[Federal Register Volume 85, Number 70 (Friday, April 10, 2020)]
[Proposed Rules]
[Pages 20342-20378]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2020-07471]
[[Page 20341]]
Vol. 85
Friday,
No. 70
April 10, 2020
Part II
Environmental Protection Agency
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40 CFR Part 63
Mercury and Air Toxics Standards for Power Plants Electronic Reporting
Revisions; Proposed Rule
Federal Register / Vol. 85, No. 70 / Friday, April 10, 2020 /
Proposed Rules
[[Page 20342]]
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ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 63
[EPA-HQ-OAR-2018-0794; FRL-10007-27-OAR]
RIN 2060-AU70
Mercury and Air Toxics Standards for Power Plants Electronic
Reporting Revisions
AGENCY: Environmental Protection Agency (EPA).
ACTION: Proposed rule.
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SUMMARY: The U.S Environmental Protection Agency (EPA) is proposing
amendments to the electronic reporting requirements for the National
Emission Standards for Hazardous Air Pollutants: Coal- and Oil-Fired
Electric Utility Steam Generating Units (also known as the Mercury and
Air Toxics Standards (MATS)). This proposed action would revise and
streamline the electronic data reporting requirements of MATS and
increase data transparency by requiring use of one electronic reporting
system, instead of two separate systems, and provide enhanced access to
MATS data. No new continuous monitoring requirements would be imposed
by this proposed action; instead, this action would reduce reporting
burden, increase MATS data flow and usage, make it easier for
inspectors and auditors to assess compliance, and encourage wider use
of continuous emissions monitoring systems (CEMS) for MATS compliance.
In addition, this proposed action would extend the current deadline for
alternative electronic data submission via portable document format
(PDF) files through December 31, 2023.
DATES:
Comments. Comments must be received on or before May 11, 2020.
Public hearing. If anyone contacts us requesting a public hearing
on or before April 15, 2020, we will hold a hearing. Additional
information about the hearing, if requested, will be posted at https://www.epa.gov/mats/regulatory-actions-final-mercury-and-air-toxics-standards-mats-power-plants. See SUPPLEMENTARY INFORMATION for
information on requesting and registering for a public hearing.
ADDRESSES: You may send comments, identified by Docket ID No. EPA-HQ-
OAR-2018-0794, by any of the following methods:
Federal eRulemaking Portal: https://www.regulations.gov/
(our preferred method). Follow the online instructions for submitting
comments.
Email: [email protected]. Include Docket ID No. EPA-
HQ-OAR-2018-0794 in the subject line of the message.
Instructions: All submissions received must include the Docket ID
No. for this rulemaking. Comments received may be posted without change
to https://www.regulations.gov/, including any personal information
provided. For detailed instructions on sending comments and additional
information on the rulemaking process, see the SUPPLEMENTARY
INFORMATION section of this document.
Out of an abundance of caution for members of the public and our
staff, the EPA Docket Center and Reading Room will be closed to public
visitors beginning at the close of business on March 31, 2020 (4:30
p.m.) to reduce the risk of transmitting COVID-19. Our Docket Center
staff will continue to provide remote customer service via email,
phone, and webform. We encourage the public to submit comments via
https://www.regulations.gov/ or email, as there will be a delay in
process mail and no hand deliveries will be accepted. For further
information on EPA Docket Center services, please visit us online at
https://www.epa.gov/dockets.
FOR FURTHER INFORMATION CONTACT: Mr. Barrett Parker, Sector Policies
and Programs Division (D243-05), Office of Air Quality Planning and
Standards, U.S. Environmental Protection Agency, Research Triangle
Park, NC 27711; telephone number: (919) 541-5635; email address:
[email protected]. For general information concerning MATS,
contact Ms. Mary Johnson, Sector Policies and Programs Division (D243-
01), Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, NC 27711; telephone number:
(919) 541-5025. For questions concerning the Emissions Collection and
Monitoring Plan System (ECMPS) Client Tool and its implementation,
contact Mr. Christopher Worley, Clean Air Markets Division, Mail Code
6204M, U.S. Environmental Protection Agency, 1200 Pennsylvania Ave. NW,
Washington, DC 20460; telephone number: (202) 343-9531; email address:
[email protected].
SUPPLEMENTARY INFORMATION: The information in this preamble is
organized as follows:
Table of Contents
I. Public Participation
II. General Information
A. Does this action apply to me?
B. What action is the Agency taking?
C. What is the Agency's authority for taking this action?
D. What are the incremental costs and benefits of this action?
III. Background
IV. What is the scope of these proposed amendments?
V. What specific amendments to 40 CFR part 63, subpart UUUUU, are
proposed by this action?
A. Proposed Revisions to the Reporting Requirements of MATS
B. Revisions to Appendix A
C. Revisions to Appendix B
D. Addition to Appendix C
E. Addition to Appendix D
F. Addition to Appendix E
VI. Proposed Revisions to Other Rule Text
VII. Statutory and Executive Order Reviews
A. Executive Order 12866: Regulatory Planning and Review and
Executive Order 13563: Improving Regulation and Regulatory Review
B. Executive Order 13771: Reducing Regulations and Controlling
Regulatory Costs
C. Paperwork Reduction Act (PRA)
D. Regulatory Flexibility Act (RFA)
E. Unfunded Mandates Reform Act (UMRA)
F. Executive Order 13132: Federalism
G. Executive Order 13175: Consultation and Coordination With
Indian Tribal Governments
H. Executive Order 13045: Protection of Children From
Environmental Health Risks and Safety Risks
I. Executive Order 13211: Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution, or Use
J. National Technology Transfer and Advancement Act (NTTAA)
K. Executive Order 12898: Federal Actions To Address
Environmental Justice in Minority Populations and Low-Income
Populations
I. Public Participation
Public hearing. Please contact Ms. Adrian Gates at (919) 541-4860
or by email at [email protected] to request a public hearing, to
register to speak at the public hearing, or to inquire as to whether a
public hearing will be held.
Docket. The EPA has established a docket for this rulemaking under
Docket ID No. EPA-HQ-OAR-2018-0794. All documents in the docket are
listed in Regulations.gov. Although listed, some information is not
publicly available, e.g., Confidential Business Information (CBI) or
other information whose disclosure is restricted by statute. Certain
other material, such as copyrighted material, is not placed on the
internet. Publicly available docket materials are available
electronically in Regulations.gov.
The EPA is temporarily suspending its Docket Center and Reading
Room for public visitors to reduce the risk of transmitting COVID-19.
Written
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comments submitted by mail will be delayed and no hand deliveries will
be accepted. Our Docket Center staff will continue to provide remote
customer service via email, phone, and webform. We encourage the public
to submit comments via https://www.regulations.gov/. For further
information and updates on EPA Docket Center services, please visit us
online at https://www.epa.gov/dockets.
The EPA continues to carefully and continuously monitor information
from the Centers for Disease Control and Prevention, local area health
departments, and our Federal partners so we can respond rapidly as
conditions change regarding COVID-19.
Instructions. Direct your comments to Docket ID No. EPA-HQ-OAR-
2018-0794. The EPA's policy is that all comments received will be
included in the public docket without change and may be made available
online at https://www.regulations.gov/, including any personal
information provided, unless the comment includes information claimed
to be CBI or other information whose disclosure is restricted by
statute. Do not submit information that you consider to be CBI or
otherwise protected through https://www.regulations.gov/ or email. This
type of information should be submitted by mail as discussed below.
The EPA may publish any comment received to its public docket.
Multimedia submissions (audio, video, etc.) must be accompanied by a
written comment. The written comment is considered the official comment
and should include discussion of all points you wish to make. The EPA
will generally not consider comments or comment contents located
outside of the primary submission (i.e., on the Web, cloud, or other
file sharing system). For additional submission methods, the full EPA
public comment policy, information about CBI or multimedia submissions,
and general guidance on making effective comments, please visit https://www.epa.gov/dockets/commenting-epa-dockets.
The https://www.regulations.gov/ website allows you to submit your
comment anonymously, which means the EPA will not know your identity or
contact information unless you provide it in the body of your comment.
If you send an email comment directly to the EPA without going through
https://www.regulations.gov/, your email address will be automatically
captured and included as part of the comment that is placed in the
public docket and made available on the internet. If you submit an
electronic comment, the EPA recommends that you include your name and
other contact information in the body of your comment and with any
digital storage media you submit. If the EPA cannot read your comment
due to technical difficulties and cannot contact you for clarification,
the EPA may not be able to consider your comment. Electronic files
should not include special characters or any form of encryption and be
free of any defects or viruses. For additional information about the
EPA's public docket, visit the EPA Docket Center homepage at https://www.epa.gov/dockets.
Submitting CBI. Do not submit information containing CBI to the EPA
through https://www.regulations.gov/ or email. Clearly mark the part or
all of the information that you claim to be CBI. For CBI information on
any digital storage media that you mail to the EPA, mark the outside of
the digital storage media as CBI and then identify electronically
within the digital storage media the specific information that is
claimed as CBI. In addition to one complete version of the comments
that includes information claimed as CBI, you must submit a copy of the
comments that does not contain the information claimed as CBI directly
to the public docket through the procedures outlined in Instructions
above. If you submit any digital storage media that does not contain
CBI, mark the outside of the digital storage media clearly that it does
not contain CBI. Information not marked as CBI will be included in the
public docket and the EPA's electronic public docket without prior
notice. Information marked as CBI will not be disclosed except in
accordance with procedures set forth in 40 Code of Federal Regulations
(CFR) part 2. Send or deliver information identified as CBI only to the
following address: OAQPS Document Control Officer (C404-02), OAQPS,
U.S. Environmental Protection Agency, Research Triangle Park, North
Carolina 27711, Attention Docket ID No. EPA-HQ-OAR-2018-0794. Note that
written comments containing CBI and submitted by mail will be delayed
and no hand deliveries will be accepted.
II. General Information
A. Does this action apply to me?
Categories and entities potentially affected by this proposed
action include:
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Examples of
Category NAICS code 1 potentially
regulated entities
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Industry.......................... 221112 Fossil fuel-fired
electric utility
steam generating
units (EGUs).
Federal government................ 2 221122 Fossil fuel-fired
EGUs owned by the
Federal government.
State/local/tribal government..... 2 221122 Fossil fuel-fired
EGUs owned by
municipalities.
921150 Fossil fuel-fired
EGUs in Indian
country.
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\1\ North American Industry Classification System.
\2\ Federal, state, or local government-owned and operated
establishments are classified according to the activity in which they
are engaged.
This table is not intended to be exhaustive, but rather provides a
guide for readers regarding entities likely to be regulated by this
action. This table lists the types of entities that EPA is now aware
could potentially be regulated by this action. Other types of entities
not listed in the table could also be regulated. To determine whether
your entity is regulated by this proposed action, you should carefully
examine the applicability criteria in 40 CFR 63.9981 of the rule. If
you have questions regarding the applicability of this action to a
particular entity, consult either the air permitting authority for the
entity or your EPA Regional representative as listed in 40 CFR 63.13.
B. What action is the Agency taking?
The EPA proposes this rule to streamline the electronic data
reporting requirements of MATS; to increase data transparency by making
more of the MATS data available in Extensible Markup Language (XML)
format; and to amend the reporting and recordkeeping requirements
associated with performance stack tests, particulate matter (PM) and
hydrogen chloride (HCl) CEMS, and PM continuous parameter monitoring
systems (CPMS).
C. What is the Agency's authority for taking this action?
The Agency's authority for taking this action is found at 42 U.S.C.
7401 et seq.
D. What are the incremental costs and benefits of this action?
As discussed in section VII.C of this preamble, this action is
expected to
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reduce overall annual source burden by 11,000 hours per year, which
when monetized is $15,079,000.
III. Background
These proposed amendments would revise the recordkeeping and
reporting requirements of the MATS rule, in response to concerns raised
by the regulated community. The MATS rule originally required affected
EGU owners or operators to report MATS rule emissions and compliance
information electronically using two data systems. See 40 CFR 63.10031
(77 FR 9304, February 16, 2012). Paragraph (a) of 40 CFR 63.10031
required EGU owners or operators that demonstrate compliance by
continuously monitoring mercury (Hg) and/or HCl and/or hydrogen
fluoride (HF) emissions to use the Emissions Collection and Monitoring
Plan System (ECMPS) Client Tool to submit monitoring plan information,
quality assurance test results, and hourly emissions data in accordance
with appendices A and B to subpart UUUUU of 40 CFR part 63. Paragraph
(f) of 40 CFR 63.10031 required performance stack test results,
performance evaluations of Hg, HCl, HF, sulfur dioxide
(SO2), and PM CEMS, 30-boiler operating day rolling average
values for certain parameters, Notifications of Compliance Status, and
semiannual compliance reports to be submitted to the EPA's WebFIRE
database via the Compliance and Emissions Data Reporting Interface
(CEDRI).
Subsequent to the publication of the MATS rule, stakeholders
suggested to the EPA that the MATS rule electronic reporting burden
could be significantly reduced if all of the required information were
reported to one data system instead of two. The stakeholders also
suggested that using one data system would benefit the EPA and the
public in their review of MATS rule data, because the information would
be reported in a consistent format. In view of these considerations,
the stakeholders urged the EPA to consider amending the MATS rule to
require all of the data to be reported through the ECMPS, a familiar
data system that most EGU owners or operators have been using since
2009 to meet the electronic reporting requirements of the Acid Rain
Program.
After careful consideration of the stakeholders' recommendations,
the EPA concluded that the increased transparency of the emissions data
and the reduction in reporting burden that could be achieved through
the use of a single data system are consistent with Agency priorities.
As a result, late in 2014 the EPA decided to take the necessary steps
to require all of the electronic reports required by the MATS rule to
be submitted through the ECMPS Client Tool. Those steps would include
revising the MATS rule, modifying the ECMPS Client Tool, creating a
detailed set of reporting instructions, and beta testing the modified
software. Recognizing that insufficient time was available to complete
these tasks before the initial compliance date for the MATS rule (April
16, 2015), the Agency embarked on a two-phased approach to complete
them.
The first phase was completed when the EPA published a final rule
requiring EGU owners or operators to suspend temporarily (until April
16, 2017) the use of the CEDRI interface as the means of submitting the
reports described in 40 CFR 63.10031(f) introductory text and (f)(1),
(2), and (4), and to use the ECMPS Client Tool to submit PDF versions
of these reports on an interim basis (see 80 FR 15510, March 24, 2015).
The specific reports required to be submitted as PDF files included:
Performance stack test reports containing enough information to assess
compliance and to demonstrate that the testing was done properly;
relative accuracy test audit (RATA) reports for SO2, HCl,
HF, and Hg CEMS; RATA reports for Hg sorbent trap monitoring systems;
response correlation audit (RCA) and relative response audit (RRA)
reports for PM CEMS; 30-boiler operating day rolling average reports
for PM CEMS, PM CPMS, and approved hazardous air pollutants (HAP)
metals CEMS; Notifications of Compliance Status; and semiannual
compliance reports. Title 40 CFR 63.10031(f)(6) of the March 24, 2015,
final rule required each PDF version of a submitted interim report to
include information that identifies the facility (name and address),
the EGU(s) to which the report applies, the applicable rule citations,
and other information. The rule further specified that in the event
that implementation of the single data system initiative was not
completed by April 16, 2017, the electronic reporting of MATS data
would revert to the original two systems approach on and after that
date.
In the preamble to the March 24, 2015, final rule, the EPA outlined
the second phase of the single data system initiative, to be executed
during the interim PDF reporting period. In phase two: (1) The Agency
would publish a direct final rule, requiring MATS-affected sources to
use the ECMPS Client Tool to submit all required reports; and (2) a
detailed set of reporting instructions would be developed and ECMPS
would be modified to receive and process the data.
Considering the magnitude of the rule changes that would be
required to execute phase two, coupled with the need to specify data
elements to be reported electronically for PM CEMS, PM CPMS, and HCl
CEMS, the Agency decided to provide stakeholders an opportunity to
review and comment on the proposed changes. The EPA issued the proposed
rule on September 29, 2016.\1\ The comment period for the 2016 proposal
(or previous proposal) was scheduled to close on October 31, 2016, but
it was subsequently extended until November 15, 2016, in response to
requests from several stakeholders for an extension.
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\1\ 81 FR 67062, September 29, 2016.
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Commenters were generally supportive of the initiative to simplify
and streamline the MATS reporting requirements and to use the ECMPS
Client Tool as the single MATS rule reporting system. However, they
expressed serious concerns about the proposal to extend the interim PDF
reporting process from April 16, 2017, to December 31, 2017. Although
they favored an extension of the PDF reporting, they were unanimous in
asserting that the proposed end date of December 31, 2017, would not
allow enough time to finalize the rule, develop the necessary XML
reporting formats and reporting instructions, and reprogram the ECMPS
Client Tool. In addition, two data acquisition and handling system
vendors stated that more time would be needed for them to adapt to the
proposed changes and to develop the reporting software for their
customers. Some of the commenters recommended that the EPA should
extend the interim PDF reporting process through calendar year 2019;
others suggested that the process should be extended for 6 to 8
calendar quarters after finalization of the rule.
In view of these considerations, on April 6, 2017, the EPA
published a final rule extending the interim PDF file reporting process
through June 30, 2018 (82 FR 16736). Technical corrections to appendix
A were also included in the rule package. The rule went into effect on
April 6, 2017. As the Agency was unable to compete the e-reporting
provisions, another extension to the interim PDF file reporting
process--through June 30, 2020--was promulgated on July 2, 2018 (83 FR
30879). This action proposes to further extend the interim PDF
reporting process through December 31, 2023, and proposes the remaining
needed amendments to the MATS rule on
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electronic reporting. Note that these proposed amendments were
developed after consideration of the comments received on the September
29, 2016, proposal.
IV. What is the scope of these proposed amendments?
This proposed action would amend the reporting requirements in 40
CFR 63.10031 of the MATS regulation, and, for consistency with those
changes, would amend related text in 40 CFR part 63, subpart UUUUU;
specifically, 40 CFR 63.10000, 63.10005, 63.10009, 63.10010, 63.10011,
63.10020, 63.10021, 63.10030, 63.10032, 63.10042, and Tables 3, 8, and
9. The recordkeeping and reporting sections of appendices A and B are
also proposed to be amended \2\ and three new appendices are proposed
to be added to the rule, i.e., appendices C, D, and E. Instead of using
the electronic reporting tool (ERT) to submit some of the MATS data via
CEDRI and submitting the remainder through the ECMPS Client Tool, as
was required by the original MATS rule, this proposed action would
allow EGU owners or operators to use the ECMPS Client Tool to report
all of the required information in XML and PDF files.
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\2\ In 2015, the EPA published a technology-neutral performance
specification and associated quality assurance (QA) test procedures
for HCl monitors (see Performance Specification 18 (PS 18) and
Quality Assurance Procedure 6 (Procedure 6) in 80 FR 38628, July 7,
2015). That rule added certification and QA test requirements for
sources electing to monitor HCl according to PS 18 and Procedure 6.
This proposed action would require the results of the appendix B
certification and QA tests to be reported electronically for periods
beginning on January 1, 2024.
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V. What specific amendments to 40 CFR part 63, subpart UUUUU, are
proposed by this action?
The proposed amendments to 40 CFR part 63, subpart UUUUU, are
discussed in detail in the paragraphs below.
A. Proposed Revisions to the Reporting Requirements of MATS
The reporting requirements of MATS are proposed to be amended as
follows:
(1) The ECMPS Client Tool would be used as the exclusive data
system for MATS reporting, in lieu of using both ECMPS and the CEDRI.
(2) The interim PDF reporting process described in 40 CFR
63.10031(f) would be further extended through December 31, 2023, to
allow sufficient time for software development, programming, and
testing. Until then, compliance with the emissions and operating limits
would continue to be assessed based on the various PDF report
submittals described in 40 CFR 63.10031(f) and data from Hg, HCl, HF,
and SO2 CEMS and sorbent trap monitoring systems, as
reported through the ECMPS Client Tool. On and after January 1, 2024,
compliance with the emissions and operating limits would be assessed
based on: (1) Quarterly compliance reports; (2) hourly data from all
continuous monitoring systems (CMS) (including PM CEMS and PM CPMS) in
XML format; (3) detailed reference method information for stack tests
and CMS performance evaluations in XML format and PDF files; (4)
Notifications of Compliance Status (if any), in PDF files; and, (5) if
applicable, supplementary data in PDF files for EGUs using paragraph
(2) of the definition of ``startup'' in 40 CFR 63.10042. The ECMPS
Client Tool would be used to submit all of these reports and
notifications.
(3) In order to properly close out the interim PDF reporting
process, 40 CFR 63.10031(f)(6) would state that PDF submittals will
still be accepted as necessary for the reports required under paragraph
(f) introductory text, (f)(1), (2), or (4) if the deadlines for
submitting those reports extend beyond December 31, 2023. As an
example, the last semiannual compliance report under the interim PDF
reporting process would cover the period from July 1, 2023, through
December 31, 2023; the deadline for submitting this report would be
January 30, 2024, and the report would be submitted using the interim
PDF reporting process.
(4) Revised paragraph (f)(2) of 40 CFR 63.10031 would expand the
quarterly reporting of 30- or 90-boiler operating day rolling average
emission rates to include units monitoring Hg, HCl, HF, and/or
SO2 emissions, and units using emissions averaging. This
change is consistent with 40 CFR 63.10031(f)(2) of the current rule,
which requires quarterly reporting of 30-boiler operating day rolling
averages for EGUs using PM CEMS, PM CPMS, and approved HAP metals CEMS.
Therefore, starting with the first quarter of 2024, the 30- or 90-
boiler operating day rolling averages (or, if applicable, rolling
weighted average emission rates (WAERs) if emissions averaging is used)
would be reported quarterly in XML format for all parameters (including
Hg, HF, HCl, and SO2). However, instead of providing these
rolling averages in separate, stand-alone reports, they would be
incorporated into the quarterly compliance reports required under 40
CFR 63.10031(g) (see section IV.A.(9) of this preamble, below).
(5) Revised paragraphs (a)(1), (2), and (5) of 40 CFR 63.10031
would clarify the electronic reporting requirements for the Hg, HCl,
HF, SO2, and auxiliary CMS. Specifically:
(i) Paragraph (a)(1) would require the electronic reporting
requirements of appendix A to be met if Hg CEMS or sorbent trap
monitoring systems are used.
(ii) Paragraph (a)(2) would require the electronic reporting
requirements of appendix B to be met, with one important qualification,
if HCl or HF monitoring systems are used. Until December 31, 2023, if
Performance Specification (PS) 18 in part 60, appendix B, is used to
certify an HCl monitor and Procedure 6 in part 60, appendix F, is used
for on-going quality assurance (QA) of the monitor, EGU owners or
operators would temporarily report only data that the existing
programming of ECMPS is able to accommodate, i.e., hourly HCl emissions
data and the results of daily calibration drift tests and RATAs;
records would have to be kept of all of the other required
certification and QA tests and supporting data. The reason for this
temporary, limited reporting is that PS 18 and Procedure 6 were not
published until July 7, 2015; therefore, it was not possible to specify
recordkeeping and reporting requirements for them in the original
version of appendix B. Now that PS 18 and Procedure 6 have been
finalized, this rule would add the necessary recordkeeping and
reporting requirements, and the interim reporting for HCl would be
discontinued as of January 1, 2024 (for further discussion, see section
IV.C of this preamble).
(iii) Paragraph (a)(5) would clarify the electronic reporting
requirements for the SO2 CEMS and the auxiliary monitoring
systems under MATS. Sources currently reporting SO2 mass
emissions under the Acid Rain Program or Cross-State Air Pollution Rule
already meet these requirements, except for paragraphs (a)(5)(iii)(C)
and (E), which would require, respectively, quarterly reporting of an
hourly SO2 emission rate data stream in units of the
applicable MATS standard (i.e., pounds per British thermal units (lb/
MMBtu) or pounds per megawatt hours (lb/MWh)) and certification
statements from the responsible official. Separate certification
statements would be required for the 40 CFR part 75 programs and MATS.
(Note: For consistency with the changes described in items (i) through
(iii), immediately above, 40 CFR 63.10031(f)(3) would be removed and
reserved).
(6) Paragraphs (b)(1) and (2) of 40 CFR 63.10031 would be amended
to recognize that some EGUs may have received extensions of their
compliance
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date under 40 CFR 63.6(i)(4). References to postmark dates for
submittal of semiannual compliance reports paragraphs would be removed
from paragraphs (b)(2) and (4); these reports currently are, and would
continue to be, submitted electronically through ECMPS as PDF files,
until they are superseded by quarterly compliance reports, starting in
the first quarter of 2024.
(7) The provision in 40 CFR 63.10031(b)(5), which allowed affected
EGU owners or operators to follow alternate submission schedules for
semiannual compliance reports would be removed. The uniform submission
schedule described in 40 CFR 63.10031(b)(1) through (4) would be
required for all affected EGUs, so that compliance with this reporting
requirement can easily be tracked.
(8) Revised 40 CFR 63.10031(b)(5) would require EGU owners or
operators to discontinue submission of semiannual compliance reports
when the interim PDF reporting period ends. The final semi-annual
compliance report would cover the period from July 1, 2023, through
December 31, 2023.
(9) EGU owners or operators would submit quarterly compliance
reports in lieu of the semiannual compliance reports, starting with
reports covering the first quarter of 2023 (see 40 CFR 63.10031(g)).
The quarterly compliance reports would retain many features of the
semiannual reports and consolidate them with other reports that were
originally required to be submitted separately on different schedules.
These compliance reports would be due within 60 days after the end of
each calendar quarter, which would allow sufficient time to receive the
results of stack tests (particularly PM, HCl, and HF tests) performed
at or near the end of a calendar quarter. Each quarterly compliance
report would include the applicable data elements listed in sections 2
through 13 of appendix E.
The owner or operator's MATS compliance strategy determines which
of the data elements in sections 2-13 of appendix E would be included
in the quarterly compliance reports. If continuous emission monitoring
were used to demonstrate compliance on a 30- or 90-boiler operating day
rolling average basis, the quarterly compliance reports would include
all of the 30- or 90-day averages calculated during the quarter. If
emissions averaging were used, EGU owners or operators would report all
of the 30- or 90-group boiler operating day WAERs calculated during the
quarter. If periodic stack testing for compliance were performed
(including Hg Low-Emitting EGU (LEE) tests and PM tests to set
operating limits for PM CPMS), the EGU owner or operator would report a
summary of each test completed during the calendar quarter and indicate
whether the test has a special purpose (i.e., if it were to be used to
establish LEE status or for emissions averaging).
The quarterly compliance reports would retain and incorporate the
following features of the semiannual compliance reports: (1) Boiler
tune-up dates; (2) monthly fuel usage data; (3) process and control
equipment malfunction information; (4) reporting of deviations; and (5)
emergency bypass information, for certain EGUs that qualify for and
elect to use the LEE compliance option for Hg. However, for EGU owners
or operators who elect to (or are required to) use CMS to demonstrate
compliance, these quarterly reports, to some extent, would move away
from traditional ``exception only'' reporting. Currently, reporting of
the excess emissions and monitor downtime information described in 40
CFR 63.10(e)(3)(v) and (vi) in PDF files has been required as part of
the semiannual compliance reports. That information includes, among
other things, identification of excess emissions periods,
identification of periods when the monitoring system was inoperative or
out of control, the reasons for the excess emission and monitor
downtime periods, corrective actions or preventative measures taken,
description of repairs or adjustments to inoperative or out-of-control
CMS, the total amount of source operating time in the reporting period,
and the excess emissions and monitor downtime, expressed as percentages
of the source operating time. As explained above, rather than this
traditional exception-only reporting, these proposed amendments would
require all of the 30- (or 90-) boiler operating day rolling averages
or WAERs for all parameters to be included in the quarterly compliance
reports. In addition, the following elements of the excess emissions
summary, with slight modifications, are proposed to be included in the
quarterly compliance reports: (1) The total number of source operating
hours in the quarter and (2) the total number of hours of monitoring
system downtime for various causes (known and unknown).
As previously noted, the requirement to report deviations would be
retained in the quarterly compliance reports. Specifically, the
revisions to 40 CFR 63.10031(d) would require the applicable data
elements in section 13 of appendix E to be reported, which include the
nature of the deviation (section 13.2), a description of the deviation
(section 13.3), and any corrective actions taken (section 13.4).
Section 13.3 further specifies the minimum amount of information that
would be reported in the description of certain deviations (i.e.,
unmonitored bypass stack usage, emissions or operating limit
exceedances, monitoring system outages, and missed or late performance
stack tests).
We believe that consolidating information in quarterly compliance
reports, as described above, rather than requiring separate submittals
of 30- (or 90-) boiler operating day rolling average reports, excess
emissions reports, and semiannual compliance reports that come in
separately at different times during the year, greatly simplifies
reporting and will make it easier for inspectors and auditors to assess
compliance with the standards. Also, quarterly, as opposed to
semiannual, reporting is advantageous because it shortens significantly
the interval between the time that deviation or exceedance reporting on
a term longer than quarterly occurs. Draft reporting instructions for
the quarterly compliance reports are provided in the rule docket and on
the OAQPS and Clean Air Markets Division (CAMD) websites. In response
to comments received, these instructions have been modified from a
previous draft version.
(10) A new paragraph, (c)(10), is being proposed to be added to
Sec. 63.10031 and would require malfunction information to be included
in the semiannual compliance reports. This is not a new requirement; it
was previously found in paragraph (g). However, as explained above,
revised paragraph (g) would require quarterly compliance reports to be
submitted, starting in 2024. Therefore, to avoid losing the requirement
to report malfunction information in the semiannual compliance reports,
the former paragraph (g) would be renamed as paragraph (c)(10) and
would be added to the list of information that must be included in the
semiannual reports. The introductory text of paragraph (c) would also
be amended, to recognize the addition of paragraph (c)(10).
(11) For consistency with the reporting requirements for the other
CMS, the Agency is not proposing a requirement for sources using PM
CPMS to submit separate quarterly excess emission summary reports in
addition to the quarterly compliance reports. After careful
consideration of comments on a previous proposal, we are persuaded that
sufficient information to assess compliance with the operating limits
of a PM CPMS would be provided
[[Page 20347]]
by: (1) The hourly PM CPMS response data reported in appendix D; (2)
the quarterly compliance reports, which specify the operating limit of
the PM CPMS, require deviations from the operating limit and monitoring
requirements to be reported, and include summarized results of the PM
tests used to develop the operating limits; and (3) the applicable
reference method data for the PM tests required to be reported under
sections 17-30 of appendix E.
We are proposing to amend Table 9 to 40 CFR part 63, subpart UUUUU,
as follows to reflect the transition away from exception-only
reporting. The applicability of the recordkeeping and reporting
requirements for excess emission and monitor downtime summary reporting
in 40 CFR 63.10(c)(7), 63.7(c)(8), and 63.10(e)(3) would end on
December 31, 2023, with the phase-out of the semiannual compliance
reports.
(12) One commenter on the previous proposal brought to light some
inconsistencies in the rule; regarding the way in which periods of
monitor downtime should be regarded and reported, i.e., whether or not
they are reportable deviations. The commenter pointed out that 40 CFR
63.10020(d) exempts monitoring equipment malfunctions and out-of-
control periods from being reported as deviations, whereas 40 CFR
63.10010(h)(6)(i), (i)(5)(i)(A) and (B), and (j)(4)(i)(A) and (B)
appear to say the opposite, requiring these downtime incidents to be
included in ``annual deviation reports.'' The EPA never intended to
exempt these particular monitor outages from being reported as
deviations; the Agency meant for the exemption to apply only to routine
QA and maintenance activities.\3\ Therefore, 40 CFR 63.10020(d) would
be clarified, and the statements in 40 CFR 63.10010(h)(6)(i),
(i)(5)(i)(A) and (B), and (j)(4)(i)(A) and (B) more closely represent
the Agency's position. But even there, the text is problematic, because
deviations are currently required to be reported in the semiannual
compliance reports (not in ``annual deviation reports'') and will
continue to be reported in the quarterly compliance reports when the
transition to quarterly reporting occurs. To address the
inconsistencies in 40 CFR 63.10020(d) and 63.10010(h)(6)(i),
(i)(5)(i)(A) and (B), and (j)(4)(i)(A) and (B), the proposed rule would
amend these rule sections by clarifying that monitor outages due to
monitoring equipment malfunctions and out-of-control periods are
deviations, and, therefore, would be reported as such in the compliance
reports.
---------------------------------------------------------------------------
\3\ The following statement from the preamble of the original
MATS rule makes this clear: ``Hours when a monitoring system is out
of service would be counted as hours of monitor down-time and may be
a deviation from the monitoring requirements of this rule unless the
rule provides an exception for routine quality control and
maintenance activities.'' (77 FR 9375, February 16, 2012).
---------------------------------------------------------------------------
The same commenter further asserted that there are other incorrect
statements in 40 CFR 63.10010(h)(6)(i), (i)(5)(i)(A), and (j)(4)(i)(A)
and (B), regarding the reporting of quality assurance/quality control
(QA/QC) activities for PM CPMS, PM CEMS, and HAP metals CEMS. These
rule sections all require the QA/QC activities to be reported ``per the
requirements of 40 CFR 63.10031(b).'' However, the reference to 40 CFR
63.10031(b), which provides the schedule for submitting semiannual
compliance reports, appears to be a typographical error. The commenter
recommended replacing it with a more general reference to 40 CFR
63.10031. The EPA agrees with the commenter that the reference to 40
CFR 63.10010(b) is inappropriate; but the comment led to examination of
inconsistencies between language in 40 CFR 63.10010(h)(6)(i),
(i)(5)(i)(A), and (j)(4)(i)(A) and (B) and language in 40 CFR
63.10010(h)(7), (i)(5)(ii), and (j)(4)(ii). The former sections require
QA/QC activities for PM CPMS, PM CEMS, and HAP metals CEMS to be
reported, while the latter sections state that the results of
monitoring system performance audits must only be made available ``upon
request.'' The Agency maintains reporting of QA test results is
mandatory for all CMS. In view of this, the EPA proposes the following
amendments. First, the reference to 40 CFR 63.10010(b) in the last
sentence in paragraphs (h)(6)(i) and (j)(4)(i)(A) and (B) would be
removed. Second, paragraphs (h)(7) and (j)(4)(ii) would be revised to
require the monitoring system performance evaluations of PM CPMS and
HAP metals CEMS to be reported. Third, a new paragraph, (k), would be
added to 40 CFR 63.10031, and would require the QA/QC activities for PM
CPMS and HAP metals CEMS to be reported quarterly in PDF files; these
reports would be due within 60 days after the end of each calendar
quarter, starting with a report for the first quarter of 2024 or, if
the methodology is not in use by the source owner or operator in the
first quarter of 2024, starting with the first calendar quarter in
which the PM CPMS or HAP metals CEMS methodology is used. Reporting as
PDF files is appropriate because there are no standardized QA test
procedures for these CMS in the CFR; their QA test requirements are
found only in source-specific MATS monitoring plans and will likely
vary from source-to-source. Finally, 40 CFR 63.10010(i) would be
revised in light of the addition of appendix C; paragraph (i) now
simply cross-references the appropriate sections of appendix C,
regarding the certification, operation, maintenance, on-going QA,
recordkeeping, and reporting requirements for PM CEMS.
(13) In all cases in which periodic stack tests (including Hg LEE
tests and PM tests that are used to develop PM CPMS operating limits)
are performed to demonstrate compliance, the proposal would retain the
requirement for the EGU owner or operator to provide the applicable
reference method data in appendix E (i.e., sections 17 et seq.) for
each stack test that is performed to demonstrate compliance. Each of
these submittals would be required to accompany the quarterly
compliance report that covers the calendar quarter in which the test
was completed. For PM tests that are used to develop PM CPMS operating
limits, you would also be required to include the information in 40 CFR
63.10023(b)(2)(vi) as part of the Test Comment data element found in
section 17.25 of appendix E.
(14) The applicable reference method data in sections 17 through 30
of appendix E would also be provided in XML format, starting with tests
completed on or after January 1, 2024, for each RATA of an Hg,
SO2, HCl, or HF monitoring system, and for each RRA, RCA, or
correlation test of a PM CEMS. The information in section 31 of
appendix E would also be provided in a PDF file for each test. The
appendix E information would be submitted concurrently with the
summarized electronic test results submitted to ECMPS under appendix A,
B, or C, or 40 CFR part 75 (for SO2 RATAs).
(15) The ECMPS Client Tool would also be used to make the following
submittals in PDF files:
(i) A detailed report of the current, active PS 11 correlation
test, if the EGU owner or operator is using a certified PM CEMS to
demonstrate compliance. For correlation tests completed prior to [DATE
60 DAYS AFTER DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL
REGISTER], the report would be due no later than 60 days after that
date. For correlation tests completed on or after [DATE 60 DAYS AFTER
DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], but
prior to January 1, 2024, the report would be due within 60 days after
the date on which the test is completed. (Note: For correlations
completed on and after January 1, 2024,
[[Page 20348]]
in lieu of a PDF report, the test results would be submitted
electronically according to section 7.2.4 of appendix C, together with
the applicable reference method data required under sections 17 through
31 of appendix E);
(ii) Any initial Notification of Compliance Status issued on or
after January 1, 2024; and
(iii) The information specified in 40 CFR 63.10031(c)(5)(ii) and
63.10020(e) for startup and shutdown incidents, if you are relying on
paragraph (2) of the definition of ``startup'' in 40 CFR 63.10042.
Starting with a report covering the first calendar quarter of 2024,
this information would be submitted along with the quarterly compliance
report. Note that 40 CFR 63.10031(c)(5)(iii) through (v), which require
the semiannual compliance reports to include the hourly CEMS and
operating parameter data recorded during startup and shutdown events
have not been carried over to this PDF report because this information
is duplicative of the hourly data reported electronically in the
quarterly emissions reports. Startup and shutdown hours are flagged in
the emissions reports and are identifiable for auditing purposes.
(16) To accommodate the required PDF reports, the applicable data
elements in 40 CFR 63.10031(f)(6)(i) through (xii) would be proposed to
be entered into the ECMPS Client Tool at the time of submission of each
PDF file. Note that the amendment to data element (xii) would replace
the word ``conducted'' with the word ``completed.''
(17) Although the ECMPS Client Tool would be used to submit the
required reports and notifications described in revised 40 CFR 63.10031
and Table 8, ECMPS would not evaluate any of the PDF submittals or any
of the XML-formatted reference method data from sections 17 through 31
of appendix E. Instead, these reports and notifications would be
transmitted directly through the EPA's Central Data Exchange using
CEDRI unaltered. ECMPS would, however, perform electronic checking of
the hourly PM CEMS data and the summarized RATAs, PM CEMS correlation
tests, RRAs, and RCAs that are submitted in XML format, in a manner
that is consistent with the way that certification and QA test results
are evaluated under the Acid Rain and Cross-State Air Pollution Rule
programs. ECMPS would use the results of these evaluations to assess
the quality-assured status of the Hg, HCl, HF, SO2, or PM
emissions data. In addition, ECMPS would perform basic checks of the
information in the quarterly compliance reports, e.g., checking for
completeness and proper formatting, but would leave compliance
assessment to those who review the reports. The EPA intends for all of
these various data submissions to work together in a complementary
fashion to enable meaningful compliance determinations. It is essential
that any problems with the data identified by the reviewers are
communicated to all involved and resolved appropriately. For example,
if, for a particular Hg RATA, a review of the reference method data
shows that the method was not done properly, the RATA would be
invalidated. If, at the time of this discovery, the deadline for
performing the RATA has passed and the allowable grace period has also
expired, this would result in invalidation of hourly emissions data,
from the expiration of the grace period until a valid RATA is performed
and passed. Consequently, resubmission of quarterly emissions reports,
recalculation of 30-day compliance averages, and resubmission of
quarterly compliance reports may become necessary.
B. Revisions to Appendix A
We are proposing to amend four sections of appendix A, i.e.,
sections 7.1.3.3, 7.1.4.3, 7.1.8.2 and 7.2.3.1, based on comments
received. The requirement in sections 7.1.3.3, 7.1.4.3, and 7.1.8.2 to
report Hg concentrations and emission rates to 3 significant figures
would be revised so that Hg concentrations in micrograms per standard
cubic meter ([mu]g/scm) and Hg emission rates in pounds per trillion
British Thermal Units or pounds per gigawatt-hour (lb/TBtu or lb/GWh)
would be reported with one leading non-zero digit and one decimal
place, in scientific notation. Conventional rounding would be used,
i.e., if the digit immediately following the first decimal place is 5
or greater, the digit in the first decimal place would be rounded
upward (increased by one); if the digit immediately following the first
decimal place is 4 or less, the digit in the first decimal place would
remain unchanged.
The requirement in section 7.2.3.1 to submit monitoring plan
information at least 21 days before the applicable compliance date in
40 CFR 63.9984 would be revised. For new units or units that install Hg
monitoring systems in order to switch from another MATS-compliant
methodology to Hg monitoring, the monitoring plan information would be
submitted at least 21 days prior to the date on which certification
testing begins. However, for units implementing Hg monitoring with a
previously-certified Hg monitoring system, the monitoring plan could be
submitted prior to or concurrent with the first quarterly emissions
report--provided that the monitoring plan would be in place when the
first emissions report is submitted so that the ECMPS Client Tool would
be able to evaluate the data.
C. Revisions to Appendix B
For affected source owners or operators desiring to continuously
monitor HCl emissions, the original version of appendix B required the
monitoring system to be certified according to PS 15 in appendix B to
40 CFR part 60. However, PS 15 applies only to Fourier Transform
Infrared (FTIR) Spectroscopy monitoring systems; therefore, the use of
other viable HCl monitoring technologies was excluded. In view of this,
the EPA regarded the requirement to use PS 15 exclusively as a
temporary measure, until a technology-neutral PS for HCl monitors could
be developed and published. In section 3.1 of appendix B, the Agency
stated its intention to publish such a PS in the near future together
with appropriate on-going QA requirements and to amend appendix B to
accommodate their use. This additional PS, (PS 18 in 40 CFR part 60,
appendix B), and the on-going QA test requirements (Procedure 6 in 40
CFR part 60, appendix F) were published on July 7, 2015 (80 FR 38628,
July 7, 2015).
Now that technology-neutral certification and QA test requirements
for HCl monitors have been promulgated, EGU owners or operators may use
any viable HCl monitoring technology that can meet the PS. However, in
order for ECMPS to accommodate all of the tests required under PS 18
and Procedure 6, additional time must be allotted for software
development. In view of this, we are proposing to revise 40 CFR
63.10031(a)(2), as previously noted, to require only information that
is compatible with the existing programming of ECMPS to be reported
electronically through December 31, 2023; this includes hourly HCl
emissions data and the results of daily calibration drift tests and
RATAs. In the interim, EGU owners or operators would be required to
keep records of all of the other certification and QA tests, which
would be reported starting in 2024.
We are proposing to revise the title to section 2.3 of appendix B
by deleting the reference to FTIR-only monitoring systems. In addition,
the recordkeeping and reporting sections of appendix B (i.e., sections
10 and 11) would be amended. Based on comments received, sections
10.1.3.3 and 10.1.7.2, HCl and
[[Page 20349]]
HF concentrations ([micro]g/scm) and emission rates (lb/MMBtu or lb/
MWh) would be reported with one leading non-zero digit and one decimal
place, in scientific notation, rather than reporting the concentrations
and rates to 3 significant figures. Conventional rounding would be
used, i.e., if the digit immediately following the first decimal place
is 5 or greater, the digit in the first decimal place would be rounded
upward (increased by one); if the digit immediately following the first
decimal place is 4 or less, the digit in the first decimal place would
remain unchanged. Sections 10 and 11 also specify the data elements
that would be recorded and reported for each of the tests required by
PS 18 and Procedure 6. The revisions would make a clear distinction
between the tests required for FTIR monitors that are following PS 15
and the test requirements of PS 18 and Procedure 6. Some of the tests
in PS 18 and Procedure 6 are similar to tests for which ECMPS
programming exists. For example, the ``measurement error test''
required for initial certification of the HCl monitor is structurally
the same as a 40 CFR part 75 linearity check. Other tests have no
counterpart in 40 CFR part 75 and would require special software
development and reporting instructions. Note that electronic reporting
of these tests through ECMPS would have been required if PS 18 and
Procedure 6 had been in place when the original MATS rule was
published. In view of this, for source owners or operators electing to
use HCl CEMS, the amendments to section 11 of appendix B would
introduce no unnecessary reporting burden. The results of certification
and on-going QA tests would be reported electronically for all CEMS
required under this rule in order for ECMPS to assess the quality-
assured status of the emissions data. The Agency also notes that not
all of the tests described in section 11 of appendix B would be
required for all HCl monitors. For example, some of the tests (i.e.,
beam intensity, temperature, and pressure verifications) are specific
to Integrated Path--Continuous Emission Monitoring Systems (IP-CEMS),
and Procedure 6 would offer a choice among three different types of
audits (i.e., cylinder gas audits, relative accuracy audits, or dynamic
spiking audits) for the required quarterly QA tests. In addition, based
on comments received, the reporting requirements for the interference
check (which is not necessarily performed on each individual analyzer)
would be reduced.
For each RATA of HCl CEMS that are completed on and after January
1, 2024, the applicable reference method data in sections 17 through 31
of appendix E would be submitted along with the electronic summary of
results required under section 11 of appendix B. To the extent
practicable, these data would be submitted prior to or concurrent with
the relevant quarterly electronic emissions report. However, as
previously noted, this may not always be possible, particularly when
the RATA is done near the end of a calendar quarter. The EPA test
Methods 26 and 26A, unlike instrumental test methods, require
laboratory analyses of the collected samples and cannot provide test
results while the test team is on-site. In view of this, section 11.4
of appendix B would allow the test results to be submitted up to 60
days after the test completion date. ``Provisional'' status may be
claimed for the emissions data affected by the test, starting from the
date and hour in which the test was completed, and continuing until the
date and hour in which the test results are submitted. If the test is
successful, the status of the data in that time period would change
from provisional to quality-assured, and no further action is required.
However, if the test is unsuccessful, the provisional data would be
invalidated and resubmission of the affected emissions report(s) would
be required.
Because a technology-neutral PS for HCl CEMS was not available
prior to April 16, 2015 (which was the compliance date for many of the
existing EGUs), EGU owners or operators interested in monitoring HCl
either had to use an FTIR system and follow PS 15 or implement another
compliance option (e.g., quarterly emission testing) while awaiting
publication of PS 18 and Procedure 6. In light of this, the EPA
proposes to revise and restructure section 11.5.1 of appendix B to
clarify when electronic reporting of hourly HCl emissions data begins.
There are two possibilities. In the first case, the monitor is used for
the initial compliance demonstration. This could either apply to a
certified FTIR monitor following PS 15 or to a certified monitor
following PS 18, if the owner or operator of the EGU received an
extension of the compliance date. In this case, EGU owners or operators
would begin reporting hourly HCl emissions through ECMPS with the first
operating hour of the initial compliance demonstration. In the second
case, another option, such as stack testing, is used for the initial
compliance demonstration and continuous monitoring is implemented at a
later time. In that case, EGU owners or operators would begin reporting
hourly HCl emissions reporting through ECMPS with the first operating
hour after successfully completing all required certification tests of
the CEMS. In either case, the first quarterly emissions report
submittal would be for the calendar quarter in which emissions
reporting begins.
The requirement in section 11.3.1 to submit monitoring plan
information at least 21 days before the applicable compliance date in
40 CFR 63.9984 would be revised. For new units or units that install
HCl and/or HF monitoring systems in order to switch from another MATS-
compliant methodology to HCl and/or HF monitoring, the monitoring plan
information would be submitted at least 21 days prior to the date on
which certification testing begins. However, for units implementing HCl
and/or HF monitoring with a previously-certified monitoring system, the
monitoring plan could be submitted prior to or concurrent with the
first quarterly emissions report.
D. Addition of Appendix C
A new appendix, i.e., appendix C, would been added to subpart UUUUU
of 40 CFR part 63. Appendix C sets forth the continuous monitoring and
reporting requirements for filterable PM. Appendix C is structurally
similar to appendices A and B, but there is one notable difference.
Appendix C would include provisions for installation and certification
of the PM CEMS, and for on-going QA of the data from the CEMS. The
monitoring system would be certified according to PS 11 in 40 CFR part
60, appendix B, and for the on-going QA tests, Procedure 2 to 40 CFR
part 60, appendix F, would be required.
After consideration of comments received, the EPA has concluded
that all PM concentrations should be reported in units of measure that
are consistent with the PM CEMS correlation. For example, if the PM
CEMS measures in units of milligrams per actual cubic meter (mg/acm)
and the concentrations used to derive the correlation curve are in
those same units, then the hourly PM concentrations would be recorded
and reported in mg/acm. Section 7.1.9.5 of appendix C would also
require the reference method readings and the PM CEMS responses
obtained in the RRAs and RCAs to be reported in the same units of
measure as the PM CEMS correlation curve.
Sections 7.1.3.3 and 7.1.7.2 would require PM concentrations and
emission rates (lb/MMBtu or lb/MWh) to be reported with one leading
non-zero digit and one decimal place, in scientific notation, rather
than reporting the
[[Page 20350]]
concentrations and rates to three significant figures. Conventional
rounding would be used, i.e., if the digit immediately following the
first decimal place is 5 or greater, the digit in the first decimal
place would be rounded upward (increased by one); if the digit
immediately following the first decimal place is 4 or less, the digit
in the first decimal place would remain unchanged.
The proposed frequencies for the on-going QA tests and the rules
for data validation are presented in Section 5 of appendix C. In
response to numerous requests from commenters, the frequency and data
validation rules for the RCAs and RRAs are similar, but not identical
to, provisions of 40 CFR part 75. The frequency of these tests would
follow the familiar calendar quarter and grace period reporting plan.
An RRA would be required once every four calendar quarters and an RCA
would be required once every 12 calendar quarters. A grace period would
be provided (i.e., 720 operating hours or one calendar quarter,
whichever comes first), to cover cases where circumstances beyond the
control of the owner or operator prevent the required test from being
completed on schedule. In addition, as explained in detail below,
section 7.2.4 of appendix C would allow the use of provisional data for
up to 60 days after completion of an RRA, RCA, or PM CEMS correlation
test.
The proposed procedures for calculating the PM emission rates in
units of the emission standard are found in section 6. These
calculation methods are basically the same as those used for Hg
monitoring systems and for HCl and HF CEMS in appendices A and B. The
proposed recordkeeping and reporting requirements are found in section
7. Section 7.1 proposed that monitoring plan records and hourly records
of operating parameters, PM concentration, diluent gas concentration,
stack gas flow rate and moisture content, and PM emission rate would be
kept. Sections 7.2.3 and 7.2.4, respectively, would require monitoring
plan information and the results of certification, recertification, and
QA tests to be reported electronically. For consistency with these
revisions to appendices A and B, section 7.2.3.1 would specify that for
new units or units installing PM CEMS in order to switch from another
MATS-compliant methodology to PM monitoring, the electronic monitoring
plan information would be submitted at least 21 days prior to the
commencement of certification testing. However, for units with
previously-certified PM CEMS that elect to implement PM monitoring, the
monitoring plan information could be submitted prior to or concurrent
with the first quarterly emissions report. Section 7.2.5 would require
quarterly electronic emissions reports to be submitted within 30 days
after the end of each calendar quarter. All electronic reports would be
submitted using the ECMPS Client Tool. However, for EGUs that have
begun using the PM CEMS compliance option prior to January 1, 2024,
electronic reporting of monitoring plan information, certification and
on-going QA test results, hourly PM emissions data, and the applicable
reference method data in appendix E would not begin until January 1,
2024, to allow time for software development and beta testing. Until
then, records of the required information and tests would be kept. For
EGUs that certify and begin using PM CEMS on or after January 1, 2024,
reporting of hourly PM emissions data would begin with the first
operating hour after successful completion of the initial PM CEMS
correlation test.
For PM CEMS correlations, RRAs, and RCAs that are completed on and
after January 1, 2024, the applicable reference method data in sections
17 through 31 of appendix E would be submitted along with the
electronic test summary required under section 7.2.4 of appendix C. To
the extent practicable, the electronic test results and the appendix E
reference method data would be submitted prior to or concurrent with
the relevant quarterly electronic emissions report. However, the EPA
recognizes that this is not always possible, particularly when an RRA
or RCA is done near the end of a calendar quarter. The EPA test Methods
5 and 5D, unlike instrumental test methods, require laboratory analyses
of the collected samples and generally cannot provide test results
while the test team is on-site. In view of this, section 7.2.4 of
appendix C would allow the test results to be submitted up to 60 days
after the test completion date. ``Provisional'' status could be claimed
for the emissions data affected by the test, starting from the date and
hour in which the test was completed, and continuing until the date and
hour in which the test results are submitted. If the test is
successful, the status of the data in that time period would change
from provisional to quality-assured, and no further action is required.
However, if the test is unsuccessful, the provisional data would be
invalidated, and resubmission of the affected emission report(s) would
be required.
E. Addition of Appendix D
We are proposing a second new appendix, i.e., appendix D, be added
to subpart UUUUU of 40 CFR part 63. Appendix D would set forth the
monitoring and reporting requirements for EGU owners or operators who
elect to use a PM CPMS to demonstrate continuous compliance.
Structurally, appendix D would be similar to appendices A, B, and C.
However, the criteria for system design and performance, the procedures
for determining operating limits, data reduction, and compliance
assessment, and certain recordkeeping requirements are not detailed in
the appendix; rather, the applicable sections of the MATS rule are
cross-referenced (see sections 2.1 through 2.4, 3.1 introductory text,
and section 3.1.1.1 of the appendix).
Section 3.1.1.2 would require the ECMPS Client Tool to be used to
create and maintain an electronic monitoring plan. The PM CPMS would be
defined as a monitoring system with a unique system ID number. The
monitoring plan would also include the current operating limit (with
units of measure), the make, model, and serial number of the PM CPMS,
the analytical principle of the monitoring system, and monitor span and
range information.
We are proposing to require operating parameter records for each
hour of operation of the affected EGUs, including the date and hour,
the EGU or stack operating time, and a flag to identify exempt startup
and shutdown hours. Hourly average PM CPMS output values would be
reported for each hour in which a valid value of the output parameter
is obtained, in units of milliamps, PM concentration, or other units of
measure, including the instrument's digital signal output equivalent. A
special code would be required to indicate operating hours in which
valid data are not obtained. The percent monitor data availability
would also be calculated in the manner established for SO2,
carbon dioxide (CO2), oxygen (O2), or moisture
monitoring systems in 40 CFR 75.32.
Sections 3.2.2 and 3.2.3, respectively, would require notifications
(to be provided in accordance with section 63.10030) and electronic
monitoring plan submittals at specified times. For units using the PM
CPMS compliance option prior to January 1, 2024, the electronic
monitoring plan information would be submitted prior to or concurrent
with the first quarterly report. For units switching to the PM CPMS
compliance option on or after January 1, 2024, the electronic
monitoring plan would be submitted no
[[Page 20351]]
later than 21 days prior to the PM test that establishes the initial
operating limit. Section 3.2.4 would require the electronic quarterly
reports to be submitted within 30 days after the end of each calendar
quarter. Reporting of hourly responses from the PM CPMS would begin
either with the first operating hour of 2024 or the first operating
hour after completion of the stack test that establishes the initial
operating limit, whichever is later. Each quarterly report would
include a compliance certification with a statement by a responsible
official that to the best of his or her knowledge, the report is true,
accurate, and complete.
In addition to the electronic quarterly reports, we are proposing
to require reporting of deviations from the operating limit in the
quarterly compliance reports required under 40 CFR 63.10031(g).
Further, section 3.2.5 of appendix D would require the results of each
performance stack test for PM that is used to establish an operating
limit to be reported electronically in the relevant quarterly
compliance report. For PM tests completed on and after January 1, 2024,
the applicable appendix E reference method data would also be submitted
along with the relevant quarterly compliance report.
F. Addition of Appendix E
We are proposing to add a third new appendix, i.e., appendix E, to
subpart UUUUU of 40 CFR part 63. Sections 2 through 13 of appendix E
list the data elements that would be reported in XML format in the
quarterly compliance reports required under 40 CFR 63.10031(g),
starting with reports covering the first quarter of 2024.
The MATS compliance strategy (e.g., whether the EGU owner or
operator elects to perform periodic stack testing, continuous
monitoring, or to use emissions averaging) and the events that occur
during each calendar quarter determine which data elements in sections
2 through 13 would be included in the quarterly compliance reports. As
noted in section V.A.(9), updated reporting instructions for these
compliance reports are found in the rule docket and are posted on the
CAMD and MATS websites.
For reasons stated in the previous proposal's Response to Comments
document (which is available in the rule docket \4\), we are proposing
to retain the basic provisions of proposed sections 14 through 21 of
appendix E, requiring details of the reference methods used for
performance stack tests and continuous monitoring system performance
evaluations to be reported in XML format. The rule would also retain
the proposed requirement in section 22 of appendix E to provide
reference method test information that is incompatible with electronic
reporting as PDF files, although it has been renumbered as section 31
and modified to include a cross-reference to 40 CFR 63.7(g), which
describes the contents of a performance test report. The applicable
reference method information in appendix E would be provided for each
stack test; each RATA of a Hg, HCl, HF, or SO2 monitoring
system; and each RRA, RCA, or correlation test of a PM CEMS that is
completed on and after January 1, 2024.
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\4\ See EPA-HQ-OAR-2018-0794 at https://www.regulations.gov/.
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To address concerns raised by the commenters about portions of the
2016 proposed rule \5\ (the previous proposal), specifically, the
reporting requirements in sections 17 through 21 of proposed appendix
E, the Agency proposes to revise and reformat the data element lists to
correspond to the compliance options described in section 16 of
appendix E. Explicitly, sections 17 through 30 would replace previously
proposed sections 17 through 21. Commenters pointed out, and the Agency
concurs, that some of the previously proposed data elements are either
unnecessary, inapplicable to MATS, or duplicative of information in
other MATS reports; these elements are proposed to be removed from the
lists and include:
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\5\ As mentioned in footnote 1, see 81 FR 67062 from September
29, 2016.
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Previously proposed 7.1.3.3.1 of appendix C to this
subpart;
Previously proposed 7.1.3.3.2 of appendix C to this
subpart;
Previously proposed 7.1.3.3.3 of appendix C to this
subpart;
Previously proposed 7.1.3.4 of appendix C to this subpart;
Previously proposed 10.4 of appendix E to this subpart;
Previously proposed 10.5.1 of appendix E to this subpart;
Previously proposed 10.5.2 of appendix E to this subpart;
Previously proposed 10.5.7 of appendix E to this subpart;
Previously proposed 17.28 of appendix E to this subpart;
Previously proposed 17.30 of appendix E to this subpart;
Previously proposed 17.37 of appendix E to this subpart;
Previously proposed 18.21 of appendix E to this subpart;
Previously proposed 19.29 of appendix E to this subpart;
Previously proposed 20.4 of appendix E to this subpart;
Previously proposed 20.15 of appendix E to this subpart;
Previously proposed 20.17 of appendix E to this subpart;
Previously proposed 20.21 of appendix E to this subpart;
Previously proposed 20.25 of appendix E to this subpart;
Previously proposed 20.30 of appendix E to this subpart;
Previously proposed 20.36 of appendix E to this subpart;
Previously proposed 20.37 of appendix E to this subpart;
Previously proposed 20.41 of appendix E to this subpart;
Previously proposed 20.42 of appendix E to this subpart;
Previously proposed 20.44 of appendix E to this subpart;
Previously proposed 20.46 of appendix E to this subpart;
Previously proposed 20.52 of appendix E to this subpart;
Previously proposed 21.14 of appendix E to this subpart;
and
Previously proposed 21.28 of appendix E to this subpart.
Reporting instructions for sections 17 through 30 have been
developed. These proposed, draft example instructions are included in
the rule docket and are posted on the MATS and CAMD websites.
The reorganized data element lists and corresponding instructions
clarify which data elements are proposed to be reported for each
compliance option and explain how the data are to be reported. Several
new data elements are proposed for the lists, to enable the ECMPS
Client Tool to be used, to enhance the quality of the data, and to
facilitate compliance. As mentioned in VI.C of this preamble, this
proposed action is expected to reduce overall annual source burden. The
Agency believes that the proposed addition of these data elements is
offset by the proposed removal of others, the proposed change to a
consistent submission frequency, and the proposed merger of separate
electronic reporting systems into just one electronic reporting system
such that overall annual source reporting burden is reduced by 11,000
hours. The proposed new data elements to be reported are as follows:
``Part.'' The previous proposal would only have required
the ``Subpart'' to be reported. To avoid any possible confusion with
other EPA regulations, both the CFR part (63) and subpart (UUUUU) need
to be included in the reports.
``APS Flags.'' For 3-level pre-test calibrations, system
bias, and drift checks, instrumental EPA test Methods
[[Page 20352]]
3A and 6C require certain acceptance criteria to be met. For each of
these tests, there is a main PS and an alternative specification. The
main PS is expressed as a percentage of span, while the alternative
specification is the absolute difference between a reference value and
the measured value. In view of this, it is important to know which
specification has been applied to ascertain whether the test was
successful or not. Therefore, alternative performance specification
(APS) flags are proposed to be added for the pre- and post-test
calibrations, bias checks, and drift checks. An APS flag of ``0''
indicates that the reported test result is based on the main
performance specification, whereas an APS flag of ``1'' means that the
reported result is based on the alternative specification.
``Test Comment.'' This text field is proposed to be added
to allow the affected sources to provide additional, pertinent
information about a particular test.
``Run Begin Date'' and ``Run End Date.'' These two data
elements are proposed to replace the previous proposed element ``Run
Date'' to cover cases where a test run begins on one day and ends on
another (e.g., if a run begins late at night and ends early the next
morning).
``Converted Concentration and Units of Measure.'' These
proposed data elements apply to correlation tests and performance
audits (RRAs and RCAs) of PM CEMS. The reference method used for these
tests is EPA test Method 5 (or, if applicable, 5D). The PM
concentrations obtained from EPA test Method 5 or 5D are expressed in
units of grams per dry standard cubic meter (g/dscm). However,
consistent with section 8.6 of PS 11, appendix C of MATS proposes to
require all PM concentrations to be reported in units of measure that
are consistent with the PM CEMS correlation curve. Most PM CEMS measure
concentration in units of milligrams per actual cubic meter (mg/acm);
others may measure at a certain temperature (e.g., mg/acm at 160
[deg]Celsius), and still others may measure on a dry basis. Therefore,
in addition to reporting the EPA test Method 5 test results in units of
g/dscm, the converted PM concentrations would be reported in units
consistent with the PM CEMS correlation curve.
``Average Sampling Rate and Units of Measure.'' These
proposed data elements are specific to EPA test Method 30B. That EPA
test Method 30B requires a post-test leak check of each sampling train.
The leakage rate must not exceed 4 percent of the average sampling
rate. Therefore, to assess compliance with this specification, both the
leakage rate and the average sampling rate would be reported. The
previous proposed rule only required the leakage rate to be reported.
``Control Device Code.'' This proposed data element refers
to the control device code or control technology National Emission
Inventory (NEI) code associated with the EGU (or group of EGUs sharing
a common stack). Providing this data element would help in EGU
categorization and emission factor development.
``Corresponding Reference Method(s), if applicable.'' This
proposed data element allows pollutant reference method run data to be
associated with concurrent measurements of the stack gas flow rate
using EPA test Method 2, and/or CO2 or O2
concentration using EPA test Method 3A, and/or stack gas moisture
content using EPA test Method 4. Reporting this data element is
necessary to ensure test methods were conducted properly so that
emission rates can be calculated.
``Corresponding Reference Method(s) Run Number, if
applicable.'' This proposed data element provides the run number of
concurrent reference method tests. The assigned run number of the EPA
test Method 1 through 4 or EPA test Method 3A tests conducted at the
same time as a reference method test needs to be reported in order to
ensure the methods were conducted properly so that emission rates can
be calculated.
``Pollutant Concentration Units of Measure.'' This
proposed data element provides the appropriate units of measure code
for the pollutant or analyte concentration, and reporting it is
necessary for comparison to the standard.
``Pollutant Emission Rate.'' This proposed data element is
the pollutant emission rate expressed in the units of the standard, and
reporting it is necessary for comparison with the standard.
``Pollutant Emission Rate Units of Measure (in units of
the standard).'' This proposed data element is the units of the
standard specified in Table 1 or 2 of this subpart. Reporting it is
necessary for comparison to the standard.
``Process Parameter Units of Measure.'' This proposed data
element identifies the process rate parameter unit of measure: GWh/h,
MWh/h, TBtu/h, or MMBTU/h, and reporting it is necessary to ensure
accurate comparisons between runs and for emission factor development
purposes.
``Total Pollutant Mass Trap A'' and ``Total Pollutant Mass
Trap B.'' These proposed data elements refer to the total mercury mass
measured by Train A and Train B, respectively, in the appropriate units
of measure. Reporting these values is necessary for quality assurance
purposes and for comparison with the standard.
``Method Detection Limit (MDL).'' This proposed data
element refers to the minimum amount of analyte that can be detected
and reported. Reporting it is necessary for calculation checks and for
emissions factor development purposes.
``Percent Spike Recovery.'' This proposed data element
refers to the spike recovery in percent, which is required to be
reported by section 8.2.6.2 in EPA test Method 30B using Equation 30B-
1.
``F-Factor (Fc).'' This proposed data element
expands the current F-factor choices to include the carbon F-Factor,
which is based on the ratio of CO2 to heat content of fuel.
Reporting it allows conversion from mass per volume to mass per heat
input for those who choose to use emissions testing.
``Compliance Limit Basis (Heat Input or Electrical
Output).'' This proposed data element identifies the denominator of the
compliance units selected for an existing EGU by its owner or operator.
Reporting this decision is necessary for comparison of results with the
standard.
``Heat Input or Electrical Output Unit of Measure.'' This
proposed data element specifies the denominator of the compliance unit
that corresponds to the means of compliance selected for an existing
EGU by its owner or operator. Reporting this unit is necessary for
comparison of results with the standard and for emission factor
development purposes.
``Pollutant Concentration.'' This proposed data element
expands the already-existing ``Emissions Concentration'' data element
to include pollutants. Reporting this data element is necessary for
comparison of results with the standard and for emission factor
development purposes.
``Stack Gas Flow Rate--dscfm.'' This proposed data element
clarifies the already-existing ``Volumetric Flow Rate--scfm'' data
element so that reporters will know to report their EGU's dry stack gas
flow rate. Reporting this data element is necessary for calculation
purposes. Several commenters \6\ on the September 29, 2016, proposed
rule (i.e., the previous proposal) stated that those proposed revisions
included a significant amount of duplicative reporting, which should be
eliminated. In response to the
[[Page 20353]]
concerns expressed by the commenters, the Agency examined the XML data
element lists for stack tests and CMS performance evaluations in order
to identify duplicative reporting and eliminate it where possible. The
following evaluations were made:
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\6\ Commenters 20612, 20597, and 20609 on Docket ID No. EPA-HQ-
OAR-2009-0234.
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First, the data elements in sections 2 through 13 of appendix E
(for the quarterly compliance reports) were compared against the data
elements in sections 17 through 30 of appendix E (corresponding to the
detailed reference method data for stack tests and CMS performance
evaluations). The two lists were found to have 20 data elements in
common, but at least 9 of these elements (i.e., Source ID (Sampling
Location), Test Number, Run Number, Run Begin Date, and a few others)
are proposed to be included in both XML schemas to properly link the
individual stack test summaries in the compliance report with the
corresponding reference method data.
Second, the data elements listed in the reporting sections of
appendices A, B, and C of MATS, requiring the results of CMS
performance evaluations (i.e., RATAs, RRAs, and RCAs) to be reported
using the ECMPS Client Tool, were compared against the corresponding
reference method data elements in sections 17 through 30 of appendix E.
Only 12 data elements common to the appendix E and ECMPS Client Tool
schemas were found. This is not surprising because appendices A, B, and
C require only summarized results of CMS performance evaluations--
details of the Reference Method tests are not reported. Of the 12 data
elements common to the appendix E and ECMPS lists, 10 of them are
proposed to be included in both schemas to properly link the CMS test
summaries with the corresponding reference method data. In view of
these two evaluations, EPA concludes that most of the duplicative
reporting found among the various data element lists is necessary to
ensure that the results of stack tests and CMS performance evaluations
summarized in the quarterly compliance reports and the QA test
submittals to the ECMPS Client Tool can be matched with the
corresponding Reference Method data. Further, the remainder of the
duplicative reporting is minimal, rather than ``significant'' as
asserted by the commenters. The Agency believes that it is best not to
modify the data element lists to eliminate this small amount of
duplicate reporting. Although the deadlines for submitting the
quarterly compliance reports and the corresponding reference method
data are the same (i.e., within 60 days after the end of the quarter),
the two XML reports might not be submitted concurrently. So, if, for
instance, the compliance report is submitted prior to the reference
method data, and certain data elements are found only in the reference
method report, a thorough assessment of compliance may not be possible
until the reference method report is received. Similar considerations
apply to the summarized CMS performance evaluations in the ECMPS Client
Tool and the corresponding reference method data, if the two XML
reports are not submitted concurrently.
VI. Proposed Revisions to Other Rule Text
The revisions to 40 CFR 63.10031 necessitate changes to other
sections of the rule to ensure that the rule is internally consistent.
Based on comments received, revisions have also been made to clarify
certain reporting requirements, to rectify inadvertent omissions, and
to correct inconsistencies. The affected rule sections are as follows:
(a) We are proposing to revise the introductory text of paragraphs
(a)(2) and (b) of 40 CFR 63.10005. The amendment to paragraph (a)(2)
would clarify that Hg compliance may either be determined on either a
30- or 90-boiler operating day rolling average basis. For consistency
with appendix E, revised paragraph (b) notes that when auxiliary stack
gas flow rate or moisture data are needed to supplement a performance
stack test conducted with an isokinetic method such as EPA test Method
5 or EPA test Method 26A, separate EPA test Method 2 or EPA Method 4
tests are not needed to satisfy the requirements of 40 CFR 63.10007 and
Table 5. Data from the isokinetic method can be used to determine the
stack gas flow rate and moisture content.
(b) We are proposing to amend 40 CFR 63.10009 as follows. The
second and third sentences in paragraph (a)(2) would be revised to
clarify the types of data that may be used to determine WAERs. Data
from Hg CEMS, sorbent trap monitoring systems, but not LEE tests, may
be used for Hg emissions averaging. For other pollutants, both CEMS
data and stack test data may be used. The last sentence of paragraph
(a)(2) would be amended to clarify that if any EGU in an averaging
group operates on any of the days in a 30- or 90-group boiler operating
day compliance period (regardless of how many or how few), the
emissions data from that EGU on those days must be included in the
weighted average. Since averaging of Hg emissions is permitted on a 30-
group boiler operating day basis, Equations 2a and 2b in 40 CFR
63.10009 apply to Hg as well as other pollutants. Therefore, the words
``for pollutants other than Hg'' would be removed from the introductory
text of paragraph (b)(2), and in the nomenclature of Equation 2a, the
words ``or sorbent trap monitoring'' would be added after the words
``unit i's CEMS'' in the definition of the term ``Heri.''
Finally, for completeness, Equations 3a and 3b would be amended by
removing the terms that pertain to quarterly stack testing. Equations
3a and 3b apply only to the 90-group boiler operating day Hg WAER limit
for coal-fired units. Coal-fired EGUs do not have the option to use
quarterly stack testing to demonstrate compliance; if a coal unit does
not qualify as a LEE, Hg emissions must be continuously monitored.
(c) As explained in section IV.A(11) above, we are proposing to
revise paragraphs (h)(6) and (7), (i), and (j)(4)(i) and (ii) of 40 CFR
63.10010 to resolve inconsistencies in the text.
(d) We are proposing to revise 40 CFR 63.10011(e) to require
Notifications of Compliance Status for initial compliance
demonstrations to include the information specified in 40 CFR
63.10030(e), and to be submitted in accordance with 40 CFR
63.10031(f)(4) or (h), as applicable. This proposed change is necessary
to cover initial Notifications of Compliance Status for both new and
existing EGUs. The interim reporting process described in 40 CFR
63.10031(f)(4) and the on-going reporting process in 40 CFR 63.10031(h)
require these Notifications to be submitted as PDF files, through
ECMPS.
(e) We are proposing to revise 40 CFR 63.10011(g)(3), 40 CFR
63.10021(i), and two sentences in Items 3 and 4 of Table 3 to be
consistent with 40 CFR 63.10031(i) and Table 8. For EGU owners or
operators relying on paragraph (2) of the definition of ``startup'' in
40 CFR 63.10042, 40 CFR 63.10031(i) retains the requirement for the
parametric data and other information in 40 CFR 63.10031(c)(5) to be
included in the semiannual compliance reports, for startup and shutdown
incidents that occur during the interim reporting period. However, in
view of the proposed phase-out of the semiannual compliance reports,
for startup and shutdown incidents that occur during each subsequent
calendar quarter, starting with the first quarter of 2024, the
supplementary information in 40 CFR 63.10031(c)(5)(ii) and 63.10020(e)
would be required to be provided as a separate PDF submittal, along
with the quarterly compliance report. As previously noted, the
requirements in 40 CFR
[[Page 20354]]
63.10031(c)(5)(iii), (iv), and (v) to report hourly average CEMS and
operating parameter values for startup and shutdown events are not
proposed to be incorporated into this PDF report because they are
duplicative of the hourly values reported under appendices A through D.
Startup and shutdown hours are flagged in the quarterly emissions
reports and can be identified for auditing purposes.
(f) We are proposing revisions to paragraphs (e)(9), (f), and
(h)(3) of 40 CFR 63.10021 as follows. Paragraph (e)(9) is unchanged
from the previous proposal, except that the December 31, 2017, and
January 1, 2018, transition dates are replaced with December 31, 2023,
and January 1, 2024, respectively. We are proposing to remove
references to the EPA's ERT and the CEDRI interface from paragraph (f)
and replace it with a general statement requiring all applicable
notifications and reports to be submitted through the ECMPS Client
Tool. We are proposing to add three statements at the end of paragraph
(f). The first statement, regarding a submission deadline that occurs
on a weekend or Federal holiday, extends the deadline to the next
business day. The second statement addresses a submission deadline that
occurs when the ECMPS system is offline for maintenance; in that case,
the deadline is extended until the first business day after the system
outage. The third statement clarifies that using the ECMPS Client Tool
to submit a required MATS report or notification satisfies the
requirement in 40 CFR 63.13 of the General Provisions to submit that
same report or notification (or the information contained in it) to the
appropriate EPA Regional office or state agency whose delegation
request has been approved. Finally, we are proposing to remove
paragraph (h)(3) because it is redundant with paragraph (i) and,
therefore, unnecessary.
(g) We are proposing to remove 40 CFR 63.10030(e)(7)(i) for the
following reasons. The requirement in the current rule for an initial
Notification of Compliance Status to include summarized results of
annual and triennial performance tests which have not been done yet is
in an incorrect location. The requirement to submit these test
summaries belongs in 40 CFR 63.10031, not 40 CFR 63.10030. Text similar
to 40 CFR 63.10030(e)(7)(i) does, in fact, exist in 40 CFR 63.10031.
Specifically, 40 CFR 63.10031(c)(7) requires the annual and triennial
test results to be summarized in the semiannual compliance reports.
Note, however, that when the semiannual compliance reports are phased
out in 2024, the requirement to provide summarized results of these
tests does not end; the test summaries must be included in the
quarterly compliance reports under 40 CFR 63.10031(g).
We are proposing to amend 40 CFR 63.10030(e)(7)(iii) to rectify an
inadvertent oversight. In the 2016 Technical Corrections rule package,
the EPA proposed a set of conditions that would allow an EGU owner or
operator to submit a request for permission to switch from a heat
input-based standard to an output-based standard. One of the proposed
conditions, in paragraph (e)(7)(iii)(A)(3) required a demonstration of
compliance with both emission limits, based on ``performance stack test
results completed within 30 days prior to'' the request. A commenter
objected to limiting this demonstration to ``stack test'' data and
asked the EPA to allow any data collected up to 45 days prior to the
request, including CEMS data, to be used. In the Response to Comments
document, the EPA agreed with these commenters, but did not make the
necessary changes to paragraph (e)(7)(iii)(A)(3) in the final rule.
This rule corrects this oversight. In addition, we are proposing to add
a note to paragraph (e)(7)(iii) to clarify that requests to switch from
one standard to the other are made subsequent to, and are not part of,
the initial Notification of Compliance Status.
(h) We are proposing to amend 40 CFR 63.10032(a) to include
references to the recordkeeping required under new appendices C (for PM
CEMS), D (for PM CPMS), and E (for quarterly compliance reports and
reference method test data). Also, in view of the move away from
semiannual compliance reporting to quarterly reporting, we are
proposing to replace the term ``semiannual compliance report'' with
references to both semiannual and quarterly compliance reports in
paragraph (a)(1).
(i) We are proposing to remove the words ``or out of control
period'' from 40 CFR 63.10042, from the definition of ``monitoring
system malfunction or out of control period'' because that definition
does not describe an out of control period. We are proposing to add a
separate definition of ``out-of-control period,'' and that definition
is similar with the definition provided in the Acid Rain Program
definitions at 40 CFR 72.2.
(j) We are proposing to revise Table 8 to subpart UUUUU of 40 CFR
part 63 to be consistent with the amendments to 40 CFR 63.10031 and the
proposed addition of appendices C, D, and E.
(k) Finally, we are proposing to revise the recordkeeping and
reporting requirements in Table 9 to 40 CFR part 63, subpart UUUUU, as
follows. First, we are proposing changes to the requirement to provide
the information in 40 CFR 63.10030(e)(1) through (8), i.e., it only
applies to initial Notifications of Compliance Status; subsequent
notifications are not required. Second, in keeping with the earlier
discussion provided in section IV.A of this preamble, we are proposing
to add a statement to clarify that the excess emissions recordkeeping
and reporting requirements of 40 CFR 63.10(c)(7) and (8) and (e)(3)(v)
and (vi) apply through December 31, 2023, when the semiannual
compliance reports are phased out. On and after January 1, 2024, all
relevant information will be provided in quarterly, as opposed to
semiannual, reports.
VII. Statutory and Executive Order Reviews
Additional information about these statutes and Executive orders
can be found at https://www.epa.gov/laws-regulations/laws-and-executive-orders.
A. Executive Order 12866: Regulatory Planning and Review and Executive
Order 13563: Improving Regulation and Regulatory Review
This action is not a significant regulatory action and was,
therefore, not submitted to the Office of Management and Budget (OMB)
for review.
B. Executive Order 13771: Reducing Regulations and Controlling
Regulatory Costs
This action is considered an Executive Order 13771 deregulatory
action. Details on the estimated cost savings of this proposed rule can
be found in the EPA's analysis of the potential costs and benefits
associated with this action.
C. Paperwork Reduction Act (PRA)
The information collection activities in this proposed rule have
been submitted for approval to OMB under the PRA. The Information
Collection Request (ICR) document that the EPA prepared has been
assigned EPA ICR number 2137.09. You can find a copy of the ICR in the
docket for this proposed rule, and it is briefly summarized here.
Respondents/affected entities: The respondents are owners or
operators of fossil fuel-fired EGUs. The United States Standard
Industrial Classification code for respondents affected by the rule is
4911 (Electric Services). The corresponding NAICS code is 2211100
(Electric Power Generation, Transmission, and Distribution).
Respondent's obligation to respond: Mandatory per 42 U.S.C. 7414 et
seq.
[[Page 20355]]
Estimated number of respondents: 1,414.
Frequency of response: Quarterly for compliance reports.
Total estimated burden: Reduction of 11,000 hours (per year).
Burden is defined at 5 CFR 1320.3(b).
Total estimated cost: Savings of $15,079,000 (per year), includes
$0 annualized capital or operation and maintenance costs.
An agency may not conduct or sponsor, and a person is not required
to respond to, a collection of information unless it displays a
currently valid OMB control number. The OMB control numbers for the
EPA's regulations in 40 CFR are listed in 40 CFR part 9.
Submit your comments on the Agency's need for this information, the
accuracy of the provided burden estimates, and any suggested methods
for minimizing respondent burden to the EPA using the docket identified
at the beginning of this rule. You may also send your ICR-related
comments to OMB's Office of Information and Regulatory Affairs via
email to [email protected], Attention: Desk Officer for the
EPA. Since OMB is required to make a decision concerning the ICR
between 30 and 60 days after receipt, OMB must receive comments no
later than May 11, 2020. The EPA will respond to any ICR-related
comments in the final rule.
D. Regulatory Flexibility Act (RFA)
I certify that this action will not have a significant economic
impact on a substantial number of small entities under the RFA. In
making this determination, the impact of concern is any significant
adverse economic impact on small entities. An agency may certify that a
rule will not have a significant economic impact on a substantial
number of small entities if the rule relieves regulatory burden, has no
net burden, or otherwise has a positive economic effect on the small
entities subject to the rule. For purposes of assessing the impacts of
this rule on small entities, the EPA considered small entities to be
defined as: (1) A small business that is an electric utility producing
4 billion kilowatt-hours or less as defined by NAICS codes 221122
(fossil fuel-fired electric utility steam generating units) and 921150
(fossil fuel-fired electric utility steam generating units in Indian
country); (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. As required by the RFA, the EPA
proposed using this alternative definition in the Federal Register of
May 3, 2011, 76 FR 25083, sought public comment, consulted with the
Small Business Administration and finalized the alternative definition
in the Federal Register of February 16, 2012, 77 FR 9433. As stated in
that document, the alternative definition would apply to this
regulation. This action reduces annual burden on small and large
entities. We have, therefore, concluded that this action will relieve
regulatory burden for all directly regulated small entities.
E. Unfunded Mandates Reform Act (UMRA)
This action does not contain an unfunded mandate of $100 million or
more as described in UMRA, 2 U.S.C. 1531-1538, and does not
significantly or uniquely affect small governments.
As described earlier, this action reduces annual burden on
governments already subject to MATS; as a result, we have determined
that this action will not result in any ``significant'' adverse
economic impact for small governments.
F. Executive Order 13132: Federalism
This action 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.
G. Executive Order 13175: Consultation and Coordination With Indian
Tribal Governments
This action does not have tribal implications as specified in
Executive Order 13175. As described earlier, this action has no
substantial direct effect on Indian tribes already subject to MATS,
since this action reduces their annual burden. Thus, Executive Order
13175 does not apply to this action.
H. Executive Order 13045: Protection of Children From Environmental
Health Risks and Safety Risks
The EPA interprets Executive Order 13045 as applying only to those
regulatory actions that concern environmental health or safety risks
that the EPA has reason to believe may disproportionately affect
children, per the definition of ``covered regulatory action'' in
section 2-202 of the Executive order. This action is not subject to
Executive Order 13045 because it does not concern an environmental
health risk or safety risk.
I. Executive Order 13211: Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution or Use
This action is not subject to Executive Order 13211, because it is
not a significant regulatory action under Executive Order 12866.
J. National Technology Transfer and Advancement Act (NTTAA)
This rulemaking does not involve technical standards.
K. Executive Order 12898: Federal Actions To Address Environmental
Justice in Minority Populations and Low-Income Populations
The EPA believes that this proposed action is not subject to
Executive Order 12898 (59 FR 7629, February 16, 1994) because it would
not establish an environmental health or safety standard. This proposed
regulatory action revises the way in which information is reported to
the Agency, increasing submission frequency and making adaptions so
that just one reporting system can be used, but reducing overall
burden; this regulatory action does not have any impact on human health
or the environment.
List of Subjects in 40 CFR Part 63
Environmental protection, Administrative practice and procedure,
Air pollution control, Hazardous substances, Intergovernmental
relations, Reporting and recordkeeping requirements.
Andrew Wheeler,
Administrator.
For the reasons set forth in the preamble, EPA proposes to amend 40
CFR part 63 as follows:
PART 63--NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS
FOR SOURCE CATEGORIES
0
1. The authority citation for part 63 continues to read as follows:
Authority: 42 U.S.C. 7401 et seq.
Subpart UUUUU--National Emission Standards for Hazardous Air
Pollutants: Coal- and Oil-Fired Electric Utility Steam Generating
Units
Sec. 63.10000 [Amended]
0
2. In Sec. 63.10000, paragraph (d)(5)(vi) is amended by adding the
words ``, where appropriate,'' immediately after the words ``CMS that
is out of control consistent with Sec. 63.8(c)(7)(i)''.
0
3. Section 63.10005 is amended by:
[[Page 20356]]
0
a. Revising the first sentence in paragraph (a)(2) introductory text;
and
0
b. Revising paragraph (b) introductory text.
The revisions read as follows:
Sec. 63.10005 What are my initial compliance requirements and by what
date must I conduct them?
(a) * * *
(2) To demonstrate initial compliance using either a CMS that
measures HAP concentrations directly (i.e., an Hg, HCl, or HF CEMS, or
a sorbent trap monitoring system) or an SO2 or PM CEMS, the
initial performance test shall consist of 30- or, if applicable for Hg,
90-boiler operating days. * * *
* * * * *
(b) Performance testing requirements. If you choose to use
performance testing to demonstrate initial compliance with the
applicable emissions limits in Tables 1 and 2 to this subpart for your
EGUs, you must conduct the tests according to Sec. 63.10007 and Table
5 to this subpart. Notwithstanding the requirements in this subpart,
when Table 5 specifies the use of isokinetic EPA test Method 5, 5D,
26A, or 29 in appendices A-3 and A-8 to part 60 of this chapter for a
stack test, if concurrent measurement of the stack gas flow rate or
moisture content is needed to convert the pollutant concentrations to
units of the standard, separate determination of these parameters using
EPA test Method 2 or EPA test Method 4 in appendices A-1 and A-3 to
part 60 of this chapter is not necessary. Instead, the stack gas flow
rate and moisture content can be determined from data that are
collected during the EPA test Method 5, 5D, 6, 26A, or 29 test (e.g.,
pitot tube (delta P) readings, moisture collected in the impingers,
etc.). For the purposes of the initial compliance demonstration, you
may use test data and results from a performance test conducted prior
to the date on which compliance is required as specified in Sec.
63.9984, provided that the following conditions are fully met:
* * * * *
0
4. Section 63.10009 is amended by:
0
a. Revising in paragraph (a)(2) the second, third, and last sentences;
0
b. In paragraph (b)(2):
0
i. In the introductory text, removing the words ``for pollutants other
than Hg''; and
0
ii. Adding in the definition for ``Heri'' the words ``or
sorbent trap monitoring system'' after the words ``unit i's CEMS''; and
0
c. Revising ``Equation 3a'' and ``Equation 3b'' in paragraph (b)(3).
The revisions read as follows:
Sec. 63.10009 May I use emissions averaging to comply with this
subpart?
(a) * * *
(2) * * * Note that except for the alternate Hg emissions limit
from EGUs in the ``unit designed for coal >= 8,300 Btu/lb''
subcategory, the averaging time for emissions averaging for pollutants
is 30-group boiler operating days (rolling daily) using data from CEMS
and sorbent trap monitoring (for Hg), or a combination of data from
CEMS and emissions testing (for other pollutants). The averaging time
for emissions averaging for the alternate Hg limit (equal to or less
than 1.0 lb/TBtu or 1.1E-2 lb/GWh) from EGUs in the ``unit designed for
coal >= 8,300 Btu/lb'' subcategory is 90-group boiler operating days
(rolling daily) using data from CEMS, sorbent trap monitoring, or a
combination of data from CEMS and sorbent trap monitoring. * * * You
must calculate the weighted average emissions rate for the group in
accordance with the procedures in this paragraph (a)(2) using the data
from all units in the group including any that operate fewer than 30
(or 90) of the preceding 30 (or 90) group boiler operating days.
* * * * *
(b) * * *
(3) * * *
[GRAPHIC] [TIFF OMITTED] TP10AP20.001
Where:
Heri = Hourly emission rate from unit i's Hg CEMS or Hg
sorbent trap monitoring system for the preceding 90-group boiler
operating days;
Rmi = Hourly heat input or gross output from unit i for
the preceding 90-group boiler operating days;
p = Number of EGUs in the emissions averaging group; and
n = Number of hours that hourly rates are collected over the 90-
group boiler operating days.
[GRAPHIC] [TIFF OMITTED] TP10AP20.002
Where:
Heri = Hourly emission rate from unit i's Hg CEMS or Hg
sorbent trap monitoring system for the preceding 90-group boiler
operating days;
Smi = Steam generation in units of pounds from unit i
that uses Hg CEMS or Hg sorbent trap monitoring for the preceding
90-group boiler operating days;
Cfmi = Conversion factor, calculated from the most recent
compliance test results, in units of heat input per pound of steam
generated or gross output per pound of steam generated, from unit i
that uses Hg CEMS or sorbent trap monitoring from the preceding 90-
group boiler operating days;
p = Number of EGUs in the emissions averaging group; and
n = Number of hours that hourly rates are collected over the 90-
group boiler operating days.
* * * * *
0
5. Section 63.10010 is amended by revising paragraphs (h)(6) and (7),
(i), and (j)(4) to read as follows:
[[Page 20357]]
Sec. 63.10010 What are my monitoring, installation, operation, and
maintenance requirements?
* * * * *
(h) * * *
(6) You must use all the data collected during all boiler operating
hours in assessing the compliance with your operating limit except:
(i) Any data recorded during periods of monitoring system
malfunctions or repairs associated with monitoring system malfunctions.
You must report any monitoring system malfunctions as deviations in
your compliance reports under Sec. 63.10031(c) or (g) (as applicable);
(ii) Any data recorded during periods when the monitoring system is
out-of-control (as specified in your site-specific monitoring plan),
repairs associated with periods when the monitoring system is out of
control, or required monitoring system quality assurance or quality
control activities conducted during out-of-control periods. You must
report any such periods as deviations in your compliance reports under
Sec. 63.10031(c) or (g) (as applicable);
(iii) Any data recorded during required monitoring system quality
assurance or quality control activities that temporarily interrupt the
measurement of output data from the PM CPMS; and
(iv) Any data recorded during periods of startup or shutdown.
(7) You must record and report the results of PM CPMS system
performance audits, in accordance with Sec. 63.10031(k). You must also
record and make available upon request the dates and duration of
periods from when the PM CPMS is out of control until completion of the
corrective actions necessary to return the PM CPMS to operation
consistent with your site-specific monitoring plan.
(i) If you choose to comply with the PM filterable emissions limit
in lieu of metal HAP limits, you may choose to install, certify,
operate, and maintain a PM CEMS and record and report the output of the
PM CEMS as specified in paragraphs (i)(1) through (8) of this section.
Compliance with the applicable PM emissions limit in Table 1 or 2 to
this subpart is determined on a 30-boiler operating day rolling average
basis.
(1) You must install and certify your PM CEMS according to section
4 of appendix C to this subpart.
(2) You must operate, maintain, and quality-assure the data from
your PM CEMS according to section 5 of appendix C to this subpart.
(3) You must reduce the data from your PM CEMS to hourly averages
in accordance with section 6.1 of appendix C to this subpart.
(4) You must collect data using the PM CEMS at all times the
process unit is operating except for periods of monitoring system
malfunctions, out-of-control periods, repairs associated with
monitoring system malfunctions or out-of-control periods, and required
monitoring system quality assurance, quality control, or maintenance
activities.
(5) You must use all the data collected during all boiler operating
hours in assessing the compliance with your emissions limit except:
(i) Any data recorded during periods of monitoring system
malfunctions and repairs associated with monitoring system
malfunctions. You must report any monitoring system malfunctions as
deviations in your compliance reports under Sec. 63.10031(c) or (g)
(as applicable);
(ii) Any data recorded during periods when the monitoring system is
out-of-control (as specified in appendix C to this subpart), repairs
associated with periods when the monitoring system is out of control,
or required monitoring system quality assurance or quality control
activities conducted during out-of-control periods. You must report any
such periods as deviations in your compliance reports under Sec.
63.10031(c) or (g) (as applicable);
(iii) Any data recorded during required monitoring system quality
assurance, quality control, or maintenance activities that temporarily
interrupt the measurement of emissions (e.g., calibrations, certain
audits, routine probe maintenance); and
(iv) Any data recorded during periods of startup or shutdown.
(6) You must keep records and report data from your PM CEMS in
accordance with section 7 of appendix C to this subpart.
(7) You must record and make available upon request the dates and
duration of periods when the PM CEMS is out-of-control to completion of
the corrective actions necessary to return the PM CEMS to operation
consistent with your site-specific monitoring plan.
(8) You must calculate each 30-boiler operating day rolling average
PM emission rate in units of the applicable emissions limit in Table 1
or 2 to this subpart, in accordance with section 6.2.4 of appendix C to
this subpart.
(j) * * *
(4) You must collect data using the HAP metals CEMS at all times
the process unit is operating and at the intervals specified in
paragraph (a) of this section, except for periods of monitoring system
malfunctions, out-of-control periods, repairs associated with
monitoring system malfunctions or out-of-control periods, and required
monitoring system quality assurance, quality control, or maintenance
activities.
(i) You must use all the data collected during all boiler operating
hours in assessing the compliance with your emission limit except:
(A) Any data collected during periods of monitoring system
malfunctions and repairs associated with monitoring system
malfunctions. You must report any monitoring system malfunctions as
deviations in your compliance reports under Sec. 63.10031(c) or (g)
(as applicable);
(B) Any data collected during periods when the monitoring system is
out of control as specified in your site-specific monitoring plan,
repairs associated with periods when the monitoring system is out of
control, or required monitoring system quality assurance or quality
control activities conducted during out-of-control periods. You must
report any out of control periods as deviations in your compliance
reports under Sec. 63.10031(c) or (g) (as applicable);
(C) Any data recorded during required monitoring system quality
assurance or quality control activities that temporarily interrupt the
measurement of emissions (e.g., calibrations, certain audits, routine
probe maintenance); and
(D) Any data recorded during periods of startup or shutdown.
(ii) You must record and report the results of HAP metals CEMS
system performance audits, in accordance with Sec. 63.10031(k) You
must also record and make available upon request the dates and duration
of periods when the HAP metals CEMS is out of control to completion of
the corrective actions necessary to return the HAP metals CEMS to
operation consistent with your site-specific performance evaluation and
quality control program plan.
* * * * *
0
6. Section 63.10011 is amended by revising paragraphs (e) and (g)(3)
to read as follows:
Sec. 63.10011 How do I demonstrate initial compliance with the
emissions limits and work practice standards?
* * * * *
(e) You must submit a Notification of Compliance Status in
accordance with Sec. 63.10031(f)(4) or (h), as applicable, containing
the results of the initial compliance demonstration, as specified in
Sec. 63.10030(e).
* * * * *
(g) * * *
(3) You must report the emissions data recorded during startup and
[[Page 20358]]
shutdown. If you are relying on paragraph (2) of the definition of
``startup'' in Sec. 63.10042, then for startup and shutdown incidents
that occur on or prior to December 31, 2023, you must also report the
applicable supplementary information in Sec. 63.10031(c)(5) in the
semiannual compliance report. For startup and shutdown incidents that
occur on or after January 1, 2024, you must provide the applicable
information in Sec. Sec. 63.10031(c)(5)(ii) and 63.10020(e) quarterly,
in PDF files, in accordance with Sec. 63.10031(i).
* * * * *
Sec. 63.10020 [Amended]
0
7. In Sec. 63.10020, paragraph (b) is amended by removing the words
``(see Sec. 63.8(c)(7) of this part)''.
0
8. Section 63.10021 is amended by:
0
a. Revising paragraphs (e)(9) and (f);
0
b. Removing and reserving paragraph (h)(3); and
0
c. Revising paragraph (i).
The revisions read as follows:
Sec. 63.10021 How do I demonstrate continuous compliance with the
emission limitations, operating limits, and work practice standards?
* * * * *
(e) * * *
(9) Prior to January 1, 2024, report the tune-up date
electronically, in a PDF file, in your semiannual compliance report, as
specified in Sec. 63.10031(f)(4) and (6) and, if requested by the
Administrator, in hard copy, as specified in Sec. 63.10031(f)(5). On
and after January 1, 2024, report the tune-up date electronically in
your quarterly compliance report, in accordance with Sec. 63.10031(g)
and section 10.2 of appendix E to this subpart. The tune-up report date
is the date when tune-up requirements in paragraphs (e)(6) and (7) of
this section are completed.
(f) You must submit the applicable reports and notifications
required under Sec. 63.10031(a) through (k) to the Administrator
electronically, using EPA's Emissions Collection and Monitoring Plan
System (ECMPS) Client Tool. If the final date of any time period (or
any deadline) for any of these submissions falls on a weekend or a
Federal holiday, the time period shall be extended to the next business
day. Moreover, if the EPA Host System supporting the ECMPS Client Tool
is offline and unavailable for submission of reports for any part of a
day when a report would otherwise be due, the deadline for reporting is
automatically extended until the first business day on which the system
becomes available following the outage. Use of the ECMPS Client Tool to
submit a report or notification required under this subpart satisfies
any requirement under subpart A of this part to submit that same report
or notification (or the information contained in it) to the appropriate
EPA Regional Office or State agency whose delegation request has been
approved.
* * * * *
(i) If you are relying on paragraph (2) of the definition of
``startup'' in Sec. 63.10042, you must provide reports concerning
activities and periods of startup and shutdown that occur on or prior
to January 1, 2024, in accordance with Sec. 63.10031(c)(5), in your
semiannual compliance report. For startup and shutdown incidents that
occur on and after January 1, 2024, you must provide the applicable
information referenced in Sec. Sec. 63.10031(c)(5)(ii) and 63.10020(e)
quarterly, in PDF files, in accordance with Sec. 63.10031(i).
0
8. Section 63.10030 is amended by:
0
a. Revising the last sentence in paragraph (e) introductory text and
paragraph (e)(7) introductory text;
0
b. Removing and reserving paragraph (e)(7)(i);
0
c. Revising paragraphs (e)(7)(iii) introductory text and
(e)(7)(iii)(A)(3);
0
d. Adding in paragraph (e)(7)(iii)(B) the word ``must'' after the word
``You''; and
0
e. Adding in paragraph (e)(7)(iii)(C) the word ``must'' after the word
``you''.
The revisions read as follows:
Sec. 63.10030 What notifications must I submit and when?
* * * * *
(e) * * * The Notification of Compliance Status report must contain
all of the information specified in paragraphs (e)(1) through (8) of
this section that applies to your initial compliance strategy.
* * * * *
(7) Except for requests to switch from one emission limit to
another, as provided in paragraph (e)(7)(iii) of this section, your
initial notification of compliance status shall also include the
following information:
* * * * *
(iii) For each of your existing EGUs, identification of each
emissions limit specified in Table 2 to this subpart with which you
plan to comply initially. (Note: If, at some future date, you wish to
switch from the limit specified in your initial notification of
compliance status, you must follow the procedures and meet the
conditions of paragraphs (e)(7)(iii)(A) through (C) of this section.)
(A) * * *
(3) Your request includes performance stack test results or valid
CMS data, obtained within 45 days prior to the date of your submission,
demonstrating that each EGU or EGU emissions averaging group is in
compliance with both the mass per heat input limit and the mass per
gross output limit;
* * * * *
0
9. Section 63.10031 is amended by:
0
a. Revising paragraphs (a), (b) introductory text, (b)(1), (2), (4),
and (5), and (c) introductory text;
0
b. Removing paragraphs (c)(5)(iii), (iv), and (v);
0
c. Adding paragraph (c)(10);
0
d. Revising paragraphs (d), (e), (f) introductory text, and (f)(1) and
(2);
0
e. Removing and reserving paragraph (f)(3);
0
f. Revising paragraphs (f)(4), (f)(6) introductory text, (f)(6)(vii)
and (xi), and (g); and
0
g. Adding paragraphs (h) through (k).
The revisions and additions read as follows:
Sec. 63.10031 What reports must I submit and when?
(a) You must submit each report in this section that applies to
you.
(1) If you are required to (or elect to) monitor Hg emissions
continuously, you must meet the electronic reporting requirements of
appendix A to this subpart.
(2) If you elect to monitor HCl and/or HF emissions continuously,
you must meet the electronic reporting requirements of appendix B to
this subpart. Notwithstanding the requirement in this paragraph (a)(2),
if you opt to certify your HCl monitor according to Performance
Specification 18 in appendix B to part 60 of this chapter and to use
Procedure 6 in appendix F to part 60 of this chapter for on-going QA of
the monitor, then, on and prior to December 31, 2023, report only
hourly HCl emissions data and the results of daily calibration drift
tests and RATAs performed on or prior to that date; keep records of all
of the other required certification and QA tests and report them,
starting in 2024.
(3) If you elect to monitor filterable PM emissions continuously,
you must meet the electronic reporting requirements of appendix C to
this subpart. Electronic reporting of hourly PM emissions data shall
begin with the later of: The first operating hour on or after January
1, 2024; or the first operating hour after completion of the initial PM
CEMS correlation test.
(4) If you elect to demonstrate continuous compliance using a PM
CPMS, you must meet the electronic reporting requirements of appendix D
to this subpart. Electronic reporting of the hourly PM CPMS output
shall begin
[[Page 20359]]
with the later of: The first operating hour on or after January 1,
2024; or the first operating hour after completion of the initial
performance stack test that establishes the operating limit for the PM
CPMS.
(5) If you elect to monitor SO2 emission rate
continuously as a surrogate for HCl, you must use the ECMPS Client Tool
to submit the following information to EPA (except where it is already
required to be reported or has been previously provided under the Acid
Rain Program or another emissions reduction program that requires the
use of part 75 of this chapter):
(i) Monitoring plan information for the SO2 CEMS and for
any additional monitoring systems that are required to convert
SO2 concentrations to units of the emission standard, in
accordance with Sec. Sec. 75.62 and 75.64(a)(4) of this chapter;
(ii) Certification, recertification, quality-assurance, and
diagnostic test results for the SO2 CEMS and for any
additional monitoring systems that are required to convert
SO2 concentrations to units of the emission standard, in
accordance with Sec. 75.64(a)(5) of this chapter; and
(iii) Quarterly electronic emissions reports. You must submit an
electronic quarterly report within 30 days after the end of each
calendar quarter, starting with a report for the calendar quarter in
which the initial 30 boiler operating day performance test begins. Each
report must include the following information:
(A) The applicable operating data specified in Sec. 75.57(b) of
this chapter;
(B) An hourly data stream for the unadjusted SO2
concentration (in ppm, rounded to one decimal place), and separate
unadjusted hourly data streams for the other parameters needed to
convert the SO2 concentrations to units of the standard.
(Note: If a default moisture value is used in the emission rate
calculations, an hourly data stream is not required for moisture;
rather, the default value must be reported in the electronic monitoring
plan.);
(C) An hourly SO2 emission rate data stream, in units of
the standard (i.e., lb/MMBtu or lb/MWh, as applicable), calculated
according to Sec. 63.10007(e) and (f)(1), rounded to the same
precision as the emission standard (i.e., with one leading non-zero
digit and one decimal place), expressed in scientific notation. Use the
following rounding convention: If the digit immediately following the
first decimal place is 5 or greater, round the first decimal place
upward (increase it by one); if the digit immediately following the
first decimal place is 4 or less, leave the first decimal place
unchanged;
(D) The results of all required daily quality-assurance tests of
the SO2 monitor and the additional monitors used to convert
SO2 concentration to units of the standard, as specified in
appendix B to part 75 of this chapter; and
(E) A compliance certification, which includes a statement, based
on reasonable inquiry of those persons with primary responsibility for
ensuring that all SO2 emissions from the affected EGUs under
this subpart have been correctly and fully monitored, by a responsible
official with that official's name, title, and signature, certifying
that, to the best of his or her knowledge, the report is true,
accurate, and complete. You must submit such a compliance certification
statement in support of each quarterly report.
(b) You must submit semiannual compliance reports according to the
requirements in paragraphs (b)(1) through (5) of this section.
(1) The first compliance report must cover the period beginning on
the compliance date that is specified for your affected source in Sec.
63.9984 (or, if applicable, the extended compliance date approved under
Sec. 63.6(i)(4)) and ending on June 30 or December 31, whichever date
is the first date that occurs at least 180 days after the compliance
date that is specified for your source in Sec. 63.9984 (or, if
applicable, the extended compliance date approved under Sec.
63.6(i)(4)).
(2) The first compliance report must be submitted electronically no
later than July 31 or January 31, whichever date is the first date
following the end of the first calendar half after the compliance date
that is specified for your source in Sec. 63.9984 (or, if applicable,
the extended compliance date approved under Sec. 63.6(i)(4)).
* * * * *
(4) Each subsequent compliance report must be submitted
electronically no later than July 31 or January 31, whichever date is
the first date following the end of the semiannual reporting period.
(5) The final semiannual compliance report shall cover the
reporting period from July 1, 2023 through December 31, 2023. Quarterly
compliance reports shall be submitted thereafter, in accordance with
paragraph (g) of this section, starting with a report covering the
first calendar quarter of 2024.
(c) The semiannual compliance report must contain the information
required in paragraphs (c)(1) through (10) of this section.
* * * * *
(10) If you had any process or control equipment malfunction(s)
during the reporting period, you must include the number, duration, and
a brief description for each type of malfunction which occurred during
the semiannual reporting period which caused or may have caused any
applicable emission limitation to be exceeded.
(d) For EGUs whose owners or operators rely on a CMS to comply with
an emissions or operating limit, the semiannual compliance reports
described in paragraph (c) of this section must include the excess
emissions and monitor downtime summary report described in Sec.
63.10(e)(3)(vi). However, starting with the first calendar quarter of
2024, reporting of the information under Sec. 63.10(e)(3)(vi) (and
under paragraph (e)(3)(v), if the applicable excess emissions and/or
monitor downtime threshold is exceeded) is discontinued for all CMS,
and you must, instead, include in the quarterly compliance reports
described in paragraph (g) of this section the applicable data elements
in section 13 of appendix E to this subpart for any ``deviation'' (as
defined in Sec. 63.10042 and elsewhere in this subpart) that occurred
during the calendar quarter. If there were no deviations, you must
include a statement to that effect in the quarterly compliance report.
(e) Each affected source that has obtained a title V operating
permit pursuant to part 70 or 71 of this chapter must report all
deviations as defined in this subpart in the semiannual monitoring
report required by 40 CFR 70.6(a)(3)(iii)(A) or 71.6(a)(3)(iii)(A). If
an affected source submits a semiannual compliance report pursuant
paragraphs (c) and (d) of this section, or two quarterly compliance
reports covering the appropriate calendar half pursuant to paragraph
(g) of this section, along with, or as part of, the semiannual
monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or
71.6(a)(3)(iii)(A), and the compliance report(s) includes all required
information concerning deviations from any emission limit, operating
limit, or work practice requirement in this subpart, submission of the
compliance report(s) satisfies any obligation to report the same
deviations in the semiannual monitoring report. Submission of the
compliance report(s) does not otherwise affect any obligation the
affected source may have to report deviations from permit requirements
to the permit authority.
(f) For each performance stack test completed prior to January 1,
2024 (including 30- (or 90-) boiler operating day Hg LEE demonstration
tests and PM
[[Page 20360]]
tests to establish operating limits for PM CPMS), you must submit a PDF
test report in accordance with paragraph (f)(6) of this section, no
later than 60 days after the date on which the testing is completed.
For each test completed on or after January 1, 2024, in accordance with
Sec. 63.10031(g), submit the applicable reference method information
in sections 17 through 31 of appendix E to this subpart along with the
quarterly compliance report for the calendar quarter in which the test
was completed.
(1) For each relative accuracy test audit (RATA) of an Hg, HCl, HF,
or SO2 monitoring system completed prior to January 1, 2024,
and for each PM CEMS correlation test, each relative response audit
(RRA) and each response correlation audit (RCA) of a PM CEMS completed
prior to that date, you must submit a PDF test report in accordance
with paragraph (f)(6) of this section, no later than 60 days after the
date on which the test is completed. For each SO2 or Hg RATA
completed on or after January 1, 2024, you must submit the applicable
reference method information in sections 17 through 31 of appendix E to
this subpart prior to or concurrent with the relevant quarterly
emissions report. For HCl or HF RATAs, and for correlation tests, RRAs,
and RCAs of PM CEMS that are completed on or after January 1, 2024,
submit the appendix E reference method information together with the
summarized electronic test results, in accordance with section 11.4 of
appendix B to this subpart or section 7.2.4 of appendix C to this part,
as applicable.
(2) If, for a particular EGU or a group of EGUs serving a common
stack, you have elected to demonstrate compliance using a PM CEMS, an
approved HAP metals CEMS, or a PM CPMS, you must submit quarterly PDF
reports in accordance with paragraph (f)(6) of this section, which
include all of the 30-boiler operating day rolling average emission
rates derived from the CEMS data or the 30-boiler operating day rolling
average responses derived from the PM CPMS data (as applicable). The
quarterly reports are due within 60 days after the reporting periods
ending on March 31st, June 30th, September 30th, and December 31st.
Submission of these quarterly reports in PDF files shall end with the
report that covers the fourth calendar quarter of 2023. Beginning with
the first calendar quarter of 2024, the compliance averages shall no
longer be reported separately, but shall be incorporated into the
quarterly compliance reports described in paragraph (g) of this
section. In addition to the compliance averages for PM CEMS, PM CPMS,
and/or HAP metals CEMS, the quarterly compliance reports described in
paragraph (g) of this section must also include the 30- (or, if
applicable 90-) boiler operating day rolling average emission rates for
Hg, HCl, HF, and/or SO2, if you have elected to (or are
required to) continuously monitor these pollutants. Further, if your
EGU or common stack is in an averaging plan, your quarterly compliance
reports must identify all of the EGUs or common stacks in the plan and
must include all of the 30- (or 90-) group boiler operating day rolling
weighted average emission rates (WAERs) for the averaging group.
* * * * *
(4) You must submit semiannual compliance reports as required under
paragraphs (b) through (d) of this section, ending with a report
covering the semiannual period from July 1 through December 31, 2023,
and Notifications of Compliance Status as required under Sec.
63.10030(e), as PDF files. Quarterly compliance reports shall be
submitted in XML format thereafter, in accordance with paragraph (g) of
this section, starting with a report covering the first calendar
quarter of 2024.
* * * * *
(6) All reports and notifications described in paragraphs (f)
introductory text and (f)(1), (2), and (4) of this section shall be
submitted to the EPA in the specified format and at the specified
frequency, using the ECMPS Client Tool. Each PDF version of a stack
test report, CEMS RATA report, PM CEMS correlation test report, RRA
report, and RCA report must include sufficient information to assess
compliance and to demonstrate that the reference method testing was
done properly. Note that EPA will continue to accept, as necessary, PDF
reports that are being phased out at the end of 2023, if the submission
deadlines for those reports extend beyond December 31, 2023. The
following data elements must be entered into the ECMPS Client Tool at
the time of submission of each PDF file:
* * * * *
(vii) An indication of the type of PDF report or notification being
submitted;
* * * * *
(xi) The date the performance test was completed (if applicable)
and the test number (if applicable); and
* * * * *
(g) Starting with a report for the first calendar quarter of 2024,
you must use the ECMPS Client Tool to submit quarterly electronic
compliance reports. Each quarterly compliance report shall include the
applicable data elements in sections 2 through 13 of appendix E to this
subpart. For each stack test summarized in the compliance report, you
must also submit the applicable reference method information in
sections 17 through 31 of appendix E to this subpart. The compliance
reports and associated appendix E information must be submitted no
later than 60 days after the end of each calendar quarter.
(h) On and after January 1, 2024, initial Notifications of
Compliance Status (if any) shall be submitted in accordance with Sec.
63.9(h)(2)(ii), as PDF files, using the ECMPS Client Tool. The
applicable data elements in paragraphs (f)(6)(i) through (xii) of this
section must be entered into ECMPS with each Notification.
(i) If you have elected to use paragraph (2) of the definition of
``startup'' in Sec. 63.10042, then, for startup and shutdown incidents
that occur on or prior to December 31, 2023, you must include the
information in Sec. 63.10031(c)(5) in the semiannual compliance
report, in a PDF file. If you have elected to use paragraph (2) of the
definition of ``startup'' in Sec. 63.10042, then, for startup and
shutdown event(s) that occur on or after January 1, 2024, you must use
the ECMPS Client Tool to submit the information in Sec. Sec.
63.10031(c)(5) and 63.10020(e) along with each quarterly compliance
report, in a PDF file, starting with a report for the first calendar
quarter of 2024. The applicable data elements in paragraphs (f)(6)(i)
through (xii) of this section must be entered into ECMPS with each
startup and shutdown report.
(j) If you elect to use a certified PM CEMS to monitor PM emissions
continuously to demonstrate compliance with this subpart and have begun
recording valid data from the PM CEMS prior to [DATE 60 DAYS AFTER DATE
OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], you must use
the ECMPS Client Tool to submit a detailed report of your PS 11
correlation test (see appendix B to part 60 of this chapter) in a PDF
file no later than 60 days after that date. For a correlation test
completed on or after [DATE 60 DAYS AFTER DATE OF PUBLICATION OF THE
FINAL RULE IN THE FEDERAL REGISTER], but prior to January 1, 2024, you
must submit the PDF report no later than 60 days after the date on
which the test is completed. For a correlation test completed on or
after January 1, 2024, you must submit the PDF report according to
section 7.2.4 of appendix C to this subpart. The applicable data
elements in paragraphs (f)(6)(i) through (xii) of this section must
[[Page 20361]]
be entered into ECMPS with the PDF report.
(k) If you elect to demonstrate compliance using a PM CPMS or an
approved HAP metals CEMS, you must submit quarterly reports of your QA/
QC activities (e.g., calibration checks, performance audits), in a PDF
file, beginning with a report for the first quarter of 2024, if the PM
CPMS or HAP metals CEMS is used for the compliance demonstration in
that quarter. Otherwise, submit a report for the first calendar quarter
in which the PM CPMS or HAP metals CEMS is used to demonstrate
compliance. These reports are due no later than 60 days after the end
of each calendar quarter. The applicable data elements in paragraphs
(f)(6)(i) through (xii) of this section must be entered into ECMPS with
the PDF report.
0
10. Section 63.10032 is amended by revising paragraphs (a) introductory
text and (a)(1) to read as follows:
Sec. 63.10032 What records must I keep?
(a) You must keep records according to paragraphs (a)(1) and (2) of
this section. If you are required to (or elect to) continuously monitor
Hg and/or HCl and/or HF and/or PM emissions, or if you elect to use a
PM CPMS, you must keep the records required under appendix A and/or
appendix B and/or appendix C and/or appendix D to this subpart. If you
elect to conduct periodic (e.g., quarterly or annual) performance stack
tests, then, for each test completed on or after January 1, 2024, you
must keep records of the applicable data elements under Sec. 63.7(g).
You must also keep records of all data elements and other information
in appendix E to this subpart that apply to your compliance strategy.
(1) In accordance with Sec. 63.10(b)(2)(xiv), a copy of each
notification or report that you submit to comply with this subpart. You
must also keep records of all supporting documentation for the initial
Notifications of Compliance Status, semiannual compliance reports, or
quarterly compliance reports that you submit.
* * * * *
0
11. Section 63.10042 is amended by:
0
a. In the definition ``Diluent cap,'' adding ``PM,'' after ``HF,'';
0
b. In the definition ``Monitoring system malfunction or out of control
period,'' removing the words ``or out of control period''; and
0
c. Adding the definition ``Out of control period'' in alphabetical
order.
The addition reads as follows:
Sec. 63.10042 What definitions apply to this subpart?
* * * * *
Out-of-control period, as it pertains to continuous monitoring
systems, means any period:
(1) Beginning with the hour corresponding to the completion of a
daily calibration or quality assurance audit that indicates that the
instrument fails to meet the applicable acceptance criteria; and
(2) Ending with the hour corresponding to the completion of an
additional calibration or quality assurance audit following corrective
action showing that the instrument meets the applicable acceptance
criteria.
* * * * *
0
12. Table 3 to subpart UUUUU is amended by revising the entries ``3. A
coal-fired, liquid oil-fired (excluding limited-use liquid oil-fired
subcategory units), or solid oil-derived fuel-fired EGU during
startup'' and ``4. A coal-fired, liquid oil-fired (excluding limited-
use liquid oil-fired subcategory units), or solid oil-derived fuel-
fired EGU during shutdown'' to read as follows:
Table 3 to Subpart UUUUU of Part 63--Work Practice Standards
[ * * * * * * * ]
----------------------------------------------------------------------------------------------------------------
If your EGU is . . . You must meet the following . . .
----------------------------------------------------------------------------------------------------------------
* * * * * * *
3. A coal-fired, liquid oil-fired (excluding a. You have the option of complying using either of the following
limited-use liquid oil-fired subcategory work practice standards:
units), or solid oil-derived fuel-fired EGU (1) If you choose to comply using paragraph (1) of the definition
during startup. of ``startup'' in Sec. 63.10042, you must operate all CMS
during startup. Startup means either the first-ever firing of
fuel in a boiler for the purpose of producing electricity, or the
firing of fuel in a boiler after a shutdown event for any
purpose. Startup ends when any of the steam from the boiler is
used to generate electricity for sale over the grid or for any
other purpose (including on site use). For startup of a unit, you
must use clean fuels as defined in Sec. 63.10042 for ignition.
Once you convert to firing coal, residual oil, or solid oil-
derived fuel, you must engage all of the applicable control
technologies except dry scrubber and SCR. You must start your dry
scrubber and SCR systems, if present, appropriately to comply
with relevant standards applicable during normal operation. You
must comply with all applicable emissions limits at all times
except for periods that meet the applicable definitions of
startup and shutdown in this subpart. You must keep records
during startup periods. You must provide reports concerning
activities and startup periods, as specified in Sec.
63.10011(g) and Sec. 63.10021(h) and (i). If you elect to use
paragraph (2) of the definition of ``startup'' in Sec.
63.10042, you must report the applicable information in Sec.
63.10031(c)(5) concerning startup periods as follows: for startup
periods that occur on or prior to December 31, 2023 in PDF files
in the semiannual compliance report; for startup periods that
occur on or after January 1, 2024, quarterly, in PDF files,
according to Sec. 63.10031(i).
(2) If you choose to comply using paragraph (2) of the definition
of ``startup'' in Sec. 63.10042, you must operate all CMS
during startup. You must also collect appropriate data, and you
must calculate the pollutant emission rate for each hour of
startup.
For startup of an EGU, you must use one or a combination of the
clean fuels defined in Sec. 63.10042 to the maximum extent
possible, taking into account considerations such as boiler or
control device integrity, throughout the startup period. You must
have sufficient clean fuel capacity to engage and operate your PM
control device within one hour of adding coal, residual oil, or
solid oil-derived fuel to the unit. You must meet the startup
period work practice requirements as identified in Sec.
63.10020(e).
Once you start firing coal, residual oil, or solid oil-derived
fuel, you must vent emissions to the main stack(s). You must
comply with the applicable emission limits beginning with the
hour after startup ends. You must engage and operate your
particulate matter control(s) within 1 hour of first firing of
coal, residual oil, or solid oil-derived fuel.
You must start all other applicable control devices as
expeditiously as possible, considering safety and manufacturer/
supplier recommendations, but, in any case, when necessary to
comply with other standards made applicable to the EGU by a
permit limit or a rule other than this Subpart that require
operation of the control devices.
[[Page 20362]]
b. Relative to the syngas not fired in the combustion turbine of
an IGCC EGU during startup, you must either: (1) Flare the
syngas, or (2) route the syngas to duct burners, which may need
to be installed, and route the flue gas from the duct burners to
the heat recovery steam generator.
c. If you choose to use just one set of sorbent traps to
demonstrate compliance with the applicable Hg emission limit, you
must comply with the limit at all times; otherwise, you must
comply with the applicable emission limit at all times except for
startup and shutdown periods.
d. You must collect monitoring data during startup periods, as
specified in Sec. 63.10020(a) and (e). You must keep records
during startup periods, as provided in Sec. Sec. 63.10032 and
63.10021(h). You must provide reports concerning activities and
startup periods, as specified in Sec. Sec. 63.10011(g),
63.10021(i), and 63.10031. If you elect to use paragraph (2) of
the definition of ``startup'' in Sec. 63.10042, you must report
the applicable information in Sec. 63.10031(c)(5) concerning
startup periods as follows: for startup periods that occur on or
prior to December 31, 2023, in PDF files in the semiannual
compliance report; for startup periods that occur on or after
January 1, 2024, quarterly, in PDF files, according to Sec.
63.10031(i).
4. A coal-fired, liquid oil-fired (excluding You must operate all CMS during shutdown. You must also collect
limited-use liquid oil-fired subcategory appropriate data, and you must calculate the pollutant emission
units), or solid oil-derived fuel-fired EGU rate for each hour of shutdown for those pollutants for which a
during shutdown. CMS is used.
While firing coal, residual oil, or solid oil-derived fuel during
shutdown, you must vent emissions to the main stack(s) and
operate all applicable control devices and continue to operate
those control devices after the cessation of coal, residual oil,
or solid oil-derived fuel being fed into the EGU and for as long
as possible thereafter considering operational and safety
concerns. In any case, you must operate your controls when
necessary to comply with other standards made applicable to the
EGU by a permit limit or a rule other than this Subpart and that
require operation of the control devices.
If, in addition to the fuel used prior to initiation of shutdown,
another fuel must be used to support the shutdown process, that
additional fuel must be one or a combination of the clean fuels
defined in Sec. 63.10042 and must be used to the maximum extent
possible, taking into account considerations such as not
compromising boiler or control device integrity.
Relative to the syngas not fired in the combustion turbine of an
IGCC EGU during shutdown, you must either: (1) Flare the syngas,
or (2) route the syngas to duct burners, which may need to be
installed, and route the flue gas from the duct burners to the
heat recovery steam generator.
You must comply with all applicable emission limits at all times
except during startup periods and shutdown periods at which time
you must meet this work practice. You must collect monitoring
data during shutdown periods, as specified in Sec. 63.10020(a).
You must keep records during shutdown periods, as provided in
Sec. Sec. 63.10032 and 63.10021(h). Any fraction of an hour in
which shutdown occurs constitutes a full hour of shutdown. You
must provide reports concerning activities and shutdown periods,
as specified in Sec. Sec. 63.10011(g), 63.10021(i), and
63.10031. If you elect to use paragraph (2) of the definition of
``startup'' in Sec. 63.10042, you must report the applicable
information in Sec. 63.10031(c)(5) concerning shutdown periods
as follows: for shutdown periods that occur on or prior to
December 31, 2023, in PDF files in the semiannual compliance
report; for shutdown periods that occur on or after January 1,
2024, quarterly, in PDF files, according to Sec. 63.10031(i).
----------------------------------------------------------------------------------------------------------------
0
13. Table 8 to subpart UUUUU is revised to read as follows:
Table 8 to Subpart UUUUU of Part 63--Reporting Requirements
[In accordance with Sec. 63.10031, you must meet the following
reporting requirements, as they apply to your compliance strategy]
------------------------------------------------------------------------
You must submit the following reports . . .
-------------------------------------------------------------------------
1. The electronic reports required under Sec. 63.10031(a)(1), if you
continuously monitor Hg emissions.
2. The electronic reports required under Sec. 63.10031(a)(2), if you
continuously monitor HCl and/or HF emissions.
Where applicable, these reports are due no later than 30 days after
the end of each calendar quarter.
3. The electronic reports required under Sec. 63.10031(a)(3), if you
continuously monitor PM emissions.
Reporting of hourly PM emissions data using ECMPS shall begin with
the first operating hour after: January 1, 2024 or the hour of
completion of the initial PM CEMS correlation test, whichever is
later.
Where applicable, these reports are due no later than 30 days after
the end of each calendar quarter.
4. The electronic reports required under Sec. 63.10031(a)(4), if you
elect to use a PM CPMS.
Reporting of hourly PM CPMS response data using ECMPS shall begin
with the first operating hour after January 1, 2024 or the first
operating hour after completion of the initial performance stack
test that establishes the operating limit for the PM CPMS,
whichever is later.
Where applicable, these reports are due no later than 30 days after
the end of each calendar quarter.
5. The electronic reports required under Sec. 63.10031(a)(5), if you
continuously monitor SO2 emissions.
Where applicable, these reports are due no later than 30 days after
the end of each calendar quarter.
6. PDF reports for all performance stack tests completed prior to
January 1, 2024 (including 30- or 90-boiler operating day Hg LEE test
reports and PM test reports to set operating limits for PM CPMS),
according to Sec. 63.10031(f) introductory text and (f)(6).
For each test, submit the PDF report no later than 60 days after the
date on which testing is completed.
For a PM test that is used to set an operating limit for a PM CPMS, the
report must also include the information in Sec. 63.10023(b)(2)(vi).
For each performance stack test completed on or after January 1,
2024, submit the test results in the relevant quarterly compliance
report under Sec. 63.10031(g), together with the applicable
reference method information in sections 17 through 31 of appendix
E to this subpart.
7. PDF reports for all RATAs of Hg, HCl, HF, and/or SO2 monitoring
systems completed prior to January 1, 2024, and for correlation tests,
RRAs and/or RCAs of PM CEMS completed prior to January 1, 2024,
according to Sec. 63.10031(f)(1) and (6).
For each test, submit the PDF report no later than 60 days after the
date on which testing is completed.
[[Page 20363]]
For each SO2 or Hg system RATA completed on or after January 1,
2024, submit the electronic test summary required by appendix A to
this subpart or part 75 of this chapter (as applicable) together
with the applicable reference method information in sections 17-30
of appendix E to this subpart, either prior to or concurrent with
the relevant quarterly emissions report.
For each HCl or HF system RATA, and for each correlation test, RRA,
and RCA of a PM CEMS completed on or after January 1, 2024, submit
the electronic test summary in accordance with section 11.4 of
appendix B to this subpart or section 7.2.4 of appendix C to this
part, as applicable, together with the applicable reference method
information in sections 17-30 of appendix E to this subpart.
8. Quarterly reports, in PDF files, that include all 30-boiler operating
day rolling averages in the reporting period derived from your PM CEMS,
approved HAP metals CEMS, and/or PM CPMS, according to Sec.
63.10031(f)(2) and (6). These reports are due no later than 60 days
after the end of each calendar quarter.
The final quarterly rolling averages report in PDF files shall cover
the fourth calendar quarter of 2023.
Starting with the first quarter of 2024, you must report all 30-
boiler operating day rolling averages for PM CEMS, approved HAP
metals CEMS, PM CPMS, Hg CEMS, Hg sorbent trap systems, HCl CEMS,
HF CEMS, and/or SO2 CEMS (or 90-boiler operating day rolling
averages for Hg systems), in XML format, in the quarterly
compliance reports required under Sec. 63.10031(g).
If your EGU or common stack is in an averaging plan, each quarterly
compliance report must identify the EGUs in the plan and include
all of the 30- or 90- group boiler operating day weighted average
emission rates (WAERs) for the averaging group.
The quarterly compliance reports must be submitted no later than 60
days after the end of each calendar quarter.
9. The semiannual compliance reports described in Sec. 63.10031(c) and
(d), in PDF files, according to Sec. 63.10031(f)(4) and (6). The due
dates for these reports are specified in Sec. 63.10031(b).
The final semiannual compliance report shall cover the period from
July 1, 2023 through December 31, 2023.
10. Notifications of compliance status, in PDF files, according to Sec.
63.10031(f)(4) and (6) until December 31, 2023, and according to Sec.
63.10031(h) thereafter.
11. Quarterly electronic compliance reports, in accordance with Sec.
63.10031(g), starting with a report for the first calendar quarter of
2024. The reports must be in XML format and must include the applicable
data elements in sections 2 through 13 of appendix E to this subpart.
These reports are due no later than 60 days after the end of each
calendar quarter.
12. Quarterly reports, in PDF files, that include the applicable
information in Sec. Sec. 63.10031(c)(5)(ii) and 63.10020(e)
pertaining to startup and shutdown events, starting with a report for
the first calendar quarter of 2024, if you have elected to use
paragraph (2) of the definition of ``startup'' in Sec. 63.10042 (see
Sec. 63.10031(i)).
These PDF reports shall be submitted no later than 60 days after the
end of each calendar quarter, along with the quarterly compliance
reports required under Sec. 63.10031(g).
13. A test report for the PS 11 correlation test (see appendix B to part
60 of this chapter) of your PM CEMS, in accordance with Sec.
63.10031(j).
If, prior to [DATE 60 DAYS AFTER DATE OF PUBLICATION OF THE FINAL
RULE IN THE FEDERAL REGISTER], you have begun using a certified PM
CEMS to demonstrate compliance with this subpart, use the ECMPS
Client Tool to submit the report, in a PDF file, no later than 60
days after that date.
For correlation tests completed on or after [DATE 60 DAYS AFTER DATE
OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], but
prior to January 1, 2024, submit the report, in a PDF file, no
later than 60 days after the date on which the test is completed.
For correlation tests completed on or after January 1, 2024, submit
the test results electronically, according to section 7.2.4 of
appendix C to this subpart, together with the applicable reference
method data in sections 17 through 31 of appendix E to this
subpart.
14. Quarterly reports that include the QA/QC activities for your PM CPMS
or approved HAP metals CEMS (as applicable), in PDF files, according to
Sec. 63.10031(k).
The first report shall cover the first calendar quarter of 2024, if
the PM CPMS or HAP metals CEMS is in use during that quarter.
Otherwise, reporting begins with the first calendar quarter in
which the PM CPMS or HAP metals CEMS is used to demonstrate
compliance.
These reports are due no later than 60 days after the end of each
calendar quarter.
------------------------------------------------------------------------
0
14. Table 9 to subpart UUUUU is amended by:
0
a. Revising the entries ``Sec. 63.9'', ``Sec. 63.10(c)(7)'', and
``Sec. 63.10(c)(8)''; and
0
b. Adding the entry ``Sec. 63.10(e)(3)(v) and (vi)'' in numerical
order.
The addition and revisions read as follows:
* * * * *
Table 9 to Subpart UUUUU of Part 63--Applicability of General Provisions
to Subpart UUUUU
[ * * * * * * * ]
------------------------------------------------------------------------
Applies to subpart
Citation Subject UUUUU
------------------------------------------------------------------------
* * * * * * *
Sec. 63.9...................... Notification Yes, except (1) for
Requirements. the 60-day
notification prior
to conducting a
performance test in
Sec. 63.9(e);
instead use a 30-
day notification
period per Sec.
63.10030(d), (2)
the notification of
the CMS performance
evaluation in Sec.
63.9(g)(1) is
limited to RATAs,
and (3) the
information
required per Sec.
63.9(h)(2)(i);
instead provide the
applicable
information in Sec.
63.10030(e)(1)
through (e)(8), for
the initial
notification of
compliance status,
only.
[[Page 20364]]
* * * * * * *
Sec. 63.10(c)(7)............... Additional Applies only through
recordkeeping December 31, 2023.
requirements
for CMS--
identifying
exceedances
and excess
emissions.
Sec. 63.10(c)(8)............... Additional Applies only through
recordkeeping December 31, 2023.
requirements
for CMS--
identifying
exceedances
and excess
emissions.
* * * * * * *
Sec. 63.10(e)(3)(v) and (vi)... Excess Applies only through
emissions and December 31, 2023.
continuous
monitoring
system
performance
reports.
* * * * * * *
------------------------------------------------------------------------
0
15. Appendix A to subpart UUUUU is amended by revising sections
``7.1.3.3'', ``7.1.4.3'', ``7.1.8.2'' and ``7.2.3.1'' to read as
follows:
Appendix A to Subpart UUUUU of Part 63--HG Monitoring Provisions
* * * * *
7. Recordkeeping and Reporting
* * * * *
7.1.3.3 The hourly Hg concentration, if a quality-assured value
is obtained for the hour ([micro]g/scm, with one leading non-zero
digit and one decimal place, expressed in scientific notation). Use
the following rounding convention: if the digit immediately
following the first decimal place is 5 or greater, round the first
decimal place upward (increase it by one); if the digit immediately
following the first decimal place is 4 or less, leave the first
decimal place unchanged;
* * * * *
7.1.4.3 The hourly Hg concentration, if a quality-assured value
is obtained for the hour ([micro]g/scm, with one leading non-zero
digit and one decimal place, expressed in scientific notation). Use
the following rounding convention: If the digit immediately
following the first decimal place is 5 or greater, round the first
decimal place upward (increase it by one); if the digit immediately
following the first decimal place is 4 or less, leave the first
decimal place unchanged. Note that when a single quality-assured Hg
concentration value is obtained for a particular data collection
period, that single concentration value is applied to each operating
hour of the data collection period.
* * * * *
7.1.8.2 The hourly Hg emissions rate (lb/TBtu or lb/GWh, as
applicable), calculated according to section 6.2.1 or 6.2.2 of this
appendix, rounded to the same precision as the standard (i.e., with
one leading non-zero digit and one decimal place, expressed in
scientific notation), if valid values of Hg concentration and all
other required parameters (stack gas volumetric flow rate, diluent
gas concentration, electrical load, and moisture data, as
applicable) are obtained for the hour. Use the following rounding
convention: If the digit immediately following the first decimal
place is 5 or greater, round the first decimal place upward
(increase it by one); if the digit immediately following the first
decimal place is 4 or less, leave the first decimal place unchanged;
* * * * *
7.2.3.1 For an EGU that begins reporting hourly Hg
concentrations with a previously-certified Hg monitoring system,
submit the monitoring plan information in section 7.1.1.2 of this
appendix prior to or concurrent with the first required quarterly
emissions report. For a new EGU, or for an EGU switching to
continuous monitoring of Hg emissions after having implemented
another allowable compliance option under this subpart, submit the
information in section 7.1.1.2 of this appendix at least 21 days
prior to the start of initial certification testing of the CEMS.
Also submit the monitoring plan information in 40 CFR 75.53(g)
pertaining to any required flow rate, diluent gas, and moisture
monitoring systems within the applicable time frame specified in
this section, if the required records are not already in place.
* * * * *
0
16. Appendix B to subpart UUUUU is amended by:
0
a. Revising the heading and introductory text of section 2.3 and
sections ``9.4'', ``10.1.3.3'', ``10.1.7.2'', ``10.1.8.1.1'',
``10.1.8.1.2'', and ``10.1.8.1.3'';
0
b. Adding sections ``10.1.8.1.4'' through ``10.1.8.1.12'' in numerical
order;
0
c. Revising sections ``11.3.1'', ``11.4 introductory text'', and
``11.4.1'';
0
d. Adding sections ``11.4.1.1'' through ``11.4.1.9'' in numerical
order;
0
e. Revising sections ``11.4.2 introductory text'', ``11.4.3.11'', and
``11.4.3.12'';
0
f. Redesignating section ``11.4.3.13'' as ``11.4.3.14'';
0
g. Adding new section ``11.4.3.13'';
0
h. Revising newly redesignated section ``11.4.3.14'';
0
i. Redesignating section ``11.4.4'' as ``11.4.13'';
0
j. Adding sections: ``11.4.4 introductory text''; ``11.4.4.1 through
11.4.4.7''; ``11.4.5 introductory text''; ``11.4.5.1''; ``11.4.5.1.1
through 11.4.5.1.9''; ``11.4.5.2 introductory text''; ``11.4.5.2.1
through 11.4.5.2.6''; ``11.4.6 introductory text''; ``11.4.6.1 through
11.4.6.8'', ``11.4.7 introductory text''; ``11.4.7.1 through
11.4.7.6''; ``11.4.8 introductory text''; ``11.4.8.1 through
11.4.8.15''; ``11.4.9 introductory text''; ``11.4.9.1 through
11.4.9.5''; ``11.4.10 introductory text''; ``11.4.10.1 through
11.4.10.8''; ``11.4.11 introductory text''; ``11.4.11.1 through
11.4.11.7''; ``11.4.12 introductory text''; and ``11.4.12.1 through
11.4.12.9''; and
0
k. Revising newly redesignated section ``11.4.13'' and section
``11.5.1''.
The revisions and additions read as follows:
Appendix B to Subpart UUUUU of Part 63--HCL and HF
Monitoring Provisions
* * * * *
2. Monitoring of HCl and/or HF Emissions
* * * * *
2.3 Monitoring System Equipment, Supplies, Definitions, and
General Operation. The following provisions apply:
* * * * *
9. Data Reduction and Calculations
* * * * *
9.4 Use Equation A-5 in appendix A of this subpart to calculate
the required 30-boiler operating day rolling average HCl or HF
emission rates. Report each 30-boiler operating day rolling average
to the same precision as the standard (i.e., with one leading non-
zero digit and one decimal place), expressed in scientific notation.
The
[[Page 20365]]
term Eho in Equation A-5 must be in the units of the
applicable emissions limit.
* * * * *
10. Recordkeeping Requirements
* * * * *
10.1.3.3 The pollutant concentration, for each hour in which a
quality-assured value is obtained. For HCl and HF, record the data
in parts per million (ppm), with one leading non-zero digit and one
decimal place, expressed in scientific notation. Use the following
rounding convention: If the digit immediately following the first
decimal place is 5 or greater, round the first decimal place upward
(increase it by one); if the digit immediately following the first
decimal place is 4 or less, leave the first decimal place unchanged.
* * * * *
10.1.7.2 The hourly HCl and/or HF emissions rate (lb/MMBtu, or
lb/MWh, as applicable), for each hour in which valid values of HCl
or HF concentration and all other required parameters (stack gas
volumetric flow rate, diluent gas concentration, electrical load,
and moisture data, as applicable) are obtained for the hour. Round
off the emission rate to the same precision as the standard (i.e.,
with one leading non-zero digit and one decimal place, expressed in
scientific notation). Use the following rounding convention: If the
digit immediately following the first decimal place is 5 or greater,
round the first decimal place upward (increase it by one); if the
digit immediately following the first decimal place is 4 or less,
leave the first decimal place unchanged;
* * * * *
10.1.8.1.1 For each required 7-day and daily calibration drift
test or daily calibration error test (including daily calibration
transfer standard tests) of the HCl or HF CEMS, record the test
date(s) and time(s), reference gas value(s), monitor response(s),
and calculated calibration drift or calibration error value(s). If
you use the dynamic spiking option for the mid-level calibration
drift check under PS 18 of appendix B to part 60 of this chapter,
you must also record the measured concentration of the native HCl in
the flue gas before and after the spike and the spiked gas dilution
factor. When using an IP-CEMS under PS 18, you must also record the
measured concentrations of the native HCl before and after
introduction of each reference gas, the path lengths of the
calibration cell and the stack optical path, the stack and
calibration cell temperatures, the instrument line strength factor,
and the calculated equivalent concentration of reference gas.
10.1.8.1.2 For the required gas audits of an FTIR HCl or HF CEMS
that is following PS 15 of appendix B to part 60 of this chapter,
record the date and time of each spiked and unspiked sample, the
audit gas reference values and uncertainties. Keep records of all
calculations and data analyses required under sections 9.1 and 12.1
of Performance Specification (PS) 15, and the results of those
calculations and analyses.
10.1.8.1.3 For each required RATA of an HCl or HF CEMS, record
the beginning and ending date and time of each test run, the
reference method(s) used, and the reference method and HCl or HF
CEMS run values. Keep records of stratification tests performed (if
any), all of the raw field data, relevant process operating data,
and all of the calculations used to determine the relative accuracy.
10.1.8.1.4 For each required beam intensity test of an HCl IP-
CEMS under PS 18 of appendix B to part 60 of this chapter, record
the test date and time, the known attenuation value (%) used for the
test, the concentration of the high-level reference gas used, the
full-beam and attenuated beam intensity levels, the measured HCl
concentrations at full-beam intensity and attenuated intensity and
the percent difference between them, and the results of the test.
For each required daily beam intensity check of an IP-CEMS under
Procedure 6 of appendix F to part 60 of this chapter, record the
beam intensity measured including the units of measure and the
results of the check.
10.1.8.1.5 For each required measurement error test of an HCl
monitor, record the date and time of each gas injection, the
reference gas concentration (low, mid, or high) and the monitor
response for each of the three injections at each of the three
levels. Also record the average monitor response and the measurement
error (ME) at each gas level and the related calculations. For
measurement error tests conducted on IP-CEMS, also record the
measured concentrations of the native HCl before and after
introduction of each reference gas, the path lengths of the
calibration cell and the stack optical path, the stack and
calibration cell temperatures, the stack and calibration cell
pressures, the instrument line strength factor, and the calculated
equivalent concentration of reference gas.
10.1.8.1.6 For each required level of detection (LOD) test of an
HCl monitor performed in a controlled environment, record the test
date, the concentrations of the reference gas and interference
gases, the results of the seven (or more) consecutive measurements
of HCl, the standard deviation, and the LOD value. For each required
LOD test performed in the field, record the test date, the three
measurements of the native source HCl concentration, the results of
the three independent standard addition (SA) measurements known as
standard addition response (SAR), the effective spike addition gas
concentration (for IP-CEMS, the equivalent concentration of the
reference gas), the resulting standard addition detection level
(SADL) value and all related calculations. For extractive CEMS
performing the SA using dynamic spiking, you must record the spiked
gas dilution factor.
10.1.8.1.7 For each required measurement error/level of
detection response time test of an HCl monitor, record the test
date, the native HCl concentration of the flue gas, the reference
gas value, the stable reference gas readings, the upscale/downscale
start and end times, and the results of the upscale and downscale
stages of the test.
10.1.8.1.8 For each required temperature or pressure measurement
verification or audit of an IP-CEMS, keep records of the test date,
the temperatures or pressures (as applicable) measured by the
calibrated temperature or pressure reference device and the IP-CEMS,
and the results of the test.
10.1.8.1.9 For each required interference test of an HCl
monitor, record (or obtain from the analyzer manufacturer records
of): The date of the test; the gas volume/rate, temperature, and
pressure used to conduct the test; the HCl concentration of the
reference gas used; the concentrations of the interference test
gases; the baseline HCl and HCl responses for each interferent
combination spiked; and the total percent interference as a function
of span or HCl concentration.
10.1.8.1.10 For each quarterly relative accuracy audit (RAA) of
an HCl monitor, record the beginning and ending date and time of
each test run, the reference method used, the HCl concentrations
measured by the reference method and CEMS for each test run, the
average concentrations measured by the reference method and the
CEMS, and the calculated relative accuracy (RA). Keep records of the
raw field data, relevant process operating data, and the
calculations used to determine the RA.
10.1.8.1.11 For each quarterly cylinder gas audit (CGA) of an
HCl monitor, record the date and time of each injection, and the
reference gas concentration (zero, mid, or high) and the monitor
response for each injection. Also record the average monitor
response and the calculated measurement error (ME) at each gas
level. For IP-CEMS, you must also record the measured concentrations
of the native HCl before and after introduction of each reference
gas, the path lengths of the calibration cell and the stack optical
path, the stack and calibration cell temperatures, the stack and
calibration cell pressures, the instrument line strength factor, and
the calculated equivalent concentration of reference gas.
10.1.8.1.12 For each quarterly dynamic spiking audit (DSA) of an
HCl monitor, record the date and time of the zero gas injection and
each spike injection, the results of the zero gas injection, the gas
concentrations (mid and high) and the dilution factors and the
monitor response for each of the six upscale injections as well as
the corresponding native HCl concentrations measured before and
after each injection. Also record the average dynamic spiking error
for each of the upscale gases, the calculated average DSA Accuracy
at each upscale gas concentration, and all calculations leading to
the DSA Accuracy.
* * * * *
11. Reporting Requirements
* * * * *
11.3.1 For an EGU that begins reporting hourly HCl and/or HF
concentrations with a previously-certified CEMS, submit the
monitoring plan information in section 10.1.1.2 of this appendix
prior to or concurrent with the first required quarterly emissions
report. For a new EGU, or for an EGU switching to continuous
monitoring of HCl and/or HF emissions after having implemented
another allowable compliance option under this subpart, submit the
information in section 10.1.1.2 of this appendix at least 21 days
prior to the start
[[Page 20366]]
of initial certification testing of the CEMS. Also submit the
monitoring plan information in 40 CFR 75.53(g) pertaining to any
required flow rate, diluent gas, and moisture monitoring systems
within the applicable time frame specified in this section, if the
required records are not already in place.
* * * * *
11.4 Certification, Recertification, and Quality-Assurance Test
Reporting Requirements. Except for daily QA tests (i.e.,
calibrations and flow monitor interference checks), which are
included in each electronic quarterly emissions report, use the
ECMPS Client Tool to submit the results of all required
certification, recertification, quality-assurance, and diagnostic
tests of the monitoring systems required under this appendix
electronically. Submit the test results either prior to or
concurrent with the relevant quarterly electronic emissions report.
However, for RATAs of the HCl monitor, if this is not possible, you
have up to 60 days after the test completion date to submit the test
results; in this case, you may claim provisional status for the
emissions data affected by the test, starting from the date and hour
in which the test was completed and continuing until the date and
hour in which the test results are submitted. If the test is
successful, the status of the data in that time period changes from
provisional to quality-assured, and no further action is required.
However, if the test is unsuccessful, the provisional data must be
invalidated and resubmission of the affected emission report(s) is
required.
11.4.1 For each daily calibration drift (or calibration error)
assessment (including daily calibration transfer standard tests),
and for each 7-day calibration drift test of an HCl or HF monitor,
report:
11.4.1.1 Facility ID information;
11.4.1.2 The monitoring component ID;
11.4.1.3 The instrument span and span scale;
11.4.1.4 For each gas injection, the date and time, the
calibration gas level (zero, mid or other), the reference gas value
(ppm), and the monitor response (ppm);
11.4.1.5 A flag to indicate whether dynamic spiking was used for
the upscale value (extractive HCl monitors, only);
11.4.1.6 Calibration drift or calibration error (percent of span
or reference gas, as applicable);
11.4.1.7 When using the dynamic spiking option, the measured
concentration of native HCl before and after each mid-level spike
and the spiked gas dilution factor; and
11.4.1.8 When using an IP-CEMS, also report the measured
concentration of native HCl before and after each upscale
measurement, the path lengths of the calibration cell and the stack
optical path, the stack and calibration cell temperatures, the stack
and calibration cell pressures, the instrument line strength factor,
and the equivalent concentration of the reference gas; and
11.4.1.9 Reason for test (for the 7-day CD test, only).
11.4.2 For each quarterly gas audit of an HCl or HF CEMS that is
following PS 15 of appendix B to part 60 of this chapter, report:
* * * * *
11.4.3.11 Standard deviation, using either Equation 2-4 in
section 12.3 of Performance Specification 2 in appendix B to part 60
of this chapter or Equation 10 in section 12.6.5 of PS 18 of
appendix B to part 60 of this chapter;
11.4.3.12 Confidence coefficient, using either Equation 2-5 in
section 12.4 of Performance Specification 2 in appendix B to part 60
of this chapter or Equation 11 in section 12.6.6 of PS 18 of
appendix B to part 60 of this chapter;
11.4.3.13 t-value; and
11.4.3.14 Relative Accuracy (RA). For FTIR monitoring systems
following PS 15 of appendix B to part 60 of this chapter, calculate
the RA using Equation 2-6 of Performance Specification 2 in appendix
B to part 60 of this chapter or, if applicable, according to the
alternative procedure for low emitters described in section 3.1.2.2
of this appendix. For HCl CEMS following PS 18 of appendix B to part
60 of this chapter, calculate the RA according to section 12.6 of PS
18. If applicable use a flag to indicate that the alternative RA
specification for low emitters has been applied.
11.4.4 For each 3-level measurement error test of an HCl
monitor, report:
11.4.4.1 Facility ID information;
11.4.4.2 Monitoring component ID;
11.4.4.3 Instrument span and span scale;
11.4.4.4 For each gas injection, the date and time, the
calibration gas level (low, mid, or high), the reference gas value
in ppm and the monitor response. When using an IP-CEMS, also report
the measured concentration of native HCl before and after each
injection, the path lengths of the calibration cell and the stack
optical path, the stack and calibration cell temperatures, the stack
and calibration cell pressures, the instrument line strength factor,
and the equivalent concentration of the reference gas;
11.4.4.5 For extractive CEMS, the mean reference value and mean
of measured values at each reference gas level (ppm). For IP-CEMS,
the mean of the measured concentration minus the average measured
native concentration minus the equivalent reference gas
concentration (ppm), at each reference gas level--see Equation 6A in
PS 18 of appendix B to part 60 of this chapter;
11.4.4.6 Measurement error (ME) at each reference gas level; and
11.4.4.7 Reason for test.
11.4.5 Beam intensity tests of an IP CEMS:
11.4.5.1 For the initial beam intensity test described in
Performance Specification 18 in appendix B to part 60 of this
chapter, report:
11.4.5.1.1 Facility ID information;
11.4.5.1.2 Date and time of the test;
11.4.5.1.3 Monitoring system ID;
11.4.5.1.4 Reason for test;
11.4.5.1.5 Attenuation value (%);
11.4.5.1.6 High level gas concentration (ppm);
11.4.5.1.7 Full and attenuated beam intensity levels, including
units of measure;
11.4.5.1.8 Measured HCl concentrations at full and attenuated
beam intensity (ppm); and
11.4.5.1.9 Percentage difference between the HCl concentrations.
11.4.5.2 For the daily beam intensity check described in
Procedure 6 of appendix F to part 60 of this chapter, report:
11.4.5.2.1 Facility ID information;
11.4.5.2.2 Date and time of the test;
11.4.5.2.3 Monitoring system ID;
11.4.5.2.4 The attenuated beam intensity level (limit)
established in the initial test;
11.4.5.2.5 The beam intensity measured during the daily check;
and
11.4.5.2.6 Results of the test (pass or fail).
11.4.6 For each temperature or pressure verification or audit of
an HCl IP-CEMS, report:
11.4.6.1 Facility ID information;
11.4.6.2 Date and time of the test;
11.4.6.3 Monitoring system ID;
11.4.6.4 Type of verification (T or P);
11.4.6.5 Stack sensor measured value;
11.4.6.6 Reference device measured value;
11.4.6.7 Results of the test (pass or fail); and
11.4.6.8 Reason for test.
11.4.7 For each interference test of an HCl monitoring system,
report:
11.4.7.1 Facility ID information;
11.4.7.2 Date of test;
11.4.7.3 Monitoring system ID;
11.4.7.4 Results of the test (pass or fail);
11.4.7.5 Reason for test; and
11.4.7.6 A flag to indicate whether the test was performed: on
this particular monitoring system; on one of multiple systems of the
same type; or by the manufacturer on a system with components of the
same make and model(s) as this system.
11.4.8 For each level of detection (LOD) test of an HCl monitor,
report:
11.4.8.1 Facility ID information;
11.4.8.2 Date of test;
11.4.8.3 Reason for test;
11.4.8.4 Monitoring system ID;
11.4.8.5 A code to indicate whether the test was done in a
controlled environment or in the field;
11.4.8.6 HCl reference gas concentration;
11.4.8.7 HCl responses with interference gas (7 repetitions);
11.4.8.8 Standard deviation of HCl responses;
11.4.8.9 Effective spike addition gas concentrations;
11.4.8.10 HCl concentration measured without spike;
11.4.8.11 HCl concentration measured with spike;
11.4.8.12 Dilution factor for spike;
11.4.8.13 The controlled environment LOD value (ppm or ppm-
meters);
11.4.8.14 The field determined standard addition detection level
(SADL in ppm or ppm-meters); and
11.4.8.15 Result of LDO/SADL test (pass/fail).
11.4.9 For each ME or LOD response time test of an HCl monitor,
report:
11.4.9.1 Facility ID information;
11.4.9.2 Date of test;
11.4.9.3 Monitoring component ID;
11.4.9.4 The higher of the upscale or downscale tests, in
minutes; and
11.4.9.5 Reason for test.
11.4.10 For each quarterly relative accuracy audit of an HCl
monitor, report:
[[Page 20367]]
11.4.10.1 Facility ID information;
11.4.10.2 Monitoring system ID;
11.4.10.3 Begin and end time of each test run;
11.4.10.4 The reference method used;
11.4.10.5 The reference method (RM) and CEMS values for each
test run, including the units of measure;
11.4.10.6 The mean RM and CEMS values for the three test runs;
11.4.10.7 The calculated relative accuracy (RA), percent; and
11.4.10.8 Reason for test.
11.4.11 For each quarterly cylinder gas audit of an HCl monitor,
report:
11.4.11.1 Facility ID information;
11.4.11.2 Monitoring component ID;
11.4.11.3 Instrument span and span scale;
11.4.11.4 For each gas injection, the date and time, the
reference gas level (zero, mid, or high), the reference gas value in
ppm, and the monitor response. When using an IP-CEMS, also report
the measured concentration of native HCl before and after each
injection, the path lengths of the calibration cell and the stack
optical path, the stack and calibration cell temperatures, the stack
and calibration cell pressures, the instrument line strength factor,
and the equivalent concentration of the reference gas;
11.4.11.5 For extractive CEMS, the mean reference gas value and
mean monitor response at each reference gas level (ppm). For IP-
CEMS, the mean of the measured concentration minus the average
measured native concentration minus the equivalent reference gas
concentration (ppm), at each reference gas level--see Equation 6A in
PS 18 of appendix B to part 60 of this chapter;
11.4.11.6 Measurement error (ME) at each reference gas level;
and
11.4.11.7 Reason for test.
11.4.12 For each quarterly dynamic spiking audit of an HCl
monitor, report:
11.4.12.1 Facility ID information;
11.4.12.2 Monitoring component ID;
11.4.12.3 Instrument span and span scale;
11.4.12.4 For the zero gas injection, the date and time, and the
monitor response (Note: The zero gas injection from a calibration
drift check performed on the same day as the upscale spikes may be
used for this purpose.);
11.4.12.5 Zero spike error;
11.4.12.6 For the upscale gas spiking, the date and time of each
spike, the reference gas level (mid- or high-), the reference gas
value (ppm), the dilution factor, the native HCl concentrations
before and after each spike, and the monitor response for each gas
spike;
11.4.12.7 Upscale spike error;
11.4.12.8 Dynamic spike accuracy (DSA) at the zero level and at
each upscale gas level; and
11.4.12.9 Reason for test.
11.4.13 Reporting Requirements for Diluent Gas, Flow Rate, and
Moisture Monitoring Systems. For the certification, recertification,
diagnostic, and QA tests of stack gas flow rate, moisture, and
diluent gas monitoring systems that are certified and quality-
assured according to part 75 of this chapter, report the information
in section 10.1.8.2 of this appendix.
* * * * *
11.5.1 The owner or operator of any affected unit shall use the
ECMPS Client Tool to submit electronic quarterly reports to the
Administrator in an XML format specified by the Administrator, for
each affected unit (or group of units monitored at a common stack).
If the certified HCl or HF CEMS is used for the initial compliance
demonstration, HCl or HF emissions reporting shall begin with the
first operating hour of the 30 boiler operating day compliance
demonstration period. Otherwise, HCl or HF emissions reporting shall
begin with the first operating hour after successfully completing
all required certification tests of the CEMS.
* * * * *
0
17. Add appendix C to subpart UUUUU to read as follows:
Appendix C to Subpart UUUUU of Part 63--PM Monitoring Provisions
1. General Provisions
1.1 Applicability. These monitoring provisions apply to the
continuous measurement of filterable particulate matter (PM)
emissions from affected EGUs under this subpart. A particulate
matter continuous emission monitoring system (PM CEMS) is used
together with other continuous monitoring systems and (as
applicable) parametric measurement devices to quantify PM emissions
in units of the applicable standard (i.e., lb/MMBtu or lb/MWh).
1.2 Initial Certification and Recertification Procedures. You,
as the owner or operator of an affected EGU that uses a PM CEMS to
demonstrate compliance with a filterable PM emissions limit in Table
1 or 2 to this subpart must certify and, if applicable, recertify
the CEMS according to Performance Specification 11 (PS-11) in
appendix B to part 60 of this chapter.
1.3 Quality Assurance and Quality Control Requirements. You must
meet the applicable quality assurance requirements of Procedure 2 in
appendix F to part 60 of this chapter.
1.4 Missing Data Procedures. You must not substitute data for
missing data from the PM CEMS. Any process operating hour for which
quality-assured PM concentration data are not obtained is counted as
an hour of monitoring system downtime.
1.5 Adjustments for Flow System Bias. When the PM emission rate
is reported on a gross output basis, you must not adjust the data
recorded by a stack gas flow rate monitor for bias, which may
otherwise be required under 40 CFR 75.24.
2. Monitoring of PM Emissions
2.1 Monitoring System Installation Requirements. Flue gases from
the affected EGUs under this subpart vent to the atmosphere through
a variety of exhaust configurations including single stacks, common
stack configurations, and multiple stack configurations. For each of
these configurations, Sec. 63.10010(a) specifies the appropriate
location(s) at which to install continuous monitoring systems (CMS).
These CMS installation provisions apply to the PM CEMS and to the
other continuous monitoring systems and parametric monitoring
devices that provide data for the PM emissions calculations in
section 6 of this appendix.
2.2 Primary and Backup Monitoring Systems. In the electronic
monitoring plan described in section 7 of this appendix, you must
create and designate a primary monitoring system for PM and for each
additional parameter (i.e., stack gas flow rate, CO2 or
O2 concentration, stack gas moisture content, as
applicable). The primary system must be used to report hourly PM
concentration values when the system is able to provide quality-
assured data, i.e., when the system is ``in control.'' However, to
increase data availability in the event of a primary monitoring
system outage, you may install, operate, maintain, and calibrate a
redundant backup monitoring system. A redundant backup system is one
that is permanently installed at the unit or stack location and is
kept on ``hot standby'' in case the primary monitoring system is
unable to provide quality-assured data. You must represent each
redundant backup system as a unique monitoring system in the
electronic monitoring plan. You must certify each redundant backup
monitoring system according to the applicable provisions in section
4 of this appendix. In addition, each redundant monitoring system
must meet the applicable on-going QA requirements in section 5 of
this appendix.
3. PM Emissions Measurement Methods
The following definitions, equipment specifications, procedures,
and performance criteria are applicable
3.1 Definitions. All definitions specified in section 3 of PS-11
in appendix B to part 60 of this chapter and section 3 of Procedure
2 in appendix F to part 60 of this chapter are applicable to the
measurement of filterable PM emissions from electric utility steam
generating units under this subpart. In addition, the following
definitions apply:
3.1.1 Stack operating hour means a clock hour during which flue
gases flow through a particular stack or duct (either for the entire
hour or for part of the hour) while the associated unit(s) are
combusting fuel.
3.1.2 Unit operating hour means a clock hour during which a unit
combusts any fuel, either for part of the hour or for the entire
hour.
3.2 Continuous Monitoring Methods.
3.2.1 Installation and Measurement Location. You must install
the PM CEMS according to Sec. 63.10010 and Section 2.4 of PS-11 in
appendix B to part 60 of this chapter.
3.2.2 Units of Measure. For the purposes of this subpart, you
shall report hourly PM concentrations in units of measure that
correspond to your PM CEMS correlation curve (e.g., mg/acm, mg/acm
@160 [deg]C, mg/wscm, mg/dscm).
3.2.3 Other Necessary Data Collection. To convert hourly PM
concentrations to the units of the applicable emissions standard
(i.e., lb/MMBtu or lb/MWh), you must collect additional data as
described in sections 3.2.3.1 and 3.2.3.2 of this appendix. You must
install, certify, operate, maintain, and quality-assure any stack
gas flow rate, CO2, O2, or moisture monitoring
systems needed for this purpose according to sections 4 and 5 of
this appendix. The calculation methods for the emission limits
described in sections
[[Page 20368]]
3.2.3.1 and 3.2.3.2 of this appendix are presented in section 6 of
this appendix.
3.2.3.1 Heat Input-Based Emission Limits. To demonstrate
compliance with a heat input-based PM emission limit in Table 2 to
this subpart, you must provide the hourly stack gas CO2
or O2 concentration, along with a fuel-specific
Fc factor or dry-basis F-factor and (if applicable) the
stack gas moisture content, in order to convert measured PM
concentrations values to the units of the standard.
3.2.3.2 Gross Output-Based Emission Limits. To demonstrate
compliance with a gross output-based PM emission limit in Table 1 or
2 to this subpart, you must provide the hourly gross output in
megawatts, along with data from a certified stack gas flow rate
monitor and (if applicable) the stack gas moisture content, in order
to convert measured PM concentrations values to units of the
standard.
4. Certification and Recertification Requirements
4.1 Certification Requirements. You must certify your PM CEMS
and the other continuous monitoring systems used to determine
compliance with the applicable emissions standard before the PM CEMS
can be used to provide data under this subpart. Redundant backup
monitoring systems (if used) are subject to the same certification
requirements as the primary systems.
4.1.1 PM CEMS. You must certify your PM CEMS according to PS-11
in appendix B to part 60 of this chapter. A PM CEMS that has been
installed and certified according to PS-11 as a result of another
state or Federal regulatory requirement or consent decree prior to
[EFFECTIVE DATE OF THE FINAL RULE] shall be considered certified for
this subpart if you can demonstrate that your PM CEMS meets the PS-
11 acceptance criteria based on the applicable emission standard in
this subpart.
4.1.2 Flow Rate, Diluent Gas, and Moisture Monitoring Systems.
You must certify the continuous monitoring systems that are needed
to convert PM concentrations to units of the standard or (if
applicable) to convert the measured PM concentrations from wet basis
to dry basis or vice-versa (i.e., stack gas flow rate, diluent gas
(CO2 or O2) concentration, or moisture
monitoring systems), in accordance with the applicable provisions in
40 CFR 75.20 and appendix A to part 75 of this chapter.
4.1.3 Other Parametric Measurement Devices. Any temperature or
pressure measurement devices that are used to convert hourly PM
concentrations to standard conditions must be installed, calibrated,
maintained, and operated according to the manufacturers'
instructions.
4.2 Recertification.
4.2.1 You must recertify your PM CEMS if it is either: Moved to
a different stack or duct; moved to a new location within the same
stack or duct; modified or repaired in such a way that the existing
correlation is altered or impacted; or replaced.
4.2.2 The flow rate, diluent gas, and moisture monitoring
systems that are used to convert PM concentration to units of the
emission standard are subject to the recertification provisions in
40 CFR 75.20(b).
4.3 Development of a New or Revised Correlation Curve. You must
develop a new or revised correlation curve if:
4.3.1 A response correlation audit (RCA) is failed and the new
or revised correlation is developed according to section 10.6 in
Procedure 2 of appendix F to part 60 of this chapter; or
4.3.2 The events described in paragraph (1) or (2) in section
8.8 of PS-11 in appendix B to part 60 of this chapter occur.
5. Ongoing Quality Assurance (QA) and Data Validation
5.1 PM CEMS.
5.1.1 Required QA Tests. Following initial certification, you
must conduct periodic QA testing of each primary and (if applicable)
redundant backup PM CEMS. The required QA tests and the performance
specifications that must be met are found in Procedure 2 of appendix
F to part 60 of this chapter (Procedure 2). Except as otherwise
provided in section 5.1.2 of this appendix, the QA tests shall be
done at the frequency specified in Procedure 2.
5.1.2 RRA and RCA Test Frequencies.
5.1.2.1 The test frequency for RRAs of the PM CEMS shall be
annual, i.e., once every four calendar quarters. The RRA must either
be performed within the fourth calendar quarter after the calendar
quarter in which the previous RRA was completed or in a grace period
(see section 5.1.3 of this appendix). When a required annual RRA is
done within a grace period, the deadline for the next RRA is four
calendar quarters after the quarter in which the RRA was originally
due, rather than the calendar quarter in which the grace period test
is completed.
5.1.2.2 The test frequency for RCAs of the PM CEMS shall be
triennial, i.e., once every twelve calendar quarters. If a required
RCA is not completed within twelve calendar quarters after the
calendar quarter in which the previous RCA was completed, it must be
performed in a grace period immediately following the twelfth
calendar quarter (see section 5.1.3 of this appendix). When an RCA
is done in a grace period, the deadline for the next RCA shall be
twelve calendar quarters after the calendar quarter in which the RCA
was originally due, rather than the calendar quarter in which the
grace period test is completed.
5.1.2.3 Successive quarterly audits (i.e., ACAs and, if
applicable, sample volume audits (SVAs)) shall be conducted at least
60 days apart.
5.1.3 Grace Period. A grace period is available, immediately
following the end of the calendar quarter in which an RRA or RCA of
the PM CEMS is due. The length of the grace period shall be the
lesser of 720 EGU (or stack) operating hours or one calendar
quarter.
5.1.4 RCA and RRA Acceptability. The results of your RRA or RCA
are considered acceptable provided that the criteria in section
10.4(5) of Procedure 2 in appendix F to part 60 of this chapter are
met for an RCA or section 10.4(6) of Procedure 2 in appendix F to
part 60 of this chapter are met for an RRA.
5.1.5 Data Validation. Your PM CEMS is considered to be out-of-
control, and you may not report data from it as quality-assured,
when, for a required certification, recertification, or QA test, the
applicable acceptance criterion (either in PS-11 in appendix B to
part 60 of this chapter or Procedure 2 in appendix F to part 60 of
this chapter) is not met. Further, data from your PM CEMS are
considered out-of-control, and may not be used for reporting, when a
required QA test is not performed on schedule or within an allotted
grace period. When an out-of-control period occurs, you must perform
the appropriate follow-up actions. For an out-of-control period
triggered by a failed QA test, you must perform and pass the same
type of test in order to end the out-of-control period. For a QA
test that is not performed on time, data from the PM CEMS remain
out-of-control until the required test has been performed and
passed. You must count all out-of-control data periods of the PM
CEMS as hours of monitoring system downtime.
5.2 Stack Gas Flow Rate, Diluent Gas, and Moisture Monitoring
Systems. The on-going QA test requirements and data validation
criteria for the primary and (if applicable) redundant backup stack
gas flow rate, diluent gas, and moisture monitoring systems are
specified in appendix B to part 75 of this chapter.
5.3 QA/QC Program Requirements. You must develop and implement a
quality assurance/quality control (QA/QC) program for the PM CEMS
and the other equipment that is used to provide data under this
subpart. You may store your QA/QC plan electronically, provided that
the information can be made available expeditiously in hard copy to
auditors and inspectors.
5.3.1 General Requirements.
5.3.1.1 Preventive Maintenance. You must keep a written record
of the procedures needed to maintain the PM CEMS and other equipment
that is used to provide data under this subpart in proper operating
condition, along with a schedule for those procedures. At a minimum,
you must include all procedures specified by the manufacturers of
the equipment and, if applicable, additional or alternate procedures
developed for the equipment.
5.3.1.2 Recordkeeping Requirements. You must keep a written
record describing procedures that will be used to implement the
recordkeeping and reporting requirements of this appendix.
5.3.1.3 Maintenance Records. You must keep a record of all
testing, maintenance, or repair activities performed on the PM CEMS,
and other equipment used to provide data under this subpart in a
location and format suitable for inspection. You may use a
maintenance log for this purpose. You must maintain the following
records for each system or device: The date, time, and description
of any testing, adjustment, repair, replacement, or preventive
maintenance action performed, and records of any corrective actions
taken. Additionally, you must record any adjustment that may affect
the ability of a monitoring system or measurement device to make
accurate measurements, and you must keep a written explanation of
the procedures used to make the adjustment(s).
5.3.2 Specific Requirements for the PM CEMS.
[[Page 20369]]
5.3.2.1 Daily, and Quarterly QA Assessments. You must keep a
written record of the procedures used for daily assessments of the
PM CEMS. You must also keep records of the procedures used to
perform quarterly ACA and (if applicable) SVA audits. You must
document how the test results are calculated and evaluated.
5.3.2.2 Monitoring System Adjustments. You must document how
each component of the PM CEMS will be adjusted to provide correct
responses after routine maintenance, repairs, or corrective actions.
5.3.2.3 Correlation Tests, Annual and Triennial Audits. You must
keep a written record of procedures used for the correlation
test(s), annual RRAs, and triennial RCAs of the PM CEMS. You must
document how the test results are calculated and evaluated.
5.3.3 Specific Requirements for Diluent Gas, Stack Gas Flow
Rate, and Moisture Monitoring Systems. The QA/QC program
requirements for the stack gas flow rate, diluent gas, and moisture
monitoring systems described in section 3.2.3 of this appendix are
specified in section 1 of appendix B to part 75 of this chapter.
5.3.4 Requirements for Other Monitoring Equipment. For the
equipment required to convert readings from the PM CEMS to standard
conditions (e.g., devices to measure temperature and pressure), you
must keep a written record of the calibrations and/or other
procedures used to ensure that the devices provide accurate data.
5.3.5 You may store your QA/QC plan electronically, provided
that you can make the information available expeditiously in hard
copy to auditors or inspectors.
6. Data Reduction and Calculations
6.1 Data Reduction and Validation.
6.1.1 You must reduce the data from PM CEMS to hourly averages,
in accordance with 40 CFR 60.13(h)(2).
6.1.2 You must reduce all CEMS data from stack gas flow rate,
CO2, O2, and moisture monitoring systems to
hourly averages according to 40 CFR 75.10(d)(1).
6.1.3 You must reduce all other data from devices used to
convert readings from the PM CEMS to standard conditions to hourly
averages according to 40 CFR 60.13(h)(2) or 75.10(d)(1). This
includes, but is not limited to, data from devices used to measure
temperature and pressure, or, for cogeneration units that calculate
gross output based on steam characteristics, devices to measure
steam flow rate, steam pressure, and steam temperature.
6.1.4 Do not calculate the PM emission rate for any unit or
stack operating hour in which valid data are not obtained for PM
concentration or for any parameter used in the PM emission rate
calculations (i.e., gross output, stack gas flow rate, stack
temperature, stack pressure, stack gas moisture content, or diluent
gas concentration, as applicable).
6.1.5 For the purposes of this appendix, part 75 substitute data
values for stack gas flow rate, CO2 concentration,
O2 concentration, and moisture content are not considered
to be valid data.
6.1.6 Operating hours in which PM concentration is missing or
invalid are hours of monitoring system downtime. The use of
substitute data for PM concentration is not allowed.
6.1.7 You must exclude all data obtained during a boiler startup
or shutdown operating hour (as defined in Sec. 63.10042) from the
determination of the 30-boiler operating day rolling average PM
emission rates.
6.2 Calculation of PM Emission Rates. Unless your PM CEMS is
correlated to provide PM concentrations at standard conditions, you
must use the calculation methods in sections 6.2.1 through 6.2.3 of
this appendix to convert measured PM concentration values to units
of the emission limit (lb/MMBtu or lb/MWh, as applicable).
6.2.1 p.m. concentrations must be at standard conditions in
order to convert them to units of the emissions limit. If your PM
CEMS measures PM concentrations at standard conditions, proceed to
section 6.2.2 or 6.2.3 of this appendix (as applicable). However, if
your PM CEMS measures PM concentrations in units of mg/acm or mg/acm
at a specified temperature (e.g., 160 [deg]C), you must first use
one of the following equations to convert the hourly PM
concentration values from actual to standard conditions:
[GRAPHIC] [TIFF OMITTED] TP10AP20.003
Where:
Cstd = PM concentration at standard conditions.
Ca = PM concentration at measurement conditions.
Ts = Stack Temperature ([deg]F).
TCEMS = CEMS Measurement Temperature ([deg]F).
PCEMS = CEMS Measurement Pressure (in. Hg).
Ps = Stack Pressure (in. Hg).
Tstd = Standard Temperature (68 [deg]F).
Pstd = Standard Pressure (29.92 in. Hg).
6.2.2 Heat Input-Based PM Emission Rates (Existing EGUs, Only).
Calculate the hourly heat input-based PM emission rates (if
applicable), in units of lb/MMBtu, according to sections 6.2.2.1 and
6.2.2.2 of this appendix.
6.2.2.1 You must select an appropriate emission rate equation
from among Equations 19-1 through 19-9 in test Method 19 in appendix
A-7 to part 60 of this chapter to convert the hourly PM
concentration values from section 6.2.1 of this appendix to units of
lb/MMBtu. Note that the EPA test Method 19 equations require the
pollutant concentration to be expressed in units of lb/scf;
therefore, you must first multiply the PM concentration by 6.24 x
10-8 to convert it from mg/scm to lb/scf.
6.2.2.2 You must use the appropriate carbon-based or dry-basis
F-factor in the emission rate equation that you have selected. You
may either use an F-factor from Table 19-2 of EPA test Method 19 in
appendix A-7 to part 60 of this chapter or from section 3.3.5 or
3.3.6 of appendix F to part 75 of this chapter.
6.2.2.3 If the hourly average O2 concentration is
above 14.0% O2 (19.0% for an IGCC) or the hourly average
CO2 concentration is below 5.0% CO2 (1.0% for
an IGCC), you may calculate the PM emission rate using the
applicable diluent cap value (as defined in Sec. 63.10042 and
specified in Sec. 63.10007(f)(1)), provided that the diluent gas
monitor is operating and recording quality-assured data).
6.2.2.4 If your selected EPA test Method 19 equation requires a
correction for the stack gas moisture content, you may either use
quality-assured hourly data from a certified part 75 moisture
monitoring system, a fuel-specific default moisture value from 40
CFR 75.11(b), or a site-specific default moisture value approved by
the Administrator under 40 CFR 75.66.
6.2.3 Gross Output-Based PM Emission Rates. For each unit or
stack operating hour, if Cstd is measured on a wet basis,
you must use Equation C-3 of this section to calculate the gross
output-based PM emission rate (if applicable). Use Equation C-4 of
this section if Cstd is measured on a dry basis:
[[Page 20370]]
[GRAPHIC] [TIFF OMITTED] TP10AP20.004
Where:
Eheo = Hourly gross output-based PM emission rate (lb/
MWh).
Cstd = PM concentration from section 6.2.1 (mg/scm), wet
basis.
Qs = Unadjusted stack gas volumetric flow rate (scfh, wet
basis).
MW = Gross output (megawatts).
6.24 x 10-8 = Conversion factor.
[GRAPHIC] [TIFF OMITTED] TP10AP20.005
Where:
Eheo = Hourly gross output-based PM emission rate (lb/
MWh).
Cstd = PM concentration from section 6.2.1 (mg/scm), dry
basis.
Qs = Unadjusted stack gas volumetric flow rate (scfh, wet
basis).
MW = Gross output (megawatts).
Bws = Proportion by volume of water vapor in the stack
gas.
6.24 x 10-8 = Conversion factor.
6.2.4 You must calculate the 30-boiler operating day rolling average
PM emission rates according to Sec. 63.10021(b).
7. Recordkeeping and Reporting
7.1 Recordkeeping Provisions. For the PM CEMS and the other
necessary continuous monitoring systems (CMS) and parameter
measurement devices installed at each affected unit or common stack,
you must maintain a file of all measurements, data, reports, and
other information required by this appendix in a form suitable for
inspection, for 5 years from the date of each record, in accordance
with Sec. 63.10033. The file shall contain the applicable
information in sections 7.1.1 through 7.1.11 of this appendix.
7.1.1 Monitoring Plan Records. For each EGU or group of EGUs
monitored at a common stack, you must prepare and maintain a
monitoring plan for the PM CEMS and the other CMS(s) needed to
convert PM concentrations to units of the applicable emission
standard.
7.1.1.1 Updates. If you make a replacement, modification, or
change in a certified CEMS that is used to provide data under this
appendix (including a change in the automated data acquisition and
handling system) or if you make a change to the flue gas handling
system and that replacement, modification, or change affects
information reported in the monitoring plan (e.g., a change to a
serial number for a component of a monitoring system), you shall
update the monitoring plan.
7.1.1.2 Contents of the Monitoring Plan. For the PM CEMS, your
monitoring plan shall contain the applicable information in sections
7.1.1.2.1 and 7.1.1.2.2 of this appendix. For required stack gas
flow rate, diluent gas, and moisture monitoring systems, your
monitoring plan shall include the applicable information required
for those systems under 40 CFR 75.53(g) and (h).
7.1.1.2.1 Electronic. Your electronic monitoring plan records
must include the following information: Unit or stack ID number(s);
unit information (type of unit, maximum rated heat input, fuel
type(s), emission controls); monitoring location(s); the monitoring
methodologies used; monitoring system information, including (as
applicable): Unique system and component ID numbers; the make,
model, and serial number of the monitoring equipment; the sample
acquisition method; formulas used to calculate emissions; operating
range and load information; monitor span and range information;
units of measure of your PM concentrations (see section 3.2.2 of
this appendix); and appropriate default values. Your electronic
monitoring plan shall be evaluated and submitted using the Emissions
Collection and Monitoring Plan System (ECMPS) Client Tool provided
by the Clean Air Markets Division (CAMD) in EPA's Office of
Atmospheric Programs.
7.1.1.2.2 Hard Copy. You must keep records of the following
items: Schematics and/or blueprints showing the location of the PM
monitoring system(s) and test ports; data flow diagrams; test
protocols; and miscellaneous technical justifications. The hard copy
portion of the monitoring plan must also explain how the PM
concentrations are measured and how they are converted to the units
of the applicable emissions limit. The equation(s) used for the
conversions must be documented. Electronic storage of the hard copy
portion of the monitoring plan is permitted.
7.1.2 Operating Parameter Records. You must record the following
information for each operating hour of each EGU and also for each
group of EGUs utilizing a monitored common stack, to the extent that
these data are needed to convert PM concentration data to the units
of the emission standard. For non-operating hours, you must record
only the items in sections 7.1.2.1 and 7.1.2.2 of this appendix. If
you elect to or are required to comply with a gross output-based PM
standard, for any hour in which there is gross output greater than
zero, you must record the items in sections 7.1.2.1 through 7.1.2.3
and (if applicable) 7.1.2.5 of this appendix; however, if there is
heat input to the unit(s) but no gross output (e.g., at unit
startup), you must record the items in sections 7.1.2.1, 7.1.2.2,
and, if applicable, section 7.1.2.5 of this appendix. If you elect
to comply with a heat input-based PM standard, you must record only
the items in sections 7.1.2.1, 7.1.2.2, 7.1.2.4, and, if applicable,
section 7.1.2.5 of this appendix.
7.1.2.1 The date and hour;
7.1.2.2 The unit or stack operating time (rounded up to the
nearest fraction of an hour (in equal increments that can range from
one hundredth to one quarter of an hour, at your option);
7.1.2.3 The hourly gross output (rounded to nearest MWe);
7.1.2.4 If applicable, the Fc factor or dry-basis F-
factor used to calculate the heat input-based PM emission rate; and
7.1.2.5 If applicable, a flag to indicate that the hour is an
exempt startup or shutdown hour.
7.1.3 PM Concentration Records. For each affected unit or common
stack using a PM CEMS, you must record the following information for
each unit or stack operating hour:
7.1.3.1 The date and hour;
7.1.3.2 Monitoring system and component identification codes for
the PM CEMS, as provided in the electronic monitoring plan, if your
CEMS provides a quality-assured value of PM concentration for the
hour;
7.1.3.3 The hourly PM concentration, in units of measure that
correspond to your PM CEMS correlation curve, for each operating
hour in which a quality-assured value is obtained. Record all PM
concentrations with one leading non-zero digit and one decimal
place, expressed in scientific notation. Use the following rounding
convention: if the digit immediately following the first decimal
place is 5 or greater, round the first decimal place upward
(increase it by one); if the digit immediately following the first
decimal place is 4 or less, leave the first decimal place unchanged.
7.1.3.4 A special code, indicating whether or not a quality-
assured PM concentration is obtained for the hour; and
7.1.3.5 Monitor data availability for PM concentration, as a
percentage of unit or stack operating hours calculated in the manner
established for SO2, CO2, O2 or
moisture monitoring systems according to 40 CFR 75.32.
7.1.4 Stack Gas Volumetric Flow Rate Records.
[[Page 20371]]
7.1.4.1 When a gross output-based PM emissions limit must be
met, in units of lb/MWh, you must obtain hourly measurements of
stack gas volumetric flow rate during EGU operation, in order to
convert PM concentrations to units of the standard.
7.1.4.2 When hourly measurements of stack gas flow rate are
needed, you must keep hourly records of the flow rates and related
information, as specified in 40 CFR 75.57(c)(2).
7.1.5 Records of Diluent Gas (CO2 or O2)
Concentration.
7.1.5.1 When a heat input-based PM emission limit must be met,
in units of lb/MMBtu, you must obtain hourly measurements of
CO2 or O2 concentration during EGU operation,
in order to convert PM concentrations to units of the standard.
7.1.5.2 When hourly measurements of diluent gas concentration
are needed, you must keep hourly CO2 or O2
concentration records, as specified in 40 CFR 75.57(g).
7.1.6 Records of Stack Gas Moisture Content.
7.1.6.1 When corrections for stack gas moisture content are
needed to demonstrate compliance with the applicable PM emissions
limit:
7.1.6.1.1 If you use a continuous moisture monitoring system,
you must keep hourly records of the stack gas moisture content and
related information, as specified in 40 CFR 75.57(c)(3).
7.1.6.1.2 If you use a fuel-specific default moisture value, you
must represent it in the electronic monitoring plan required under
section 7.1.1.2.1 of this appendix.
7.1.7 PM Emission Rate Records. For applicable PM emission
limits in units of lb/MMBtu or lb/MWh, you must record the following
information for each affected EGU or common stack:
7.1.7.1 The date and hour;
7.1.7.2 The hourly PM emissions rate (lb/MMBtu or lb/MWh, as
applicable), calculated according to section 6.2.2 or 6.2.3 of this
appendix, rounded to the same precision as the standard (i.e., with
one leading non-zero digit and one decimal place, expressed in
scientific notation), expressed in scientific notation. Use the
following rounding convention: if the digit immediately following
the first decimal place is 5 or greater, round the first decimal
place upward (increase it by one); if the digit immediately
following the first decimal place is 4 or less, leave the first
decimal place unchanged. You must calculate the PM emission rate
only when valid values of PM concentration and all other required
parameters required to convert PM concentration to the units of the
standard are obtained for the hour;
7.1.7.3 An identification code for the formula used to derive
the hourly PM emission rate from measurements of the PM
concentration and other necessary parameters (i.e., Equation C-3 or
C-4 in section 6.2.3 of this appendix or the applicable EPA test
Method 19 equation);
7.1.7.4 If applicable, indicate that the diluent cap has been
used to calculate the PM emission rate; and
7.1.7.5 If applicable, indicate that the default electrical load
(as defined in Sec. 63.10042) has been used to calculate the hourly
PM emission rate.
7.1.7.6 Indicate that the PM emission rate was not calculated
for the hour, if valid data are not obtained for PM concentration
and/or any of the other parameters in the PM emission rate equation.
For the purposes of this appendix, substitute data values for stack
gas flow rate, CO2 concentration, O2
concentration, and moisture content reported under part 75 of this
chapter are not considered to be valid data. However, when the gross
output (as defined in Sec. 63.10042) is reported for an operating
hour with zero output, the default electrical load value is treated
as quality-assured data.
7.1.8 Other Parametric Data. If your PM CEMS measures PM
concentrations at actual conditions, you must keep records of the
temperatures and pressures used in Equation C-1 or C-2 in section
6.2.1 of this appendix to convert the measured hourly PM
concentrations to standard conditions.
7.1.9 Certification, Recertification, and Quality Assurance Test
Records. For any PM CEMS used to provide data under this subpart,
you must record the following certification, recertification, and
quality-assurance information:
7.1.9.1 The test dates and times, reference values, monitor
responses, monitor full scale value, and calculated results for the
required 7-day drift tests and for the required daily zero and
upscale calibration drift tests;
7.1.9.2 The test dates and times and results (pass or fail) of
all daily system optics checks and daily sample volume checks of the
PM CEMS (as applicable);
7.1.9.3 The test dates and times, reference values, monitor
responses, and calculated results for all required quarterly ACAs;
7.1.9.4 The test dates and times, reference values, monitor
responses, and calculated results for all required quarterly SVAs of
extractive PM CEMS;
7.1.9.5 The test dates and times, reference method readings and
corresponding PM CEMS responses (including the units of measure),
and the calculated results for all PM CEMS correlation tests, RRAs
and RCAs. For the correlation tests, you must indicate which model
is used (i.e., linear, logarithmic, exponential, polynomial, or
power) and record the correlation equation. For the RRAs and RCAs,
the reference method readings and PM CEMS responses must be reported
in the same units of measure as the PM CEMS correlation;
7.1.9.6 The cycle time and sample delay time for PM CEMS that
operate in batch sampling mode; and
7.1.9.7 Supporting information for all required PM CEMS
correlation tests, RRAs, and RCAs, including records of all raw
reference method and monitoring system data, the results of sample
analyses to substantiate the reported test results, as well as
records of sampling equipment calibrations, reference monitor
calibrations, and analytical equipment calibrations.
7.1.10 For stack gas flow rate, diluent gas, and moisture
monitoring systems, you must keep records of all certification,
recertification, diagnostic, and on-going quality-assurance tests of
these systems, as specified in 40 CFR 75.59(a).
7.1.11 For each temperature measurement device (e.g., RTD or
thermocouple) and pressure measurement device used to convert
measured PM concentrations to standard conditions according to
Equation C-1 or C-2 in section 6.2.1 of this appendix, you must keep
records of all calibrations and other checks performed to ensure
that accurate data are obtained.
7.2 Reporting Requirements.
7.2.1 General Reporting Provisions. You must comply with the
following requirements for reporting PM emissions from each affected
EGU (or group of EGUs monitored at a common stack) under this
subpart:
7.2.1.1 Notifications, in accordance with section 7.2.2 of this
appendix;
7.2.1.2 Monitoring plan reporting, in accordance with section
7.2.3 of this appendix;
7.2.1.3 Certification, recertification, and QA test submittals,
in accordance with section 7.2.4 of this appendix; and
7.2.1.4 Electronic quarterly emissions report submittals, in
accordance with section 7.2.5 of this appendix.
7.2.2 Notifications. You must provide notifications for each
affected unit (or group of units monitored at a common stack) under
this subpart in accordance with Sec. 63.10030.
7.2.3 Monitoring Plan Reporting. For each affected unit (or
group of units monitored at a common stack) under this subpart using
PM CEMS to measure PM emissions, you must make electronic and hard
copy monitoring plan submittals as follows:
7.2.3.1 For an EGU that begins reporting hourly PM
concentrations on January 1, 2024 with a previously-certified PM
CEMS, submit the monitoring plan information in section 7.1.1.2 of
this appendix prior to or concurrent with the first required
quarterly emissions report. For a new EGU, or for an EGU switching
to continuous monitoring of PM emissions after having implemented
another allowable compliance option under this subpart, submit the
information in section 7.1.1.2 of this appendix at least 21 days
prior to the start of initial certification testing of the PM CEMS.
Also submit the monitoring plan information in 40 CFR 75.53(g)
pertaining to any required flow rate, diluent gas, and moisture
monitoring systems within the applicable time frame specified in
this section, if the required records are not already in place.
7.2.3.2 Whenever an update of the monitoring plan is required,
as provided in section 7.1.1.1 of this appendix, you must submit the
updated information either prior to or concurrent with the relevant
quarterly electronic emissions report.
7.2.3.3 All electronic monitoring plan submittals and updates
shall be made to the Administrator using the ECMPS Client Tool. Hard
copy portions of the monitoring plan shall be submitted to the
appropriate delegated authority.
7.2.4 Certification, Recertification, and Quality-Assurance Test
Reporting. Except for daily QA tests of the required monitoring
systems (i.e., calibration error or drift tests, sample volume
checks, system optics checks, and flow monitor interference checks),
you must submit the results of all required certification,
recertification, and quality-assurance tests described in sections
7.1.9.1
[[Page 20372]]
through 7.1.9.6 and 7.1.10 of this appendix electronically (except
for test results previously submitted, e.g., under the Acid Rain
Program), using the ECMPS Client Tool. Submit the results of the QA
test (i.e., RCA or RRA) or, if applicable, a new PM CEMS correlation
test, either prior to or concurrent with the relevant quarterly
electronic emissions report. If this is not possible, you have up to
60 days after the test completion date to submit the test results;
in this case, you may claim provisional status for the emissions
data affected by the QA test or correlation, starting from the date
and hour in which the test was completed and continuing until the
date and hour in which the test results are submitted. For an RRA or
RCA, if the applicable audit specifications are met, the status of
the emissions data in the relevant time period changes from
provisional to quality-assured, and no further action is required.
For a successful correlation test, apply the correlation equation
retrospectively to the raw data to change the provisional status of
the data to quality-assured, and resubmit the affected emissions
report(s). However, if the applicable performance specifications are
not met, the provisional data must be invalidated, and resubmission
of the affected quarterly emission report(s) is required. For a
failed RRA or RCA, you must take corrective actions and proceed
according to the applicable requirements found in sections 10.5
through 10.7 of Procedure 2 in appendix F to part 60 of this chapter
until a successful QA test report is submitted. If a correlation
test is unsuccessful, you may not report quality-assured data from
the PM CEMS until the results of a subsequent correlation test show
that the specifications in section 13.0 of PS-11 in appendix B to
part 60 of this chapter are met.
7.2.5 Quarterly Reports.
7.2.5.1 For each affected EGU (or group of EGUs monitored at a
common stack), the owner or operator must use the ECMPS Client Tool
to submit electronic quarterly emissions reports to the
Administrator, in an XML format specified by the Administrator,
starting with a report for the later of:
7.2.5.1.1 The first calendar quarter of 2024; or
7.2.5.1.2 The calendar quarter in which the initial PM CEMS
correlation test is completed.
7.2.5.2 You must submit the electronic reports within 30 days
following the end of each calendar quarter, except for EGUs that
have been placed in long-term cold storage (as defined in 40 CFR
72.2).
7.2.5.3 Each of your electronic quarterly reports shall include
the following information:
7.2.5.3.1 The date of report generation;
7.2.5.3.2 Facility identification information;
7.2.5.3.3 The information in sections 7.1.2 through 7.1.7 of
this appendix that is applicable to your PM emission measurement
methodology; and
7.2.5.3.4 The results of all daily QA assessments, i.e.,
calibration drift checks and (if applicable) sample volume checks of
the PM CEMS, calibration error tests of the other continuous
monitoring systems that are used to convert PM concentration to
units of the standard, and (if applicable) flow monitor interference
checks.
7.2.5.4 Compliance Certification. Based on a reasonable inquiry
of those persons with primary responsibility for ensuring that all
PM emissions from the affected unit(s) under this subpart have been
correctly and fully monitored, the owner or operator must submit a
compliance certification in support of each electronic quarterly
emissions monitoring report. The compliance certification shall
include a statement by a responsible official with that official's
name, title, and signature, certifying that, to the best of his or
her knowledge, the report is true, accurate, and complete.
0
18. Add appendix D to subpart UUUUU to read as follows:
Appendix D to Subpart UUUUU of Part 63--PM CPMS Monitoring Provisions
1. General Provisions
1.1 Applicability. These monitoring provisions apply to the
continuous monitoring of the output from a particulate matter
continuous parametric monitoring system (PM CPMS), for the purpose
of assessing continuous compliance with an applicable emissions
limit in Table 1 or 2 to this subpart.
1.2 Summary of the Method. The output from an instrument capable
of continuously measuring PM concentration is continuously recorded,
either in milliamps, PM concentration, or other units of measure. An
operating limit for the PM CPMS is established initially, based on
data recorded by the monitoring system during a performance stack
test. The performance test is repeated annually and the operating
limit is reassessed. In-between successive performance tests, the
output from the PM CPMS serves as an indicator of continuous
compliance with the applicable emissions limit.
2. Continuous Monitoring of the PM CPMS Output
2.1 System Design and Performance Criteria. The PM CPMS must
meet the design and performance criteria specified in Sec. Sec.
63.10010(h)(1)(i) through (iii) and 63.10023(b)(2)(iii) and (iv). In
addition, an automated data acquisition and handling system (DAHS)
is required to record the output from the PM CPMS and to generate
the quarterly electronic data reports required under section 3.2.4
of this appendix.
2.2 Installation Requirements. Install the PM CPMS at an
appropriate location in the stack or duct, in accordance with Sec.
63.10010(a).
2.3 Determination of Operating Limits.
2.3.1 In accordance with Sec. Sec. 63.10007(a)(3), 63.10011(b),
and 63.10023(a) and Table 6 to this subpart, you must determine an
initial site-specific operating limit for your PM CPMS, using data
recorded by the monitoring system during a performance stack test
that demonstrates compliance with one of the following emissions
limits in Table 1 or 2 to this subpart: Filterable PM; total non-Hg
HAP metals; total HAP metals including Hg (liquid oil-fired units,
only); individual non-Hg HAP metals; or individual HAP metals
including Hg (liquid oil-fired units, only).
2.3.2 In accordance with Sec. 63.10005(d)(2)(i), you must
perform the initial stack test no later than the applicable date in
Sec. 63.9984(f), and according to Sec. Sec. 63.10005(d)(2)(iii)
and 63.10006(a), the performance test must be repeated annually to
document compliance with the emissions limit and to reassess the
operating limit.
2.3.3 Calculate the operating limits according to Sec.
63.10023(b)(1) for existing units, and Sec. 63.10023(b)(2) for new
units.
2.4 Data Reduction and Compliance Assessment.
2.4.1 Reduce the output from the PM CPMS to hourly averages, in
accordance with Sec. 63.8(g)(2) and (5).
2.4.2 To determine continuous compliance with the operating
limit, you must calculate 30-boiler operating day rolling average
values of the output from the PM CPMS, in accordance with Sec. Sec.
63.10010(h)(3) through (6) and 63.10021(c) and Table 7 to this
subpart.
2.4.3 In accordance with Sec. Sec. 63.10005(d)(2)(ii) and
63.10022(a)(2) and Table 4 to this subpart, the 30-boiler operating
day rolling average PM CPMS output must be maintained at or below
the operating limit. However, if exceedances of the operating limit
should occur, you must follow the applicable procedures in Sec.
63.10021(c)(1) and (2).
3. Recordkeeping and Reporting
3.1 Recordkeeping Provisions. You must keep the applicable
records required under Sec. 63.10032(b) and (c) for your PM CPMS.
In addition, you must maintain a file of all measurements, data,
reports, and other information required by this appendix in a form
suitable for inspection, for 5 years from the date of each record,
in accordance with Sec. 63.10033.
3.1.1 Monitoring Plan Records.
3.1.1.1 You must develop and maintain a site-specific monitoring
plan for your PM CPMS, in accordance with Sec. 63.10000(d).
3.1.1.2 In addition to the site-specific monitoring plan
required under Sec. 63.10000(d), you must use the ECMPS Client Tool
to prepare and maintain an electronic monitoring plan for your PM
CPMS.
3.1.1.2.1 Contents of the Electronic Monitoring Plan. The
electronic monitoring plan records must include the unit or stack ID
number(s), monitoring location(s), the monitoring methodology used
(i.e., PM CPMS), the current operating limit of the PM CPMS
(including the units of measure), unique system and component ID
numbers, the make, model, and serial number of the PM CPMS, the
analytical principle of the monitoring system, and monitor span and
range information.
3.1.1.2.2 Electronic Monitoring Plan Updates. If you replace or
make a change to a PM CPMS that is used to provide data under this
subpart (including a change in the automated data acquisition and
handling system) and the replacement or change affects information
reported in the electronic monitoring plan (e.g., changes to the
make, model and serial number when a PM CPMS
[[Page 20373]]
is replaced), you must update the monitoring plan.
3.1.2 Operating Parameter Records. You must record the following
information for each operating hour of each affected unit and for
each group of units utilizing a common stack. For non-operating
hours, record only the items in sections 3.1.2.1 and 3.1.2.2 of this
appendix.
3.1.2.1 The date and hour;
3.1.2.2 The unit or stack operating time (rounded up to the
nearest fraction of an hour (in equal increments that can range from
one hundredth to one quarter of an hour, at the option of the owner
or operator); and
3.1.2.3 If applicable, a flag to indicate that the hour is an
exempt startup or shutdown hour.
3.1.3 PM CPMS Output Records. For each affected unit or common
stack using a PM CPMS, you must record the following information for
each unit or stack operating hour:
3.1.3.1 The date and hour;
3.1.3.2 Monitoring system and component identification codes for
the PM CPMS, as provided in the electronic monitoring plan, for each
operating hour in which the monitoring system is not out-of-control
and a valid value of the output parameter is obtained;
3.1.3.3 The hourly average output from the PM CPMS, for each
operating hour in which the monitoring system is not out-of-control
and a valid value of the output parameter is obtained, either in
milliamps, PM concentration, or other units of measure, as
applicable;
3.1.3.4 A special code for each operating hour in which the PM
CPMS is out-of-control and a valid value of the output parameter is
not obtained; and
3.1.3.5 Percent monitor data availability (PMA) for the PM CPMS,
calculated in the manner established for SO2,
CO2, O2 or moisture monitoring systems
according to Sec. 75.32 of this chapter.
3.1.4 Records of PM CPMS Audits and Out-of-Control Periods. In
accordance with Sec. 63.10010(h)(7), you must record, and make
available upon request, the results of PM CPMS performance audits,
as well as the dates of PM CPMS out-of-control periods and the
corrective actions taken to return the system to normal operation.
3.2 Reporting Requirements.
3.2.1 General Reporting Provisions. You must comply with the
following requirements for reporting PM CPMS data from each affected
EGU (or group of EGUs monitored at a common stack) under this
subpart:
3.2.1.1 Notifications, in accordance with section 3.2.2 of this
appendix;
3.2.1.2 Monitoring plan reporting, in accordance with section
3.2.3 of this appendix;
3.2.1.3 Report submittals, in accordance with sections 3.2.4 and
3.2.5 of this appendix.
3.2.2 Notifications. You must provide notifications for the
affected unit (or group of units monitored at a common stack) in
accordance with Sec. 63.10030.
3.2.3 Monitoring Plan Reporting. For each affected unit (or
group of units monitored at a common stack) under this subpart using
a PM CPMS you must make monitoring plan submittals as follows:
3.2.3.1 For units using the PM CPMS compliance option prior to
January 1, 2024, submit the electronic monitoring plan information
in section 3.1.1.2.1 of this appendix prior to or concurrent with
the first required electronic quarterly report. For units switching
to the PM CPMS methodology on or after January 1, 2024, submit the
electronic monitoring plan no later than 21 days prior to the date
on which the PM test is performed to establish the initial operating
limit.
3.2.3.2 Whenever an update of the electronic monitoring plan is
required, as provided in section 3.1.1.2.2 of this appendix, the
updated information must be submitted either prior to or concurrent
with the relevant quarterly electronic emissions report.
3.2.3.3 All electronic monitoring plan submittals and updates
shall be made to the Administrator using the ECMPS Client Tool.
3.2.3.4 In accordance with Sec. 63.10000(d), you must submit
the site-specific monitoring plan described in section 3.1.1.1 of
this appendix to the Administrator, if requested.
3.2.4 Electronic Quarterly Reports.
3.2.4.1 For each affected EGU (or group of EGUs monitored at a
common stack) that is subject to the provisions of this appendix,
reporting of hourly responses from the PM CPMS will begin either
with the first operating hour in the third quarter of 2023 or the
first operating hour after completion of the initial stack test that
establishes the operating limit, whichever is later. The owner or
operator must then use the ECMPS Client Tool to submit electronic
quarterly reports to the Administrator, in an XML format specified
by the Administrator, starting with a report for the later of:
3.2.4.1.1 The first calendar quarter of 2024; or
3.2.4.1.2 The calendar quarter in which the initial operating
limit for the PM CPMS is established.
3.2.4.2 The electronic quarterly reports must be submitted
within 30 days following the end of each calendar quarter, except
for units that have been placed in long-term cold storage (as
defined in Sec. 72.2 of this chapter).
3.2.4.3 Each electronic quarterly report shall include the
following information:
3.2.4.3.1 The date of report generation;
3.2.4.3.2 Facility identification information; and
3.2.4.3.3 The information in sections 3.1.2 and 3.1.3 of this
appendix.
3.2.4.4 Compliance Certification. Based on a reasonable inquiry
of those persons with primary responsibility for ensuring that the
output from the PM CPMS has been correctly and fully monitored, the
owner or operator shall submit a compliance certification in support
of each electronic quarterly report. The compliance certification
shall include a statement by a responsible official with that
official's name, title, and signature, certifying that, to the best
of his or her knowledge, the report is true, accurate, and complete.
3.2.5 Performance Stack Test Results. You must use the ECMPS
Client Tool to report the results of all performance stack tests
conducted to document compliance with the applicable emissions limit
in Table 1 or 2 to this subpart, as follows:
3.2.5.1 Report a summary of each test electronically, in XML
format, in the relevant quarterly compliance report under Sec.
63.10031(g); and
3.2.5.2 Provide a complete stack test report as a PDF file, in
accordance with Sec. 63.10031(f) or (h), as applicable.
0
19. Add appendix E to subpart UUUUU to read as follows:
Appendix E to Subpart UUUUU of Part 63--Data Elements
1.0 You must record the electronic data elements in this
appendix that apply to your compliance strategy under this subpart.
The applicable data elements in sections 2 through 13 of this
appendix must be reported in the quarterly compliance reports
required under Sec. 63.10031(g), in an XML format prescribed by the
Administrator, starting with a report that covers the first quarter
of 2024. For stack tests used to demonstrate compliance, RATAs, PM
CEMS correlations, RRAs and RCAs that are completed on and after
January 1, 2024, the applicable data elements in sections 17 through
30 of this appendix must be reported in an XML format prescribed by
the Administrator, and the information in section 31 of this
appendix must be reported in as one or more PDF files.
2.0 MATS Compliance Report Root Data Elements. You must record
the following data elements and include them in each quarterly
compliance report:
2.1 ORIS Code;
2.2 Facility Name;
2.3 Facility Registry Identifier;
2.4 Title 40 Part;
2.5 Applicable Subpart;
2.6 Calendar Year;
2.7 Calendar Quarter; and
2.8 Submission Comment (Optional).
3.0 Performance Stack Test Summary. If you elect to demonstrate
compliance using periodic performance stack testing (including 30-
boiler operating day Hg LEE tests), record the following data
elements for each test:
3.1 Parameter;
3.2 Test Location ID;
3.3 Test Number;
3.4 Test Begin Date, Hour, and Minute;
3.5 Test End Date, Hour, and Minute;
3.6 Timing of Test (either performed on-schedule according to
Sec. 63.10006(f), or was late);
3.7 Averaging Plan Indicator;
3.8 Averaging Group ID (if applicable);
3.9 EPA Test Method Code;
3.10 Emission Limit, Including Units of Measure;
3.11 Average Pollutant Emission Rate;
3.12 LEE Indicator;
3.13 LEE Basis (if applicable); and
3.14 Submission Comment (Optional).
4.0 Operating limit Data (PM CPMS, only):
4.1 Parameter Type;
4.2 Operating Limit; and
4.3 Units of Measure.
5.0 Performance Test Run Data. For each run of the performance
stack test, record the following data elements:
5.1 Run Number;
[[Page 20374]]
5.2 Run Begin Date, Hour, and Minute;
5.3 Run End Date, Hour, and Minute;
5.4 Pollutant Concentration and units of measure;
5.5 Emission Rate;
5.6 EPA test Method 19 Equation (if applicable);
5.7 Total Sampling Time; and
5.8 Total Sample Volume.
6.0 Conversion Parameters. For the parameters that are used to
convert the pollutant concentration to units of the emission
standard (including, as applicable, CO2 or O2
concentration, stack gas flow rate, stack gas moisture content, F-
factors, and gross output), record:
6.1 Parameter Type;
6.2 Parameter Source; and
6.3 Parameter Value, including Units of Measure.
7.0 QA Parameters: For key parameters that are used to quality-
assure the reference method data (including, as applicable, filter
temperature, % isokinetic, leak check results, % breakthrough, %
spike recovery, and relative deviation), record:
7.1 Parameter Type;
7.2 Parameter Value; and
7.3 Pass/Fail Status.
8.0 Averaging Group Configuration. If a particular EGU or common
stack is included in an averaging plan, record the following data
elements:
8.1 Parameter Being Averaged;
8.2 Averaging Group ID; and
8.3 Unit or Common Stack ID.
9.0 Compliance Averages. If you elect to (or are required to)
demonstrate compliance using continuous monitoring system(s) on a
30-boiler operating day rolling average basis (or on a 30- or 90-
group boiler operating day rolling weighted average emission rate
(WAER) basis, if your monitored EGU or common stack is in an
averaging plan), you must record the following data elements for
each average emission rate (or, for units in an averaging plan, for
each weighted average emission rate (WAER)):
9.1 Unit or Common Stack ID;
9.2 Averaging Group ID (if applicable);
9.3 Parameter Being Averaged;
9.4 Date;
9.5 Average Type;
9.6 Units of Measure; and
9.7 Average Value.
9.8 Comment Field.
10.0 Unit Information. You must record the following data
elements for each EGU:
10.1 Unit ID;
10.2 Date of Last Tune-up; and
10.3 Emergency Bypass Information. If your coal-fired EGU, solid
oil-derived fuel-fired EGU, or IGCC is equipped with a main stack
and a bypass stack (or bypass duct) configuration, and has qualified
to use the LEE compliance option, you must report the following
emergency bypass information annually, in the compliance report for
the fourth calendar quarter of the year:
10.3.1 The number of emergency bypass hours for the year, as a
percentage of the EGU's annual operating hours;
10.3.2 A description of each emergency bypass event during the
year, including the cause and corrective actions taken;
10.3.3 An explanation of how clean fuels were burned to the
maximum extent possible during each emergency bypass event;
10.3.4 An estimate of the emissions released during each
emergency bypass event. You must also show whether LEE status has
been retained or lost, based on the emissions estimate and the
results of the previous LEE retest; and
10.3.5 If there were no emergency bypass events during the year,
a statement to that effect.
11.0 Fuel Usage Information. Record the following monthly fuel
usage information:
11.1 Calendar Month;
11.2 Each Type of Fuel Used During the Calendar Month in the
Quarter;
11.3 Quantity of Each Type of Fuel Combusted in Each Calendar
Month in the Quarter, with Units of Measure;
11.3 New Fuel Type Indicator (if applicable); and
11.4 Date of Performance Test Using the New Fuel (if
applicable).
12.0 Malfunction Information (if applicable): If there was a
malfunction of the process equipment or control equipment during the
reporting period that caused (or may have caused) an exceedance of
an emissions or operating limit, record:
12.1 Event Begin Date and Hour (if known);
12.2 Event End Date and Hour;
12.3 Malfunction Description; and
12.4 Corrective Action.
13.0 Deviations. If there were any deviations during the
reporting period, record:
13.1 Unit, Common Stack, or Averaging Group ID;
13.2 The nature of the deviation, as either:
13.2.1 Emission limit exceeded;
13.2.2 Operating limit exceeded;
13.2.3 Work practice standard not met;
13.2.4 Testing requirement not met;
13.2.5 Monitoring requirement not met; or
13.2.6 Other requirement not met.
13.3 A description of the deviation, as follows:
13.3.1 For a performance stack test or a 30- (or 90-) boiler
operating day rolling average that exceeds an emissions or operating
limit, record the parameter (e.g., HCl, Hg, PM), the limit that was
exceeded, and either the date of the non-complying performance test
or the beginning and ending dates of the non-complying rolling
average;
13.3.2 If an unmonitored bypass stack was used during the
reporting period, record the total number of hours of bypass stack
usage;
13.3.3 For failure to collect required monitoring data during
the reporting period, record the monitored parameter, the total
source operating time (hours), and the total number of hours of
monitor downtime for:
13.3.3.1 Monitoring system malfunctions;
13.3.3.2 Out-of-control periods;
13.3.3.3 Non-monitoring equipment malfunctions;
13.3.3.4 QA/QC activities (e.g., calibrations, performance
audits)
13.3.3.5 Routine maintenance
13.3.3.6 Other known causes; and
13.3.3.7 Unknown causes.
13.3.4 If a performance stack test was due within the quarter
but was not done, record the parameter (e.g., HCl, PM), the test
deadline, and a statement that the test was not done as required;
13.3.5 For a late performance stack test conducted during the
quarter, record the parameter, the test deadline, and the number of
days that elapsed between the test deadline and the test completion
date.
13.4 Record any corrective actions taken in response to the
deviation.
13.5 If there were no deviations during the quarter, record a
statement to that effect.
14.0 Reference Method Data Elements. For each of the following
tests that is completed on and after January 1, 2024, you must
record and report the applicable electronic data elements in
sections 17 through 29 of this appendix, pertaining to the reference
method(s) used for the test (see section 16 of this appendix).
14.1 Each quarterly, annual, or triennial stack test used to
demonstrate compliance (including 30- (or 90-) boiler operating day
Hg LEE tests and PM tests used to set operating limits for PM CPMS);
14.2 Each relative accuracy test audit (RATA) of your Hg, HCl,
HF, or SO2 CEMS or each RATA of your Hg sorbent trap
monitoring system; and
14.3 Each correlation test, relative response audit (RRA) and
each response correlation audit (RCA) of your PM CEMS.
15.0 You must report the applicable data elements for each test
described in section 14 of this appendix in an XML format prescribed
by the Administrator.
15.1 For each stack test completed during a particular calendar
quarter and contained in the quarterly compliance report, you must
submit along with the quarterly compliance report, the data elements
in sections 17 and 18 of this appendix (which are common to all
tests) and the applicable data elements in sections 19 through 31 of
this appendix associated with the reference method(s) used.
15.2 For each RATA, PM CEMS correlation, RRA, or RCA, when you
use the ECMPS Client Tool to report the test results as required
under appendix A, B, or C to this subpart or, for SO2
RATAs under part 75 of this chapter, you must submit along with the
test results, the data elements in sections 17 and 18 of this
appendix and, for each test run, the data elements in sections 19
through 30 of this appendix that are associated with the reference
method(s) used.
15.3 For each stack test, RATA, PM CEMS correlation, RRA, and
RCA, you must also provide the information described in section 31
of this appendix as a PDF file, either along with the quarterly
compliance report (for stack tests) or together with the test
results reported under appendix A, B, or C to this subpart or part
75 of this chapter (for RATAs, RRAs, RCAs, or PM CEMS correlations).
16.0 Applicable Reference Methods. One or more of the following
EPA reference methods is needed for the tests described in sections
14.1 through 14.3 of this appendix: Method 1, Method 2, Method 3A,
Method 4, Method 5, Method 5D, Method 6C, Method 26, Method 26A,
Method 29, and/or Method
[[Page 20375]]
30B in appendices A-1 through A-4 and A-8 of part 60 of this
chapter.
16.1 Application of EPA test Methods 1 and 2 in appendices A-1
of part 60 of this chapter. If you use periodic stack testing to
comply with an output-based emissions limit, you must determine the
stack gas flow rate during each performance test run in which EPA
test Method 5, 5D, 26, 26A, 29, or 30B in appendices A-3 and A-8 of
part 60 of this chapter is used, in order to convert the measured
pollutant concentration to units of the standard. For EPA test
Methods 5, 5D, 26A and 29, which require isokinetic sampling, the
delta-P readings made with the pitot tube and manometer at the
Method 1 traverse points, taken together with measurements of stack
gas temperature, pressure, diluent gas concentration (from a
separate EPA test Method 3A or 3B test) and moisture, provide the
necessary data for the EPA test Method 2 flow rate calculations.
Note that even if you elect to comply with a heat input-based
standard, when EPA test Method 5, 5D, 26A, or 29 is used, you must
still use EPA test Method 2 to determine the average stack gas
velocity (vs), which is needed for the percent isokinetic
calculation. The EPA test Methods 26 and 30B do not require
isokinetic sampling; therefore, when either of these methods is
used, if the stack gas flow rate is needed to comply with the
applicable output-based emissions limit, you must make a separate
EPA test Method 2 determination during each test run.
16.2 Application of EPA test Method 3A in appendix A-2 of part
60 of this chapter. If you elect to perform periodic stack testing
to comply with a heat input-based emissions limit, a separate
measurement of the diluent gas (CO2 or O2)
concentration is required for each test run in which EPA test Method
5, 5D, 26, 26A, 29, or 30B in appendices A-3 and A-8 of part 60 of
this chapter is used, in order to convert the measured pollutant
concentration to units of the standard. The EPA test Method 3A is
the preferred CO2 or O2 test method, although
EPA test Method 3B may be used instead. Diluent gas measurements are
also needed for stack gas molecular weight determinations when using
EPA test Method 2 in appendix A-1 of part 60 of this chapter.
16.3 Application of EPA test Method 4 in appendix A-3 of part 60
of this chapter. For performance stack tests, depending on which
equation is used to convert pollutant concentration to units of the
standard, measurement of the stack gas moisture content, using EPA
test Method 4, may also be required for each test run. The EPA test
Method 4 moisture data are also needed for the EPA test Method 2 in
appendix A-1 of part 60 of this chapter calculations (to determine
the molecular weight of the gas) and for the RATA of an Hg CEMS that
measures on a wet basis, when RM 30B is used. Other applications
that require EPA test Method 4 moisture determinations include:
RATAs of an SO2 monitor, when the reference method and
CEMS data are measured on a different moisture basis (wet or dry);
conversion of wet-basis pollutant concentrations to the units of a
heat input-based emissions limit when certain equations in EPA test
Method 19 in appendix A-7 of part 60 of this chapter are used (e.g.,
Eq. 19-3, 19-4, or 19-8); and stack gas molecular weight
determinations. When EPA test Method 5, 5D, 26A, or 29 in appendices
A-3 and A-8 of part 60 of this chapter is used for the performance
test, the EPA test Method 4 moisture determination may be made by
using the water collected in the impingers together with data from
the dry gas meter; alternatively, a separate EPA test Method 4
determination may be made. However, when EPA test Method 26 or 30B
in appendix A-8 of part 60 of this chapter is used, EPA test Method
4 must be performed separately.
16.4 Applications of EPA test Methods 5 and 5D in appendix A-3
of part 60 of this chapter. The EPA test Method 5 (or, if applicable
5D) must be used for the following applications: to demonstrate
compliance with a filterable PM emissions limit; for PM tests used
to set operating limits for PM CPMS; and for the initial
correlations, RRAs and RCAs of a PM CEMS.
16.5 Applications of EPA test Method 6C in appendix A-4 of part
60 of this chapter. If you elect to monitor SO2 emissions
from your coal-fired EGU as a surrogate for HCl, the SO2
CEMS must be installed, certified, operated, and maintained
according to 40 CFR part 75. Part 75 allows the use of EPA test
Methods 6, 6A, 6B, and 6C in appendix A-4 of part 60 of this chapter
for the required RATAs of the SO2 monitor. However, in
practice, only instrumental EPA test Method 6C is used.
16.6 Applications of EPA test Methods 26 and 26A in appendix A-8
of pat 60 of this chapter. The EPA test Method 26A may be used for
quarterly HCl or HF stack testing, or for the RATA of an HCl or HF
CEMS. The EPA test Method 26 may be used for quarterly HCl or HF
stack testing; however, for the RATAs of an HCl monitor that is
following Performance Specification 18 and Procedure 6 in appendices
B and F to part 60 of this chapter, EPA test Method 26 may only be
used if approved upon request.
16.7 Applications of EPA test Method 29 in appendix A-8 of part
60 of this chapter. The EPA test Method 29 may be used for periodic
performance stack tests to determine compliance with individual or
total HAP metals emissions limits. For coal-fired EGUs, the total
HAP emissions limits exclude Hg.
16.8 Applications of EPA test Method 30B in appendix A-8 of part
60 of this chapter. The EPA test Method 30B is used for 30- (or 90-)
boiler operating day Hg LEE tests and RATAs of Hg CEMS and sorbent
trap monitoring systems, and it may be used for quarterly Hg stack
testing (oil-fired EGUs, only).
17.0 Facility and Test Company Information. In accordance with
Sec. 63.7(e)(3), a test is defined as three or more runs of one or
more EPA Reference Method(s) conducted to measure the amount of a
specific regulated pollutant, pollutants, or surrogates being
emitted from a particular EGU (or group of EGUs that share a common
stack), and to satisfy requirements of this subpart. On or after
January 1, 2024, you must report the data elements in sections 17
and 18, each time that you complete a required performance stack
test, RATA, PM CEMS correlation, RRA, or RCA at the affected EGU(s),
using EPA test Method 5, 5B, 5D, 6C, 26, 26A, 29, or 30B in
appendices A-3 and A-8 of part 60 of this chapter. You must also
report the applicable data elements in sections 19 through 25 of
this appendix for each test. If any separate, corresponding EPA test
Method 2, 3A, or 4 in appendices A-1 through A-3 of part 60 of this
chapter test is conducted to in order to convert a pollutant
concentration to the units of the applicable emission standard given
in Table 1 or 2 to this subpart or to convert pollutant
concentration from wet to dry basis (or vice-versa), you must also
report the applicable data elements in sections 26 through 31 of
this appendix.
The applicable data elements in sections 17 through 31 of this
appendix must be submitted separately, in XML format, along with the
quarterly Compliance Report (for stack tests) or along with the
electronic test results submitted to the ECMPS Client Tool (for CMS
performance evaluations). The Electronic Reporting Tool (ERT) or an
equivalent schema can be utilized to create this XML file. Note:
Ideally, for all of the tests completed at a given facility in a
particular calendar quarter, the applicable data elements in
sections 17 through 31 of this appendix should be submitted together
in one XML file. However, as shown in Table 8 to this subpart, the
timelines for submitting stack test results and CMS performance
evaluations are not identical. Therefore, for calendar quarters in
which both types of tests are completed, it may not be possible to
submit the applicable data elements for all of those tests in a
single XML file; separate submittals may be necessary to meet the
applicable reporting deadlines.
17.1 Part;
17.2 Subpart;
17.3 ORIS Code;
17.4 Facility Name;
17.5 Facility Address;
17.6 Facility City;
17.7 Facility County;
17.8 Facility State;
17.9 Facility Zip Code;
17.10 Facility Point of Contact;
17.11 Facility Contact Phone Number;
17.12 Facility Contact Email;
17.13 EPA Facility Registration System (FRS) Number;
17.14 Source Classification Code (SCC);
17.15 State Facility ID;
17.16 Project Number;
17.17 Name of Test Company;
17.18 Test Company Address;
17.19 Test Company City;
17.20 Test Company State;
17.21 Test Company Zip Code;
17.22 Test Company Point of Contact;
17.23 Test Company Contact Phone Number;
17.24 Test Company Contact Email; and
17.25 Test Comment (Optional).
18.0 Source Information Data Elements. You must report the
following data elements, as applicable, for each source for which at
least one test is included in the XML file:
18.1 Source ID (Sampling Location);
18.2 Stack (Duct) Diameter (Circular Stack) (in.);
18.3 Equivalent Diameter (Rectangular Duct or Stack) (in.);
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18.4 Area of Stack;
18.5 Control Device Code; and
18.6 Control Device Description.
19.0 Run-Level and Lab Data Elements for EPA test Methods 5, 5B,
5D, 26A, and 29 of Appendices A-3 and A-8 of Part 60 of this
Chapter. You must report the appropriate Source ID (i.e., Data
Element 18.1) and the following data elements, as applicable, for
each run of each performance stack test, PM CEMS correlation test,
RATA, RRA, or RCA conducted using isokinetic EPA test Method 5, 5B,
5D, or 26A. If your EGU is oil-fired and you use EPA test Method 26A
to conduct stack tests for both HCl and HF, you must report these
data elements separately for each pollutant. When you use EPA test
Method 29 to measure the individual HAP metals, total filterable
HAPs metals and total HAP metals, report only the run-level data
elements (sections 19.1, 19.3 through 19.30, and 19.38 through 19.41
of this appendix), and the point-level and lab data elements in
sections 20 and 21 of this appendix:
19.1 Test Number;
19.2 Pollutant Name;
19.3 EPA Test Method;
19.4 Run Number;
19.5 Corresponding Reference Method(s), if applicable;
19.6 Corresponding Reference Method(s) Run Number, if
applicable;
19.7 Number of Traverse Points;
19.8 Run Begin Date;
19.9 Run Start Time (Clock Time Start);
19.10 Run End Date;
19.11 Run End Time (Clock Time End);
19.12 Barometric Pressure;
19.13 Static Pressure;
19.14 Cumulative Elapsed Sampling Time;
19.15 Percent O2;
19.16 Percent CO2;
19.17 Pitot Tube ID;
19.18 Pitot Tube Calibration Coefficient;
19.19 Nozzle Calibration Diameter;
19.20 F-Factor (Fd, Fw, or Fc);
19.21 Calibration Coefficient of Dry Gas Meter (Y);
19.22 Total Volume of Liquid Collected in Impingers and Silica
Gel;
19.23 Percent Moisture--Actual;
19.24 Dry Molecular Weight of Stack Gas;
19.25 Wet Molecular Weight of Stack Gas;
19.26 Initial Reading of Dry Gas Meter Volume (dcf);
19.27 Final Reading of Dry Gas Meter Volume (dcf);
19.28 Stack Gas Velocity--fps;
19.29 Stack Gas Flow Rate--dscfm;
19.30 Type of Fuel;
19.31 Pollutant Mass Collected (value);
19.32 Pollutant Mass Unit of Measure;
19.33 Detection Limit Flag;
19.34 Pollutant Concentration;
19.35 Pollutant Concentration Unit of Measure;
19.36 Pollutant Emission Rate;
19.37 Pollutant Emission Rate Units of Measure (in Units of the
Standard);
19.38 Compliance Limit Basis (Heat Input or Electrical Output);
19.39 Heat Input or Electrical Output Unit of Measure;
19.40 Process Parameter (value);
19.41 Process Parameter Unit of Measure;
19.42 Converted Concentration for PM CEMS only; and
19.43 Converted Concentration Units (Units of Correlation for PM
CEMS).
20.0 Point-Level Data Elements for EPA test Methods 5, 5B, 5D,
26A, & 29 in Appendices A-3 and A-8 of Part 60 of this Chapter. To
link the point-level data with the run data in the xml schema, you
must report the Source ID (i.e., Data Element 18.1), EPA Test Method
(Data Element 19.3), Run Number (Data Element 19.4), and Run Begin
Date (Data Element 19.8) with the following point-level data
elements for each run of each performance stack test, PM CEMS
correlation test, RATA, RRA, or RCA conducted using isokinetic EPA
test Method 5, 5B, 5D, 26A, or 29. Note that these data elements are
required for all EPA test Method 29 applications, whether the method
is being used to measure the total or individual HAP metals
concentrations:
20.1 Traverse Point ID;
20.2 Stack Temperature;
20.3 Differential Pressure Reading ([Delta]P);
20.4 Orifice Pressure Reading ([Delta]H);
20.5 Dry Gas Meter Inlet Temperature;
20.6 Dry Gas Meter Outlet Temperature; and
20.7 Filter Temperature.
21.0 Laboratory Results for EPA test Method 29 in Appendix A-8
of Part 60 of this Chapter--Total or Individual Multiple HAP Metals.
If you use EPA test Method 29 and elect to comply with the total or
individual HAP metals standards, you must report run-level data
elements 19.1 through 19.34 in section 19 of this appendix, and the
point-level data elements in section 20 of this appendix. To link
the laboratory data with the run data in the xml schema, you must
report the Source ID (i.e., Data Element 18.1), EPA Test Method
(Data Element 19.3), Run Number (Data Element 19.4), and Run Begin
Date (Data Element 19.8) with the results of the laboratory
analyses. Regardless of whether you elect to comply with the total
HAP metals standard or the individual HAP metals standard, you must
report the front half catch, the back half catch and the sum of the
front and back half catches collected with EPA test Method 29 for
each individual HAP metal and for the total HAP metals. The list of
individual HAP metals is Antimony, Arsenic, Beryllium, Cadmium
Chromium, Cobalt, Lead, Manganese, Nickel, Selenium and Mercury (if
applicable). You must also calculate and report the pollutant
emission rates(s) in relation to the standard(s) with which you have
elected to comply and the units specified in Table 5 to this subpart
as follows:
21.1 Each Individual HAP metal total mass collected:
21.1.1 Pollutant Name;
21.1.2 Pollutant Mass Collected;
21.1.3 Pollutant Mass Units of Measure; and
21.1.4 Detection Limit Flag.
21.2 Each Individual HAP metal Front Half:
21.2.1 Pollutant Name;
21.2.2 Pollutant Mass Collected;
21.2.3 Pollutant Mass Units of Measure; and
21.2.4 Detection Limit Flag.
21.3 Each Individual HAP metal Back Half:
21.3.1 Pollutant Name;
21.3.2 Pollutant Mass Collected;
21.3.3 Pollutant Mass Units of Measure; and
21.3.4 Detection Limit Flag.
21.4 Each Individual HAP metal concentration:
21.4.1 Pollutant Name;
21.4.2 Pollutant Concentration; and
21.4.3 Pollutant Concentration Units of Measure.
21.5 Each Individual HAP metal emission rate in units of the
standard:
21.5.1 Pollutant Name
21.5.2 Pollutant Emission Rate and
21.5.3 Pollutant Emission Rate Units of Measure.
21.6 Each Individual HAP metal emission rate in units of lbs/
MMBTU or lbs/MW (per Table 5 to this subpart):
21.6.1 Pollutant Name;
21.6.2 Pollutant Emission Rate; and
21.6.3 Pollutant Emission Rate Units of Measure.
21.7 Total Filterable HAPs metals mass collected:
21.7.1 Pollutant Name;
21.7.2 Pollutant Mass Collected;
21.7.3 Pollutant Mass Units of Measure; and
21.7.4 Detection Limit Flag.
21.8 Total Filterable HAPs metals concentration:
21.8.1 Pollutant Name;
21.8.2 Pollutant Concentration; and
21.8.3 Pollutant Concentration Units of Measure.
21.9 Total Filterable HAPs metals in units of lbs/MMBtu or lbs/
MW (per Table 5 to this subpart):
21.9.1 Pollutant Name;
21.9.2 Pollutant Emission Rate; and
21.9.3 Pollutant Emission Rate Units of Measure.
21.10 Total HAPs metals mass collected:
21.10.1 Pollutant Name;
21.10.2 Pollutant Mass Collected;
21.10.3 Pollutant Mass Units of Measure; and
21.10.4 Detection Limit Flag.
21.11 Total HAPs metals concentration
21.11.1 Pollutant Name;
21.11.2 Pollutant Concentration; and
21.11.3 Pollutant Concentration Units of Measure.
21.12 Total HAPs metals Emission Rate in Units of the Standard:
21.12.1 Pollutant Name;
21.12.2 Pollutant Emission Rate; and
21.12.3 Pollutant Emission Rate Units of Measure.
21.13 Total HAPs metals Emission Rate in lbs/MMBtu or lbs/MW
(per Table 5 to this subpart):
21.13.1 Pollutant Name;
21.13.2 Pollutant Emission Rate; and
21.13.3 Pollutant Emission Rate Units of Measure.
22.0 Run-Level and Lab Data Elements for EPA test Method 26 in
Appendix A-8 to Part 60 of this Chapter. If you use EPA test Method
26, you must report the Source ID (i.e., Data Element 18.1) and the
following run-level data elements for each test run. If
[[Page 20377]]
your EGU is oil-fired and you use EPA test Method 26 to conduct
stack tests for both HCl and HF, you must report these data elements
separately for each pollutant:
22.1 Test Number;
22.2 Pollutant Name;
22.3 EPA Test Method;
22.4 Run Number;
22.5 Corresponding Reference Method(s), if applicable;
22.6 Corresponding Reference Method(s) Run Number, if
applicable;
22.7 Number of Traverse Points;
22.8 Run Begin Date;
22.9 Run Start Time (Clock Start Time);
22.10 Run End Date;
22.11 Run End Time (Clock End Time);
22.12 Barometric Pressure;
22.13 Cumulative Elapsed Sampling Time;
22.14 Calibration Coefficient of Dry Gas Meter (Y);
22.15 Initial Reading of Dry Gas Meter Volume (dcf);
22.16 Final Reading of Dry Gas Meter Volume (dcf);
22.17 Percent O2;
22.18 Percent CO2;
22.19 Type of Fuel;
22.20 F-Factor (Fd, Fw, or Fc);
22.21 Pollutant Mass Collected (value);
22.22 Pollutant Mass Units of Measure;
22.23 Detection Limit Flag;
22.24 Pollutant Concentration;
22.25 Pollutant Concentration Unit of Measure;
22.26 Compliance Limit Basis (Heat Input or Electrical Output);
22.27 Heat Input or Electrical Output Unit of Measure;
22.28 Process Parameter (value);
22.29 Process Parameter Unit of Measure;
22.30 Pollutant Emission Rate; and
22.31 Pollutant Emission Rate Units of Measure (in the Units of
the Standard).
23.0 Point-Level Data Elements for EPA test Method 26 in
Appendix A-8 to Part 60 of this Chapter. To link the point-level
data in this Section with the run-level data in the XML schema, you
must report the Source ID (i.e., Data Element 18.1), EPA Test Method
(Data Element 22.3), Run Number (Data Element 22.4), and Run Begin
Date (Data Element 22.8) from section 22 of this appendix and the
following point-level data elements for each run of each EPA test
Method 26 test:
23.1 Traverse Point ID;
23.2 Filter Temperature; and
23.3 Dry Gas Meter Temperature.
24.0 Run-Level Data for EPA test Method 30B in Appendix A-8 to
Part 60 of this Chapter. You must report Source ID (i.e., Data
Element 18.1) and the following run-level data elements for each EPA
test Method 30B test run:
24.1 Test Number;
24.2 Pollutant Name;
24.3 EPA Test Method;
24.4 Run Number;
24.5 Corresponding Reference Method(s), if applicable;
24.6 Corresponding Reference Method(s) Run Number, if
applicable;
24.7 Number of Traverse Points;
24.8 Run Begin Date;
24.9 Run Start Time (Clock Time Start);
24.10 Run End Date;
24.11 Run End Time (Clock Time End);
24.12 Barometric Pressure;
24.13 Percent O2;
24.14 Percent CO2;
24.15 Cumulative Elapsed Sampling Time;
24.16 Calibration Coefficient of Dry Gas Meter Box A (Y);
24.17 Initial Reading of Dry Gas Meter Volume (A);
24.18 Final Reading of Dry Gas Meter Volume (A);
24.19 Calibration Coefficient of Dry Gas Meter Box B (Y);
24.20 Initial Reading of Dry Gas Meter Volume (B);
24.21 Final Reading of Dry Gas Meter Volume (B);
24.22 Gas Sample Volume Units of Measure;
24.23 Post-Run Leak Rate (A);
24.24 Post-Run Leak Check Vacuum (A);
24.25 Post-Run Leak Rate (B);
24.26 Post-Run Leak Check Vacuum (B);
24.27 Sorbent Trap ID (A);
24.28 Pollutant Mass Collected, Section 1 (A);
24.29 Pollutant Mass Collected, Section 2 (A);
24.30 Mass of Spike on Sorbent Trap A;
24.31 Total Pollutant Mass Trap A;
24.32 Sorbent Trap ID (B);
24.33 Pollutant Mass Collected, Section 1 (B);
24.34 Pollutant Mass Collected, Section 2 (B);
24.35 Mass of Spike on Sorbent Trap B;
24.36 Total Pollutant Mass Trap B;
24.37 Pollutant Mass Units of Measure;
24.38 Pollutant Average Concentration;
24.39 Pollutant Concentration Units of Measure;
24.40 Method Detection Limit (MDL);
24.41 Percent Spike Recovery;
24.42 Type of Fuel;
24.43 F-Factor (Fd, Fw, or Fc);
24.44 Compliance Limit Basis (Heat Input or Electrical Output);
24.45 Heat Input or Electrical Output Unit of Measure;
24.46 Process Parameter (value);
24.47 Process Parameter Unit of Measure;
24.48 Pollutant Emission Rate; and
24.49 Pollutant Emission Rate Unit of Measure (in the Units of
the Standard).
25.0 Point-Level Data Elements for EPA test Method 30B in
Appendix A-8 to Part 60 of this Chapter. You must report the Source
ID (i.e., Data Element 18.1), EPA Test Method (Data Element 24.3),
Run Number (Data Element 24.4), and Run Begin Date (Data Element
24.8) and the following point-level data elements for each run of
each EPA test Method 30B test:
25.1 Traverse Point ID;
25.2 Dry Gas Meter Temperature (A);
25.3 Sample Flow Rate (A) (L/min);
25.4 Dry Gas Meter Temperature (B); and
25.5 Sample Flow Rate (B) (L/min).
26.0 Pre-Run Data Elements for EPA test Methods 3A and 6C in
Appendices A-2 and A-4 of Part 60 of this Chapter. You must report
the Source ID (i.e., Data Element 18.1) and the following Pre-run
data elements for each SO2 RATA using instrumental EPA
test Method 6C, and for each instrumental EPA test Method 3A
O2 or CO2 test that is performed to convert a
pollutant concentration to the units of measure of the applicable
emission unit of standard in Table 1 or 2 to this subpart:
26.1 Test Number;
26.2 EPA Test Method;
26.3 Calibration Gas Cylinder Analyte;
26.4 Cylinder Gas Units of Measure;
26.5 Date of Calibration;
26.6 Calibration Low-Level Gas Cylinder ID;
26.7 Calibration Low-Level Gas Concentration;
26.8 Calibration Low-Level Cylinder Expiration Date;
26.9 Calibration Mid-Level Gas Cylinder ID;
26.10 Calibration Mid-Level Gas Concentration;
26.11 Calibration Mid-Level Cylinder Expiration Date;
26.12 Calibration High-Level Gas Cylinder ID;
26.13 Calibration High-Level Gas Concentration;
26.14 Calibration High-Level Cylinder Expiration Date;
26.15 Calibration Span;
26.16 Low-Level Gas Response;
26.17 Low-Level Calibration Error;
26.18 Low-Level APS Flag;
26.19 Mid-Level Gas Response;
26.20 Mid-Level Calibration Error;
26.21 Mid-Level APS Flag;
26.22 High-Level Gas Response;
26.23 High-Level Calibration Error; and
26.24 High-Level APS Flag.
27.0 Run-Level Data Elements for EPA test Methods 3A and 6C in
Appendices A-2 and A-4 of Part 60 of this Chapter. You must report
the Source ID (i.e., Data Element 18.1) and following run-level data
elements for each run of each SO2 RATA using instrumental
EPA test Method 6C, and for each run of each corresponding
instrumental EPA test Method 3A test that is performed to convert a
pollutant concentration to the applicable emission unit of standard
in Table 1 or 2 to this subpart:
27.1 Test Number;
27.2 Pollutant or Analyte Name;
27.3 EPA Test Method;
27.4 Run Number;
27.5 Corresponding Reference Method(s), if applicable;
27.6 Corresponding Reference Method(s) Run Number(s), if
applicable;
27.7 Number of Traverse Points;
27.8 Run Begin Date;
27.9 Run Start Time (Clock Time Start);
27.10 Run End Date;
27.11 Run End Time (Clock Time End);
27.12 Cumulative Elapsed Sampling Time;
27.13 Upscale (mid or high) Gas Level;
27.14 Pre-Run Low-Level Response;
27.15 Pre-Run Low-Level System Bias;
27.16 Pre-Run Low-Level Bias APS Flag;
27.17 Pre-Run Upscale (mid or high) Response;
27.18 Pre-Run Upscale (mid or high) System Bias;
27.19 Pre-Run Upscale (mid or high) Bias APS Flag;
[[Page 20378]]
27.20 Post-Run Low-Level Response;
27.21 Post-Run Low-Level System Bias;
27.22 Post-Run Low-Level Bias APS Flag;
27.23 Post-Run Low-Level Drift;
27.24 Post-Run Low-Level Drift APS Flag;
27.25 Post-Run Upscale (mid or high) Response;
27.26 Post-Run Upscale (mid or high) System Bias;
27.27 Post-Run Upscale (mid or high) System Bias APS Flag;
27.28 Post-Run Upscale (mid or high) Drift;
27.29 Post-Run Upscale (mid or high) Drift APS Flag;
27.30 Unadjusted Raw Emissions Average Concentration;
27.31 Calculated Average Concentration, Adjusted for Bias
(Cgas);
27.32 Concentration Units of Measure (Dry or wet);
27.33 Type of Fuel;
27.34 Process Parameter (value); and
27.35 Process Parameter Units of Measure.
28.0 Run-Level Data Elements for EPA test Method 2 in Appendix
A-1 of Part 60 of this Chapter. When you make a separate
determination of the stack gas flow rate using EPA test Method 2
separately, corresponding to a pollutant reference method test,
i.e., when data from the pollutant reference method cannot determine
the stack gas flow rate, you must report the Source ID (i.e., 18.1)
and following run-level data elements for each EPA test Method 2
test run:
28.1 Test Number;
28.2 EPA Test Method;
28.3 Run Number;
28.4 Number of Traverse Points;
28.5 Run Begin Date;
28.6 Run Start Time (Clock Time Start);
28.7 Run End Date;
28.8 Run End Time (Clock Time End);
28.9 Pitot Tube ID;
28.10 Pitot Tube Calibration Coefficient;
28.11 Barometric Pressure;
28.12 Static Pressure;
28.13 Percent O2;
28.14 Percent CO2;
28.15 Percent Moisture--actual;
28.16 Dry Molecular Weight of Stack Gas;
28.17 Wet Molecular Weight of Stack Gas;
28.18 Stack Gas Velocity--fps; and
28.19 Stack Gas Flow Rate--dscfm.
29.0 Point-Level Data Elements for EPA test Method 2 in Appendix
A-1 of Part 60 of this Chapter. For each run of each separate EPA
test Method 2 test, you must report the Source ID (i.e., Data
Element 18.1), EPA Test Method (Data Element 28.2), Run Number (Data
Element 28.3), and Run Begin Date (Data Element 28.5) and the
following point-level data elements:
29.1 Traverse Point ID;
29.2 Stack Temperature; and
29.3 Differential Pressure Reading ([Delta]P).
30.0 Run-Level Data Elements for EPA test Method 4 in Appendix
A-3 of Part 60 of this Chapter. When you make a separate EPA test
Method 4 determination of the stack gas moisture content
corresponding to a pollutant reference method test, i.e., when data
from the pollutant reference method cannot determine the moisture
content, you must report the Source ID (i.e., Data Element 18.1) and
the following run-level data elements for each EPA test Method 4
test run:
30.1 Test Number;
30.2 EPA Test Method;
30.3 Run Number;
30.4 Number of Traverse Points;
30.5 Run Begin Date;
30.6 Run Start Time (Clock Time Start);
30.7 Run End Date;
30.8 Run End Time (Clock Time End);
30.9 Barometric Pressure;
30.10 Calibration Coefficient of Dry Gas Meter (Y);
30.11 Volume of Water Collected in Impingers and Silica Gel;
30.12 Percent Moisture-actual;
30.13 Initial Reading of Dry Gas Meter Volume (dcf);
30.14 Final Reading of Dry Gas Meter Volume (dcf); and
30.15 Dry Gas Meter Temperature (Average).
31.0 Other Information for Each Test or Test Series. You must
provide each test included in the XML data file described in this
appendix with supporting documentation, in a PDF file submitted
concurrently with the XML file, such that all the data required to
be reported by Sec. 63.7(g) are provided. That supporting data
include but are not limited to diagrams showing the location of the
test site and the sampling points, laboratory report(s) including
analytical calibrations, calibrations of source sampling equipment,
calibration gas cylinder certificates, raw instrumental data, field
data sheets, QA data (e.g., field recovery spikes) and any required
audit results and stack testers' credentials (if applicable). The
applicable data elements in Sec. 63.10031(f)(6)(i) through (xii) of
this section must be entered into ECMPS with each PDF submittal; the
test number(s) (see Sec. 63.10031(f)(6)(xi)) must be included. The
test number(s) must match the test number(s) in sections 19 through
31 of this appendix (as applicable).
[FR Doc. 2020-07471 Filed 4-9-20; 8:45 am]
BILLING CODE 6560-50-P