change, unless the comment 
contains copyrighted material, CBI, or other information whose 
disclosure is restricted by statute. When EPA identifies a comment 
containing copyrighted material, EPA will provide a reference to that 
material in the version of the comment that is placed in EPA's 
electronic public docket. The entire printed comment, including the 
copyrighted material, will be available in the public docket.
    Public comments submitted on computer disks that are mailed or 
delivered to the docket will be transferred to EPA's electronic public 
docket. Public comments that are mailed or delivered to the Docket will 
be scanned and placed in EPA's electronic public docket. Where 
practical, physical objects will be photographed, and the photograph 
will be placed in EPA's electronic public docket along with a brief 
description written by the docket staff.
    For additional information about EPA's electronic public docket, 
visit EPA Dockets online or see 67 FR 38102, May 31, 2002.

C. How and To Whom Do I Submit Comments?

    You may submit comments electronically, by mail, by facsimile, or 
through hand delivery/courier. To ensure proper receipt by EPA, 
identify the appropriate docket identification number in the subject 
line on the first page of your comment. Please ensure that your 
comments are submitted within the specified comment period. Comments 
received after the close of the comment period will be marked ``late.'' 
EPA is not required to consider these late comments. However, late 
comments may be considered if time permits.
    1. Electronically. If you submit an electronic comment as 
prescribed below, EPA recommends that you include your name, mailing 
address, and an e-mail address or other contact information in the body 
of your comment. Also include this contact information on the outside 
of any disk or CD-ROM you submit, and in any cover letter accompanying 
the disk or CD-ROM. This ensures that you can be identified as the 
submitter of the comment and allows EPA to contact you in case EPA 
cannot read your comment due to technical difficulties or needs further 
information on the substance of your comment. EPA's policy is that EPA 
will not edit your comment, and any identifying or contact information 
provided in the body of a comment will be included as part of the 
comment that is placed in the official public docket, and made 
available in EPA's electronic public docket. If EPA cannot read your 
comment due to technical difficulties and cannot contact you for 
clarification, EPA may not be able to consider your comment.
    i. EPA Dockets. Your use of EPA's electronic public docket to 
submit comments to EPA electronically is EPA's preferred method for 
receiving comments. Go directly to EPA Dockets at http://www.epa.gov/edocket, and follow the online instructions for submitting comments. To 
access EPA's electronic public docket from the EPA Internet Home Page, 
select ``Information Sources,'' ``Dockets,'' and ``EPA Dockets.'' Once 
in the system, select ``search,'' and then key in Docket ID No. OAR-
2002-0071. The system is an ``anonymous access'' system, which means 
EPA will not know your identity, e-mail address, or other contact 
information unless you provide it in the body of your comment.
    ii. E-mail. Comments may be sent by electronic mail (e-mail) to [email protected], Attention Docket ID No. OAR-2002-0071. In 
contrast to EPA's electronic public docket, EPA's e-mail system is not 
an ``anonymous access'' system. If you send an e-mail comment directly 
to the Docket without going through EPA's electronic public docket, 
EPA's e-mail system automatically captures your e-mail address. E-mail 
addresses that are automatically captured by EPA's e-mail system are 
included as part of the comment that is placed in the official public 
docket and made available in EPA's electronic public docket.
    iii. Disk or CD-ROM. You may submit comments on a disk or CD-ROM 
that you mail to the mailing address identified in Unit I.C.2. These 
electronic submissions will be accepted in WordPerfect or ASCII file 
format. Avoid the use of special characters and any form of encryption.
    2. By Mail. Send duplicate copies of your comments to: ``Update of 
Continuous Instrumental Test Methods,'' Environmental Protection 
Agency, Mail Code 6102T, 1200 Pennsylvania Ave., NW., Washington, DC, 
20460, Attention Docket ID No. OAR-2002-0071.
    3. By Hand Delivery or Courier. Deliver your comments to: EPA 
Docket Center, EPA West, Room 108, 1301 Constitution Ave., NW., 
Washington, DC 20460, Attention Docket ID No. OAR-2002-0071. Such 
deliveries are only accepted during the Docket's normal hours of 
operation as identified in Unit I.B.1.
    4. By Facsimile. Fax your comments to: 202-566-1741, Attention 
Docket ID No. OAR-2002-0071.

D. How Should I Submit CBI to the Agency?

    Do not submit information that you consider to be CBI 
electronically through EPA's electronic public docket or by e-mail. 
Only send or deliver information identified as CBI to the docket 
address to the attention of Docket ID No. OAR-2002-0071. You may claim 
information that you submit to EPA as CBI by marking any part or all of 
that information as CBI (if you submit CBI on disk or CD-ROM, mark the 
outside of the disk or CD-ROM as CBI and then identify electronically 
within the disk or CD-ROM the specific information that is CBI). 
Information so marked will not be disclosed except in accordance with 
procedures set forth in 40 CFR part 2.
    In addition to one complete version of the comment that includes 
any information claimed as CBI, a copy of the comment that does not 
contain the information claimed as CBI must be submitted for inclusion 
in the public docket and EPA's electronic public docket. If you submit 
the copy that does not contain CBI on disk or CD-ROM, mark the outside 
of the disk or CD-ROM clearly that it does not contain CBI. Information 
not marked as CBI will be included in the public docket and EPA's 
electronic public docket without prior notice. If you have any 
questions about CBI or the procedures for claiming CBI, please consult 
the person identified in the FOR FURTHER INFORMATION CONTACT section.

[[Page 58840]]

E. What Should I Consider as I Prepare My Comments for EPA?

    You may find the following suggestions helpful for preparing your 
comments:
    1. Explain your views as clearly as possible.
    2. Describe any assumptions that you used.
    3. Provide any technical information and/or data you used that 
support your views.
    4. If you estimate potential burden or costs, explain how you 
arrived at your estimate.
    5. Provide specific examples to illustrate your concerns.
    6. Offer alternatives.
    7. Make sure to submit your comments by the comment period deadline 
identified.
    8. To ensure proper receipt by EPA, identify the appropriate docket 
identification number in the subject line on the first page of your 
response. It would also be helpful if you provided the name, date, and 
Federal Register citation related to your comments.
Background
    Methods 3A, 6C, 7E, 10, and 20 are instrumental test methods for 
determining diluent (oxygen and carbon dioxide), sulfur dioxide, 
nitrogen oxides, and carbon monoxide emissions from stationary sources. 
The methods were developed for boilers, electric utility plants, 
refinery catalytic cracking catalyst regenerators, and gas turbines 
covered under the New Source Performance Standards (NSPS) in 40 CFR 
part 60. They were later adopted into the Acid Rain regulations and 
State and regional programs. The test methods were not developed at the 
same time and do not contain consistent equipment and performance 
requirements. Currently, some methods require more up-to-date equipment 
than others and some have more stringent performance requirements than 
others. These dissimilarities have hampered the current trend of using 
the methods together in the field. We are proposing to make collective 
changes that would render the methods easier to use by harmonizing 
their requirements. This would also update obsolete requirements and 
add flexibility by allowing alternatives to various equipment and 
performance specifications. The revisions we are proposing to the data 
reduction procedures would increase the certainty of the generated 
data.
    On August 27, 1997 (62 FR 45369), many of the updates of this 
action were proposed with a larger action that amended the stationary 
source testing and monitoring rules in 40 CFR parts 60, 61, and 63. In 
that proposal, minor revisions and updates were made and all test 
methods and performance specifications were revised into the new 
Environmental Monitoring Management Council (EMMC) format. Several 
commenters asserted that the preamble gave inadequate notice of the 
changes we were making to the instrumental methods. They argued that 
the proposal provided an inadequate basis and purpose statement and 
that it misled readers into thinking that no substantive changes were 
being made to the methods. Due to the large number of changes we were 
making in the regulations at that time, and in light of the section 
307(d) requirements, the commenters requested that we address the 
instrumental method revisions through a separate proposal and not 
promulgate them with the rest of that package.
    We agreed with these commenters concerns and stated our intention 
in the final rule [65 FR 61744] to repropose the revisions to the 
instrumental methods as a separate rule. In today's notice, we are 
proposing to revise equipment and procedures in the instrumental 
methods where appropriate to make their requirements consistent. We are 
also rewriting the methods in EMMC format. We have considered the 
comments we received pertinent to these methods in the August 27 
proposal and are summarizing the major ones in this preamble. We will 
formally address all significant relevant comments from the first 
proposal in the final notice of these amendments.
    Outline. The information presented in this preamble is organized as 
follows:

I. Why Are These Amendments Being Made to the Instrumental Methods?
II. What Changes Are Being Proposed to the Methods?
III. What Major Comments From the Previous Proposal are Pertinent to 
This Reproposal?
IV. What Statutory and Executive Orders Apply to This Rule?

I. Why Are These Amendments Being Proposed?

    Amendments to Methods 3A, 6C, 7E, 10, and 20 are needed to update 
their performance requirements to state-of-the-art levels, remove 
obsolete specifications, harmonize similar requirements, and simplify 
to enhance their utility and reduce the costs of testing.

II. What Changes Are Being Proposed to the Methods?

    We are proposing that Methods 3A, 6C, 7E, 10, and 20 in appendix A 
of 40 CFR 60 be revised to: (1) Make their equipment specifications and 
procedures as similar as possible to make them easier to use together 
in the field, (2) remove obsolete procedures and equipment listings, 
(3) add alternative performance tests, and (4) change their outline to 
conform with the standard EMMC format. We are proposing to base the 
analyzer calibration error on a percentage of the manufacturer 
certified gas value and the sampling system bias on a percentage of the 
applicable emission standard (except in Method 3A) instead of the span. 
For Method 3A, we are basing the tests on a percentage of the analyzer 
range. For the current bias test, the span may be chosen over a range 
of values instead of being a prescribed value. Under this allowance, 
the higher the span chosen for a test, the easier the performance 
criterion is met. We are proposing to base the bias test on a fixed 
value (the emission standard) to eliminate nonuniformity in stringency 
based on the tester's choice of a span. The calibration drift test that 
is currently required before and after each run would be dropped. We 
feel the bias test is a good enough indicator of analytical drift. We 
are also proposing to redefine the span as the highest concentration of 
the calibration curve (equivalent to the high-level calibration gas 
value).
    The requirements of Method 10 would be modernized by upgrading many 
of its requirements to the current level of Methods 3A, 6C, and 7E. The 
analyzer calibration error test, sampling system bias test, and the 
calibration gases now required in Methods 3A, 6C, and 7E are being 
proposed for Method 10.
    Methods 3A, 6C, and 10 are being proposed as abbreviated methods 
that reference Method 7E for much of the detail. Method 7E is being 
proposed as the full-length descriptive method. To remove the testing 
duplication between Method 20 and other methods, Method 20 would 
reference Methods 3A and 6C for diluent and sulfur dioxide 
measurements. The equations in Method 20 for concentration correction, 
fuel factor, and emission rate would be moved to Method 7E. Method 20 
would exist as a placeholder in order to maintain references to it in 
State regulation and permit citations.
    We are proposing the following specific changes to Methods 3A, 6C, 
7E, 10 and 20:

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    1. Method 10 would incorporate the calibration error test and 
between-run sampling system bias tests.
    2. The performance criteria for bias test would be based on the 
concentration of the emission standard rather than the span. The 
requirement to correct the sample concentration for sampling system 
bias is replaced by a calculation of the run uncertainty.
    3. Initial interference tests may be analyzer type-certified by 
manufacturers. Thereafter, an interference test of major potential 
interferences would be required at least annually. An alternative 
interference test would be allowed for Method 6C.
    4. Three calibration gases would be required for each test method 
(Method 10 now requires four gases). The calibration gases would have 
to be of EPA traceability protocol quality and be in the same 
concentration ranges as now prescribed in Method 6C.
    5. The Method 20 calculations would be moved to Method 7E. Methods 
3A and 6C would be referenced for diluent and sulfur dioxide 
measurements.
    6. Method 7E would require an NO2 to NO converter 
efficiency test before each test for systems that convert 
NO2 to NO before analysis.
    7. Chemiluminescence analyzers would not be the only allowed 
technology for Method 7E.
    8. In Method 10, alternatives to the ascarite and silica gel 
interference traps would be allowed.
    9. A table summarizing quality control measures, performance 
requirements, and acceptable alternatives would be added.
    10. Specific requirements for sampling point selection would be 
added.
    11. Provisions for manufacturer certification of interference and 
stability would be added.
    12. The methods would be reformatted in the EMMC format.

III. What Major Comments From the Previous Proposal Are Pertinent to 
This Reproposal?

    The public comments received from the previous proposal have been 
evaluated and will be addressed comprehensively in the Comments and 
Responses Document that supplements the final rule following from this 
proposal. A number of revisions have been made to the proposed methods 
based on these comments. In this preamble, we discuss the comments that 
have resulted in significant revisions. Other minor revisions have been 
made based on specific comments, but these will be addressed later in 
the Summary of Comments and Responses Document.
    Several commenters expressed concern that the proposed calculation 
of the bias test relative to the applicable emission standard added 
confusion for tests conducted at facilities not subject to an emission 
standard. The commenters argued that this new approach would upset 
market-based program tests and tests where the emission standard is in 
units other than concentration.
    We consider these concerns valid and are now proposing to allow 
market-based programs to continue to base the acceptance tests on the 
span. For cases where the emission standard is in units other than 
concentration, we are proposing a conversion table to help determine a 
concentration equivalent to the emission standard.
    Commenters were both for and against eliminating the calibration 
drift test. Since the sampling system bias check includes a measurement 
of analytical drift, we believe the calibration drift test is not 
necessary. Additionally, the proposed requirements for manufacturer's 
certification of stability for low-concentration analyzers and the 
yearly recheck of the analyzer for interferences promotes the use of 
better and more stable analytical technology.
    One commenter noted that there is no carbon dioxide or oxygen 
emission standard for any source. For this reason, the commenter felt 
that sampling system bias limits should not be tied to emission limits. 
We agree with the commenter and are proposing to base the bias test 
limits in Method 3A on a percentage of the analyzer range instead of a 
percentage of the emission standard.
    One commenter suggested that EPA specify a minimum number of 
sampling points when there is no applicable regulation. We are adding 
the Method 1 sampling point specifications in this proposal and 
allowing the option to conduct a stratification test if fewer sampling 
points are believed adequate.
    Several commenters preferred we replace the requirement to use the 
high-level gas in the bias test with the option to use either the mid- 
or high-level gas, depending upon which gas is closer to the stack gas 
concentration. This proposal has incorporated this recommendation.
    One commenter suggested that developing interference data was the 
responsibility of the instrument supplier, not the tester. The 
commenter thought the current interference test was excessive, could 
lead to sloppy work or even falsification of interference data, and 
limits the range of sources where the method could be used. We have 
added an allowance for manufacturer certification of instruments, and 
we are requiring this certification where instruments will be used 
routinely to measure low (<15 ppm) concentrations. However, we feel 
that an ongoing program to ensure the instrument is properly maintained 
and is appropriate for the test facility is still needed. In this 
proposal we are adding an abbreviated check for major potential 
interferences, performed after the initial test and at least on a 
yearly basis, to show that the analyzer remains interference-free. We 
feel that maintaining the instrument in this way will increase data 
quality and promote instrument reliability.
    Other commenters asked that the interference test be clarified. It 
was not clear whether the test must be performed with the first 
sampling event in a State or region, or the first sampling event of the 
calendar year. Was the test to be repeated if an analyzer undergoes 
significant maintenance? Would gas, oil, or coal boilers be considered 
different source types and require separate interference tests? One 
commenter recommended we consider modifying the requirement by stating 
that once an interference check is performed on a certain make or model 
of analyzer, additional checks on that company's same model need not be 
performed.
    This proposal clearly states that the interference test is required 
for each different source category you test. This is irrespective of 
the regulatory jurisdiction or calendar year. The test must be repeated 
at each source category when a major instrument component (e.g., 
detector) is replaced. Gas-, oil-, and coal-fired boilers would be 
considered the same source category if the test gas interference check 
is performed. This procedure challenges the analyzer with a number of 
potential interference gases. If the Method 6C/Method 6 comparison 
interference check is used for sulfur dioxide, we feel the potential 
interference differences among the three boiler types warrants three 
separate interference tests. However, we are proposing to allow the 
test gas interference check as an alternative to the Method 6C/Method 6 
comparison interference test in Method 6C. We are proposing to allow 
the instrument manufacturers to type-certify analyzers to fulfill the 
initial interference test requirement.
    Many commenters objected to the proposed bias correction equation 
and argued it was too complicated. We are proposing to drop the bias 
correction requirement in favor of calculating the level of uncertainty 
for a run.

[[Page 58842]]

IV. Statutory and Executive Order Reviews

A. Executive Order 12866--Regulatory Planning and Reviews

    Under Executive Order 12866 (58 FR 51735 October 4, 1993), we must 
determine whether this regulatory action is ``significant'' and 
therefore subject to Office of Management and Budget (OMB) review and 
the requirements of this Executive Order. The Order defines 
``significant regulatory action'' as one that is likely to result in a 
rule that may: (1) Have an annual effect on the economy of $100 million 
or more or adversely affects in a material way the economy, a sector of 
the economy, productivity, competition, jobs, the environment, public 
health or safety, or State, local, or tribal governments or 
communities; (2) create a serious inconsistency or otherwise interferes 
with an action taken or planned by another agency; (3) materially alter 
the budgetary impact of entitlements, grants, user fees, or loan 
programs, or the rights and obligations of recipients thereof; or (4) 
raise novel legal or policy issues arising out of legal mandates, the 
President's priorities, or the principles set forth in the Executive 
Order.
    We have determined that this rule is not a ``significant regulatory 
action'' under the terms of Executive Order 12866 and is therefore not 
subject to OMB review. We have determined that this regulation would 
result in none of the economic effects set forth in section 1 of the 
Order because it does not impose emission measurement requirements 
beyond those specified in the current regulations, nor does it change 
any emission standard.

B. Paperwork Reduction Act

    This rule does not impose any information collection burden that 
requires OMB review and approval under the provisions of the Paperwork 
Reduction Act of 1995 (44 U.S.C. 3501 et seq.).

C. Regulatory Flexibility Act

    The RFA generally requires an agency to prepare a regulatory 
flexibility analysis of any rule subject to notice and comment 
rulemaking requirements under the Administrative Procedure Act or any 
other statute unless the agency certifies that the rule will not have a 
significant economic impact on a substantial number of small entities. 
Small entities include small businesses, small organizations, and small 
governmental jurisdictions.
    For purposes of assessing the impacts of today's rule on small 
entities, small entity is defined as: (1) A small business as defined 
by the Small Business Administration's regulations at 13 CFR 121.201; 
(2) a small governmental jurisdiction that is a government of a city, 
county, town, school district or special district with a population of 
less than 50,000; and (3) a small organization that is any not-for-
profit enterprise which is independently owned and operated and is not 
dominant in its field. Entities potentially affected by this action 
include those listed in Table 1 of section I.A.
    After considering the economic impacts of today's proposed rule on 
small entities, I certify that this action will not have a significant 
economic impact on a substantial number of small entities. We are 
proposing to amend five instrumental test methods that are used to 
measure air pollutant emissions from stationary sources. The intended 
effect of this rule is to harmonize, simplify, and update the test 
methods. The methods were originally developed for specific industry 
applications but have since been adapted to general testing 
applications. These proposed revisions would remove inconsistencies in 
equipment and performance specifications so each method would be 
similar in these respects and have expanded applicability. We are also 
proposing to add helpful calculation procedures, quality assurance 
recommendations, and provisions for sampling at low concentrations. A 
large number of industries are already subject to the provisions 
requiring the use of these methods.
    We invite comments on all aspects of the proposal and its impacts 
on small entities.

D. Unfunded Mandates Reform Act

    Title II of the Unfunded Mandates Reform Act of 1995 (UMRA), Public 
Law 104-4, establishes requirements for Federal agencies to assess the 
effects of their regulatory actions on State, local, and tribal 
governments and the private sector. Under section 202 of the UMRA, EPA 
generally must prepare a written statement, including a cost-benefit 
analysis, for proposed and final rules with ``Federal mandates'' that 
may result in expenditures to State, local, and tribal governments, in 
the aggregate, or to the private sector, of $100 million or more in any 
one year. Before promulgating an EPA rule for which a written statement 
is needed, section 205 of the UMRA generally requires EPA to identify 
and consider a reasonable number of regulatory alternatives and adopt 
the least costly, most cost-effective or least burdensome alternative 
that achieves the objectives of the rule. The provisions of section 205 
do not apply when they are inconsistent with applicable law. Moreover, 
section 205 allows EPA to adopt an alternative other than the least 
costly, most cost-effective or least burdensome alternative if the 
Administrator publishes with the final rule an explanation why that 
alternative was not adopted. Before EPA establishes any regulatory 
requirements that may significantly or uniquely affect small 
governments, including tribal governments, it must have developed under 
section 203 of the UMRA a small government agency plan. The plan must 
provide for notifying potentially affected small governments, enabling 
officials of affected small governments to have meaningful and timely 
input in the development of EPA regulatory proposals with significant 
Federal intergovernmental mandates, and informing, educating, and 
advising small governments on compliance with the regulatory 
requirements.
    Today's rule contains no Federal mandates (under the regulatory 
provisions of Title II of the UMRA) for State, local, or tribal 
governments or the private sector. The rule imposes no enforceable duty 
on any State, local, or tribal governments or the private sector. In 
any event, EPA has determined that this rule does not contain a Federal 
mandate that may result in expenditures of $100 million or more for 
State, local, and tribal governments, in the aggregate, or the private 
sector in any one year. Thus, today's rule is not subject to the 
requirements of sections 202 and 205 of the UMRA.

E. Executive Order 13132--Federalism

    Executive Order 13132, entitled ``Federalism'' (64 FR 43255, August 
10, 1999), requires EPA to develop an accountable process to ensure 
``meaningful and timely input by State and local officials in the 
development of regulatory policies that have federalism implications.'' 
``Policies that have federalism implications'' are defined in the 
Executive Order to include regulations that have ``substantial direct 
effects on the States, on the relationship between the national 
government and the States, or on the distribution of power and 
responsibilities among the various levels of government.''
    This rule does not have federalism implications. It will not have 
substantial direct effects on the States, on the relationship between 
the national government and the States, or on the distribution of power 
and responsibilities among the various levels of government, as 
specified in Executive Order 13132. Thus, the

[[Page 58843]]

requirements of section 6 of the Executive Order do not apply to this 
rule.
    In the spirit of Executive Order 13132, and consistent with EPA 
policy to promote communications between EPA and State and local 
governments, EPA specifically solicits comment on this proposed rule 
from State and local officials.

F. Executive Order 13175--Consultation and Coordination with Tribal 
Governments

    Executive Order 13175, entitled ``Consultation and Coordination 
with Indian Tribal Governments'' (65 FR 67249, November 6, 2000), 
requires EPA to develop an accountable process to ensure ``meaningful 
and timely input by tribal officials in the development of regulatory 
policies that have tribal implications.'' ``Policies that have tribal 
implications'' is defined in the Executive Order to include regulations 
that have ``substantial direct effects on one or more Indian tribes, on 
the relationship between the Federal government and the Indian tribes, 
or on the distribution of power and responsibilities between the 
Federal government and Indian tribes.''
    This proposed rule does not have tribal implications. It will not 
have substantial direct effects on tribal governments, on the 
relationship between the Federal government and Indian tribes, or on 
the distribution of power and responsibilities between the Federal 
government and Indian tribes, as specified in Executive Order 13175. In 
this proposed rule, we are simply updating five emission test methods 
that applicable facilities are already subject to. Thus, Executive 
Order 13175 does not apply to this rule.

G. Executive Order 13045--Protection of Children From Environmental 
Health Risks and Safety Risks

    Executive Order 13045 applies to any rule that EPA determines (1) 
is ``economically significant'' as defined under Executive Order 12866, 
and (2) the environmental health or safety risk addressed by the rule 
has a disproportionate effect on children. If the regulatory action 
meets both criteria, the Agency must evaluate the environmental health 
or safety effects of the planned rule on children and explain why the 
planned regulation is preferable to other potentially effective and 
reasonably feasible alternatives considered by the Agency.
    The EPA interprets Executive Order 13045 as applying only to 
regulatory actions that are based on health or safety risks, such that 
the analysis required under section 5-501 of the Executive Order has 
the potential to influence the regulation. This final rule is not 
subject to Executive Order 13045, because it is not based on health or 
safety risks.

H. Executive Order 13211--Actions Concerning Regulations That 
Significantly Affect Energy Supply, Distribution, or Use

    This action is not subject to Executive Order 13211, ``Actions 
Concerning Regulations That Significantly Affect Energy Supply, 
Distribution, or Use'' (66 FR 28355, May 22, 2001) because it is not a 
significant regulatory action under Executive Order 12866.

I. NTTAA--National Technology Transfer and Advancement Act

    Section 12(d) of the National Technology Transfer and Advancement 
Act of 1995 (NTTAA), Public Law 104-113 (15 U.S.C. 272), directs us to 
use voluntary consensus standards (VCSs) in our regulatory activities 
unless to do so would be inconsistent with applicable law or otherwise 
impractical. Voluntary consensus standards are technical standards 
(e.g., materials specifications, test methods, sampling procedures, 
business practices, etc.) that are developed or adopted by VCS bodies. 
The NTTAA requires us to provide Congress, through OMB, explanations 
when we decide not to use available and applicable VCSs. We are not 
proposing new test methods in this rulemaking but are revising and 
updating methods that have already been mandated for evaluating 
compliance with current emission standards. Therefore, NTTAA does not 
apply.

List of Subjects in 40 CFR Part 60

    Environmental protection, Air pollution control, New sources, Test 
methods and procedures, Performance specifications, Continuous emission 
monitors.

    Dated: September 24, 2003.
Marianne Lamont Horinko,
Acting Administrator.
    For the reasons stated in the preamble, the Environmental 
Protection Agency proposes to amend title 40, chapter I of the Code of 
Federal Regulations as follows:

PART 60--STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES

    1. The authority citation for part 60 continues to read as follows:

    Authority: 42 U.S.C. 7401, 7411, 7413, 7414, 7416, 7601, and 
7602.

Appendix A--Test Methods [Amended]

    2. By revising Methods 3A, 6C, 7E, 10, and 20 to read as follows:

Appendix A to Part 60--Test Methods

* * * * *

Method 3A--Determination of Oxygen and Carbon Dioxide Emissions From 
Stationary Sources (Instrumental Analyzer Procedure)

1.0 Scope and Application

What Is Method 3A?

    Method 3A is a procedure for measuring oxygen (O2) 
and carbon dioxide (CO2) in stationary source emissions 
using a continuous instrumental analyzer. Quality assurance and 
quality control requirements are included to assure that you, the 
tester, collect data of known quality. You must document your 
adherence to these specific requirements for equipment, supplies, 
sample collection and analysis, calculations, and data analysis.
    This method does not completely describe all equipment, 
supplies, and sampling and analytical procedures you will need but 
refers to other methods for some of the details. Therefore, to 
obtain reliable results, you should also have a thorough knowledge 
of these additional test methods:
    (1) Method 1--Sample and Velocity Traverses for Stationary 
Sources.
    (2) Method 3--Gas Analysis for the Determination of Molecular 
Weight.
    (3) Method 4--Determination of Moisture Content in Stack Gases.
    (4) Method 7E--Determination of Nitrogen Oxides Emissions From 
Stationary Sources (Instrumental Analyzer Procedure).
    All methods in this list appear in 40 CFR part 60, appendix A.
    1.1 Analytes. What does this method determine?

----------------------------------------------------------------------------------------------------------------
                Analyte                   CAS No.                            Sensitivity
----------------------------------------------------------------------------------------------------------------
Oxygen (O2)...........................    7782-44-7  See Discussion in section 1.3.
Carbon dioxide (CO2)..................     124-38-9  See Discussion in section 1.3.
----------------------------------------------------------------------------------------------------------------

    1.2 Applicability. When is this method required? Method 3A is a 
requirement in specific New Source Performance Standards, Clean Air 
Marketing Rules, and State Implementation Plans and Permits where 
measuring O2 and CO2 concentrations in

[[Page 58844]]

emissions and performance testing continuous emission monitors at 
stationary sources is required. Other regulations may also identify 
its use.
    1.3 Data Quality Objectives. How good must my collected data be? 
Refer to section 1.3 of Method 7E.

2.0 Summary of Method

    Using continuous or intermittent sampling, you extract a gas 
sample from the emissions unit under investigation. You then convey 
the sample to a gas analyzer and measure the concentration of 
O2 or CO2. You must adhere to the performance 
requirements to validate your data.

3.0 Definitions

    3.1 The Analyzer Calibration Error, Calibration Curve, 
Calibration Gas, High-Level Gas, Mid-Level Gas, Low-Level Gas, Data 
Recorder, Gas Analyzer, Interference Check, Measurement System, 
Response Time, Sampling System, and Sampling System Bias are the 
same as in sections 3.0 of Method 7E.

4.0 Interferences [Reserved]

5.0 Safety

    Refer to section 5.0 of Method 7E.

6.0 Equipment and Supplies

    Figure 7E-1 in Method 7E is a schematic diagram of an acceptable 
measurement system. You must use a measurement system for 
O2 and CO2 that meets the following 
specifications for the essential components.
    6.1 Sample Probe, Particulate Filter, Heated Sample Line, Sample 
Line, Moisture Removal System, Sample Pump, Flow Control/Gas 
Manifold, Sample Gas Manifold, and Data Recorder. You must follow 
the noted specifications in section 6.1 of Method 7E.
    6.2 Analyzer. An instrument that continuously measures 
O2 or CO2 in the gas stream and meets the 
specifications in section 13.0.

7.0 Reagents and Standards

    7.1 Calibration Gas. What calibration gases do I need? Refer to 
section 7.1 of Method 7E for the calibration gas requirements. You 
have five options for the calibration gas. The tests for analyzer 
calibration error and sampling system bias require span, mid-, and 
low-level gases.
    (a) CO2 in nitrogen (N2).
    (b) CO2 in air.
    (c) CO2/SO2 gas mixture in N2.
    (d) O2/SO2 gas mixture in N2.
    (e) O2/CO2/SO2 gas mixture in 
N2.
    7.2 Interference Check. What reagents do I need for the 
interference check? Use the reagents listed in Table 7E-1 of Method 
7E to conduct the interference check.

8.0 Sample Collection, Preservation, Storage, and Transport

Emission Test Procedure

    8.1 Sampling Site and Sampling Points. You must follow section 
8.1 of Method 7E.
    8.2 Measurement System Performance Tests. You must follow the 
calibration gas verification, measurement system preparation, 
analyzer calibration error test, initial sampling system bias check, 
response time, Interference Check, and validation of runs procedures 
in sections 8.2 and 8.3 of Method 7E.
    8.3 Sample Collection. Follow the procedures in section 8.4 of 
Method 7E.
    8.4 Validation of Runs. Follow section 8.5 of Method 7E.

9.0 Quality Control

    Follow quality control procedures in section 9.0 of Method 7E.

10.0 Calibration and Standardization

    Follow the procedures for calibration and standardization in 
section 10.0 of Method 7E.

11.0 Analytical Procedures

    Because sample collection and analysis are performed together 
(see section 8), additional discussion of the analytical procedure 
is not necessary.

12.0 Calculations and Data Analysis

    You must follow the procedures for calculations and data 
analysis in section 12.0 of Method 7E.

13.0 Method Performance

    13.1 The Analytical Range, Sensitivity, Analyzer Calibration 
Error, Response Time, Interference Test, and Alternative Dynamic 
Spike Check specifications are the same as in section 13.0 of Method 
7E.
    13.2 Sampling System Bias. The pre- and post-run sampling system 
bias must be within +/-3 percent of the manufacturer certified 
concentration for the mid- and span-level calibration gases and less 
than +/-0.25 percent of upper range.

14.0 Pollution Prevention [Reserved]

15.0 Waste Management [Reserved]

16.0 Alternative Procedures

    16.1 Dynamic spiking procedure and manufacturer's stability 
test. These procedures are the same as in section 16 of Method 7E.

17.0 References

    1. ``EPA Traceability Protocol for Assay and Certification of 
Gaseous Calibration Standards'' September 1997 as amended, EPA-600/
R-97/121.

18.0 Tables, Diagrams, Flowcharts, and Validation Data

* * * * *

Method 6C--Determination of Sulfur Dioxide Emissions From Stationary 
Sources (Instrumental Analyzer Procedure)

1.0 Scope and Application

What is Method 6C?

    Method 6C is a procedure for measuring sulfur dioxide 
(SO2) in stationary source emissions using a continuous 
instrumental analyzer. Quality assurance and quality control 
requirements are included to assure that you, the tester, collect 
data of known quality. You must document your adherence to these 
specific requirements for equipment, supplies, sample collection and 
analysis, calculations, and data analysis. This method does not 
completely describe all equipment, supplies, and sampling and 
analytical procedures you will need but refers to other methods for 
some of the details. Therefore, to obtain reliable results, you 
should also have a thorough knowledge of these additional test 
methods:
    (a) Method 1--Sample and Velocity Traverses for Stationary 
Sources.
    (b) Method 3A--Determination of Oxygen and Carbon Dioxide 
Concentrations in Emissions from Stationary Sources (Instrumental 
Analyzer Procedure).
    (c) Method 4--Determination of Moisture Content in Stack Gases.
    (d) Method 6--Determination of Sulfur Dioxide Emissions from 
Stationary Sources.
    All methods in this list appear in 40 CFR part 60, appendix A.
    1.1 Analytes. What does this method determine?

----------------------------------------------------------------------------------------------------------------
                Analyte                   CAS No.                            Sensitivity
----------------------------------------------------------------------------------------------------------------
SO2...................................    7446-09-5  See discussion in section 1.3.
----------------------------------------------------------------------------------------------------------------

    1.2 Applicability. When is this method required? Method 6C is 
required in specific New Source Performance Standards, Clean Air 
Marketing rules, and State Implementation Plans and permits where 
measuring SO2 concentrations in stationary source 
emissions is required. Other regulations may also require its use.
    1.3 Data Quality Objectives. Refer to section 1.3 of Method 7E.

2.0 Summary of Method

    In this method, you continuously sample the emission gas and 
convey the sample to an analyzer that measures the concentration of 
SO2. Properly designed and operated analyzers based on 
ultraviolet, nondispersive infrared, or fluorescence detection 
principles have been used successfully. Analyzers based on other 
detection principles may be acceptable, however you must meet the 
performance requirements of this method regardless of type of 
detector principle used.

3.0 Definitions

    3.1 The Analyzer Calibration Error, Calibration Curve, Direct 
Calibration, System Calibration, Calibration Gas, Data Recorder, Gas 
Analyzer, Measurement System, Range, Response Time, Sampling System 
Bias, and Span are the same as in sections 3.0 of Method 7E.

[[Page 58845]]

    3.2 Interference check means a test intended to detect analyzer 
responses to things other than the compound of interest, usually a 
gas present in the measured gas stream, that is not adequately 
accounted for in the calibration procedure and hence results in 
excessive bias.

4.0 Interferences [Reserved]

5.0 Safety

    Refer to section 5.0 of Method 7E.

6.0 Equipment and Supplies

    Figure 7E-1 of Method 7E is a schematic diagram of an acceptable 
measurement system. You must use a measurement system for 
SO2 that meets the following specifications for the 
essential components.
    6.1 What do I need for the measurement system? Sample Probe, 
Particulate Filter, Heated Sample Line, Sample Lines, Moisture 
Removal System, Sample Pump, Flow Control/Gas Manifold, Sample Gas 
Manifold, and Data Recorder. You must follow the noted 
specifications in section 6.1 of Method 7E.
    6.2 SO2 Analyzer. An instrument that uses an 
ultraviolet, nondispersive infrared, fluorescence, or other 
detection principal to continuously measure SO2 in the 
gas stream and meets the specifications in section 13.0. The dual-
range analyzer provisions of section 6.1.8.1 of Method 7E apply.
    6.3 What additional equipment do I need for the interference 
check? Use the apparatus described in section 6.0 of Method 6. 
Figure 6C-2 illustrates the interference check sampling train. In 
cases where the emission concentrations are less than 15 ppm, the 
alternative interference check detailed in section 16.1 should be 
used.

7.0 Reagents and Standards

    7.1 Calibration Gas. What calibration gases do I need? Refer to 
section 7.1 of Method 7E for the calibration gas requirements.
    You have five options for your calibration gas.
    (a) SO2 in nitrogen (N2).
    (b) SO2 in air.
    (c) SO2 and CO2 in N2.
    (d) SO2 and O2 in N2.
    (e) SO2/CO2/O2 gas mixture in 
N2.
    7.2 Additional Calibration Gas Requirements When Using a 
Fluorescence Analyzer. When you use a fluorescence-based analyzer 
and calibration gas (c), (d), or (e), the O2 or 
CO2 concentration in your calibration gas must be within 
1 percent (absolute) of the O2 (CO2) 
concentration in the effluent sample. If you use a fluorescence-
based analyzer and a calibration gas that is SO2 in air, 
you may use the nomographs provided by the gas vendor to determine 
the quenching correction factor. You must know the concentrations of 
O2 and CO2 in the effluent.
    7.3 Interference Check. What additional reagents do I need for 
the interference check? Use the reagents described in section 7.0 of 
Method 6 to conduct the interference check. For gas concentration 
less than 15 ppm, the test gases for the alternative interference 
check are listed in Table 7E-3 of Method 7E.
    7.3.1 Alternative Analyzer Interference Check. As an alternative 
to the above, you may conduct an alternative interference check by 
sequentially introducing the gases listed in Figure 7E-3 of Method 
7E (one at a time) both with and without SO2 into the 
calibrated analyzer and recording the apparent concentrations after 
waiting at least 3 times the analyzer response time. This is then 
repeated with a blend containing a known SO2 
concentration greater than 80 percent of the analyzer's range and 
calculating the difference between the known value and the apparent 
concentration. For each potential interferent gas, identify the 
largest of the 2 absolute values as the potential interference. The 
interference for all potential interferent gases in the source 
category must be less than 2.5 percent of the upper range limit to 
be acceptable. Record the data on a form similar to Figure 6C-8.

8.0 Sample Collection, Preservation, Storage, and Transport

Emission Test Procedure

    8.1 Sampling Site and Sampling Points. You must follow section 
8.1 of Method 7E.
    8.2 Measurement System Performance Tests. You must follow the 
Calibration Gas Verification, Measurement System Preparation, 
Analyzer Calibration Error Test, Initial Sampling System Bias Check, 
and Measurement System Response Time procedures in section 8.2 of 
Method 7E.
    8.3 Interference Check. You must conduct an interference check 
consisting of at least three runs before or during the initial field 
test of a particular source category (type of facility). This 
interference check must be repeated yearly on each individual gas 
analyzer. When testing under conditions of low concentrations (<15 
ppm), the alternative interference check in section 16.1 must be 
used; it is an acceptable alternative in other applications. For the 
interference check, build the modified Method 6 sampling train (flow 
control valve, two midget impingers containing 3 percent 
H2O2, and dry gas meter) shown in Figure 6C-2. 
Connect the sampling train to the sample bypass discharge vent. 
Record the dry gas meter reading before you begin sampling. 
Simultaneously collect modified Method 6 and Method 6C samples. Open 
the flow control valve in the modified Method 6 train as you begin 
to sample with Method 6C. Adjust the Method 6 sampling rate to 1 
liter per minute (+/-10 percent). If your modified Method 6 train 
does not include a pump, you risk biasing the results high if you 
over-pressurize the midget impingers and cause a leak. You can 
reduce this risk by cautiously increasing the flow rate as sampling 
begins. After completing a run, record the final dry gas meter 
reading, meter temperature, and barometric pressure. Recover and 
analyze the contents of the midget impingers using the procedures in 
Method 6. (You do not need to analyze performance audit samples with 
this interference check.) Determine the average valid gas 
concentration reported by Method 6C for the run.
    8.4 Sample Collection. Follow section 8.1. Sample within 5 
percent of the rate you used during the sampling system bias check
    8.5 Post-Run Sampling System Bias Check and Alternative Dynamic 
Spike Procedure. Follow sections 8.5 and 8.6 of Method 7E.

9.0 Quality Control

    Follow quality control procedures in section 9.0 of Method 7E.

10.0 Calibration and Standardization

    Follow the procedures for calibration and standardization in 
section 10.0 of Method 7E.

11.0 Analytical Procedures

    Because sample collection and analysis are performed together 
(see section 8), additional discussion of the analytical procedure 
is not necessary.

12.0 Calculations and Data Analysis

    You must follow the procedures for calculations and data 
analysis in section 12.0 of Method 7E as applicable.

13.0 Method Performance

    13.1 The Analytical Range, Sensitivity, System Response and 
Minimum Sampling Times, Analyzer Calibration Error, Sampling System 
Bias, and Alternative Dynamic Spike Check specifications are the 
same as in section 13.0 of Method 7E.
    13.2 Interference Test. Documentation of successful completion, 
within the last 12 months at the specific source category, where the 
difference between the analyzer and the modified Method 6 result is 
less than 7 percent of the modified Method 6 result for each of a 
minimum of 3 runs.
    13.3 Alternative Interference Check. Same as in section 13.6 of 
Method 7E.

14.0 Pollution Prevention [Reserved]

15.0 Waste Management [Reserved]

16.0 Alternative Procedures

    16.1 Alternative Interference Check. The interference check 
detailed in section 8.3 of Method 7E may be used as an alternative 
interference check.
    16.2 Dynamic Spiking Procedure, Manufacturer's Stability Test 
and Annual Primary Interference Recheck (as applicable). These 
procedures are the same as in section 16 of Method 7E.

17.0 References

    1. ``EPA Traceability Protocol for Assay and Certification of 
Gaseous Calibration Standards'' September 1997 as amend, EPA-600/R-
97/121.

18.0 Tables, Diagrams, Flowcharts, and Validation Data

BILLING CODE 6560-50-P

[[Page 58846]]

[GRAPHIC] [TIFF OMITTED] TP10OC03.020

BILLING CODE 6560-50-C
* * * * *

Method 7E--Determination of Nitrogen Oxides Emissions From Stationary 
Sources (Instrumental Analyzer Procedure)

1.0 Scope and Application

What Is Method 7E?

    Method 7E is a procedure for measuring nitrogen oxides 
(NOX) in stationary source emissions using a continuous 
instrumental analyzer. Quality assurance and quality control 
requirements are included to assure that you, the tester, collect 
data of known quality. You must document your adherence to these 
specific requirements for equipment, supplies, sample collection and 
analysis, calculations, and data analysis. This method does not 
completely describe all equipment, supplies, and sampling and 
analytical procedures you will need but refers to other methods for 
some of the details. Therefore, to obtain reliable results, you 
should also have a thorough knowledge of these additional test 
methods:
    (a) Method 1--Sample and Velocity Traverses for Stationary 
Sources.
    (b) Method 4--Determination of Moisture Content in Stack Gases.
    1.1 Analytes. What does this method determine? (All methods in 
this list appear in 40 CFR part 60, appendix A.)

----------------------------------------------------------------------------------------------------------------
                Analyte                   CAS No.                            Sensitivity
----------------------------------------------------------------------------------------------------------------
Nitric oxide (NO).....................   10102-43-9  See discussion in section 1.3.
Nitrogen dioxide (NO2)................   10102-44-0
----------------------------------------------------------------------------------------------------------------

    1.2 Applicability. When is this method required? Method 7E is 
required in specific New Source Performance Standards, Clean Air 
Marketing Rules, and State Implementation Plans and Permits where 
measuring NOX concentrations in stationary source 
emissions is required. Other regulations may also require its use.
    1.3 Data Quality Objectives (DQO). What quality of data is this 
method designed to produce? The data quality objectives define the 
quality of data you need for the test. Method 7E is designed for 
determining compliance with Federal and State emission standards. 
For this purpose, data acceptability is evaluated through 
performance tests whose accuracy is determined relative to the 
applicable emission standard concentration. Therefore, the quality 
of data is emphasized at the compliance concentration levels. 
However, we do not intend the method to penalize you for calibrating 
to measure accurately emissions well below the emission limit. In 
applications where there is no emission limitation (e.g., market-
based programs), acceptable performance is based on the span instead 
of the emission standard. You are required to calculate and report 
an uncertainty estimate for your data. This encourages the use of 
better technology and techniques but does not require it when not 
needed by your DQO. This uncertainty provides data quality 
information for future secondary data users.
    1.3.1 Data Quality Assessment. It is possible to meet the method 
QA/QC requirements and still not be certain you are making the 
correct data decision. This is a phenomena with all measurements 
since measurements are inherently an estimate of the true value no 
matter how precisely and accurately they are made. However, by 
separating the reporting of measured data and uncertainty estimates, 
the method provides the data users various options to assess the 
data quality when the tester deviates from the procedures. For 
example, the data user might decide to look at the upper uncertainty 
estimate if the question of concern is ``Am I sure the average 
emissions are less than an emission limit?'' or at the lower 
uncertainty estimate if the question of concern is ``Am I sure the 
average emissions are greater than an emission limit?'' Data of 
lesser quality may be accepted if the data user deems the testing 
objectives are met. For example, if the measured average emissions 
are less than the emission limit but a small fraction of the data 
exceeded the analyzer range, the data user may choose to accept this 
data as adequate to show compliance with the emission limit. The 
regulating agency is considered the data user and therefore makes 
the final assessment of data quality.
    1.3.2 Data Quality Assessment for low emitters. Is performance 
relief granted to low-emission units? Yes, there are interim special 
sampling system bias performance criteria and allowances to use the 
alternative interference check and dynamic spike procedures. You 
should refer to section 13 for an explanation.
    1.3.3 How is the calibration designed when test units are 
covered by more than one

[[Page 58847]]

emission limit? In most cases where an emission unit is subject to 
more than one emission limit, the analysis should be designed for 
the most stringent limit. An emission unit that is shown to be in 
compliance with the most stringent limit when the analysis is 
designed in this way is also in compliance with the other applicable 
limits.

2.0 Summary of Method

    In this method, you continuously sample the emission gas and 
convey the sample to an analyzer that measures the concentration of 
NOX. You may measure NO and NO2 separately or 
simultaneously together but, for purposes of this method, 
NOX is the sum of NO and NO2. You must adhere 
to the performance requirements of this method to validate your 
data.

3.0 Definitions

    3.1 Analyzer calibration error means the difference between the 
manufacturer certified calibration gas concentration and the 
concentration reported by the analyzer in direct calibration mode.
    3.2 Calibration curve means the relationship between the 
analyzer's response and the concentration of the gas introduced to 
the analyzer over the calibration range of the analyzer.
    3.2.1 Direct Calibration means introducing the calibration gases 
directly to the analyzer according to manufacturer's published 
calibration procedure.
    3.2.2 System Calibration means introducing the calibration gases 
into the measurement system at the probe and upstream of all sample 
conditioning components.
    3.3 Calibration gas means the gas mixture containing 
NOX at a concentration of known pedigree and produced and 
certified in accordance with ``EPA Traceability Protocol for Assay 
and Certification of Gaseous Calibration Standards,'' September 
1997, as amended August 25, 1999, EPA-600/R-97/121. The tests for 
analyzer calibration error and sampling system bias require a span-, 
mid-, and low-level calibration gases.
    3.4 Converter Efficiency Gas means a calibration gas with a 
known NO2 concentration.
    3.5 Data recorder means the equipment that permanently records 
the concentrations reported by the analyzer.
    3.6 Gas analyzer means the equipment that senses the gas being 
measured and generates an output proportional to its concentration.
    3.7 Interference check means the test intended to detect 
analyzer responses to things other than the compound of interest, 
usually a gas present in the measured gas stream, that is not 
adequately accounted for in the calibration procedure and hence 
results in excessive bias.
    3.8 Measurement system means all the equipment used to determine 
the NOX concentration. The measurement system comprises 
six major subsystems: Acquisition, sample transport, sample 
conditioning, flow control/gas manifold, gas analyzer, and data 
recorder.
    3.9 Range means the interval between the nominal minimum and 
maximum concentration that the gas analyzer manufacturer cites for 
the analyzer full-scale response. Gas analyzers that have single-
range or multiple-range capability with either automated or manual 
switching are potentially acceptable. The range must be at least 5 
percent greater than the concentration of the span-level gas you use 
to calibrate the analyzer, so that sampling system bias can be 
determined.
    3.10 Response time is the time it takes the data acquisition 
system to read 95 percent of the stable reading from a step change 
in concentration when the sampling system is operating at its design 
flow rate.
    3.11 Sampling system bias means the difference between the 
manufacturer certified calibration gas concentration and the 
concentration the analytical system gives for the same gas when it 
is introduced in system calibration mode, divided by the emission 
standard.
    3.12 Span means the highest concentration of the calibration 
curve and is synonymous with the concentration of the highest 
calibration gas. In most cases, the span will be higher than the 
concentration of the emission standard.

4.0 Interferences [Reserved]

5.0 Safety

    What safety measures should I consider when using this method? 
This method may require you to work with hazardous materials and in 
hazardous conditions. We encourage you to establish safety 
procedures before using this method. Among other precautions, you 
should become familiar with the safety recommendations in the gas 
analyzer user's manual. Occupational Safety and Health 
Administration (OSHA) regulations may also apply to you.

6.0 Equipment and Supplies

    The performance criteria in this method will be met or exceeded 
most of the time if you are properly using equipment designed for 
this application.
    6.1 What do I need for the measurement system? Figure 7E-1 is a 
diagram of an example measurement system. You may use alternative 
equipment and supplies provided (1) your sample flow rate is 
maintained within 5 percent of the design flow rate, (2) the probe, 
filter, and the sample line from the sample probe to the moisture 
removal system (if necessary) is constructed of materials which do 
not absorb or otherwise alter the sample gas and are heated to at 
least 140 [deg]C (284 [deg]F) or 25 [deg]C (77 [deg]F) above the 
concentration dew point of the sample, whichever is higher, to 
prevent condensation, and (3) the interference and sampling system 
bias criteria are met. An NOX measurement system that 
meets the following specifications is likely to meet the 
interference and sampling system bias requirements and are provided 
as guidance. The essential components of the measurement system are 
described below:
    6.1.1 Sample Probe (Stinger). Glass, stainless steel, or 
equivalent, of sufficient length to traverse the sample points. The 
sampling probe must reach all sample points and be heated to at 
least 140 [deg]C (284 [deg]F) to prevent condensation or 25 [deg]C 
(77 [deg]F) above the concentration dew point of the sample, 
whichever is higher.
    6.1.1.1 Particulate Filter. An in-stack or out-of-stack filter. 
The probe filter and all flow components located at the probe must 
be heated to at least 140 [deg]C (284 [deg]F) or 25 [deg]C (77 
[deg]F) above the dew point of the sample, whichever is higher. The 
filter media must be included in the sampling system bias test and 
be made of materials that are nonreactive to the gas being sampled.
    6.1.2 Heated Sample Line. The sample line from the probe to the 
moisture removal system (if necessary) and to the sample pump should 
be made of stainless steel, teflon, or other material that does not 
absorb or otherwise alter the sample gas. Heat the sample line 
between the probe and moisture removal system to at least 140 [deg]C 
(284 [deg]F) to prevent condensation or 25 [deg]C (77 [deg]F) above 
the dew point of the sample, whichever is higher.
    6.1.3 Sample Lines. Stainless steel or Teflon tubing to 
transport the sample from the moisture removal system to the flow 
control gas manifold.
    6.1.4 Moisture Removal System. A thermo-electric type condenser 
or similar device to remove condensate continuously from the sample 
gas while maintaining minimal contact between the condensate and the 
sample gas. The gas temperature at the outlet of the drier must be 
<60 [deg]F (15 [deg]C) as measured in the drier outlet tubing, and 
the drier outlet gas dew point temperature must be maintained equal 
to or less than 41 [deg]F (5 [deg]C). The moisture removal system is 
not necessary for analyzers that measure gas concentrations on a wet 
basis. For these analyzers (1) heat the sample line and all sample 
transport components up to the inlet of the analyzer to at least 140 
[deg]C (284 [deg]F) or 25 [deg]C (77 [deg]F) above the concentration 
dew point of the sample, whichever is higher, to prevent 
condensation, and (2) determine the moisture content and correct the 
measured gas concentrations to a dry basis using appropriate 
methods, subject to the approval of the Administrator. You do not 
need to determine sample moisture content if your analyzer measures 
concentration on a wet basis when (1) a wet basis CO2 
analyzer operated according to Method 3A is used to obtain 
simultaneous measurements, and (2) the pollutant/CO2 
measurement system is used to determine emissions in units of the 
standard. The wet analyzer must pass the same sampling system bias 
check as the dry measurement system. The sampling system bias check 
must include the same water (+/-1 percent absolute) concentration 
found in the sample.
    6.1.5 Sample Pump. A leak-free pump to pull the sample gas 
through the system at a flow rate sufficient to minimize the 
response time of the measurement system. The pump may be constructed 
of any material that is nonreactive to the gas being sampled.
    6.1.6 Flow Control/Gas Manifold. An assembly of manual or 
solenoid valves to allow the introduction of calibration gases 
either directly to the gas analyzer in direct mode, or into the 
measurement system, at the probe, in system mode. A calibration 
valve assembly, three-way valve assembly, or equivalent, for 
blocking the sample gas flow

[[Page 58848]]

and introducing calibration gases directly to the gas analyzers, and 
a valve to flow calibration gas through the entire measurement 
system, flooding the sampling probe when in the system mode (for 
bias check). Use either a flow control valve and rotameter or an 
equivalent valve. Use a back-pressure regulator, or equivalent, to 
maintain constant pressure in the sample gas manifold.
    6.1.7 Sample Gas Manifold. The sample gas manifold diverts a 
portion of the sample to the analyzer, delivering the remainder to 
the by-pass discharge vent. The manifold should also be able to 
introduce calibration gases directly to the analyzer. The manifold 
must be made of material that does not react with NOX or 
the calibration gas and be configured to safely discharge the bypass 
gas.
    6.1.8 NOX analyzer. An instrument that continuously 
measures NOX in the gas stream and meets the 
specifications in section 13.0. Analyzers that operate on the 
principle of chemiluminescence with an NO2 to NO 
converter have been used to successfully meet the performance 
criteria in the past. Analyzers operating on other principles may 
also be used provided the performance criteria are met.
    6.1.8.1 Dual Range Analyzers. Some manufacturers may certify a 
gas analyzer with a single large range which you may use with proper 
data recorders as two separate analyzers if you use the proper sets 
of calibration gases and meet the interference, analyzer calibration 
error, and sampling system bias checks. However, we caution you that 
the larger range affects the sensitivity in some analyzers and this 
may affect your ability to meet the performance requirements when 
operated on the lower range.
    6.1.9 Data Recording. A strip chart recorder, analog computer, 
digital recorder, or data logger for recording measurement data. The 
data recording resolution (i.e., readability) must be no larger than 
0.5 percent of span. Alternatively, a digital or analog meter having 
a resolution no larger than 0.5 percent of span may be used, and the 
readings may be recorded manually. If this alternative is used, the 
readings must be from equally spaced intervals of no more than 1 
minute over the duration of the sampling run.

7.0 Reagents and Standards

    7.1 Calibration Gas. What calibration gases do I need? Your 
calibration gas must be certified in accordance with ``EPA 
Traceability Protocol for Assay and Certification of Gaseous 
Calibration Standards'' September 1997, as amended August 25, 1999, 
EPA-600/R-97/121. The calibration gas certification (or 
recertification) must be complete and the test must be completed 
before the expiration date. The goal is to bracket the sample 
concentrations and have at least one calibration gas below and one 
above the measurements. Use a minimum of the following calibration 
gas concentrations:
    7.1.1 Span-Level Gas. The span-level gas sets the analyzer span 
which is the maximum concentration that is considered potentially 
valid for a test.
    7.1.2 Mid-Level Gas. The mid-level gas must have a concentration 
that is 20 to 70 percent of the concentration of the span-level gas.
    7.1.3 Low-Level Gas. The low-level gas must have a concentration 
that is less than 20 percent of the span-level gas.
    7.1.4 Converter Efficiency Gas. The converter efficiency gas 
must have a concentration of NO2 that is within 50 
percent of the measured NO2 concentration.
    7.2 Interference Check. What additional reagents do I need for 
the interference check? Use the test gases listed in table 7E-3 to 
conduct the interference check.

8.0 Sample Collection, Preservation, Storage, and Transport

Emission Test Procedure

    Since you are allowed to choose different options to comply with 
some of the performance criteria, it is your responsibility to 
identify the specific options you followed, document your meeting 
the performance criteria and frequency for that option, or identify 
any deviations from the method.
    8.1 What sampling site and sampling points do I select?
    8.1.1 Unless otherwise specified in an applicable regulation or 
by the administrator, use the traverse points listed in and located 
according to Method 1. Alternatively, you may conduct a 
stratification test as described in section 8.1.3 to determine if 
fewer traverse points may be used. For performance testing of 
continuous emission monitoring systems, follow the sampling site 
procedures in the appropriate performance specification or 
applicable regulation.
    8.1.2 General Sampling Point Requirements. Traverse all sampling 
points you choose from above, and sample at each point for an equal 
length of time. Record the sampling data. If you are comparing the 
data from individual traverse points as in the stratification test, 
you must delay recording data at each point for 2 times the system 
response time. The minimum time you must sample at each point is 2 
times the system response time. You must record data at least every 
minute. Usually the test is designed for sampling longer than 1 
minute per point to better characterize the source's temporal 
variability. If the test is designed such that the sampling time for 
each point is greater than 10 times the system response time, then 
you may start recording data at the first traverse point after 
purging the system at least 2 times the system response time. After 
recording for the designed period of time, you may move to the next 
traverse point and continue recording, omitting the requirement to 
delay recording for 2 times the system response at the subsequent 
traverse points. However, you must recondition the sampling system 
for at least 2 times the system response time prior to recording at 
the next traverse point if you remove the probe from the stack. You 
may satisfy the multipoint traverse requirement by sampling 
sequentially using a single-hole probe or a multi-hole probe 
designed to sample from each hole at the same (+/-10 percent of 
mean) flow rate.
    8.1.3 Determination of Stratification. If the results of a 
stratification test show your unit to be unstratified, you may 
traverse at fewer points than required by Method 1. To test for 
stratification, use a probe of appropriate length to measure the 
NOX and diluent (O2 or CO2) 
concentrations at each traverse point selected according to Method 
1. Calculate the individual point and mean NOX 
concentrations, corrected for diluent. If the range of average 
dilution-corrected concentrations for all points is less than or 
equal to +/-5 percent of the mean concentration, you may collect 
samples from a single point that most closely matches the mean. 
Alternatively, if the range of the individual traverse point 
concentrations, corrected for dilution, is equal to or less than +/-
10 percent of the mean, you may take samples from 3 or more points 
on one diameter provided the points are located on the diameter of 
the stack exhibiting the highest average concentration during the 
stratification test. Space the points at 16.7, 50.0, and 83.3 
percent of the measurement line (i.e., divide the diameter into 
equal length segments and sample at their midpoints.)
    8.2 Measurement System Performance Tests. What initial 
performance criteria must my system meet before I begin collecting 
samples? Before measuring emissions, perform the following 
procedures:
    a. Calibration gas verification;
    b. Measurement system preparation and analyzer calibration error 
test;
    c. NO2 to NO conversion efficiency test, if 
applicable;
    d. Initial sampling system bias check;
    e. System response time test; and
    f. Interference check.
    8.2.1 Calibration gas verification. How must I verify the 
concentrations of my calibration gases? Obtain a certificate from 
the gas manufacturer and confirm that the documentation includes all 
information required by the Traceability Protocol. Confirm that the 
manufacturer certification is complete and current.
    8.2.2 Measurement system preparation. How do I prepare my 
measurement system? Assemble, prepare, and precondition the 
measurement system according to your standard operating procedure. 
Achieve the correct sampling rate. Ensure that your calibration 
gases are in the proper range and will result in the measured 
emissions being between 20 and 100 percent of the span. Perform a 
direct calibration of the gas analyzer (see section 10.1), and 
conduct the analyzer calibration error test.
    8.2.3 Analyzer Calibration Error Test. How do I confirm my 
analyzer calibration is correct? After you have calibrated your 
analyzer according to the manufacturer recommended procedure, you 
must conduct an analyzer calibration error test before the first run 
and again after any failed sampling system bias tests. In this test 
you introduce the same low-, mid-, and span gases (that you just 
used to calibrate the analyzer in direct calibration mode) into the 
measurement system at any point upstream of the analyzer but 
preferably again in direct calibration mode. You must maintain the 
correct flow rate at the analyzer, but do not make adjustments for 
any other purpose. Record the analyzer's response to each 
calibration gas on a form similar to table 7E-1. For each 
calibration gas, calculate the analyzer

[[Page 58849]]

calibration error as the difference between the measured 
concentration and the manufacturer certified concentration. The 
difference should be less than 2 percent of the manufacturer 
certified concentration for the low-, mid-, and span gases.
    8.2.4 NO2 to NO Conversion Efficiency Test. You must 
conduct an NO2 to NO conversion efficiency test on all 
analyzers whose measurement principal converts NO2 to NO 
before analyzing for NOX. Introduce a known concentration 
of NO2 to the analyzer in direct calibration mode and 
record the stable gas concentration displayed by the analyzer. 
(Note: Because the measurement data uncertainty calculation adjusts 
for converter efficiencies less than 100 percent and because the 
converter efficiency may change with concentration, we suggest the 
known concentration introduced be within a range of 50-150 percent 
of the average measured concentration.) Alternatively, the procedure 
for determining conversion efficiency using NO in 40 CFR 86.123-78 
may be used. For those analyzers whose measurement principal detects 
NO2 in the sample directly without a converter, this 
requirement is waived because the calibration gas requirements will 
assure adequate accounting for NO2.
    8.2.5 Initial Sampling System Bias Check. Begin by introducing 
the span-level calibration gas (or mid-level gas if closer to the 
emissions concentration) in system calibration mode. Record the gas 
concentration displayed by the analyzer and the time it takes to 
reach a stable value on a form similar to Table 7E-2. A value is 
considered stable when the maximum difference between 3 consecutive 
recordings is not more than 0.5 percent of certified value and the 
mean is at least 97 percent of the certified value. Then introduce 
the zero gas in system calibration mode and similarly record the gas 
concentration displayed by the analyzer and the time it takes the 
measurement system to decrease to a stable zero value from the 
higher value. Operate the measurement system at the normal sampling 
rate. Make only the adjustments necessary to achieve proper 
calibration gas flow rates at the analyzer. First, calculate the 
measurement system response time (see section 8.2.6) and then 
calculate the sampling system bias (see section 12.5). See sections 
13.3 and 13.5 for acceptable performance criteria. If sampling 
system bias is excessive, take corrective action until an acceptable 
performance is achieved. You must repeat the analyzer calibration 
error test and sampling system bias check whenever a sampling system 
bias check is excessive. You must also repeat the sampling system 
bias check at the end of each run.
    8.2.6 Measurement System Response Time. You must determine the 
measurement system response time during the initial sampling system 
bias check. Observe the times required to achieve 95 percent of a 
stable response for both the low- and high-level gases. The longer 
interval is the response time.
    8.3 Interference Check. Conduct an interference response test of 
the gas analyzer prior to its initial use in the field. Recheck the 
analyzer if you make changes that could alter the interference 
response (e.g., a change in the gas detector). You can introduce the 
interference test gases (see Table 7E-3) into the measurement system 
separately or as mixtures. This test must be performed both with and 
without NOX (NO and NO2) which should be at a 
concentration of at least 80 percent of the analyzer range. Measure 
the total interference response of the system to these gases in 
ppmv. Record the responses and determine the interference using 
Table 7E-4. A copy of this data including the date completed and 
signed certification must be included. This interference test is 
valid for 1 calendar year unless major analytical components are 
replaced. If major components are replaced, the annual primary 
interference gas recheck described in section 16.3 must be performed 
before returning the analyzer to service. You must conduct the 
primary interference gas recheck on an annual basis.
    8.4 Sample Collection. Collect samples following section 8.1. 
Sample within 5 percent of the rate you used during the sampling 
system bias check.
    8.5 Post-Run Sampling System Bias Check. How do I confirm that 
each sample I collect is valid? After each run, repeat the sampling 
system bias check to validate the run. Do not make adjustments 
(other than to attain the design sampling rate) to the measurement 
system between the run and completion of the sampling system bias 
check. If you do not pass this post-run sampling system bias test, 
then the run does not meet this method?s quality assurance. To meet 
this method's quality assurance requirements, you must fix the 
problem, pass another analyzer calibration error test and sampling 
system bias test before repeating the run. Record the bias test 
results on a form similar to Table 7E-2.
    8.6 Alternative Dynamic Spike Procedure. If I want to use the 
dynamic spike procedure to validate my data, what procedure should I 
follow? You may comply with the dynamic spiking procedure and 
requirements provided in section 16.2 during each test as an 
alternative to the analyzer calibration error test and the pre- and 
post-run sampling system bias checks.

9.0 Quality Control

    What is a summary of the quality control measures I must take?

                                             Summary Table of QA/QC
----------------------------------------------------------------------------------------------------------------
                                          QA/QC            Acceptance                              Suggested
    Status     Process or element     specification         criteria       Checking frequency  corrective action
----------------------------------------------------------------------------------------------------------------
S \1\........  Identify Data User  ..................  Regulatory Agency   Before designing
                                                        or other primary    test.
                                                        end user of data.
M \2\........  Analyzer Design...  Analyzer range....  Sufficiently  than span-                      analyzer or
                                                        level gas to                            reduce span
                                                        determine                               value.
                                                        sampling system
                                                        bias.
S............  ..................  Analyzer            < 2% of range.....  Manufacturer        Use different
                                    resolution or                           design.             analyzer.
                                    sensitivity.
S............  ..................  Analyzer response   < 30 Seconds.
                                    time.
M............  ..................  Interference gas    < 2.5% of upper     Valid for 1 year.
                                    check.              range limit See
                                                        Table 7E-3.
M............  Calibration Gases.  Traceability        Valid certificate   ..................  Recertify; new
                                    protocol (G1, G2).  uncertainty < 2%.                       standard.
M............  ..................  Span-level limit..  Chosen so           Each run..........  Use a different
                                                        measurements are                        cylinder.
                                                        all <= span.
M............  ..................  Mid-level limit...  20 to 70% of span-  Each run..........  Use a different
                                                        level gas.                              cylinder.
M............  ..................  Low-level limit...  < 20% of span-      Each run..........  Use a different
                                                        level gas.                              cylinder.
S............  Data Recorder       Data resolution...  < 1% of span......  Manufacturer        Replace recorder.
                Design.                                                     design.
S............  Sample Extraction.  Probe material....  SS or quartz if     Each run..........  Replace material.
                                                        stack 
                                                        500[deg] F.
M............  Sample Extraction.  Probe temperature.  Heated   Each run..........  Adjust
                                                        140[deg] C or                           temperature.
                                                        25[deg] C greater
                                                        than the dew
                                                        point.

[[Page 58850]]

 
M............  Analyzer &          Analyzer            < 2 percent of the  Before initial run  Fix problem;
                Calibration Gas     calibration error.  manufacturer        and after failed    retest.
                Performance.                            certified           sampling system
                                                        concentration for   bias test.
                                                        the mid- and span-
                                                        level calibration
                                                        gases (or 2
                                                        percent of span
                                                        if not subject to
                                                        an emission
                                                        standard); for
                                                        the zero gas less
                                                        than +/-0.25% of
                                                        span.
M............  System Performance  Sampling system     5% of std for high- Before/after each   Fix problem;
                                    bias.               level and zero      run.                retest.
                                                        gas; where
                                                        emission std is
                                                        <= 10 ppmv, there
                                                        is a temporary
                                                        alternative if
                                                        the absolute
                                                        value of the bias
                                                        is <=0.50 ppmv.
M............  System Performance  System response     Determines minimum  During initial
                                    time.               sampling time per   sampling system
                                                        point.              bias test.
M............  System Performance  NO2	NO conversion    90% of  After every test..  Fix problem or
                                    efficiency.         certified value.                        replace
                                                                                                equipment.
M............  System Performance  Minimum sample      2 times the system  Each sample point.
                                    time.               response time
                                                        plus purge time.
M............  System Performance  Stable sample flow  < +/-5% of          Each run..........  Adjust flow.
                                    rate (surrogate     required flow.
                                    for maintaining
                                    system response
                                    time).
M............  Sample Point        Follow Method 1
                Selection.          OR.
A............  ..................  Stratification      < 5% of mean = 1-   Prior to or during  Relocate or
                                    test.               point.              first run.          follow Method 1.
                                                        < 10% of mean = 3-
                                                        point.
A............  Multiple Sample     No. of openings in  Single or           Each run..........  Change the
                Points              probe.              multihole (rake).                       number.
                Simultaneously.
M............  Sample Line.......  Line material &     SS =140[deg] C,                         temperature.
                                    dryer).             or 25[deg] C
                                                        greater than the
                                                        dew point until
                                                        moisture removed.
S............  ..................  Line material &     SS or PTFE; no      Each run.
                                    temp(after dryer).  heat req'd after
                                                        dryer.
S............  Calibration Valve.  Material..........  SS................  Each run..........  Replace valve.
S............  Sample Pump.......  Material..........  Inert to sample     Verified if         Replace pump.
                                                        constituents.       sampling system
                                                                            bias test is
                                                                            passed.
S............  Manifolding.......  Material..........  Inert to sample     Verified if bias    Replace.
                                                        constituents.       test is passed.
S............  Moisture Removal..  Equipment type      < +/-5% target      Verified if bias    Replace
                                    (condenser or       compound removal.   test is passed.     equipment.
                                    permeation dryer).
S............  Particulate         Inertness of        Pass sampling       Verified if bias    Replace filter.
                Removal.            filter.             system bias test.   test is passed.
S............  ..................  Filter temperature  Maintained  95 [deg]C.
M............  Data Recording....  Frequency.........  <= 1 minute         During run........  Remeasure.
                                                        average.
M............  Data Parameters...  Sample              All 1-minute        Each run..........  Note in report.
                                    concentration       averages within
                                    range.              analyzer range.
M............  Data Quality        Calculate upper     Additional          Each Run.
                Assessment Using    and lower           requirement is
                Sampling System     uncertainty         that the apparent
                Bias Data.          limits for each     bias must be
                                    run using the       between +/-5% of
                                    mean measured       emission limit
                                    data, converter     equivalent
                                    efficiency, and     concentration or
                                    the largest and     < 1.5 ppmv. See
                                    smallest sampling   section 12.5 for
                                    system bias for     equations and
                                    that run.           conditions.

[[Page 58851]]

 
M-A3.........  Alternative Data    Dynamic spike.....   5 1-    Before and after    Redo after
                Quality Check.                          min avgs. with      each test & in      correcting
                                                        average 100 +/-5%   place of pre- and   problem, retest.
                                                        recovery for        post-run sampling
                                                        pretest and 100 +/  system bias tests
                                                        -10% for post-      and interference
                                                        test or <=0.2       check.
                                                        ppmv. See section
                                                        12.3 for equation.
M-A..........  Data Quality        Calculate upper     See section 12.6.2  Each test.
                Assessment Using    and lower           for equations and
                Dynamic spike       uncertainty         conditions.
                Recovery data.      limits for each
                                    test using the
                                    mean measured
                                    data, and
                                    converter
                                    efficiency and
                                    the largest (and
                                    smallest) spike
                                    recovery.
----------------------------------------------------------------------------------------------------------------
1 S = Suggested.
2 M = Mandatory.
3 A = * * *.

10.0 Calibration and Standardization

What Measurement System Calibrations Are Required?

    10.1 Initial Analyzer Calibration. You may introduce the 
calibration gases in any sequence. Make all necessary adjustments to 
calibrate the gas analyzer and data recorder. If your analyzer 
measures NO and NO2 separately, then you must use both NO 
and NO2 calibration gases. You may use a non-linear 
calibration curve to convert your gas analyzer's response to the 
equivalent gas concentration. However, you must establish the non-
linear calibration curve before conducting the analyzer calibration 
error test. If you use a non-linear calibration curve, you must use 
it for all sample and calibration measurements. You must also 
include a copy of the manufacturer's certification of the 
calibration gases which include the 13 documentation requirements in 
the EPA Traceability Protocol For Assay and Certification of Gaseous 
Calibration Standards, September 1997, as amended August 25, 1999 
(http://www.epa.gov/ttn/emc/) as part of the test report. Then you 
must pass the analyzer calibration error check. In addition, unless 
you follow the alternative dynamic spiking option, you must pass the 
sampling system bias test before you start measurements.

11.0 Analytical Procedures

    Because sample collection and analysis are performed together 
(see section 8), additional discussion of the analytical procedure 
is not necessary.

12.0 Calculations and Data Analysis

    12.1 Nomenclature. The terms used in the equations are defined 
as follows:

B = Sampling system bias.
BWS = Moisture content of sample gas as measured with 
Method 4 or other approved method, percent/100.
Cadj = Pollutant concentration corrected to 15 percent 
O2 ppmv.
Cd = Pollutant or diluent concentration adjusted to dry 
conditions, ppmv or percent.
Cdir = Direct calibration concentration (ppmv) of a 
calibration gas, dry basis, reported by gas analyzer.
Ch = Concentration (ppmv) corresponding to the emission 
standard (determined in section 12.1.1).
Cs = System calibration concentration (ppmv) of a 
calibration gas, dry basis, reported by gas analyzer.
Cv = Manufacturer certified concentration (ppmv) of a 
calibration gas, dry basis.
Cw = Pollutant or diluent concentration measured under 
moist sample conditions, ppmv, percent, or ng/sm\3\ (lb/scf).
%CO2 = Measured CO2 concentration measured, 
dry basis, percent.
%CO2w = Measured CO2 concentration measured on 
a moist sample basis, percent.
DF = Dilution factor of the spike gas; this value shall be [gE]10.
E = Mass emission rate of pollutant per gross calorific value of the 
fuel from Method 19, ng/J (lb/10\6\ Btu).
EffNO2 = NO2 to NO converter efficiency.
Fc = Ratio of the volume of carbon dioxide produced to 
the gross calorific value of the fuel from Method 19, dsm\3\/J 
(dscf/10\6\ Btu).
Fd = Ratio of the volume of dry effluent gas to the gross 
calorific value of the fuel from Method 19, dsm\3\/J (dscf/10\6\ 
Btu).
Fo = Fuel factor based on the ratio of oxygen volume to 
the ultimate CO2 volume produced by the fuel at zero 
percent excess air, dimensionless.
GCV = Gross calorific value of the fuel consistent with the ultimate 
analysis, kJ/kg (Btu/lb).
K = Conversion factor.
M = Mass of NOx.
%O2 = Measured O2 concentration dry basis, 
percent.
SF6(dir) = SF6 (or tracer gas) concentration 
measured directly in undiluted spike gas.
SF6(spk) = Diluted SF6 (or tracer gas) 
concentration measured in a spiked sample.
Spikedir = Concentration of NOX in the spike 
standard measured in direct calibration mode.
XCO2 = CO2 correction factor, percent.
0.209 = Fraction of air that is oxygen, percent/100.
5.9 = 20.9 percent O2-15 percent O2, the 
defined O2 correction value, percent.

    12.1.1 Concentration equivalent of the emission standard. What 
if my emission standard is not in units of concentration?

BILLING CODE 6560-250-P

[[Page 58852]]

[GRAPHIC] [TIFF OMITTED] TP10OC03.021

BILLING CODE 6560-50-C
    12.2 Analyzer Calibration Error Test. Use Equation 7E-1 to 
calculate the analyzer calibration error for each calibration gas.
[GRAPHIC] [TIFF OMITTED] TP10OC03.002

    12.3 Alternative Dynamic Spike Recovery. Use Equation 7E-2 to 
calculate the alternative dynamic spike recovery.
[GRAPHIC] [TIFF OMITTED] TP10OC03.003

    12.4 Sampling System Bias Check. Use Equation 7E-3 to calculate 
the sampling system bias for each calibration gas.
[GRAPHIC] [TIFF OMITTED] TP10OC03.004

    12.5 NO2-NO Conversion Efficiency. Use Equation 7E-4 
to calculate the NO2 to NO converter efficiency.
[GRAPHIC] [TIFF OMITTED] TP10OC03.005

    12.6 Uncertainty Estimate.
    12.6.1 Using the largest (and smallest) bias value obtained in 
the pre- and/or post-run sampling system bias test, calculate and 
report an upper and lower uncertainty interval around each run 
average concentration using Equation 7E-5.
[GRAPHIC] [TIFF OMITTED] TP10OC03.006

    12.6.2 Using the largest (and smallest) recovery obtained in the 
pre- and post-test ADSC, calculate and report an upper and lower 
uncertainty interval around the test average concentration using 
Equation 7E-6.
[GRAPHIC] [TIFF OMITTED] TP10OC03.007

    12.7 Miscellaneous calculations.
    12.7.1 Moisture Correction. The data you use for most of the 
calculations must be on a dry basis. Use Equation 7E-7 if any of 
your measurements need to be corrected to a dry basis.
[GRAPHIC] [TIFF OMITTED] TP10OC03.008

    12.7.2 Using CO2 as the diluent monitor. You must 
have an equivalent CO2 correction factor if pollutant 
concentrations are to be corrected to 15 percent O2 and 
you measure CO2 concentration in lieu of O2 
concentration. Perform the following procedures to calculate the 
CO2 correction factor.
    12.7.2.1 Using the values obtained from section 12.3.2 of Method 
19 and Equation 7E-8, calculate the fuel-specific FO 
value for the fuel burned during the test.

[[Page 58853]]

[GRAPHIC] [TIFF OMITTED] TP10OC03.009

    12.7.2.2 Use Equation 7E-9 to calculate the equivalent 
CO2 correction factor for correcting measurement data to 
15 percent O2.
[GRAPHIC] [TIFF OMITTED] TP10OC03.010

    12.7.2.3 Correct the pollutant concentrations to 15 percent 
O2 equivalent. Using Equations 7E-10, calculate the 
NOX gas concentrations adjusted to 15 percent 
O2. The correction to 15 percent O2 is very sensitive to 
the accuracy of the O2 or CO2 concentration 
measurement. Therefore, oxygen or CO2 analyzer stability 
and careful calibration are necessary.
[GRAPHIC] [TIFF OMITTED] TP10OC03.011

    12.7.3 Dilution Adjustment of Pollutant Concentration Using 
O2 Concentration. Use Equation 7E-11 to calculate the 
concentration adjusted to 15 percent O2.
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    12.7.4 Average Adjusted NOX Concentration. To 
calculate the average adjusted NOX concentration, sum the 
adjusted values for each sample point and divide by the number of 
points (k) for each run using Equation 7E-12.
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    12.7.5 NOX Emission Rate Calculations. Calculate the 
emission rates for NOX in units of pollutant mass per 
quantity of heat input using the pollutant and diluent 
concentrations and fuel-specific F-factors based on the fuel 
combustion characteristics. You must convert the measured 
concentrations of pollutant from parts per million by volume (ppmv) 
to mass per unit volume. See Table 7E-2 for conversion factors.

            Table 7E-2.--Conversion Factors for Concentration
------------------------------------------------------------------------
                                                         Multiply by
               From                       To          conversion factor
                                                            (CV)
------------------------------------------------------------------------
g/sm\3\...........................  ng/sm\3\......  10\9\
mg/sm\3\..........................  ng/sm\3\......  10\6\
lb/scf............................  ng/sm\3\......  1.602 x 10\13\
ppmv (NOX)........................  ng/sm\3\......  1.912 x 10\6\
ppmv (NOX)........................  lb/scf........  1.194 x 10-7
------------------------------------------------------------------------

    12.7.5.1 Calculation of Emission Rate Using Oxygen Correction. 
The O2 concentration and pollutant concentration must be 
on a dry basis. Use Equation 7E-13 to calculate the pollutant 
emission rate in units of mass NOX per unit of heat 
input.
[GRAPHIC] [TIFF OMITTED] TP10OC03.014

    12.7.5.2 Calculation of Emission Rate Using Carbon Dioxide 
Correction. The CO2 concentration and the pollutant 
concentration may be on either a wet basis or a dry basis. Both 
concentrations must be on the same basis for the calculations. Use 
Equation 7E-14 or 7E-15 to calculate the pollutant emission rate in 
units of mass NOX per unit of heat input.
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    12.7.5.3 Calculation of mass emission rate using fuel usage rate 
and F-Factors. Use Equation 7E-16
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13.0 Method Performance

    13.1 Analytical Range. Your span-level calibration gas sets the 
upper limit of your instrument's calibration. Choose the span-level 
calibration gas that would result in the sampled gases being on-
scale and averaging 20-100 percent of the span. If at any time 
during a run a measured 1-minute average gas concentration exceeds 
the span, you must at a minimum identify and report these minutes as 
deviations of the method. Depending on the data quality objectives 
of the sampling program, this event may require additional 
corrective action before proceeding with the test program. See 
section 1.3.1 for discussion.
    13.2 Sensitivity. See discussion in section 1.3.1.
    13.3 System Response and Minimum Sampling Times. The system 
response time determines the minimum sampling time at each sampling 
point. There is no minimum system response time specified, however 
the minimum sampling time per sample point is 2 times the system 
response time plus purge time. For example, if you use a sampling 
system with a 2 minute system response time, this means that in 
addition to purging the system for at least 4 minutes, you must 
record a minimum of 4 one-minute averages at each sample point.
    13.4 Analyzer Calibration Error. The difference between the 
direct calibration response and the manufacturer certified 
concentration must be less than +/-2 percent of the manufacturer 
certified concentration for the low-, mid- and span-level 
calibration gases and +/-0.25 percent of analyzer upper range limit 
for the zero gas.
    13.5 Sampling System Bias. The pre- and post-run sampling system 
bias must be within +/-5 percent of the concentration equivalent of 
the emission standard (or +/-5 percent of span if not subject to an 
emission standard) for the low- and span-level (or mid-level, as 
applicable) calibration gases. However, for test facilities with 
emission standards equivalent to 10.0 ppmv or less, if the absolute 
value of the bias is less than or equal to 0.50 ppmv, then the 
requirements of the sampling system bias test are satisfied. This 
provision for low-standard facilities is valid only for tests 
completed within 3 years of the effective date of this amendment's 
promulgation.
    13.6 Interference Check. The interference response must not be 
greater than 2.5 percent of the analyzer upper range limit.
    13.7 NO2 to NO Conversion Efficiency Test (as applicable). The 
conversion efficiency must be greater than 90 percent of the 
certified value of the test gas.
    13.8 Alternative Dynamic Spike Check (ADSC). If your analyzer 
has been certified through the manufacturer's stability test, you 
may substitute a pre- and post-test ADSC for the interference check 
and pre- and post-run sampling system bias checks. Recoveries of 
both pre-test spikes must be within 100 +/-5 percent . Recoveries of 
both the post-test ADSC spikes must be within 100 +/-10 percent. If 
the absolute difference between the calculated spike value (CS) and 
measured spike value (Cm) is equal to or less than 0.20 ppmv, then 
the requirements of the ADSC are met. This provision for low-
standard facilities is valid only for tests completed within 3 years 
of the effective date of this amendment's promulgation.

14.0 Pollution Prevention [Reserved]

15.0 Waste Management [Reserved]

16.0 Alternative Procedures

    16.1 Dynamic Spiking Procedure. You may choose to validate your 
test data with this alternative dynamic spiking procedure. You must 
meet the following requirements to use this option.
    16.1.1 You must certify that you followed a written procedure 
and have demonstrated ability, within the last calender year, to 
operate the spiking system following that written procedure in 
either a simulated or actual application. Demonstrated ability means 
that you have operated the spiking system at a target concentration 
equal to or less than the target concentration for this test and 
obtained a data set of 30 1-minute averages with a mass recovery of 
100 +/-5 percent of the mass of NOX spiked with a 
relative standard deviation of those 30 1-minute averages equal or 
less than 5 percent.
    16.1.2 Spiking procedure requirements. You must follow the 
written procedure that you have demonstrated your ability to 
perform. The volume of the spike gas added must be less than 10 
percent of the total volume. The dynamic spiking procedure must be 
done before the first run and repeated after the last run of the 
test program. However, the pre-test requirement is waived if you 
provide a valid certification that the analyzer has been shown to 
meet the manufacturer's stability test in section 16.2 below. Both 
the pre- and post-test must consist of 2 target levels. One level 
must add between 1 and 2 time the native mass and the other level 
must add between 5 and 1 times the native stack NOX mass 
in the sample stream. The spikes must be prepared from a gas 
certified by the traceability protocol (G1 or G2) to contain 
NOX of known concentration with an uncertainty equal to 
or

[[Page 58854]]

less than 2 percent. The minimum number of datum to represent each 
target concentration are 5; we strongly suggest more since you must 
calculate and report an uncertainty range around the measured 
concentration based on these recoveries. If the recovery is outside 
100 +/-10 percent, then the reason for the bias should be determined 
and reported. As a condition of your using this option, you must 
document and confirm that during the entire test you operated within 
the ambient temperature and pressure and voltage ranges certified by 
the manufacturer. You must also list all manufacturer fault and 
alarm codes and identify any that were activated during the test.
    16.1.3 Example spiking procedure using a tracer gas. Introduce 
the spike/tracer gas at a constant flow rate of 10 percent of the 
total sample flow. (Note: Use the rotameter at the end of the 
sampling train to estimate the required spike/tracer gas flow rate.) 
Use a mass flow meter (+/-2 percent), to monitor the spike flow 
rate. Record the spike flow rate every 1 minute. Wait for at least 2 
times the response time T, then record at least 5 successive 1 
minute averages of the spiked sample gas. The spiked concentration 
shall be within 5 percent of the mean of the 5 measurements. 
Calculate the dilution factor using the tracer gas as follows:
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    16.2 Manufacturer's Stability Test. Subject each analyzer model 
to a range of potential effects to demonstrate its stability 
following the procedures provided in 40 CFR 53.23, 53.55, and 53.56 
and provide the information in a summary format. A copy of this 
information must be included in each test report.
    16.3 Annual Primary Interference Gas Recheck. Perform an 
interference gas check using the 4 primary interference gases 
identified in the manufacturer's stability test on an annual basis, 
when indicated as corrective action by an alarm or fault and, 
whenever major component repairs are required. Record the responses. 
For each of the 4 primary interference gases, the 95 percent 
confidence interval determined in the manufacturer stability test 
must include the abbreviated interference gas check value prior to 
returning the analyzer to service.

17.0 References

    1. ``EPA Traceability Protocol for Assay and Certification of 
Gaseous Calibration Standards' September 1997 as amended, EPA-600/R-
97/121.

18.0 Tables, Diagrams, Flowcharts, and Validation Data

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                                  Table 7E-1.--Analyzer Calibration Error Data
----------------------------------------------------------------------------------------------------------------
    Source identification: XXXXXXXX  Test personnel:       Analyzer calibration error data for  sampling runs:
        XXXXXXXX  Date: XXXXXXXX Time: XXXXXXXX            XXXXXXXX  Analyzer model No. XXXXX Serial No. XXXXX
----------------------------------------------------------------------------------------------------------------
                                         Manufacturer         Analyzer
                                          certified         calibration          Absolute           Percent
                                        cylinder value        response          difference         difference
                                       (indicate units)   (indicate units)   (indicate units)
----------------------------------------------------------------------------------------------------------------
                                                      A                  B  [verbar]A-B[verba  [[verbar]A-B[verb
                                                                                           r]           ar]]*100
-------------------------------------
Low calibration gas.................  .................  .................  .................  .................
Mid-level caliberation gas..........  .................  .................  .................  .................
Span-level calibration gas..........  .................  .................  .................  .................
----------------------------------------------------------------------------------------------------------------


              Table 7E-2.--Sampling System Bias Check Data
------------------------------------------------------------------------
 
-------------------------------------------------------------------------
Source identification: XXXXXXXX Run number: XXXXXXXX
Test personnel: XXXXXXXX Emission std: XXXXXXXX Concentration
 equivalent: XXXXXXXX
Date: XXXXXXXX Response time: XXXXXXXX
Analyzer model No. XXXXXXXX Serial No. XXXXXXXX


--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                               Initial values                     Final values
                                                                                     -------------------------------------------------------------------
                                                                     Calibration gas                     System bias                       System bias
                                                                       value (ppmv)   System response    (percent of    System response    (percent of
                                                                                           (ppmv)       emission std.        (ppmv)       emission std.
                                                                                                         equivalent)                       equivalent)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Low-level gas......................................................  ...............  ...............  ...............  ...............  ...............
Span- (or mid-) level gas..........................................  ...............  ...............  ...............  ...............  ...............
--------------------------------------------------------------------------------------------------------------------------------------------------------

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                                    Table 7E-5.--Manufacturer Stability Test
----------------------------------------------------------------------------------------------------------------
                                         Analyzer model test frequency
                                  ------------------------------------------
                                                 Quarterly or
         Test description                           not to                           Acceptance criteria
                                    Annual  (or    exceed 50       Each
                                   1st quarter)   production     analyzer
                                                     units
----------------------------------------------------------------------------------------------------------------
Thermal Stability................            X   ............  ............  Temperature range when drift does
                                                                              not exceed 3% of analyzer range
                                                                              over a 2-hour run when measured
                                                                              with NOX present @ >=80% of range.
Fault Conditions.................            X   ............  ............  Note 1.
Alarm Conditions.................            X   ............  ............  Note 2.
Interference Gas Test............            X             X   ............  1. I(annual) <=2.5% of range.
                                                                             2. I(quarterly) <= I(annual).
Insensitivity to Supply Voltage              X             X   ............  1. Both +/-10% of nominal voltage
 Variations.                                                                  (or the manufacturer specified
                                                                              range) must produce no more than
                                                                              2% of range drift at either 0 or
                                                                              with NoX present >80% of range.
                                                                             2. Drift(quarterly) <=
                                                                              Drift(annual).
Analyzer Calibration Error.......            X             X             X   For a low, medium, and span gas,
                                                                              the difference between
                                                                              manufacturer certified value and
                                                                              analyzer response in direct
                                                                              calibration mode, no more than 2%
                                                                              of manufacturer certified value.
Analyzer Response Time...........            X             X             X   RT(individual) & RT(quarterly) <=
                                                                              RT(annual).
Intrinsic Source Gas Analyzer                X             X   ............  1. Identify (annually).
 Settings/Adjustments.                                                       2. Settings(quart) <=
                                                                              setting(annual).
Primary 4 Interference Gas Test..  ............            X             X   1. I(annual4) <= 2.5% of range.
                                                                             2. Each analyzer measured response
                                                                              must be <= the response obtained
                                                                              from the annual analyzer test for
                                                                              each of the 4 gases.
----------------------------------------------------------------------------------------------------------------
Note 1: Identify conditions which, when they occur, are deemed by the manufacturer to result in performance
  which is not in compliance with this performance specification. These are to be indicated both audibly or
  visually and electrically. The annual test must document that these indicators correlate with the intended
  fault condition.
Note 2: Identify conditions which, when they occur, the manufacturer recommends review and/or corrective action
  by trained service personnel to prevent further deterioration of analyzer performance that could result in
  performance which is not in compliance with this performance specification. These are to be indicated both
  audibly or visually and electrically. The annual test must document that these alarms correlate with the
  intended alarm condition.

* * * * *

Method 10--Determination of Carbon Monoxide Emissions From Stationary 
Sources (Instrumental Analyzer Procedure)

1.0 Scope and Application

What Is Method 10?

    Method 10 is a procedure for measuring carbon monoxide (CO) in 
stationary source emissions using a continuous instrumental 
analyzer. Quality assurance and quality control requirements are 
included to assure that you, the tester, collect data of known 
quality. You must document your adherence to these specific 
requirements for equipment, supplies, sample collection and 
analysis, calculations, and data analysis. This method does not 
completely describe all equipment, supplies, and sampling and 
analytical procedures you will need but refers to other methods for 
some of the details. Therefore, to obtain reliable results, you 
should also have a thorough knowledge of these additional test 
methods:
    (a) Method 1--Sample and Velocity Traverses for Stationary 
Sources.
    (b) Method 4--Determination of Moisture Content in Stack Gases.
    (c) Method 7E--Determination of Nitrogen Oxides Emissions From 
Stationary Sources (Instrumental Analyzer Procedure).
    All methods in this list appear in 40 CFR part 60, appendix A.
    1.1 Analytes. What does this method determine?

----------------------------------------------------------------------------------------------------------------
               Analyte                    CAS No.                            Sensitivity
----------------------------------------------------------------------------------------------------------------
CO...................................     630-08-0   See discussion in section 1.3.
----------------------------------------------------------------------------------------------------------------

    1.2 Applicability. When is this method required? Method 10 is 
required in specific New Source Performance Standards and State 
Implementation Plans and permits where measuring CO concentrations 
in stationary source emissions is required. Other regulations may 
also require its use.
    1.3 Data Quality Objectives. Refer to section 1.3 of Method 7E.

2.0 Summary of Method

    In this method, you continuously or intermittently sample the 
emission gas and convey the sample to a nondispersive infrared 
analyzer (NDIR) that measures the concentration of CO. You must 
adhere to the performance requirements of this method to validate 
your data.

3.0 Definitions

    3.1 The Analyzer Calibration Error, Calibration Curve, Direct 
Calibration, System Calibration, Calibration Gas, Data Recorder, Gas 
Analyzer, Interference Check, Measurement System, Range, Response 
Time, Sampling System Bias, and Span are the same as in sections 3.0 
of Method 7E.

4.0 Interferences

    Any substance having a strong absorption of infrared energy will 
interfere to some extent. The following table gives examples. The 
table shows how the interference ratio can be higher when the 
measuring device has a low range (0-100 ppm). You can eliminate 
major interference problems by using silica gel and ascarite traps. 
If you use ascarite traps, correct the measured gas volume for the 
CO2 removed in the trap. Instrument correction is also an 
acceptable means of compensating for interference.

------------------------------------------------------------------------
           Device range (ppm)                   Interference ratio
------------------------------------------------------------------------
1500-3000...............................  3.5% H20 per 7 ppm CO.
1500-3000...............................  10% CO2 per 10 ppm CO.
 0-100..................................  3.5% H2O per 25 ppm CO.

[[Page 58861]]

 
 0-100..................................  10% CO2 per 50 ppm CO.
------------------------------------------------------------------------

5.0 Safety

    Refer to section 5.0 of Method 7E.

6.0 Equipment and Supplies

    Figures 10-1, 10-2, and 10-3 are schematic diagrams of 
acceptable continuous and integrated measurement systems and the 
analytical system. You must use a measurement system for CO that 
meets the following specifications for the essential components.
    6.1 What do I need for the measurement system? Sample Probe, 
Particulalte Filter, Heated Sample Line, Sample Lines, Moisture 
Removal System, Sample Pump, Flow Control/Gas Manifold, Sample Gas 
Manifold, and Data Recorder. You must follow the noted 
specifications in section 6.1 of Method 7E.
    6.2 CO Analyzer. An instrument that uses nondispersive infrared 
detection principal to continuously measure CO in the gas stream and 
meets the specifications in section 13.0. The dual-range analyzer 
provisions of section 6.1.8.1 of Method 7E apply.

7.0 Reagents and Standards

    7.1 Calibration Gas. What calibration gases do I need? Refer to 
section 7.1 of Method 7E for the calibration gas requirements.
    7.2 Interference Check. What additional reagents do I need for 
the interference check? Use the test gases listed in Table 7E-5 of 
Method 7E to conduct the interference check. Conduct the 
interference check by sequentially introducing the gases listed in 
Table 7E-5 (one at a time) both with and without CO into the 
calibrated analyzer and recording the apparent concentrations after 
waiting at least 3 times the analyzer response time. This is then 
repeated with a blend containing a known CO concentration greater 
than 80 percent of the analyzer's range and calculating the 
difference between the known value and the apparent concentration. 
For each potential interferent gas, identify the largest of the 2 
absolute values as the potential interference. The interference for 
all potential interferent gases in the source category must be less 
than 2.5 percent of the range to be acceptable. Record the data on a 
form similar to Figure 7E-8.

8.0 Sample Collection, Preservation, Storage, and Transport

Emission Test Procedure

    8.1 Sampling Site and Sampling Points. You must follow section 
8.1 of Method 7E.
    8.2 Measurement System Performance Tests. You must follow the 
Calibration Gas Verification, Measurement System Preparation, 
Analyzer Calibration Error Test, Initial Sampling System Bias Check, 
Measurement System Response Time, and Interference Check procedures 
in sections 8.2 and 8.3 of Method 7E.
    8.3 Sample Collection. Follow section 8.1. Sample within 5 
percent of the rate you used during the sampling system bias check.
    8.4 Post-Run Sampling System Bias Check and Alternative Dynamic 
Spike Procedure. Follow sections 8.5 and 8.6 of Method 7E.

9.0 Quality Control

    Follow quality control procedures in section 9.0 of Method 7E.

10.0 Calibration and Standardization

    Follow the procedures for calibration and standardization in 
section 10.0 of Method 7E.

11.0 Analytical Procedures

    Because sample collection and analysis are performed together 
(see section 8), additional discussion of the analytical procedure 
is not necessary.

12.0 Calculations and Data Analysis

    You must follow the procedures for calculations and data 
analysis in section 12.0 of Method 7E, as applicable.

13.0 Method Performance

    13.1 The Analytical Range, Sensitivity, System Response and 
Minimum Sampling Times, Analyzer Calibration Error, Sampling System 
Bias, Interference Test and Alternative Dynamic Spike Check 
specifications are the same as in section 13.0 of Method 7E.

14.0 Pollution Prevention [Reserved]

15.0 Waste Management [Reserved]

16.0 Alternative Procedures

    16.1 Alternative Interference Check.
    16.2 Dynamic Spiking Procedure, Manufacturer's Stability Test 
and Annual Primary Interference Recheck (as applicable). These 
procedures are the same as in section 16 of Method 7E.

17.0 References

    1. ``EPA Traceability Protocol for Assay and Certification of 
Gaseous Calibration Standards'' September 1997 as amended, EPA-600/
R-97/121.

18.0 Tables, Diagrams, Flowcharts, and Validation Data

                                             Table 10-1.--Field Data
----------------------------------------------------------------------------------------------------------------
 
----------------------------------------------------------------------------------------------------------------
Location:                                                                   Date:
---------------------------------------------------------------------------
Test:                                                                       Operator:
---------------------------------------------------------------------------
             Clock Time                Rotameter Reading liters/min (cfm)                 Comments
-------------------------------------
 
-------------------------------------
 
-------------------------------------
 
-------------------------------------
 
-------------------------------------
 
-------------------------------------
 
-------------------------------------
 
-------------------------------------
----------------------------------------------------------------------------------------------------------------


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* * * * *

Method 20--Determination of Nitrogen Oxides and Sulfur Dioxide 
Emissions From Stationary Gas Turbines

1.0 Scope and Application

What Is Method 20?

    Method 20 contains the details you must follow when using an 
instrumental analyzer to determine concentrations of nitrogen 
oxides, oxygen, and sulfur dioxide in the emissions from stationary 
gas turbines. This method refers to other methods for specific 
instructions for equipment and performance requirements, supplies, 
sample collection and analysis, calculations, and data analysis. All 
methods that are referenced are in appendix A of 40 CFR part 60.
    1.1 Analytes. What does this method determine?

----------------------------------------------------------------------------------------------------------------
                Analyte                   CAS No.                            Sensitivity
----------------------------------------------------------------------------------------------------------------
Nitrogen oxides (NOX) as nitrogen       ...........  See section 1.3 of Method 7E.
 dioxide.
    Nitric oxide (NO).................   10102-43-9  ...........................................................
    Nitrogen dioxide (NO2)............   10102-44-0  ...........................................................
Diluent oxygen (O2) or carbon dioxide   ...........  See section 1.3 of Method 3A.
 (CO2).
Sulfur dioxide (SO2)..................    7446-09-5  See section 1.3 of Method 6C.
----------------------------------------------------------------------------------------------------------------

    1.2 Applicability. When is this method required? Method 6C is 
required in specific New Source Performance Standards, Clean Air 
Marketing rules, and State Implementation Plans and permits where 
measuring SO2 concentrations in stationary source 
emissions is required. Other regulations may also require its use.
    1.3 Data Quality Objectives. Refer to section 1.3 of Method 7E.

2.0 Summary of Method

    In this method, NOX, O2 (or 
CO2), and SO2 are measured using the following 
methods:
    Method 1--Sample and Velocity Traverses for Stationary Sources.
    (a) Method 7E--Determination of Nitrogen Oxides Emissions From 
Stationary Sources (Instrumental Analyzer Procedure).
    (b) Method 3A--Determination of Oxygen and Carbon Dioxide 
Emissions From Stationary Sources (Instrumental Analyzer Procedure).
    (c) Method 6C--Determination of Sulfur Dioxide Emissions From 
Stationary Sources (Instrumental Analyzer Procedure).

3.0 Definitions

    Refer to section 3.0 of Method 7E.

4.0 Interferences [Reserved]

5.0 Safety

    Refer to section 5.0 of Method 7E.

6.0 Equipment and Supplies

    The measurement system design is shown in Figure 20-1. Refer to 
the appropriate methods listed in section 2.0 for equipment and 
supplies.

7.0 Reagents and Standards

    Refer to the appropriate methods listed in section 2.0 for 
reagents and standards.

8.0 Sample Collection, Preservation, Storage, and Transport

Emission Test Procedure

    8.1 Sampling Site and Sampling Points. You must follow section 
8.1 of Method 7E.
    8.2 Measurement System Performance Tests. You must follow the 
Calibration Gas Verification, Measurement System Preparation, 
Analyzer Calibration Error Test, NO2 to NO Conversion 
Efficiency Test (as applicable), Initial Sampling System Bias Check, 
System Response Time.
    8.3 Sample Collection. Follow section 8.4 of Method 7E.
    8.4 Post-Run Sampling System Bias Check and Alternative Dynamic 
Spike Procedure. Follow sections 8.5 and 8.6 of Method 7E.

9.0 Quality Control

    Follow quality control procedures in section 9.0 of Method 7E.

10.0 Calibration and Standardization

    Follow the procedures for calibration and standardization in 
section 10.0 of Method 7E.

11.0 Analytical Procedures

    Because sample collection and analysis are performed together 
(see section 8), additional discussion of the analytical procedure 
is not necessary.

12.0 Calculations and Data Analysis

    You must follow the procedures for calculations and data 
analysis in section 12.0 of the appropriate method listed in section 
2.0.

13.0 Method Performance

    13.1 The Analytical Range, Sensitivity, System Response and 
Minimum Sampling Times, Analyzer Calibration Error, Sampling System 
Bias, NO2 to NO Conversion Efficiency Test (as 
applicable), Interference Check, and Alternative Dynamic Spike Check 
specifications are the same as in section 13.0 of Method 7E.

14.0 Pollution Prevention [Reserved]

15.0 Waste Management [Reserved]

16.0 Alternative Procedures

    Refer to section 16.0 of the appropriate method listed in 
section 2.0 for alternative procedures.

17.0 References

    Refer to section 17.0 of the appropriate method listed in 
section 2.0 for references.

18.0 Tables, Diagrams, Flowcharts, and Validation Data

    In addition to Figure 20-1, refer to section 18.0 of the 
appropriate method listed in section 2.0 for tables, diagrams, 
flowcharts, and validation data.

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* * * * *
[FR Doc. 03-24909 Filed 10-9-03; 8:45 am]
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