[Federal Register: October 10, 2003 (Volume 68, Number 197)]
[Proposed Rules]
[Page 58837-58866]
From the Federal Register Online via GPO Access [wais.access.gpo.gov]
[DOCID:fr10oc03-28]
[[Page 58837]]
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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
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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 curtis.foston@epa.gov or harrison.terry@epa.gov.
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
[[Page 58839]]
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 a-and-r-docket@epamail.gov, 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.
[GRAPHIC] [TIFF OMITTED] TP10OC03.012
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.
[GRAPHIC] [TIFF OMITTED] TP10OC03.013
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.
[GRAPHIC] [TIFF OMITTED] TP10OC03.015
[GRAPHIC] [TIFF OMITTED] TP10OC03.016
12.7.5.3 Calculation of mass emission rate using fuel usage rate
and F-Factors. Use Equation 7E-16
[GRAPHIC] [TIFF OMITTED] TP10OC03.017
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
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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
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.
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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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