Mercury and Air Toxics Standards for Power Plants Electronic Reporting Revisions, 55744-55780 [2020-15950]
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55744
Federal Register / Vol. 85, No. 175 / Wednesday, September 9, 2020 / Rules and Regulations
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 63
[EPA–HQ–OAR–2018–0794; FRL–10011–53–
OAR]
RIN 2060–AU70
Mercury and Air Toxics Standards for
Power Plants Electronic Reporting
Revisions
Environmental Protection
Agency (EPA).
ACTION: Final rule.
AGENCY:
The U.S Environmental
Protection Agency (EPA) is finalizing
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 action revises and
streamlines the electronic data reporting
requirements of MATS, increases data
transparency by requiring use of one
electronic reporting system instead of
two separate systems, and provides
enhanced access to MATS data. No new
monitoring requirements are imposed
by this final action; instead, this action
reduces reporting burden, increases
MATS data flow and usage, makes it
easier for inspectors and auditors to
assess compliance, and encourages
wider use of continuous emissions
monitoring systems (CEMS) for MATS
compliance. In addition, this final
action extends the current deadline for
alternative electronic data submission
via portable document format (PDF)
files through December 31, 2023.
DATES: This final rule is effective on
September 9, 2020.
ADDRESSES: The EPA has established a
docket for this action under Docket ID
No. EPA–HQ–OAR–2018–0794. All
documents in the docket are listed on
the https://www.regulations.gov/
website. Although listed, some
information is not publicly available,
e.g., Confidential Business Information
SUMMARY:
or other information whose disclosure is
restricted by statute. Certain other
material, such as copyrighted material,
is not placed on the internet and will be
publicly available only in hard copy
form. Publicly available docket
materials are available electronically
through https://www.regulations.gov/.
Out of an abundance of caution for
members of the public and our staff, the
EPA Docket Center and Reading Room
was closed to the public, with limited
exceptions, to reduce the risk of
transmitting COVID–19. Our Docket
Center staff will continue to provide
remote customer service via email,
phone, and webform. For further
information and updates on EPA Docket
Center services and the current status,
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: parker.barrett@epa.gov.
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;
email address: johnson.mary@epa.gov.
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:
worley.christopher@epa.gov.
SUPPLEMENTARY INFORMATION: The
information in this preamble is
organized as follows:
A. Does this action apply to me?
B. Where can I get a copy of this document
and other related information?
C. Judicial Review and Administrative
Reconsideration
D. What action is the Agency taking?
E. What is the Agency’s authority for taking
this action?
F. What are the incremental costs and
benefits of this action?
II. Background
III. What is the scope of these amendments?
IV. What are the specific amendments to 40
CFR part 63, subpart UUUUU as a result
of this action?
A. 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
V. Revisions to Other Rule Text
VI. 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
L. Congressional Review Act (CRA)
Table of Contents
Categories and entities potentially
affected by this action include:
I. General Information
NAICS code 1
Category
Industry .......................................................................................
Federal government ....................................................................
State/local/tribal government ......................................................
221112
2 221122
2 221122
921150
1 North
I. General Information
A. Does this action apply to me?
Examples of potentially regulated entities
Fossil
Fossil
Fossil
Fossil
fuel-fired
fuel-fired
fuel-fired
fuel-fired
electric utility steam generating units (EGUs).
EGUs owned by the federal government.
EGUs owned by municipalities.
EGUs in Indian country.
American Industry Classification System.
state, or local government-owned and operated establishments are classified according to the activity in which they are engaged.
2 Federal,
This table is not intended to be
exhaustive, but rather provides a guide
for readers regarding entities likely to be
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regulated by this action. This table lists
the types of entities that the EPA is now
aware could potentially be regulated by
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this action. Other types of entities not
listed in the table could also be
regulated. To determine whether your
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entity is regulated by this 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. Where can I get a copy of this
document and other related
information?
In addition to being available in the
docket, an electronic copy of this final
action will also be available on the
internet. Following signature by the
EPA Administrator, the EPA will post a
copy of this final action at: https://
www.epa.gov/mats/regulatory-actionsfinal-mercury-and-air-toxics-standardsmats-power-plants. Following
publication in the Federal Register, the
EPA will post the Federal Register
version and key technical documents at
this same website.
C. Judicial Review and Administrative
Reconsideration
Under Clean Air Act (CAA) section
307(b)(1), judicial review of this final
action is available only by filing a
petition for review in the United States
Court of Appeals for the District of
Columbia Circuit by November 9, 2020.
Under CAA section 307(b)(2), the
requirements established by this final
rule may not be challenged separately in
any civil or criminal proceedings
brought by the EPA to enforce the
requirements.
Section 307(d)(7)(B) of the CAA
further provides that only an objection
to a rule or procedure which was raised
with reasonable specificity during the
period for public comment (including
any public hearing) may be raised
during judicial review. This section also
provides a mechanism for the EPA to
reconsider the rule if the person raising
an objection can demonstrate to the
Administrator that it was impracticable
to raise such objection within the period
for public comment or if the grounds for
such objection arose after the period for
public comment (but within the time
specified for judicial review) and if such
objection is of central relevance to the
outcome of the rule. Any person seeking
to make such a demonstration should
submit a Petition for Reconsideration to
the Office of the Administrator, U.S.
Environmental Protection Agency,
Room 3000, WJC South Building, 1200
Pennsylvania Ave. NW, Washington, DC
20460, with a copy to both the person(s)
listed in the preceding FOR FURTHER
INFORMATION CONTACT section, and the
Associate General Counsel for the Air
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and Radiation Law Office, Office of
General Counsel (Mail Code 2344A),
U.S. Environmental Protection Agency,
1200 Pennsylvania Ave. NW,
Washington, DC 20460.
D. What action is the Agency taking?
The EPA is finalizing 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).
E. 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.
F. What are the incremental costs and
benefits of this action?
As discussed in section VI.C of this
preamble, this action is expected to
reduce overall annual source burden by
11,000 hours per year, which when
monetized is $15,079,000.
II. Background
These amendments 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
ECMPS Client Tool to submit
monitoring plan information, quality
assurance (QA) 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
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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), (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
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reports. Section 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 MATSaffected 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.
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
1 81
FR 67062, September 29, 2016.
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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 complete 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).
The Agency continued to develop the
remaining electronic reporting and
recordkeeping requirements,
considering the comments received on
the September 29, 2016 (81 FR 67062)
proposal. When that effort was
complete, rather than finalizing those
requirements, the Agency decided to
again provide stakeholders with an
opportunity to review and comment on
the requirements, so the Agency issued
a proposal with those requirements on
April 10, 2020 (85 FR 20342).
Thirty-five comment letters were
received, and they are available in the
docket. Many of those comments were
similar to comments submitted before in
other proposals and have been
addressed previously. Responses for the
comments on this action are included in
the Response to Comments document
which is also available in the docket.
Significant comments can be sorted into
eight groups; their general descriptions
and responses follow.
1. Comments received on other MATS
regulatory actions, e.g., removal of the
appropriate and necessary
determination, are not relevant for this
action and were not addressed.
Likewise, comments regarding other
regulatory actions, e.g., insecticides and
pesticides, are not relevant for this
action and were not addressed.
2. A majority of commenters
supported extending the use of PDF
reporting until January 2024. Many
industry commenters suggested splitting
the package so the extension could be
finalized, and more time could be spent
on reviewing the other portions of the
package. The Agency is not splitting the
package and appreciates the support for
the extension until the ECMPS Client
Tool is reprogrammed and ready for use.
The Agency sees no need for additional
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time to comment on the proposed
revisions, as those revisions have been
available for review and comment for
over 3 years—since the September 29,
2016, proposal.
3. Commenters sought clarification on
the conditions that would cause
monitoring downtime to be considered
a deviation, and the regulation provides
that clarification.
4. Industry commenters sought to
have consistent application of grace
periods and ongoing QA check periods
(based on operating quarters only) for
PM CEMS and PM CPMS; however,
these instruments differ from other
CEMS because except for the annual
testing, there is no other time when the
monitoring system is compared to a
certified reference method value to
determine accuracy. This difference
means that techniques allowing for
additional periods before testing is
required puts EGU owners or operators,
as well as the environment, at
additional risk of elevated emissions
during such periods. Due to this
difference, and its potential effects, the
regulation will not provide grace
periods beyond 1 calendar quarter or
ongoing QA checks based on operating
quarters only.
5. Commenters sought clarification on
Hg low-emitting EGU (LEE) testing
calculations, and the regulation
provides such clarification in 40 CFR
63.10005(h)(3)(iii).
6. Some commenters continue to
assert that data elements in appendix E
are duplicative, but as described before,
those data elements are already required
and represent the minimum bits of
information needed to ensure smooth
operation of an electronic reporting
system. Even so, clarifications from
already-mentioned deviation and
monitoring downtime circumstances, as
well as for reporting span values and
fuel usage, have been provided in
appendix E.
7. One commenter asked the Agency
to reconsider allowing the use of
alternate semi-annual reporting
submission dates established by
operating permit programs, at least until
the ECMPS Client Tool is operational;
the Agency agrees that this flexibility
should be maintained during the
extension period, and the rule has been
revised to allow use of such alternate
semi-annual reporting dates.
8. Finally, some commenters
requested continued engagement with
stakeholders as the new ECMPS Client
Tool software is developed and tested.
Consistent with previous ECMPS
reporting instructions changes and the
implementation of previous MATS
reporting changes, the Agency will
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provide draft reporting instructions and
XML schema documentation prior to
implementation and engage
stakeholders during the development
and testing of software.
This action finalizes an extension of
the interim PDF reporting process
through December 31, 2023, and
finalizes the remaining needed
amendments to the MATS rule on
electronic reporting. Note that these
amendments were developed after
consideration of the comments received
on the September 29, 2016, and April
10, 2020, proposals. III. What is the
scope of these amendments?
This action amends the reporting
requirements in 40 CFR 63.10031 of the
MATS regulation, and, for consistency
with those changes, amends 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. In addition, the
recordkeeping and reporting sections of
appendices A and B are amended 2 and
three new appendices are 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 action allows EGU
owners or operators to use the ECMPS
Client Tool to report all of the required
information in XML and PDF files.
IV. What are the specific amendments
to 40 CFR part 63, subpart UUUUU as
a result of this action?
The amendments to 40 CFR part 63,
subpart UUUUU are discussed in detail
in the paragraphs below.
A. Revisions to the Reporting
Requirements of MATS
The reporting requirements of MATS
are amended as follows:
(1) The ECMPS Client Tool is 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) is
extended through December 31, 2023, to
allow sufficient time for software
development, programming, and testing.
2 In 2015, the EPA published a technology-neutral
performance specification and associated QA test
procedures for HCl monitors (see Performance
Specification 18 (PS 18) and 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 action requires 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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Until then, compliance with the
emissions and operating limits will
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 is
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 is
required 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) states that PDF submittals
are still 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 covers the period
from July 1, 2023, through December 31,
2023; the deadline for submitting this
report is January 30, 2024, and the
report is submitted using the interim
PDF reporting process.
(4) Revised paragraph (f)(2) of 40 CFR
63.10031 expands 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)
are reported quarterly in XML format for
all parameters (including Hg, HF, HCl,
and SO2). However, instead of providing
these rolling averages in separate, standalone reports, they are incorporated into
the quarterly compliance reports
required under 40 CFR 63.10031(g) (see
section IV.A.(9) of this preamble,
below).
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(5) Revised paragraphs (a)(1), (2), and
(5) of 40 CFR 63.10031 clarify the
electronic reporting requirements for the
Hg, HCl, HF, SO2, and additional CMS.
Specifically:
(i) Paragraph (a)(1) requires the
electronic reporting requirements of
appendix A to be met if Hg CEMS or
sorbent trap monitoring systems are
used.
(ii) Paragraph (a)(2) requires 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 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 QA of
the monitor, EGU owners or operators
will 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 are 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 adds the necessary
recordkeeping and reporting
requirements, and the interim reporting
for HCl will be discontinued as of
January 1, 2024 (for further discussion,
see section IV.C of this preamble).
(iii) Paragraph (a)(5) clarifies the
electronic reporting requirements for the
SO2 CEMS and the additional
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 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 are 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) is removed and reserved).
(6) Paragraphs (b)(1) and (2) of 40 CFR
63.10031 are amended to recognize that
some EGUs may have received
extensions of their compliance date
under 40 CFR 63.6(i)(4). References to
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postmark dates for submittal of
semiannual compliance reports
paragraphs are removed from
paragraphs (b)(2) and (4); these reports
currently are, and 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 allows affected
EGU owners or operators to follow
alternate submission schedules for
semiannual compliance reports are
discontinued when the interim PDF
reporting period ends. When that
interim PDF reporting period ends, the
uniform submission schedule described
in 40 CFR 63.10031(b)(1) through (4) is
required for all affected EGUs, so that
compliance with this reporting
requirement can easily be tracked.
(8) New 40 CFR 63.10031(b)(6) will
require EGU owners or operators to
discontinue submission of semiannual
compliance reports when the interim
PDF reporting period ends. The final
semiannual compliance report covers
the period from July 1, 2023, through
December 31, 2023.
(9) EGU owners or operators submit
quarterly compliance reports in lieu of
the semiannual compliance reports,
starting with reports covering the first
quarter of 2024 (see 40 CFR
63.10031(g)). The quarterly compliance
reports 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 will be due within
60 days after the end of each calendar
quarter, which allows 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 includes 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 are included in the quarterly
compliance reports. If continuous
emission monitoring were used to
demonstrate compliance on a 30- or 90boiler operating day rolling average
basis, the quarterly compliance reports
include all of the 30- or 90-day averages
calculated during the quarter. If
emissions averaging were used, EGU
owners or operators report all of the 30or 90-group boiler operating day WAERs
calculated during the quarter. If periodic
stack testing for compliance were
performed (including Hg LEE tests and
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PM tests to set operating limits for PM
CPMS), the EGU owner or operator
reports 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
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,
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 exceptiononly reporting, these amendments
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
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 is retained in the
quarterly compliance reports.
Specifically, the revisions to 40 CFR
63.10031(d) 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
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(section 13.4). Section 13.3 further
specifies the minimum amount of
information reported in the description
of certain deviations or monitoring
downtime (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 makes 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. In response to comments
received, these instructions have been
modified from a previous draft version.
(10) A new paragraph (c)(10) is added
to section 63.10031 and requires
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) requires 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) has been renamed
as paragraph (c)(10) and is added to the
list of information that must be included
in the semiannual reports. The
introductory text of paragraph (c) is also
amended, to recognize the addition of
paragraph (c)(10).
(11) For consistency with the
reporting requirements for the other
CMS, the regulation does not require
source owners or operators using PM
CPMS to submit separate quarterly
excess emission summary reports in
addition to the quarterly compliance
reports. After careful consideration of
comments on the previous proposal, we
are persuaded that sufficient
information to assess compliance with
the operating limits of a PM CPMS will
be provided 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
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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.
Table 9 to 40 CFR part 63, subpart
UUUUU is amended 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 63.7(c)(8), 63.10(c)(7), and
63.10(e)(3) ends 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. We thought the
April proposal addressed this concern,
but other commenters asked for
clarification during the current
comment period. As the Agency meant
to exempt periods of routine QA or
quality control (QC) and routine
maintenance from deviation reporting
but not from monitoring downtime
reporting, language in 40 CFR
63.10010(h)(5), (i)(4), and (j)(4) has been
clarified, along with the clarifications to
40 CFR 63.10020(b) and (d), 40 CFR
63.10010(h)(6)(i) and (ii), (i)(5)(i) and
(ii), and (j)(4)(i)(A) and (B) that were
proposed in April. We also clarified the
corresponding data elements in section
13 of Appendix E.
In response to comments for
clarification concerning reporting of QA
test results, which the Agency maintains
is mandatory for all CMS, the regulation
has been amended at 40 CFR 63.10010
to remove the last sentence in
paragraphs (h)(6)(i), (j)(4)(i)(A) and (B);
to require the monitoring system
performance evaluations of PM CPMS
and HAP metals CEMS be reported in
paragraphs (h)(7) and (j)(4)(ii),
respectively; to require the QA/QC
activities for PM CPMS and HAP metals
CEMS be reported quarterly in PDF files
in 40 CFR 63.10031(k); and to crossreference the appropriate sections of
appendix C, regarding the certification,
operation, maintenance, on-going QA,
recordkeeping, and reporting
requirements for PM CEMS in 40 CFR
63.10010(i).
(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 rule
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retains 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 is 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, EGU owners or operators will 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 will be required to 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 is provided in a PDF file for
each test. The appendix E information is
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 is also
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
November 9, 2020, the report is due no
later than 60 days after that date. For
correlation tests completed on or after
November 9, 2020, but prior to January
1, 2024, the report is due within 60 days
after the date on which the test is
completed. (Note: For correlations
completed on and after January 1, 2024,
in lieu of a PDF report, the test results
are 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 40 CFR
63.10020(e) for startup and shutdown
incidents, if an EGU owner or operator
is 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 is submitted
along with the quarterly compliance
report. Note that 40 CFR
63.10031(c)(5)(iii) through (v), which
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55749
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) are entered into the
ECMPS Client Tool at the time of
submission of each PDF file. Note that
the amendment to data element (xii)
replaces the word ‘‘conducted’’ with the
word ‘‘completed.’’
(17) Although the ECMPS Client Tool
is used to submit the required reports
and notifications described in revised
40 CFR 63.10031 and Table 8, ECMPS
does 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 are transmitted
directly through the EPA’s Central Data
Exchange using CEDRI unaltered.
ECMPS does, 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 uses the results of
these evaluations to assess the qualityassured status of the Hg, HCl, HF, SO2,
or PM emissions data. In addition,
ECMPS performs basic checks of the
information in the quarterly compliance
reports, e.g., checking for completeness
and proper formatting, but leaves
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 improper RATA results in
invalidation of hourly emissions data,
from the expiration of the grace period
until a valid RATA is performed and
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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
Based on comments received, six
sections of appendix A, i.e., sections
5.1.1, 7.1.1.2.1, 7.1.3.3, 7.1.4.3, 7.1.8.2
and 7.2.3.1 are amended and described,
here. The requirement in section 5.1.1
regarding required QA testing is
clarified to allow daily calibrations to be
performed offline and to specify that
ongoing QA testing other than RATAs
can be performed at no particular load
levels.
The requirement in section 7.1.1.2.1
for electronic reporting is expanded to
include emission controls. As part of the
re-examination of the list of data
elements that compose a complete test
report, suggested by commenters, this
data element was found to be missing in
this section. 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 three significant figures is
revised so that Hg concentrations in
micrograms per standard cubic meter
(mg/scm) and Hg emission rates in
pounds per trillion British Thermal
Units or pounds per gigawatt-hour are
reported with one leading non-zero digit
and one decimal place, in scientific
notation. Conventional rounding is
used, i.e., if the digit immediately
following the first decimal place is 5 or
greater, the digit in the first decimal
place is 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 remains
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 is
revised. For new EGUs or EGUs that
install Hg monitoring systems in order
to switch from another MATScompliant methodology to Hg
monitoring, the monitoring plan
information is submitted at least 21 days
prior to the date on which certification
testing begins. However, for EGUs
implementing Hg monitoring with a
previously-certified Hg monitoring
system, the monitoring plan may be
submitted prior to or concurrent with
the first quarterly emissions report—
provided that the monitoring plan is in
place when the first emissions report is
submitted so that the ECMPS Client
Tool is able to evaluate the data.
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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 are promulgated, EGU
owners or operators may use any viable
HCl monitoring technology that can
meet PS 18. 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,
40 CFR 63.10031(a)(2) is revised, 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
are required to keep records of all of the
other certification and QA tests, which
would be reported starting in 2024.
The title to section 2.3 of appendix B
is revised 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) are amended. Based
on comments received, sections 10.1.3.3
and 10.1.7.2, HCl and HF concentrations
(mg/scm) and emission rates (lb/MMBtu
or lb/MWh) are reported with one
leading non-zero digit and one decimal
place, in scientific notation, rather than
reporting the concentrations and rates to
three significant figures. Conventional
rounding is used, i.e., if the digit
immediately following the first decimal
place is 5 or greater, the digit in the first
decimal place is rounded upward
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(increased by one); if the digit
immediately following the first decimal
place is 4 or less, the digit in the first
decimal place remains unchanged.
Sections 10 and 11 also specify the data
elements that are recorded and reported
for each of the tests required by PS 18
and Procedure 6. The revisions 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 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 introduce no
unnecessary reporting burden. The
results of certification and on-going QA
tests are 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
are required for all HCl monitors. For
example, some of the tests (i.e., beam
intensity, temperature, and pressure
verifications) are specific to integrated
path-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) are 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
are submitted along with the electronic
summary of results required under
section 11 of appendix B. To the extent
practicable, these data are 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
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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 allows
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 is 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 change from provisional to
quality-assured, and no further action is
required. However, if the test is
unsuccessful, the provisional data are
invalidated, and resubmission of the
affected emissions report(s) is 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, section 11.5.1 of
appendix B now clarifies 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 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 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 is 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 is
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 must be submitted at
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17:41 Sep 08, 2020
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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
may be submitted prior to or concurrent
with the first quarterly emissions report.
Section 11.4.13 clarifies the reporting
requirements for stack gas flow rate,
moisture, and diluent gas monitoring
systems that are used for certification,
recertification, diagnostic, and QA tests
are from section 10.1.8.2 of this
appendix; such systems are also
certified and quality-assured according
to 40 CFR part 75 of this chapter.
D. Addition of Appendix C
A new appendix, i.e., appendix C, is
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 includes
provisions for installation and
certification of the PM CEMS, and for
on-going QA of the data from the CEMS.
The monitoring system is 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 is being required.
After consideration of comments
received, the EPA has concluded that all
PM concentrations will 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 are recorded and
reported in mg/acm. Section 7.1.9.5 of
appendix C also requires 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 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 concentrations
and rates to three significant figures.
Conventional rounding is used, i.e., if
the digit immediately following the first
decimal place is 5 or greater, the digit
in the first decimal place is 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 remains unchanged.
The frequencies for the on-going QA
tests and the rules for data validation
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55751
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 follows the
familiar calendar quarter and grace
period reporting plan. An RRA is
required once every 4 calendar quarters
and an RCA is required once every 12
calendar quarters. A grace period is
provided (i.e., 720 operating hours or 1
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
allows the use of provisional data for up
to 60 days after completion of an RRA,
RCA, or PM CEMS correlation test.
The 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 recordkeeping
and reporting requirements are found in
section 7. Section 7.1 requires
monitoring plan records and hourly
records of operating parameters, PM
concentration, diluent gas
concentration, stack gas flow rate and
moisture content, and PM emission
rates are kept. Sections 7.2.3 and 7.2.4,
respectively, require monitoring plan
information and the results of
certification, recertification, and QA
tests are reported electronically. For
consistency with these revisions to
appendices A and B, section 7.2.3.1
specifies 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
is submitted at least 21 days prior to the
commencement of certification testing.
However, for EGUs with previouslycertified PM CEMS that elect to
implement PM monitoring, the
monitoring plan information may be
submitted prior to or concurrent with
the first quarterly emissions report.
Section 7.2.5 requires quarterly
electronic emissions reports are
submitted within 30 days after the end
of each calendar quarter. All electronic
reports are submitted using the ECMPS
Client Tool. However, for EGUs that
began 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
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data, and the applicable reference
method data in appendix E does not
begin until January 1, 2024, to allow
time for software development and beta
testing. Until then, records of the
required information and tests are kept.
For EGUs that certify and begin using
PM CEMS on or after January 1, 2024,
reporting of hourly PM emissions data
begin with the first operating hour after
successful completion of the initial PM
CEMS correlation test.
For PM CEMS correlations, RRAs, and
RCAs completed on and after January 1,
2024, the applicable reference method
data in sections 17 through 31 of
appendix E are 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 are 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 allows 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 is 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
would be invalidated, and resubmission
of the affected emission report(s) is
required.
E. Addition of Appendix D
A new appendix, i.e., appendix D, is
added to subpart UUUUU of 40 CFR
part 63. Appendix D sets 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 is 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
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introductory text, and section 3.1.1.1 of
the appendix).
Section 3.1.1.2 requires the ECMPS
Client Tool to be used to create and
maintain an electronic monitoring plan.
The PM CPMS is defined as a
monitoring system with a unique system
ID number. The monitoring plan also
includes 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.
The rule requires 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 are 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 is required to
indicate operating hours in which valid
data are not obtained. The percent
monitor data availability is 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,
require notifications (provided in
accordance with 40 CFR 63.10030) and
electronic monitoring plan submittals at
specified times. For EGUs using the PM
CPMS compliance option prior to
January 1, 2024, the electronic
monitoring plan information is
submitted prior to or concurrent with
the first quarterly report. For EGUs
switching to the PM CPMS compliance
option on or after January 1, 2024, the
electronic monitoring plan is submitted
no later than 21 days prior to the PM
test that establishes the initial operating
limit. Section 3.2.4 requires 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
begins 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
includes 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, the rule requires 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
requires the results of each performance
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stack test for PM that is used to establish
an operating limit are 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 are also submitted along
with the relevant quarterly compliance
report.
F. Addition of Appendix E
A new appendix, i.e., appendix E, is
added to subpart UUUUU of 40 CFR
part 63. Sections 2 through 13 of
appendix E list the data elements that
are 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 are included in
the quarterly compliance reports. As
noted in section V.A.(9) of this
preamble, updated reporting
instructions for these compliance
reports are found in the rule docket.
For reasons stated in the previous
proposal’s Response to Comments
document (which is available in the rule
docket 3), the basic provisions of
sections 14 through 21 of appendix E,
requiring details of the reference
methods used for performance stack
tests and CMS performance evaluations
are reported in XML format are retained.
The rule also retains the 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 is 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.
To address concerns raised by the
commenters about portions of the 2016
proposed rule 4 (the previous proposal),
specifically, the reporting requirements
in sections 17 through 21 of proposed
appendix E, the data element lists are
3 See EPA–HQ–OAR–2018–0794 at https://
www.regulations.gov/.
4 As mentioned in footnote 1, see 81 FR 67062,
September 29, 2016.
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revised and reformatted to correspond
to the compliance options described in
section 16 of appendix E. Explicitly,
sections 17 through 30 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
have been removed from the lists and
include:
• 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.
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Reporting instructions for sections 17
through 30 have been developed. These
draft example instructions are included
in the rule docket.
The reorganized data element lists
and corresponding instructions clarify
which data elements are reported for
each compliance option and explain
how the data are reported. Several new
data elements are in 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 action is
expected to reduce overall annual
source burden. The Agency believes that
the addition of these data elements is
offset by the removal of others, the
change to a consistent submission
frequency, and the 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
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
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 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 PS, whereas an APS flag of ‘‘1’’
means that the reported result is based
on the APS.
• ‘‘Test Comment.’’ This text field is
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 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 data elements
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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 requires 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
degrees 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 must
be reported in units consistent with the
PM CEMS correlation curve.
• ‘‘Average Sampling Rate and Units
of Measure.’’ These data elements are
specific to EPA test Method 30B. That
EPA test Method 30B requires a posttest 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 must be
reported. The previous proposed rule
only required the leakage rate to be
reported.
• ‘‘Control Device Code.’’ This data
element refers to the control device code
or control technology National Emission
Inventory code associated with the EGU
(or group of EGUs sharing a common
stack). Providing this data element helps
in EGU categorization and emission
factor development.
• ‘‘Corresponding Reference
Method(s), if applicable.’’ This 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 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
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methods were conducted properly so
that emission rates can be calculated.
• ‘‘Pollutant Concentration Units of
Measure.’’ This 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
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 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 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
data elements refer to the total Hg mass
measured by Train A and Train B,
respectively, in the appropriate units of
measure. Reporting these values is
necessary for QA purposes and for
comparison with the standard.
• ‘‘Method Detection Limit (MDL).’’
This 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
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 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 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 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
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comparison of results with the standard
and for emission factor development
purposes.
• ‘‘Pollutant Concentration.’’ This
data element expands the alreadyexisting ‘‘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 data element clarifies the alreadyexisting ‘‘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 5 on the
September 29, 2016, proposed rule (i.e.,
the previous proposal) suggested that
those proposed revisions included a
significant amount of duplicative
reporting, which should be eliminated.
In response to the concerns expressed
by the commenters, the Agency
examined the XML data element lists
twice—once in 2016 and recently after
closure of the current comment period—
for stack tests and CMS performance
evaluations, in order to identify
duplicative reporting and eliminate it
where possible. The following
evaluations were made:
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 nine of these
elements (i.e., Source ID (Sampling
Location), Test Number, Run Number,
Run Begin Date, and a few others) are
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
5 Commenters 20612, 20597, and 20609 on Docket
ID No. EPA–HQ–OAR–2009–0234.
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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 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, the
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
some 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.
V. 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 were
made to clarify certain reporting
requirements, to rectify inadvertent
omissions, and to correct
inconsistencies. The affected rule
sections are as follows:
(a) The introductory text of
paragraphs (a)(2), (b), and (h)(3)(iii) of
40 CFR 63.10005 is revised. The
amendment to paragraph (a)(2) clarifies
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
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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 may be used to
determine the stack gas flow rate and
moisture content. Revised section
(h)(3)(iii) addresses a commenter’s
request for clarification on how to
calculate a 30-day Hg LEE test average.
(b) Section 40 CFR 63.10009 is
amended as follows. The second and
third sentences in paragraph (a)(2) are
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) is 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’’ are removed from the
introductory text of paragraph (b)(2),
and in the nomenclature of Equation 2a,
the words ‘‘or sorbent trap monitoring’’
are added after the words ‘‘unit i’s
CEMS’’ in the definition of the term
‘‘Heri.’’ Finally, for completeness,
Equations 3a and 3b are 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 coalfired 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, paragraphs (h)(6) and (7), (i),
(j)(4)(i), and (j)(4)(ii) of 40 CFR 63.10010
are revised to resolve inconsistencies in
the text.
(d) Section 40 CFR 63.10011(e) is
revised to require Notifications of
Compliance Status for initial
compliance demonstrations include the
information specified in 40 CFR
63.10030(e), and are submitted in
accordance with 40 CFR 63.10031(f)(4)
or 40 CFR 63.10031(h), as applicable.
This change is necessary to cover initial
Notifications of Compliance Status for
both new and existing EGUs. The
interim reporting process described in
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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) Sections 40 CFR 63.10011(g)(3), 40
CFR 63.10021(i), and two sentences in
Items 3 and 4 of Table 3 are revised 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) be included in the
semiannual compliance reports, for
startup and shutdown incidents that
occur during the interim reporting
period. However, in view of the phaseout 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 40 CFR
63.10020(e) is required to be provided
as a separate PDF submittal, along with
the quarterly compliance report. As
previously noted, the requirements in
40 CFR 63.10031(c)(5)(iii), (iv), and (v)
to report hourly average CEMS and
operating parameter values for startup
and shutdown events are not
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) Paragraphs (e)(9), (f), and (h)(3) of
40 CFR 63.10021 are revised 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. References to the EPA’s
ERT and the CEDRI interface from
paragraph (f) are removed and replaced
with a general statement requiring all
applicable notifications and reports be
submitted through the ECMPS Client
Tool. Three statements are added 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
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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
removing paragraph (h)(3) because it is
redundant with paragraph (i) and,
therefore, unnecessary.
(g) Previous section 40 CFR
63.10030(e)(7)(i) is removed 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 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).
The requirements of section 40 CFR
63.10030(e)(7)(iii) are amended 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, 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,
a note is added 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) The requirements of 40 CFR
63.10032(a) are amended to include
references to the recordkeeping required
under new appendices C (for PM
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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, the term ‘‘semiannual
compliance report’’ is replaced with
references to both semiannual and
quarterly compliance reports in
paragraph (a)(1).
(i) The words ‘‘or out of control
period’’ are removed from the definition
of ‘‘monitoring system malfunction or
out of control period’’ in 40 CFR
63.10042 because that definition does
not describe an out of control period. A
separate definition of ‘‘out-of-control
period’’ is added, and that definition is
similar with the definition provided in
the Acid Rain Program definitions at 40
CFR 72.2.
(j) Table 8 to subpart UUUUU of 40
CFR part 63 is revised to be consistent
with the amendments to 40 CFR
63.10031 and the proposed addition of
appendices C, D, and E.
(k) Finally, the recordkeeping and
reporting requirements in Table 9 to 40
CFR part 63, subpart UUUUU are
revised as follows. First, the
requirement to provide the information
in 40 CFR 63.10030(e)(1) through (8) is
clarified, 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, a statement
clarifying that the excess emissions
recordkeeping and reporting
requirements of 40 CFR 63.10(c)(7) and
(8) and 63.10(e)(3)(v) and (vi) apply
through December 31, 2023, when the
semiannual compliance reports are
phased out, is added. On and after
January 1, 2024, all relevant information
is provided in quarterly, as opposed to
semiannual, reports.
VI. Statutory and Executive Order
Reviews
Additional information about these
statutes and Executive Orders can be
found at https://www.epa.gov/lawsregulations/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.
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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 final 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 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 2137.10.
You can find a copy of the ICR in the
docket for this rule, and it is briefly
summarized here. The information
collection requirements are not
enforceable until OMB approves them.
This rule continues to require
collection, recording, and submission of
data pertinent to demonstrating
compliance with rule requirements.
This action consolidates separate
reporting systems into one reporting
system by 2024; maintains the
information already required to be
collected, recorded, and submitted; and
changes the submission frequency from
semiannual to quarterly while
consolidating the number and type of
reports to be submitted.
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.
Estimated number of respondents:
1,414.
Frequency of response: Quarterly for
compliance reports.
Total estimated burden: 273,000
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. When
OMB approves this ICR, the Agency will
announce that approval in the Federal
Register and publish a technical
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amendment to 40 CFR part 9 to display
the OMB control number for the
approved information collection
activities contained in this 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-forprofit 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.
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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 rulemaking does not involve
technical standards.
K. Executive Order 12898: Federal
Actions To Address Environmental
Justice in Minority Populations and
Low-Income Populations
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 amends 40 CFR part 63
as follows:
PART 63—NATIONAL EMISSION
STANDARDS FOR HAZARDOUS AIR
POLLUTANTS FOR SOURCE
CATEGORIES
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
[Amended]
2. In § 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 section 63.8(c)(7)(i).’’
■ 3. Section 63.10005 is amended by:
■ a. Revising the first sentence in
paragraph (a)(2) introductory text;
■ b. Revising paragraph (b) introductory
text; and
■ c. Revising paragraph (h)(3)(iii).
The revisions read as follows:
§ 63.10005 What are my initial compliance
requirements and by what date must I
conduct them?
The EPA believes that this action is
not subject to Executive Order 12898 (59
FR 7629, February 16, 1994) because it
does not establish an environmental
health or safety standard. This
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
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This action is subject to the CRA, and
the EPA will submit a rule report to
each House of the Congress and to the
Comptroller General of the United
States. This action is not a ‘‘major rule’’
as defined by 5 U.S.C. 804(2).
■
J. National Technology Transfer and
Advancement Act (NTTAA)
17:41 Sep 08, 2020
L. Congressional Review Act (CRA)
§ 63.10000
This action is not subject to Executive
Order 13211, because it is not a
significant regulatory action under
Executive Order 12866.
VerDate Sep<11>2014
impact on human health or the
environment.
(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
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the applicable emissions limits in
Tables 1 and 2 to this subpart for your
EGUs, you must conduct the tests
according to 40 CFR 63.10007 and Table
5 to this subpart. Notwithstanding these
requirements, when Table 5 specifies
the use of isokinetic EPA test Method 5,
5D, 26A, or 29 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 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 40 CFR 63.9984, provided
that the following conditions are fully
met:
*
*
*
*
*
(h) * * *
(3) * * *
(iii) Calculate the average Hg
concentration, in mg/m3 (dry basis), for
each of LEE test runs comprising the 30(or 90-) boiler operating day
performance test, as the arithmetic
average of all Method 30B sorbent trap
results from the LEE test period. Also
calculate, as applicable, the average
values of CO2 or O2 concentration, stack
gas flow rate, stack gas moisture
content, and gross output for the LEE
test period. Then:
*
*
*
*
*
■ 4. Section 63.10009 is amended by:
■ a. Revising in paragraph (a)(2) the
second, third, and last sentences;
■ b. In paragraph (b)(2):
■ i. In the introductory text, removing
the words ‘‘for pollutants other than
Hg’’;
■ ii. In the definition for ‘‘Heri’’ adding
the words ‘‘or sorbent trap monitoring
system’’ after the words ‘‘unit i’s
CEMS’’; and
■ c. In paragraph (b)(3) revising
‘‘Equation 3a’’ and ‘‘Equation 3b.’’
The revisions read as follows:
§ 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
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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 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) * * *
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,
n = Number of hours that hourly rates are
collected over the 90-group boiler
operating days.
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,
n = Number of hours that hourly rates are
collected over the 90-group boiler
operating days.
section, except for required monitoring
system quality assurance or quality
control activities (including, as
applicable, calibration checks and
required zero and span adjustments),
and any scheduled maintenance as
defined in your site-specific monitoring
plan.
(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 40 CFR 63.10031(c) or (g) (as
applicable);
(ii) Any data recorded during periods
when the monitoring system is out-ofcontrol (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 40 CFR
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 40 CFR
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 sitespecific 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
*
*
*
*
*
5. Section 63.10010 is amended by
revising paragraphs (h)(5), (6), (7), (i),
and (j)(4) to read as follows:
■
§ 63.10010 What are my monitoring,
installation, operation, and maintenance
requirements?
*
*
*
*
*
(h) * * *
(5) You must collect data using the
PM CPMS at all times the process unit
is operating and at the intervals
specified in paragraph (h)(1)(ii) of this
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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 and at the intervals
specified in paragraph (a) of this
section, except for required monitoring
system quality assurance or quality
control activities and any scheduled
maintenance as defined in your sitespecific monitoring plan.
(5) 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 and
repairs associated with monitoring
system malfunctions. You must report
any monitoring system malfunctions as
deviations in your compliance reports
under 40 CFR 63.10031(c) or (g) (as
applicable);
(ii) Any data recorded during periods
when the monitoring system is out-ofcontrol (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 outof-control periods. You must report any
such periods as deviations in your
compliance reports under 40 CFR
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
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17:41 Sep 08, 2020
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intervals specified in paragraph (a) of
this section, except for required
monitoring system quality assurance or
quality control activities, and any
scheduled maintenance as defined in
your site-specific monitoring plan.
(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 40 CFR 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 outof-control periods. You must report any
out of control periods as deviations in
your compliance reports under 40 CFR
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
40 CFR 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.
*
*
*
*
*
■ 6. Section 63.10011 is amended by
revising paragraphs (e) and (g)(3) to read
as follows:
§ 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
40 CFR 63.10031(f)(4) or (h), as
applicable, containing the results of the
initial compliance demonstration, as
specified in 40 CFR 63.10030(e).
*
*
*
*
*
(g) * * *
(3) You must report the emissions
data recorded during startup and
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shutdown. If you are relying on
paragraph (2) of the definition of startup
in 40 CFR 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 40 CFR
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 40 CFR
63.10031(c)(5)(ii) and 40 CFR
63.10020(e) quarterly, in PDF files, in
accordance with 40 CFR 63.10031(i).
*
*
*
*
*
■ 7. Section 63.10020 is amended by
revising paragraphs (a), (b), and (d) to
read as follows:
§ 63.10020 How do I monitor and collect
data to demonstrate continuous
compliance?
(a) You must monitor and collect data
according to this section and the sitespecific monitoring plan required by
§ 63.10000(d).
(b) You must operate the monitoring
system and collect data at all required
intervals at all times that the affected
EGU is operating, except for required
monitoring system quality assurance or
quality control activities, including, as
applicable, calibration checks and
required zero and span adjustments, and
any scheduled maintenance as defined
in your site-specific monitoring plan.
You are required to affect monitoring
system repairs in response to
monitoring system malfunctions and to
return the monitoring system to
operation as expeditiously as
practicable.
*
*
*
*
*
(d) Periods of monitoring system
malfunctions or monitoring system outof-control periods, repairs associated
with monitoring system malfunctions or
monitoring system out-of-control
periods, and required monitoring
system quality assurance or quality
control activities excluding zero and
span checks must be reported as time
the monitor was inoperative (downtime)
under 63.10(c). Failure to collect
required quality-assured data during
monitoring system malfunctions,
monitoring system out-of-control
periods, or repairs associated with
monitoring system malfunctions or
monitoring system out-of-control
periods is a deviation from the
monitoring requirements.
*
*
*
*
*
■ 8. Section 63.10021 is amended by:
■ a. Revising paragraphs (e)(9) and (f);
■ b. Removing and reserving paragraph
(h)(3); and
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c. Revising paragraph (i).
The revisions read as follows:
§ 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 40 CFR
63.10031(f)(4) and (6) and, if requested
by the Administrator, in hard copy, as
specified in 40 CFR 63.10031(f)(5). On
and after January 1, 2024, report the
tune-up date electronically in your
quarterly compliance report, in
accordance with 40 CFR 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
40 CFR 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 40 CFR
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 40 CFR 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 40 CFR 63.10031(c)(5)(ii)
and 40 CFR 63.10020(e) quarterly, in
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PDF files, in accordance with 40 CFR
63.10031(i).
■ 9. Section 63.10030 is amended by:
■ a. In paragraph (e) introductory text
revising the last sentence;
■ b. Revising paragraph (e)(7)
introductory text;
■ c. Removing and reserving paragraph
(e)(7)(i);
■ d. Revising paragraph (e)(7)(iii)
introductory text;
■ e. Revising paragraph (e)(7)(iii)(A)(3);
■ f. Adding in paragraph (e)(7)(iii)(B)
the word ‘‘must’’ after the word ‘‘You’’;
and
■ g. Adding in paragraph (e)(7)(iii)(C)
the word ‘‘must’’ after the word ‘‘you’’.
The revisions and additions read as
follows:
§ 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;
*
*
*
*
*
■ 10. Section 63.10031 is amended by:
■ a. Revising paragraphs (a), (b)
introductory text, (b)(1), (2), (4), (5);
■ b. Adding paragraph (b)(6);
■ c. Revising paragraph (c) introductory
text;
■ d. Removing and reserving paragraphs
(c)(5)(iii), (c)(5)(iv), and (c)(5)(v);
■ e. Adding paragraph (c)(10);
■ f. Revising paragraphs (d), (e), (f)
introductory text, (f)(1), and (2);
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g. Removing and reserving paragraph
(f)(3);
■ h. Revising paragraphs (f)(4), (f)(6)
introductory text, (f)(6)(vii), (f)(6)(xi),
and (g); and
■ i. Adding paragraphs (h), (i), (j) and
(k), to read as follows:
■
§ 63.10031
when?
What reports must I submit and
(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 this
requirement, 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 relative accuracy test
audits (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
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):
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(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 sections 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 section 75.64(a)(5); 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 section 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 40 CFR
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
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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 40 CFR 63.9984
(or, if applicable, the extended
compliance date approved under 40
CFR 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 40 CFR 63.9984 (or, if
applicable, the extended compliance
date approved under 40 CFR 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
40 CFR 63.9984 (or, if applicable, the
extended compliance date approved
under 40 CFR 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) For each affected source that is
subject to permitting regulations
pursuant to part 70 or part 71 of this
chapter, and if the permitting authority
has established dates for submitting
semiannual reports pursuant to 40 CFR
70.6(a)(3)(iii)(A) or 40 CFR
71.6(a)(3)(iii)(A), through the reporting
period that ends December 31, 2023,
you may submit the first and subsequent
compliance reports according to the
dates the permitting authority has
established instead of according to the
dates in paragraphs (b)(1) through (4) of
this section.
(6) 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
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55761
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) Excess emissions and deviation
reporting. 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 40 CFR
63.10(e)(3)(vi). However, starting with
the first calendar quarter of 2024,
reporting of the information under 40
CFR 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 40 CFR
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 part 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 40 CFR
71.6(a)(3)(iii)(A). If an affected source
submits a semiannual compliance report
pursuant to 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 40 CFR
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
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day Hg LEE demonstration tests and PM
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 40 CFR 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 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 30boiler 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
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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.
(3) [Reserved]
(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 section 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, (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
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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 40 CFR 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 40 CFR 63.10042, then, for
startup and shutdown incidents that
occur on or prior to December 31, 2023,
you must include the information in 40
CFR 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 40 CFR
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 40 CFR 63.10031(c)(5)
and 40 CFR 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 November 9, 2020, 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
November 9, 2020, 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 paragraph
(f)(6)(i) through (xii) of this section must
be entered into ECMPS with the PDF
report.
(k) If you elect to demonstrate
compliance using a PM CPMS or an
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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 paragraph
(f)(6)(i) through (xii) of this section must
be entered into ECMPS with the PDF
report.
■ 11. Section 63.10032 is amended by
revising paragraphs (a) introductory text
and (a)(1) to read as follows:
§ 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 40 CFR 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 40 CFR
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.
*
*
*
*
*
■ 12. Section 63.10042 is amended by:
■ a. In the definition ‘‘Diluent cap’’
adding the word ‘‘PM,’’ after the word
‘‘HF,’’;
■ b. In the definition ‘‘Monitoring
system malfunction or out of control
period’’ removing the words ‘‘or out of
control period’’; and
■ c. Adding the definition ‘‘Out of
control period’’ in alphabetical order.
The addition reads as follows:
§ 63.10042
subpart?
What definitions apply to this
*
*
*
*
*
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.
*
*
*
*
*
■ 13. 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 coalfired, liquid oil-fired (excluding limiteduse 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 limited-use liquid oil-fired
subcategory units), or solid oilderived fuel-fired EGU during
startup.
*
*
*
*
*
a. You have the option of complying using either of the following work practice standards:
(1) If you choose to comply using paragraph (1) of the definition of ‘‘startup’’ in § 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 § 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 § 63.10011(g) and § 63.10021(h) and (i). If you
elect to use paragraph (2) of the definition of startup in 40 CFR 63.10042, you must report the applicable information in 40 CFR 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
40 CFR 63.10031(i).
(2) If you choose to comply using paragraph (2) of the definition of ‘‘startup’’ in § 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 § 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
§ 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 PM control(s) within 1 hour of first firing of coal, residual
oil, or solid oil-derived fuel.
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TABLE 3 TO SUBPART UUUUU OF PART 63—WORK PRACTICE STANDARDS—Continued
*
*
*
If your EGU is . . .
*
*
*
*
*
*
You must meet the following . . .
4. A coal-fired, liquid oil-fired (excluding limited-use liquid oil-fired
subcategory units), or solid oilderived fuel-fired EGU during
shutdown.
*
*
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.
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 § 63.10020(a) and (e). You
must keep records during startup periods, as provided in §§ 63.10021(h) and 63.10032. You must
provide reports concerning activities and startup periods, as specified in §§ 63.10011(g),
63.10021(i), and 63.10031. If you elect to use paragraph (2) of the definition of startup in 40 CFR
63.10042, you must report the applicable information in 40 CFR 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 40 CFR 63.10031(i).
You must operate all CMS during shutdown. You must also collect appropriate data, and you must calculate the pollutant emission rate for each hour of shutdown for those pollutants for which a 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 § 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 § 63.10020(a). You must keep records during shutdown periods, as
provided in §§ 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 §§ 63.10011(g), 63.10021(i), and 63.10031. If you elect to use paragraph (2) of the definition of
startup in 40 CFR 63.10042, you must report the applicable information in 40 CFR 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 40 CFR 63.10031(i).
*
14. Table 8 to subpart UUUUU is
revised to read as follows:
■
TABLE 8 TO SUBPART UUUUU OF PART 63—REPORTING REQUIREMENTS
[In accordance with 40 CFR 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 40 CFR 63.10031 (a)(1), if you continuously monitor Hg emissions.
2. The electronic reports required under 40 CFR 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 40 CFR 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 40 CFR 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 40 CFR 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.
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TABLE 8 TO SUBPART UUUUU OF PART 63—REPORTING REQUIREMENTS—Continued
[In accordance with 40 CFR 63.10031, you must meet the following reporting requirements, as they apply to your compliance strategy]
You must submit the following reports . . .
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 the introductory text of 40 CFR 63.10031(f) and 40 CFR
63.10031(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 40 CFR
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 40 CFR 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 40 CFR 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.
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 through 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 through 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 40 CFR 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 40 CFR 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 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 40 CFR 63.10031(c) and (d), in PDF files, according to 40 CFR 63.10031(f)(4) and (6). The
due dates for these reports are specified in 40 CFR 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 40 CFR 63.10031(f)(4) and (6) until December 31, 2023, and according to 40
CFR 63.10031(h) thereafter.
11. Quarterly electronic compliance reports, in accordance with 40 CFR 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 40 CFR 63.10031(c)(5)(ii) and 40 CFR 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 40 CFR 63.10042 (see 40 CFR 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 40 CFR 63.10031(g).
13. A test report for the PS 11 correlation test of your PM CEMS, in accordance with 40 CFR 63.10031(j).
If, prior to November 9, 2020, 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 November 9, 2020, 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 40 CFR 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.
*
*
*
*
*
15. Table 9 to subpart UUUUU is
amended by:
■
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a. Revising the entries ‘‘63.9’’and
‘‘63.10(c)(7) and (8)’’; and
■ b. Adding the entry ‘‘§ 63.10(e)(3)(v)
and (vi)’’.
■
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follows:
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TABLE 9 TO SUBPART UUUUU OF PART 63—APPLICABILITY OF GENERAL PROVISIONS TO SUBPART UUUUU
[*
*
*
Citation
*
*
Subject
*
*]
Applies to subpart UUUUU
*
*
*
§ 63.9 ................................... Notification Requirements .................
*
*
*
*
Yes, except (1) for the 60-day notification prior to conducting a performance test in § 63.9(e); instead use a 30-day notification period per
§ 63.10030(d), (2) the notification of the CMS performance evaluation in
§ 63.9(g)(1) is limited to RATAs, and (3) the information required per
§ 63.9(h)(2)(i); instead provide the applicable information in
§ 63.10030(e)(1) through (8), for the initial notification of compliance status, only.
*
*
*
§ 63.10(c)(7) ........................ Additional recordkeeping requirements for CMS — identifying
exceedances and excess emissions.
§ 63.10(c)(8) ........................ Additional recordkeeping requirements
for
CMS—identifying
exceedances and excess emissions.
*
*
*
Applies only through December 31, 2023.
*
*
*
§ 63.10(e)(3)(v) and (vi) ...... Excess emissions and CMS performance reports.
*
*
*
Applies only through December 31, 2023.
*
*
*
Applies only through December 31, 2023.
*
*
■
16. Appendix A to subpart UUUUU is
amended by revising sections 5.1.1,
7.1.1.2.1, 7.1.3.3, 7.1.4.3, 7.1.8.2, and
7.2.3.1 to read as follows:
electronic monitoring plan shall be evaluated
and submitted using the ECMPS Client Tool
provided by the Clean Air Markets Division
in the Office of Atmospheric Programs of the
EPA.
Appendix A to Subpart UUUUU of Part
63—HG Monitoring Provisions
*
*
*
*
*
*
5. Ongoing Quality Assurance (QA) and Data
Validation
*
*
*
*
*
5.1.1 Required QA Tests. Periodic QA
testing of each Hg CEMS is required
following initial certification. The required
QA tests, the test frequencies, and the
performance specifications that must be met
are summarized in Table A–2, below. All
tests must be performed with the affected
unit(s) operating (i.e., combusting fuel),
however, the daily calibration may optionally
be performed off-line. The RATA must be
performed at normal load, but no particular
load level is required for the other tests. For
each test, follow the same basic procedures
in section 4.1.1 of this appendix that were
used for initial certification.
*
*
*
*
*
7. Recordkeeping and Reporting
*
*
*
*
*
7.1.1.2.1 Electronic. The electronic
monitoring plan records must include the
following: unit or stack ID number(s);
monitoring location(s); the Hg monitoring
methodologies used; emissions controls; Hg
monitoring system information, including,
but not limited to: Unique system and
component ID numbers; the make, model,
and serial number of the monitoring
equipment; the sample acquisition method;
formulas used to calculate Hg emissions; and
Hg monitor span and range information. The
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*
*
*
*
7.1.3.3 The hourly Hg concentration, if a
quality-assured value is obtained for the hour
(mg/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
(mg/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.
*
*
*
*
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*
*
*
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 previouslycertified 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 section
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.
*
*
*
*
*
17. Appendix B to subpart UUUUU is
amended by:
■ a. Revising the heading and
introductory text of section 2.3;
■ b. Revising 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;
■
*
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
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c. Adding sections 10.1.8.1.4 through
10.1.8.1.12;
■ d. Revising sections 11.3.1, 11.4
introductory text, and 11.4.1;
■ e. Adding sections 11.4.1.1 through
11.4.1.9;
■ f. Revising section 11.4.2 introductory
text;
■ g. Revising sections 11.4.3.11 and
11.4.3.12;
■ h. Re-designating section 11.4.3.13 as
11.4.3.14;
■ i. Adding new section 11.4.3.13;
■ j. Re-designating section 11.4.4 as
11.4.13;
■ k. 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;
11.4.12.1 through 11.4.12.9; and 11.4.13;
and revising 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 30boiler 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
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
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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, 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, 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 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, 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
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the test. For each required daily beam
intensity check of an IP–CEMS under
Procedure 6, 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 (ME) 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 ME at each gas level and
the related calculations. For ME 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 ME/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
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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. Keep records of
the raw field data, relevant process operating
data, and the calculations used to determine
the relative accuracy.
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 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.
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*
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11. Reporting Requirements
*
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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
of initial certification testing of the CEMS.
Also submit the monitoring plan information
in section 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.
*
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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
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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;
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,
report:
*
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11.4.3.11 Standard deviation, using either
Equation 2–4 in section 12.3 of PS 2 in
appendix B to part 60 of this chapter or
Equation 10 in section 12.6.5 of PS 18;
11.4.3.12 Confidence coefficient, using
either Equation 2–5 in section 12.4 of PS 2
in appendix B to part 60 of this chapter or
Equation 11 in section 12.6.6 of PS 18;
11.4.3.13 t-value; and
11.4.3.14 Relative Accuracy. For FTIR
monitoring systems following PS 15,
calculate the relative accuracy using
Equation 2–6 of PS 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, calculate the
relative accuracy according to section 12.6 of
PS 18. If applicable use a flag to indicate that
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the alternative relative accuracy specification
for low emitters has been applied.
11.4.4 For each 3-level ME 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;
11.4.4.6 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 PS 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 (temperature
or pressure);
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:
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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 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 (seven 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 RAA of an HCl
monitor, report:
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 and
CEMS values for each test run, including the
units of measure;
11.4.10.6 The mean reference method and
CEMS values for the three test runs;
11.4.10.7 The calculated relative
accuracy, 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
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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;
11.4.11.6 ME at each reference gas level;
and
11.4.11.7 Reason for test.
11.4.12 For each quarterly DSA 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 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.
*
*
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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.
*
*
*
*
*
18. Subpart UUUUU of part 63 is
amended by adding appendix C 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 PM emissions from
affected EGUs under this subpart. A PM
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CEMS is used together with other CMS 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 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 section 75.24 of this chapter.
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, 40 CFR 63.10010(a) specifies
the appropriate location(s) at which to install
CMS. These CMS installation provisions
apply to the PM CEMS and to the other CMS
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.
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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 40 CFR 63.10010 and Section
2.4 of PS–11.
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 °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
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 Table 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 CMS
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
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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 the effective date of this subpart 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 section 75.20 of this chapter
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 section 75.20(b)
of this chapter.
4.3 Development of a New or Revised
Correlation Curve. You must develop a new
or revised correlation curve if:
4.3.1 An 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 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 PS 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 4
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, below). When a
required annual RRA is done within a grace
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period, the deadline for the next RRA is 4
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
12 calendar quarters. If a required RCA is not
completed within 12 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,
below). When an RCA is done in a grace
period, the deadline for the next RCA shall
be 12 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 1 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 ongoing 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 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
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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.
5.3.2.1 Daily, and Quarterly Quality
Assurance 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.
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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 Caculations
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) of this chapter.
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) of
this chapter.
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
40 CFR 75.10(d)(1) of this chapter. 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 40 CFR 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 PM 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, below (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 °C), you must first use
one of the following equations to convert the
hourly PM concentration values from actual
to standard conditions:
Ps = Stack Pressure (in. Hg)
Tstd = Standard Temperature (68 °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
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
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Where:
Cstd = PM concentration at standard
conditions
Ca = PM concentration at measurement
conditions
Ts = Stack Temperature (°F)
TCEMS = CEMS Measurement Temperature
(°F)
PCEMS = CEMS Measurement Pressure (in.
Hg)
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concentration by 6.24 × 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 section 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 40 CFR 63.10042 and specified
in 40 CFR 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 fuelspecific default moisture value from 40 CFR
75.11(b) of this chapter, or a site-specific
default moisture value approved by the
Administrator under section 75.66 of this
chapter.
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 to calculate the gross
output-based PM emission rate (if
applicable). Use Equation C–4 if Cstd is
measured on a dry basis:
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 × 10¥8 = Conversion factor
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 × 10¥8 = Conversion factor
6.2.4 You must calculate the 30–boiler
operating day rolling average PM emission
rates according to 40 CFR 63.10021(b).
7. Recordkeeping and Reporting
7.1 Recordkeeping Provisions. For the PM
CEMS and the other necessary 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 40 CFR 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 (DAHS)) 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) of
this chapter.
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); and
appropriate default values. Your electronic
monitoring plan shall be evaluated and
submitted using the 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 1
hundredth to 1 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 drybasis 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
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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 of this chapter.
7.1.4 Stack Gas Volumetric Flow Rate
Records.
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) of this chapter.
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) of
this chapter.
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) of this chapter.
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
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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 40 CFR
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 40 CFR
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 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
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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) of this chapter.
7.1.11 For each temperature measurement
device (e.g., resistance temperature detector
or thermocouple) and pressure measurement
device used to convert measured PM
concentrations to standard conditions
according to Equation C–1 or C–2, 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
quality assurance 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 40 CFR
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
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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 quality assurance 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 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 quality
assurance 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 quality assurance 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
until a successful quality assurance test
report is submitted. If a correlation test is
unsuccessful, you may not report quality-
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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 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 section 72.2 of this chapter).
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 quality
assurance 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.
19. Subpart UUUUU of part 63 is
amended by adding appendix D, 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 PM CPMS,
for the purpose of assessing continuous
compliance with an applicable emissions
limit in Table 1 or Table 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
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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 40 CFR
63.10010(h)(1)(i) through (iii) and 40 CFR
63.10023(b)(2)(iii) and (iv). In addition, an
automated 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 40 CFR
63.10010(a).
2.3 Determination of Operating Limits.
2.3.1 In accordance with 40 CFR
63.10007(a)(3), 40 CFR 63.10011(b), 40 CFR
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 Table 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 40 CFR
63.10005(d)(2)(i), you must perform the
initial stack test no later than the applicable
date in 40 CFR 63.9984(f), and according to
40 CFR 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 40 CFR 63.10023(b)(1) for
existing units, and 40 CFR 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
40 CFR 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 40 CFR
63.10010(h)(3) through (6), 40 CFR
63.10021(c), and Table 7 to this subpart.
2.4.3 In accordance with 40 CFR
63.10005(d)(2)(ii), 40 CFR 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 40 CFR
63.10021(c)(1) and (2).
3. RECORDKEEPING AND REPORTING.
3.1 Recordkeeping Provisions. You must
keep the applicable records required under
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40 CFR 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
40 CFR 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 63.10000(d).
3.1.1.2 In addition to the site-specific
monitoring plan required under 40 CFR
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 DAHS) 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 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 1
hundredth to 1 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-ofcontrol 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-ofcontrol 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
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and a valid value of the output parameter is
not obtained; and
3.1.3.5 Percent monitor data availability
for the PM CPMS, calculated in the manner
established for SO2, CO2, O2 or moisture
monitoring systems according to section
75.32 of this chapter.
3.1.4 Records of PM CPMS Audits and
Out-of-Control Periods. In accordance with
40 CFR 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 40 CFR 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 40 CFR
63.10000(d), you must submit the sitespecific 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
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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 section 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 Table 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 40 CFR
63.10031(g); and
3.2.5.2 Provide a complete stack test
report as a PDF file, in accordance with 40
CFR 63.10031(f) or (h), as applicable.
20. Subpart UUUUU of part 63 is
amended by adding appendix E, 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 40 CFR 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:
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2.1 Energy Information Administration’s
Office of Regulatory Information Systems
(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 onschedule according to 40 CFR 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
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 Quality Assurance Parameters: For
key parameters that are used to quality-assure
the reference method data (including, as
applicable, filter temperature, percent
isokinetic, leak check results, percent
breakthrough, percent 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;
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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 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 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 fuelfired 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. If subject to
an emissions limit, 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;
11.4 New Fuel Type Indicator (if
applicable); and
11.5 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 and Monitoring
Downtime. If there were any deviations or
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monitoring downtime 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;
13.2.6 Monitoring downtime incurred; or
13.2.7 Other requirement not met.
13.3 A description of the deviation, or
monitoring downtime, 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 periods where valid
monitoring data are not reported during the
reporting period, record the monitored
parameter, the total source operating time
(hours), and the total number of hours of
monitoring deviation or downtime and other
information, as indicated, for:
13.3.3.1 Monitoring system malfunctions/
repairs (deviation and downtime);
13.3.3.2 Out-of-control periods/repairs
(deviation and downtime);
13.3.3.3 Non-monitoring equipment
malfunctions (downtime);
13.3.3.4 QA/QC activities (excluding zero
and span checks) (downtime);
13.3.3.5 Routine maintenance
(downtime);
13.3.3.6 Other known causes (downtime);
and
13.3.3.7 Unknown causes (downtime).
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 and/or no
monitoring downtime 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);
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14.2 Each 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, RRA and each
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, 2, 3A, 4, 5, 5D, 6C, 26, 26A, 29,
and/or 30B.
16.1 Application of EPA test Methods 1
and 2. 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 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 EPA test
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.
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16.2 Application of EPA test Method 3A.
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 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.
16.3 Application of EPA test Method 4.
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 calculations (to
determine the molecular weight of the gas)
and for the RATA of an Hg CEMS that
measures on a wet basis, when EPA test
Method 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 EPA test Method 19 equations
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 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
is used, EPA test Method 4 must be
performed separately.
16.4 Applications of EPA test Methods 5
and 5D. 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.
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 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. 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 PS 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.
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16.7 Applications of EPA test Method 29.
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. 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 40 CFR
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. 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 test is conducted in
order to convert a pollutant concentration to
the units of the applicable emission standard
given in Table 1 or Table 2 of 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;
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17.13 EPA Facility Registration System
Number;
17.14 Source Classification Code;
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, PM CPMS
operating limits, if applicable).
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.);
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.
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 HAP metals and total HAP metals,
report only the run-level data elements (19.1,
19.3 through 19.30, and 19.38 through 19.41),
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;
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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. 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 (DP);
20.4 Orifice Pressure Reading (DH);
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
Methods 29 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 runlevel data elements 19.1 through 19.34 in
Section 19, and the point-level data elements
in Section 20. 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,
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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 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):
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 HAP 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 HAP 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 HAP metals in units
of lbs/MMBtu or lbs/MW (per Table 5):
21.9.1 Pollutant Name;
21.9.2 Pollutant Emission Rate; and
21.9.3 Pollutant Emission Rate Units of
Measure.
21.10 Total HAP 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 HAP metals concentration
21.11.1 Pollutant Name;
21.11.2 Pollutant Concentration; and
21.11.3 Pollutant Concentration Units of
Measure.
21.12 Total HAP metals Emission Rate in
Units of the Standard:
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21.12.1 Pollutant Name;
21.12.2 Pollutant Emission Rate; and
21.12.3 Pollutant Emission Rate Units of
Measure.
21.13 Total HAP metals Emission Rate in
lbs/MMBtu or lbs/MW (per Table 5):
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. 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
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. 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 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. You must report Source ID (i.e. Data
Element 18.1) and the following run-level
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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;
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. 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:
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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. 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 of 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 Span (High-Level) Gas
Concentration;
26.14 Calibration High-Level Cylinder
Expiration Date;
26.15 Low-Level Gas Response;
26.16 Low-Level Calibration Error;
26.17 Low-Level Alternate Performance
Specification (APS) Flag;
26.18 Mid-Level Gas Response;
26.19 Mid-Level Calibration Error;
26.20 Mid-Level APS Flag;
26.21 High-Level Gas Response;
26.22 High-Level Calibration Error; and
26.23 High-Level APS Flag.
27.0 Run-Level Data Elements for EPA
test Methods 3A and 6C. 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 of
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;
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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;
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. 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., Data
Element 18.1) and following run-level data
elements for each EPA test Method 2 test run:
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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. 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 pointlevel data elements:
29.1 Traverse Point ID;
29.2 Stack Temperature; and
29.3 Differential Pressure Reading (DP).
30.0 Run-Level Data Elements for EPA
test Method 4. 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;
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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 40 CFR
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, quality assurance data
(e.g. field recovery spikes) and any required
audit results and stack testers’ credentials (if
applicable). The applicable data elements in
40 CFR 63.10031(f)(6)(i) through (xii) of this
section must be entered into ECMPS with
each PDF submittal; the test number(s) (see
40 CFR 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. 2020–15950 Filed 9–8–20; 8:45 am]
BILLING CODE 6560–50–P
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[Federal Register Volume 85, Number 175 (Wednesday, September 9, 2020)]
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[Pages 55744-55780]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2020-15950]
[[Page 55743]]
Vol. 85
Wednesday,
No. 175
September 9, 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; Final Rule
Federal Register / Vol. 85, No. 175 / Wednesday, September 9, 2020 /
Rules and Regulations
[[Page 55744]]
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ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 63
[EPA-HQ-OAR-2018-0794; FRL-10011-53-OAR]
RIN 2060-AU70
Mercury and Air Toxics Standards for Power Plants Electronic
Reporting Revisions
AGENCY: Environmental Protection Agency (EPA).
ACTION: Final rule.
-----------------------------------------------------------------------
SUMMARY: The U.S Environmental Protection Agency (EPA) is finalizing
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 action revises and streamlines the
electronic data reporting requirements of MATS, increases data
transparency by requiring use of one electronic reporting system
instead of two separate systems, and provides enhanced access to MATS
data. No new monitoring requirements are imposed by this final action;
instead, this action reduces reporting burden, increases MATS data flow
and usage, makes it easier for inspectors and auditors to assess
compliance, and encourages wider use of continuous emissions monitoring
systems (CEMS) for MATS compliance. In addition, this final action
extends the current deadline for alternative electronic data submission
via portable document format (PDF) files through December 31, 2023.
DATES: This final rule is effective on September 9, 2020.
ADDRESSES: The EPA has established a docket for this action under
Docket ID No. EPA-HQ-OAR-2018-0794. All documents in the docket are
listed on the https://www.regulations.gov/ website. Although listed,
some information is not publicly available, e.g., Confidential Business
Information or other information whose disclosure is restricted by
statute. Certain other material, such as copyrighted material, is not
placed on the internet and will be publicly available only in hard copy
form. Publicly available docket materials are available electronically
through https://www.regulations.gov/. Out of an abundance of caution
for members of the public and our staff, the EPA Docket Center and
Reading Room was closed to the public, with limited exceptions, to
reduce the risk of transmitting COVID-19. Our Docket Center staff will
continue to provide remote customer service via email, phone, and
webform. For further information and updates on EPA Docket Center
services and the current status, 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; email address: [email protected]. 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. General Information
A. Does this action apply to me?
B. Where can I get a copy of this document and other related
information?
C. Judicial Review and Administrative Reconsideration
D. What action is the Agency taking?
E. What is the Agency's authority for taking this action?
F. What are the incremental costs and benefits of this action?
II. Background
III. What is the scope of these amendments?
IV. What are the specific amendments to 40 CFR part 63, subpart
UUUUU as a result of this action?
A. 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
V. Revisions to Other Rule Text
VI. 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
L. Congressional Review Act (CRA)
I. General Information
A. Does this action apply to me?
Categories and entities potentially affected by this action
include:
------------------------------------------------------------------------
Examples of potentially
Category NAICS code \1\ regulated entities
------------------------------------------------------------------------
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.
------------------------------------------------------------------------
\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 the 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
[[Page 55745]]
entity is regulated by this 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. Where can I get a copy of this document and other related
information?
In addition to being available in the docket, an electronic copy of
this final action will also be available on the internet. Following
signature by the EPA Administrator, the EPA will post a copy of this
final action at: https://www.epa.gov/mats/regulatory-actions-final-mercury-and-air-toxics-standards-mats-power-plants. Following
publication in the Federal Register, the EPA will post the Federal
Register version and key technical documents at this same website.
C. Judicial Review and Administrative Reconsideration
Under Clean Air Act (CAA) section 307(b)(1), judicial review of
this final action is available only by filing a petition for review in
the United States Court of Appeals for the District of Columbia Circuit
by November 9, 2020. Under CAA section 307(b)(2), the requirements
established by this final rule may not be challenged separately in any
civil or criminal proceedings brought by the EPA to enforce the
requirements.
Section 307(d)(7)(B) of the CAA further provides that only an
objection to a rule or procedure which was raised with reasonable
specificity during the period for public comment (including any public
hearing) may be raised during judicial review. This section also
provides a mechanism for the EPA to reconsider the rule if the person
raising an objection can demonstrate to the Administrator that it was
impracticable to raise such objection within the period for public
comment or if the grounds for such objection arose after the period for
public comment (but within the time specified for judicial review) and
if such objection is of central relevance to the outcome of the rule.
Any person seeking to make such a demonstration should submit a
Petition for Reconsideration to the Office of the Administrator, U.S.
Environmental Protection Agency, Room 3000, WJC South Building, 1200
Pennsylvania Ave. NW, Washington, DC 20460, with a copy to both the
person(s) listed in the preceding FOR FURTHER INFORMATION CONTACT
section, and the Associate General Counsel for the Air and Radiation
Law Office, Office of General Counsel (Mail Code 2344A), U.S.
Environmental Protection Agency, 1200 Pennsylvania Ave. NW, Washington,
DC 20460.
D. What action is the Agency taking?
The EPA is finalizing 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).
E. 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.
F. What are the incremental costs and benefits of this action?
As discussed in section VI.C of this preamble, this action is
expected to reduce overall annual source burden by 11,000 hours per
year, which when monetized is $15,079,000.
II. Background
These amendments 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 ECMPS Client Tool to submit
monitoring plan information, quality assurance (QA) 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), (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
[[Page 55746]]
reports. Section 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.
---------------------------------------------------------------------------
\1\ 81 FR 67062, September 29, 2016.
---------------------------------------------------------------------------
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 complete 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).
The Agency continued to develop the remaining electronic reporting
and recordkeeping requirements, considering the comments received on
the September 29, 2016 (81 FR 67062) proposal. When that effort was
complete, rather than finalizing those requirements, the Agency decided
to again provide stakeholders with an opportunity to review and comment
on the requirements, so the Agency issued a proposal with those
requirements on April 10, 2020 (85 FR 20342).
Thirty-five comment letters were received, and they are available
in the docket. Many of those comments were similar to comments
submitted before in other proposals and have been addressed previously.
Responses for the comments on this action are included in the Response
to Comments document which is also available in the docket. Significant
comments can be sorted into eight groups; their general descriptions
and responses follow.
1. Comments received on other MATS regulatory actions, e.g.,
removal of the appropriate and necessary determination, are not
relevant for this action and were not addressed. Likewise, comments
regarding other regulatory actions, e.g., insecticides and pesticides,
are not relevant for this action and were not addressed.
2. A majority of commenters supported extending the use of PDF
reporting until January 2024. Many industry commenters suggested
splitting the package so the extension could be finalized, and more
time could be spent on reviewing the other portions of the package. The
Agency is not splitting the package and appreciates the support for the
extension until the ECMPS Client Tool is reprogrammed and ready for
use. The Agency sees no need for additional time to comment on the
proposed revisions, as those revisions have been available for review
and comment for over 3 years--since the September 29, 2016, proposal.
3. Commenters sought clarification on the conditions that would
cause monitoring downtime to be considered a deviation, and the
regulation provides that clarification.
4. Industry commenters sought to have consistent application of
grace periods and ongoing QA check periods (based on operating quarters
only) for PM CEMS and PM CPMS; however, these instruments differ from
other CEMS because except for the annual testing, there is no other
time when the monitoring system is compared to a certified reference
method value to determine accuracy. This difference means that
techniques allowing for additional periods before testing is required
puts EGU owners or operators, as well as the environment, at additional
risk of elevated emissions during such periods. Due to this difference,
and its potential effects, the regulation will not provide grace
periods beyond 1 calendar quarter or ongoing QA checks based on
operating quarters only.
5. Commenters sought clarification on Hg low-emitting EGU (LEE)
testing calculations, and the regulation provides such clarification in
40 CFR 63.10005(h)(3)(iii).
6. Some commenters continue to assert that data elements in
appendix E are duplicative, but as described before, those data
elements are already required and represent the minimum bits of
information needed to ensure smooth operation of an electronic
reporting system. Even so, clarifications from already-mentioned
deviation and monitoring downtime circumstances, as well as for
reporting span values and fuel usage, have been provided in appendix E.
7. One commenter asked the Agency to reconsider allowing the use of
alternate semi-annual reporting submission dates established by
operating permit programs, at least until the ECMPS Client Tool is
operational; the Agency agrees that this flexibility should be
maintained during the extension period, and the rule has been revised
to allow use of such alternate semi-annual reporting dates.
8. Finally, some commenters requested continued engagement with
stakeholders as the new ECMPS Client Tool software is developed and
tested. Consistent with previous ECMPS reporting instructions changes
and the implementation of previous MATS reporting changes, the Agency
will
[[Page 55747]]
provide draft reporting instructions and XML schema documentation prior
to implementation and engage stakeholders during the development and
testing of software.
This action finalizes an extension of the interim PDF reporting
process through December 31, 2023, and finalizes the remaining needed
amendments to the MATS rule on electronic reporting. Note that these
amendments were developed after consideration of the comments received
on the September 29, 2016, and April 10, 2020, proposals. III. What is
the scope of these amendments?
This action amends the reporting requirements in 40 CFR 63.10031 of
the MATS regulation, and, for consistency with those changes, amends
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. In addition, the
recordkeeping and reporting sections of appendices A and B are amended
\2\ and three new appendices are 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 action allows EGU owners or operators to use the ECMPS
Client Tool to report all of the required information in XML and PDF
files.
---------------------------------------------------------------------------
\2\ In 2015, the EPA published a technology-neutral performance
specification and associated QA test procedures for HCl monitors
(see Performance Specification 18 (PS 18) and 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 action requires the results of the appendix B
certification and QA tests to be reported electronically for periods
beginning on January 1, 2024.
---------------------------------------------------------------------------
IV. What are the specific amendments to 40 CFR part 63, subpart UUUUU
as a result of this action?
The amendments to 40 CFR part 63, subpart UUUUU are discussed in
detail in the paragraphs below.
A. Revisions to the Reporting Requirements of MATS
The reporting requirements of MATS are amended as follows:
(1) The ECMPS Client Tool is 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) is extended through December 31, 2023, to allow sufficient
time for software development, programming, and testing. Until then,
compliance with the emissions and operating limits will 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 is 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 is required 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) states that PDF submittals are still
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
covers the period from July 1, 2023, through December 31, 2023; the
deadline for submitting this report is January 30, 2024, and the report
is submitted using the interim PDF reporting process.
(4) Revised paragraph (f)(2) of 40 CFR 63.10031 expands 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)
are 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 are
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
clarify the electronic reporting requirements for the Hg, HCl, HF,
SO2, and additional CMS. Specifically:
(i) Paragraph (a)(1) requires the electronic reporting requirements
of appendix A to be met if Hg CEMS or sorbent trap monitoring systems
are used.
(ii) Paragraph (a)(2) requires 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
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 QA of the
monitor, EGU owners or operators will 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 are 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 adds the necessary recordkeeping and reporting
requirements, and the interim reporting for HCl will be discontinued as
of January 1, 2024 (for further discussion, see section IV.C of this
preamble).
(iii) Paragraph (a)(5) clarifies the electronic reporting
requirements for the SO2 CEMS and the additional 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 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 are
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) is removed and reserved).
(6) Paragraphs (b)(1) and (2) of 40 CFR 63.10031 are amended to
recognize that some EGUs may have received extensions of their
compliance date under 40 CFR 63.6(i)(4). References to
[[Page 55748]]
postmark dates for submittal of semiannual compliance reports
paragraphs are removed from paragraphs (b)(2) and (4); these reports
currently are, and 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 allows affected
EGU owners or operators to follow alternate submission schedules for
semiannual compliance reports are discontinued when the interim PDF
reporting period ends. When that interim PDF reporting period ends, the
uniform submission schedule described in 40 CFR 63.10031(b)(1) through
(4) is required for all affected EGUs, so that compliance with this
reporting requirement can easily be tracked.
(8) New 40 CFR 63.10031(b)(6) will require EGU owners or operators
to discontinue submission of semiannual compliance reports when the
interim PDF reporting period ends. The final semiannual compliance
report covers the period from July 1, 2023, through December 31, 2023.
(9) EGU owners or operators submit quarterly compliance reports in
lieu of the semiannual compliance reports, starting with reports
covering the first quarter of 2024 (see 40 CFR 63.10031(g)). The
quarterly compliance reports 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 will be due within 60 days after the end of each
calendar quarter, which allows 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
includes 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 are 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 include all of
the 30- or 90-day averages calculated during the quarter. If emissions
averaging were used, EGU owners or operators 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 LEE
tests and PM tests to set operating limits for PM CPMS), the EGU owner
or operator reports 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 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, 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 amendments 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 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 is
retained in the quarterly compliance reports. Specifically, the
revisions to 40 CFR 63.10031(d) 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 reported in the
description of certain deviations or monitoring downtime (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 makes 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. In
response to comments received, these instructions have been modified
from a previous draft version.
(10) A new paragraph (c)(10) is added to section 63.10031 and
requires 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) requires 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) has been renamed as paragraph (c)(10) and is added to the list of
information that must be included in the semiannual reports. The
introductory text of paragraph (c) is also amended, to recognize the
addition of paragraph (c)(10).
(11) For consistency with the reporting requirements for the other
CMS, the regulation does not require source owners or operators using
PM CPMS to submit separate quarterly excess emission summary reports in
addition to the quarterly compliance reports. After careful
consideration of comments on the previous proposal, we are persuaded
that sufficient information to assess compliance with the operating
limits of a PM CPMS will be provided 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
[[Page 55749]]
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.
Table 9 to 40 CFR part 63, subpart UUUUU is amended 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 63.7(c)(8), 63.10(c)(7),
and 63.10(e)(3) ends 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. We thought the April proposal addressed
this concern, but other commenters asked for clarification during the
current comment period. As the Agency meant to exempt periods of
routine QA or quality control (QC) and routine maintenance from
deviation reporting but not from monitoring downtime reporting,
language in 40 CFR 63.10010(h)(5), (i)(4), and (j)(4) has been
clarified, along with the clarifications to 40 CFR 63.10020(b) and (d),
40 CFR 63.10010(h)(6)(i) and (ii), (i)(5)(i) and (ii), and (j)(4)(i)(A)
and (B) that were proposed in April. We also clarified the
corresponding data elements in section 13 of Appendix E.
In response to comments for clarification concerning reporting of
QA test results, which the Agency maintains is mandatory for all CMS,
the regulation has been amended at 40 CFR 63.10010 to remove the last
sentence in paragraphs (h)(6)(i), (j)(4)(i)(A) and (B); to require the
monitoring system performance evaluations of PM CPMS and HAP metals
CEMS be reported in paragraphs (h)(7) and (j)(4)(ii), respectively; to
require the QA/QC activities for PM CPMS and HAP metals CEMS be
reported quarterly in PDF files in 40 CFR 63.10031(k); and to cross-
reference the appropriate sections of appendix C, regarding the
certification, operation, maintenance, on-going QA, recordkeeping, and
reporting requirements for PM CEMS in 40 CFR 63.10010(i).
(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 rule retains 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 is 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, EGU owners or operators will 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 will be required to 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 is provided in a PDF file for each test. The appendix E
information is 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 is also 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
November 9, 2020, the report is due no later than 60 days after that
date. For correlation tests completed on or after November 9, 2020, but
prior to January 1, 2024, the report is due within 60 days after the
date on which the test is completed. (Note: For correlations completed
on and after January 1, 2024, in lieu of a PDF report, the test results
are 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 40
CFR 63.10020(e) for startup and shutdown incidents, if an EGU owner or
operator is 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 is 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) are entered into the
ECMPS Client Tool at the time of submission of each PDF file. Note that
the amendment to data element (xii) replaces the word ``conducted''
with the word ``completed.''
(17) Although the ECMPS Client Tool is used to submit the required
reports and notifications described in revised 40 CFR 63.10031 and
Table 8, ECMPS does 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 are transmitted
directly through the EPA's Central Data Exchange using CEDRI unaltered.
ECMPS does, 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 uses
the results of these evaluations to assess the quality-assured status
of the Hg, HCl, HF, SO2, or PM emissions data. In addition,
ECMPS performs basic checks of the information in the quarterly
compliance reports, e.g., checking for completeness and proper
formatting, but leaves 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 improper RATA results in
invalidation of hourly emissions data, from the expiration of the grace
period until a valid RATA is performed and
[[Page 55750]]
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
Based on comments received, six sections of appendix A, i.e.,
sections 5.1.1, 7.1.1.2.1, 7.1.3.3, 7.1.4.3, 7.1.8.2 and 7.2.3.1 are
amended and described, here. The requirement in section 5.1.1 regarding
required QA testing is clarified to allow daily calibrations to be
performed offline and to specify that ongoing QA testing other than
RATAs can be performed at no particular load levels.
The requirement in section 7.1.1.2.1 for electronic reporting is
expanded to include emission controls. As part of the re-examination of
the list of data elements that compose a complete test report,
suggested by commenters, this data element was found to be missing in
this section. 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 three significant
figures is revised so that Hg concentrations in micrograms per standard
cubic meter ([micro]g/scm) and Hg emission rates in pounds per trillion
British Thermal Units or pounds per gigawatt-hour are reported with one
leading non-zero digit and one decimal place, in scientific notation.
Conventional rounding is used, i.e., if the digit immediately following
the first decimal place is 5 or greater, the digit in the first decimal
place is 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 remains 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 is revised. For new EGUs or EGUs that install Hg
monitoring systems in order to switch from another MATS-compliant
methodology to Hg monitoring, the monitoring plan information is
submitted at least 21 days prior to the date on which certification
testing begins. However, for EGUs implementing Hg monitoring with a
previously-certified Hg monitoring system, the monitoring plan may be
submitted prior to or concurrent with the first quarterly emissions
report--provided that the monitoring plan is in place when the first
emissions report is submitted so that the ECMPS Client Tool is 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 are promulgated, EGU owners or operators may use any
viable HCl monitoring technology that can meet PS 18. 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, 40 CFR 63.10031(a)(2) is revised, 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 are required to keep records of all of the other
certification and QA tests, which would be reported starting in 2024.
The title to section 2.3 of appendix B is revised 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) are amended. Based on comments received, sections 10.1.3.3 and
10.1.7.2, HCl and HF concentrations ([micro]g/scm) and emission rates
(lb/MMBtu or lb/MWh) are reported with one leading non-zero digit and
one decimal place, in scientific notation, rather than reporting the
concentrations and rates to three significant figures. Conventional
rounding is used, i.e., if the digit immediately following the first
decimal place is 5 or greater, the digit in the first decimal place is
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 remains unchanged. Sections 10 and 11 also specify the data
elements that are recorded and reported for each of the tests required
by PS 18 and Procedure 6. The revisions 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 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 introduce no unnecessary
reporting burden. The results of certification and on-going QA tests
are 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 are required for all HCl monitors. For
example, some of the tests (i.e., beam intensity, temperature, and
pressure verifications) are specific to integrated path-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)
are 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 are submitted along with the electronic summary of
results required under section 11 of appendix B. To the extent
practicable, these data are 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
[[Page 55751]]
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 allows 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 is 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 change from
provisional to quality-assured, and no further action is required.
However, if the test is unsuccessful, the provisional data are
invalidated, and resubmission of the affected emissions report(s) is
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, section 11.5.1
of appendix B now clarifies 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 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
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 is 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 is 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 must 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 may be submitted prior to or concurrent with the first
quarterly emissions report.
Section 11.4.13 clarifies the reporting requirements for stack gas
flow rate, moisture, and diluent gas monitoring systems that are used
for certification, recertification, diagnostic, and QA tests are from
section 10.1.8.2 of this appendix; such systems are also certified and
quality-assured according to 40 CFR part 75 of this chapter.
D. Addition of Appendix C
A new appendix, i.e., appendix C, is 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 includes provisions for installation and certification of
the PM CEMS, and for on-going QA of the data from the CEMS. The
monitoring system is 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 is being required.
After consideration of comments received, the EPA has concluded
that all PM concentrations will 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 are recorded and
reported in mg/acm. Section 7.1.9.5 of appendix C also requires 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 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 concentrations and rates to three significant figures.
Conventional rounding is used, i.e., if the digit immediately following
the first decimal place is 5 or greater, the digit in the first decimal
place is 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 remains unchanged.
The 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 follows the
familiar calendar quarter and grace period reporting plan. An RRA is
required once every 4 calendar quarters and an RCA is required once
every 12 calendar quarters. A grace period is provided (i.e., 720
operating hours or 1 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
allows the use of provisional data for up to 60 days after completion
of an RRA, RCA, or PM CEMS correlation test.
The 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 recordkeeping and reporting
requirements are found in section 7. Section 7.1 requires monitoring
plan records and hourly records of operating parameters, PM
concentration, diluent gas concentration, stack gas flow rate and
moisture content, and PM emission rates are kept. Sections 7.2.3 and
7.2.4, respectively, require monitoring plan information and the
results of certification, recertification, and QA tests are reported
electronically. For consistency with these revisions to appendices A
and B, section 7.2.3.1 specifies 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 is submitted
at least 21 days prior to the commencement of certification testing.
However, for EGUs with previously-certified PM CEMS that elect to
implement PM monitoring, the monitoring plan information may be
submitted prior to or concurrent with the first quarterly emissions
report. Section 7.2.5 requires quarterly electronic emissions reports
are submitted within 30 days after the end of each calendar quarter.
All electronic reports are submitted using the ECMPS Client Tool.
However, for EGUs that began 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
[[Page 55752]]
data, and the applicable reference method data in appendix E does not
begin until January 1, 2024, to allow time for software development and
beta testing. Until then, records of the required information and tests
are kept. For EGUs that certify and begin using PM CEMS on or after
January 1, 2024, reporting of hourly PM emissions data begin with the
first operating hour after successful completion of the initial PM CEMS
correlation test.
For PM CEMS correlations, RRAs, and RCAs completed on and after
January 1, 2024, the applicable reference method data in sections 17
through 31 of appendix E are 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 are 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
allows 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 is 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 would be invalidated, and
resubmission of the affected emission report(s) is required.
E. Addition of Appendix D
A new appendix, i.e., appendix D, is added to subpart UUUUU of 40
CFR part 63. Appendix D sets 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 is 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 requires the ECMPS Client Tool to be used to create
and maintain an electronic monitoring plan. The PM CPMS is defined as a
monitoring system with a unique system ID number. The monitoring plan
also includes 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.
The rule requires 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 are 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 is required to indicate operating hours in which valid data are
not obtained. The percent monitor data availability is 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, require notifications
(provided in accordance with 40 CFR 63.10030) and electronic monitoring
plan submittals at specified times. For EGUs using the PM CPMS
compliance option prior to January 1, 2024, the electronic monitoring
plan information is submitted prior to or concurrent with the first
quarterly report. For EGUs switching to the PM CPMS compliance option
on or after January 1, 2024, the electronic monitoring plan is
submitted no later than 21 days prior to the PM test that establishes
the initial operating limit. Section 3.2.4 requires 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 begins
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 includes 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, the rule requires
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 requires the results of each performance stack test
for PM that is used to establish an operating limit are 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 are also submitted along with the relevant
quarterly compliance report.
F. Addition of Appendix E
A new appendix, i.e., appendix E, is added to subpart UUUUU of 40
CFR part 63. Sections 2 through 13 of appendix E list the data elements
that are 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 are included in the quarterly compliance reports. As noted
in section V.A.(9) of this preamble, updated reporting instructions for
these compliance reports are found in the rule docket.
For reasons stated in the previous proposal's Response to Comments
document (which is available in the rule docket \3\), the basic
provisions of sections 14 through 21 of appendix E, requiring details
of the reference methods used for performance stack tests and CMS
performance evaluations are reported in XML format are retained. The
rule also retains the 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 is 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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\3\ 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 \4\ (the previous proposal), specifically, the
reporting requirements in sections 17 through 21 of proposed appendix
E, the data element lists are
[[Page 55753]]
revised and reformatted to correspond to the compliance options
described in section 16 of appendix E. Explicitly, sections 17 through
30 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 have
been removed from the lists and include:
---------------------------------------------------------------------------
\4\ As mentioned in footnote 1, see 81 FR 67062, 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 draft example instructions are included in the rule
docket.
The reorganized data element lists and corresponding instructions
clarify which data elements are reported for each compliance option and
explain how the data are reported. Several new data elements are in 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 action is expected to reduce overall annual
source burden. The Agency believes that the addition of these data
elements is offset by the removal of others, the change to a consistent
submission frequency, and the 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 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 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 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 PS, whereas an APS flag of ``1'' means that the reported
result is based on the APS.
``Test Comment.'' This text field is 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 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
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 requires 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 degrees 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 must be reported in units consistent with the PM CEMS
correlation curve.
``Average Sampling Rate and Units of Measure.'' These 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 must be reported. The previous proposed rule
only required the leakage rate to be reported.
``Control Device Code.'' This data element refers to the
control device code or control technology National Emission Inventory
code associated with the EGU (or group of EGUs sharing a common stack).
Providing this data element helps in EGU categorization and emission
factor development.
``Corresponding Reference Method(s), if applicable.'' This
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 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
[[Page 55754]]
methods were conducted properly so that emission rates can be
calculated.
``Pollutant Concentration Units of Measure.'' This 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 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 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 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 data elements refer to the total Hg mass measured by
Train A and Train B, respectively, in the appropriate units of measure.
Reporting these values is necessary for QA purposes and for comparison
with the standard.
``Method Detection Limit (MDL).'' This 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 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 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 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
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 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 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 \5\ on the September 29, 2016, proposed rule
(i.e., the previous proposal) suggested that those proposed revisions
included a significant amount of duplicative reporting, which should be
eliminated. In response to the concerns expressed by the commenters,
the Agency examined the XML data element lists twice--once in 2016 and
recently after closure of the current comment period--for stack tests
and CMS performance evaluations, in order to identify duplicative
reporting and eliminate it where possible. The following evaluations
were made:
---------------------------------------------------------------------------
\5\ Commenters 20612, 20597, and 20609 on Docket ID No. EPA-HQ-
OAR-2009-0234.
---------------------------------------------------------------------------
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 nine of these elements (i.e., Source ID (Sampling
Location), Test Number, Run Number, Run Begin Date, and a few others)
are 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 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, the 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 some 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.
V. 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 were made to clarify certain
reporting requirements, to rectify inadvertent omissions, and to
correct inconsistencies. The affected rule sections are as follows:
(a) The introductory text of paragraphs (a)(2), (b), and
(h)(3)(iii) of 40 CFR 63.10005 is revised. The amendment to paragraph
(a)(2) clarifies 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
[[Page 55755]]
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 may be used to determine the stack gas flow rate and moisture
content. Revised section (h)(3)(iii) addresses a commenter's request
for clarification on how to calculate a 30-day Hg LEE test average.
(b) Section 40 CFR 63.10009 is amended as follows. The second and
third sentences in paragraph (a)(2) are 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) is 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'' are
removed from the introductory text of paragraph (b)(2), and in the
nomenclature of Equation 2a, the words ``or sorbent trap monitoring''
are added after the words ``unit i's CEMS'' in the definition of the
term ``Heri.'' Finally, for completeness, Equations 3a and
3b are 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, paragraphs (h)(6) and
(7), (i), (j)(4)(i), and (j)(4)(ii) of 40 CFR 63.10010 are revised to
resolve inconsistencies in the text.
(d) Section 40 CFR 63.10011(e) is revised to require Notifications
of Compliance Status for initial compliance demonstrations include the
information specified in 40 CFR 63.10030(e), and are submitted in
accordance with 40 CFR 63.10031(f)(4) or 40 CFR 63.10031(h), as
applicable. This 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) Sections 40 CFR 63.10011(g)(3), 40 CFR 63.10021(i), and two
sentences in Items 3 and 4 of Table 3 are revised 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) be included in the semiannual
compliance reports, for startup and shutdown incidents that occur
during the interim reporting period. However, in view of the 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 40 CFR 63.10020(e) is required to be provided as
a separate PDF submittal, along with the quarterly compliance report.
As previously noted, the requirements in 40 CFR 63.10031(c)(5)(iii),
(iv), and (v) to report hourly average CEMS and operating parameter
values for startup and shutdown events are not 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) Paragraphs (e)(9), (f), and (h)(3) of 40 CFR 63.10021 are
revised 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. References to the EPA's ERT and the CEDRI interface
from paragraph (f) are removed and replaced with a general statement
requiring all applicable notifications and reports be submitted through
the ECMPS Client Tool. Three statements are added 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 removing
paragraph (h)(3) because it is redundant with paragraph (i) and,
therefore, unnecessary.
(g) Previous section 40 CFR 63.10030(e)(7)(i) is removed 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 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).
The requirements of section 40 CFR 63.10030(e)(7)(iii) are amended
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, 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, a
note is added 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) The requirements of 40 CFR 63.10032(a) are amended to include
references to the recordkeeping required under new appendices C (for PM
[[Page 55756]]
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, the term
``semiannual compliance report'' is replaced with references to both
semiannual and quarterly compliance reports in paragraph (a)(1).
(i) The words ``or out of control period'' are removed from the
definition of ``monitoring system malfunction or out of control
period'' in 40 CFR 63.10042 because that definition does not describe
an out of control period. A separate definition of ``out-of-control
period'' is added, and that definition is similar with the definition
provided in the Acid Rain Program definitions at 40 CFR 72.2.
(j) Table 8 to subpart UUUUU of 40 CFR part 63 is revised to be
consistent with the amendments to 40 CFR 63.10031 and the proposed
addition of appendices C, D, and E.
(k) Finally, the recordkeeping and reporting requirements in Table
9 to 40 CFR part 63, subpart UUUUU are revised as follows. First, the
requirement to provide the information in 40 CFR 63.10030(e)(1) through
(8) is clarified, 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, a statement clarifying that the excess emissions
recordkeeping and reporting requirements of 40 CFR 63.10(c)(7) and (8)
and 63.10(e)(3)(v) and (vi) apply through December 31, 2023, when the
semiannual compliance reports are phased out, is added. On and after
January 1, 2024, all relevant information is provided in quarterly, as
opposed to semiannual, reports.
VI. 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 final 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 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 2137.10. You can find a copy of the ICR in the docket for this
rule, and it is briefly summarized here. The information collection
requirements are not enforceable until OMB approves them.
This rule continues to require collection, recording, and
submission of data pertinent to demonstrating compliance with rule
requirements. This action consolidates separate reporting systems into
one reporting system by 2024; maintains the information already
required to be collected, recorded, and submitted; and changes the
submission frequency from semiannual to quarterly while consolidating
the number and type of reports to be submitted.
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.
Estimated number of respondents: 1,414.
Frequency of response: Quarterly for compliance reports.
Total estimated burden: 273,000 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. When OMB
approves this ICR, the Agency will announce that approval in the
Federal Register and publish a technical amendment to 40 CFR part 9 to
display the OMB control number for the approved information collection
activities contained in this 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.
[[Page 55757]]
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 action is not subject to Executive Order
12898 (59 FR 7629, February 16, 1994) because it does not establish an
environmental health or safety standard. This 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.
L. Congressional Review Act (CRA)
This action is subject to the CRA, and the EPA will submit a rule
report to each House of the Congress and to the Comptroller General of
the United States. This action is not a ``major rule'' as defined by 5
U.S.C. 804(2).
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 amends 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 section 63.8(c)(7)(i).''
0
3. Section 63.10005 is amended by:
0
a. Revising the first sentence in paragraph (a)(2) introductory text;
0
b. Revising paragraph (b) introductory text; and
0
c. Revising paragraph (h)(3)(iii).
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 40 CFR 63.10007 and Table
5 to this subpart. Notwithstanding these requirements, when Table 5
specifies the use of isokinetic EPA test Method 5, 5D, 26A, or 29 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 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 40 CFR 63.9984, provided that the following conditions are
fully met:
* * * * *
(h) * * *
(3) * * *
(iii) Calculate the average Hg concentration, in [micro]g/m\3\ (dry
basis), for each of LEE test runs comprising the 30- (or 90-) boiler
operating day performance test, as the arithmetic average of all Method
30B sorbent trap results from the LEE test period. Also calculate, as
applicable, the average values of CO2 or O2
concentration, stack gas flow rate, stack gas moisture content, and
gross output for the LEE test period. Then:
* * * * *
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'';
0
ii. In the definition for ``Heri'' adding the words ``or
sorbent trap monitoring system'' after the words ``unit i's CEMS''; and
0
c. In paragraph (b)(3) revising ``Equation 3a'' and ``Equation 3b.''
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
[[Page 55758]]
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 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] TR09SE20.000
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,
n = Number of hours that hourly rates are collected over the 90-
group boiler operating days.
[GRAPHIC] [TIFF OMITTED] TR09SE20.001
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,
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,
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)(5), (6), (7),
(i), and (j)(4) to read as follows:
Sec. 63.10010 What are my monitoring, installation, operation, and
maintenance requirements?
* * * * *
(h) * * *
(5) You must collect data using the PM CPMS at all times the
process unit is operating and at the intervals specified in paragraph
(h)(1)(ii) of this section, except for required monitoring system
quality assurance or quality control activities (including, as
applicable, calibration checks and required zero and span adjustments),
and any scheduled maintenance as defined in your site-specific
monitoring plan.
(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 40 CFR 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
40 CFR 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 40 CFR 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
[[Page 55759]]
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 and at the intervals specified in paragraph
(a) of this section, except for required monitoring system quality
assurance or quality control activities and any scheduled maintenance
as defined in your site-specific monitoring plan.
(5) 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 and repairs associated with monitoring system
malfunctions. You must report any monitoring system malfunctions as
deviations in your compliance reports under 40 CFR 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 40 CFR
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 required monitoring system
quality assurance or quality control activities, and any scheduled
maintenance as defined in your site-specific monitoring plan.
(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 40 CFR 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 40 CFR 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 40 CFR 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 40 CFR 63.10031(f)(4) or (h), as applicable, containing
the results of the initial compliance demonstration, as specified in 40
CFR 63.10030(e).
* * * * *
(g) * * *
(3) You must report the emissions data recorded during startup and
shutdown. If you are relying on paragraph (2) of the definition of
startup in 40 CFR 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 40 CFR 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 40 CFR 63.10031(c)(5)(ii) and 40 CFR 63.10020(e)
quarterly, in PDF files, in accordance with 40 CFR 63.10031(i).
* * * * *
0
7. Section 63.10020 is amended by revising paragraphs (a), (b), and (d)
to read as follows:
Sec. 63.10020 How do I monitor and collect data to demonstrate
continuous compliance?
(a) You must monitor and collect data according to this section and
the site-specific monitoring plan required by Sec. 63.10000(d).
(b) You must operate the monitoring system and collect data at all
required intervals at all times that the affected EGU is operating,
except for required monitoring system quality assurance or quality
control activities, including, as applicable, calibration checks and
required zero and span adjustments, and any scheduled maintenance as
defined in your site-specific monitoring plan. You are required to
affect monitoring system repairs in response to monitoring system
malfunctions and to return the monitoring system to operation as
expeditiously as practicable.
* * * * *
(d) Periods of monitoring system malfunctions or monitoring system
out-of-control periods, repairs associated with monitoring system
malfunctions or monitoring system out-of-control periods, and required
monitoring system quality assurance or quality control activities
excluding zero and span checks must be reported as time the monitor was
inoperative (downtime) under 63.10(c). Failure to collect required
quality-assured data during monitoring system malfunctions, monitoring
system out-of-control periods, or repairs associated with monitoring
system malfunctions or monitoring system out-of-control periods is a
deviation from the monitoring requirements.
* * * * *
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
[[Page 55760]]
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 40 CFR 63.10031(f)(4) and (6) and, if requested by the
Administrator, in hard copy, as specified in 40 CFR 63.10031(f)(5). On
and after January 1, 2024, report the tune-up date electronically in
your quarterly compliance report, in accordance with 40 CFR 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 40 CFR 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 40 CFR 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 40 CFR 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 40 CFR 63.10031(c)(5)(ii) and 40 CFR 63.10020(e)
quarterly, in PDF files, in accordance with 40 CFR 63.10031(i).
0
9. Section 63.10030 is amended by:
0
a. In paragraph (e) introductory text revising the last sentence;
0
b. Revising paragraph (e)(7) introductory text;
0
c. Removing and reserving paragraph (e)(7)(i);
0
d. Revising paragraph (e)(7)(iii) introductory text;
0
e. Revising paragraph (e)(7)(iii)(A)(3);
0
f. Adding in paragraph (e)(7)(iii)(B) the word ``must'' after the word
``You''; and
0
g. Adding in paragraph (e)(7)(iii)(C) the word ``must'' after the word
``you''.
The revisions and additions 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
10. Section 63.10031 is amended by:
0
a. Revising paragraphs (a), (b) introductory text, (b)(1), (2), (4),
(5);
0
b. Adding paragraph (b)(6);
0
c. Revising paragraph (c) introductory text;
0
d. Removing and reserving paragraphs (c)(5)(iii), (c)(5)(iv), and
(c)(5)(v);
0
e. Adding paragraph (c)(10);
0
f. Revising paragraphs (d), (e), (f) introductory text, (f)(1), and
(2);
0
g. Removing and reserving paragraph (f)(3);
0
h. Revising paragraphs (f)(4), (f)(6) introductory text, (f)(6)(vii),
(f)(6)(xi), and (g); and
0
i. Adding paragraphs (h), (i), (j) and (k), to 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 this requirement, 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 relative accuracy test
audits (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 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):
[[Page 55761]]
(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 sections 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 section 75.64(a)(5); 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 section 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 40 CFR 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 40
CFR 63.9984 (or, if applicable, the extended compliance date approved
under 40 CFR 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 40 CFR 63.9984
(or, if applicable, the extended compliance date approved under 40 CFR
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 40 CFR 63.9984 (or, if applicable,
the extended compliance date approved under 40 CFR 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) For each affected source that is subject to permitting
regulations pursuant to part 70 or part 71 of this chapter, and if the
permitting authority has established dates for submitting semiannual
reports pursuant to 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR
71.6(a)(3)(iii)(A), through the reporting period that ends December 31,
2023, you may submit the first and subsequent compliance reports
according to the dates the permitting authority has established instead
of according to the dates in paragraphs (b)(1) through (4) of this
section.
(6) 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) Excess emissions and deviation reporting. 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 40 CFR 63.10(e)(3)(vi). However, starting
with the first calendar quarter of 2024, reporting of the information
under 40 CFR 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 40 CFR 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 part 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 40 CFR
71.6(a)(3)(iii)(A). If an affected source submits a semiannual
compliance report pursuant to 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 40 CFR 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
[[Page 55762]]
day Hg LEE demonstration tests and PM 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 40 CFR 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 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.
(3) [Reserved]
(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 section
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, (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 40 CFR
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 40 CFR 63.10042, then, for startup and shutdown
incidents that occur on or prior to December 31, 2023, you must include
the information in 40 CFR 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 40 CFR 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 40 CFR
63.10031(c)(5) and 40 CFR 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 November 9, 2020, 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 November 9, 2020, 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 paragraph (f)(6)(i) through (xii) of this section must be
entered into ECMPS with the PDF report.
(k) If you elect to demonstrate compliance using a PM CPMS or an
[[Page 55763]]
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 paragraph
(f)(6)(i) through (xii) of this section must be entered into ECMPS with
the PDF report.
0
11. 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 40 CFR 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 40 CFR 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
12. Section 63.10042 is amended by:
0
a. In the definition ``Diluent cap'' adding the word ``PM,'' after the
word ``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
13. 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 a. You have the option of complying
(excluding limited-use liquid oil- using either of the following work
fired subcategory units), or practice standards:
solid oil-derived fuel-fired EGU (1) If you choose to comply using
during startup. paragraph (1) of the definition 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 40 CFR 63.10042, you
must report the applicable
information in 40 CFR
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 40 CFR 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 PM control(s)
within 1 hour of first firing of
coal, residual oil, or solid oil-
derived fuel.
[[Page 55764]]
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.
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.
63.10021(h) and 63.10032. 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 40 CFR 63.10042,
you must report the applicable
information in 40 CFR
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 40 CFR
63.10031(i).
4. A coal-fired, liquid oil-fired You must operate all CMS during
(excluding limited-use liquid oil- shutdown. You must also collect
fired subcategory units), or appropriate data, and you must
solid oil-derived fuel-fired EGU calculate the pollutant emission
during shutdown. rate for each hour of shutdown for
those pollutants for which a 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 40 CFR 63.10042, you
must report the applicable
information in 40 CFR
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 40 CFR 63.10031(i).
------------------------------------------------------------------------
* * * * *
0
14. Table 8 to subpart UUUUU is revised to read as follows:
Table 8 to Subpart UUUUU of Part 63--Reporting Requirements
[In accordance with 40 CFR 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 40 CFR 63.10031 (a)(1), if you
continuously monitor Hg emissions.
2. The electronic reports required under 40 CFR 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 40 CFR 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 40 CFR 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 40 CFR 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.
[[Page 55765]]
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 the introductory text of 40 CFR 63.10031(f) and 40 CFR
63.10031(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 40 CFR
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 40 CFR 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 40 CFR 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.
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
through 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 through 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 40 CFR
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 40 CFR 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 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 40 CFR 63.10031(c) and
(d), in PDF files, according to 40 CFR 63.10031(f)(4) and (6). The due
dates for these reports are specified in 40 CFR 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 40
CFR 63.10031(f)(4) and (6) until December 31, 2023, and according to 40
CFR 63.10031(h) thereafter.
11. Quarterly electronic compliance reports, in accordance with 40 CFR
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 40 CFR 63.10031(c)(5)(ii) and 40 CFR 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 40 CFR 63.10042 (see 40 CFR
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 40 CFR 63.10031(g).
13. A test report for the PS 11 correlation test of your PM CEMS, in
accordance with 40 CFR 63.10031(j).
If, prior to November 9, 2020, 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 November 9, 2020, 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
40 CFR 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
15. Table 9 to subpart UUUUU is amended by:
0
a. Revising the entries ``63.9''and ``63.10(c)(7) and (8)''; and
0
b. Adding the entry ``Sec. 63.10(e)(3)(v) and (vi)''.
The addition and revision read as follows:
[[Page 55766]]
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 (8), for
the initial
notification of
compliance status,
only.
* * * * * * *
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.
CMS
performance
reports.
* * * * * * *
------------------------------------------------------------------------
0
16. Appendix A to subpart UUUUU is amended by revising sections 5.1.1,
7.1.1.2.1, 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
* * * * *
5. Ongoing Quality Assurance (QA) and Data Validation
* * * * *
5.1.1 Required QA Tests. Periodic QA testing of each Hg CEMS is
required following initial certification. The required QA tests, the
test frequencies, and the performance specifications that must be
met are summarized in Table A-2, below. All tests must be performed
with the affected unit(s) operating (i.e., combusting fuel),
however, the daily calibration may optionally be performed off-line.
The RATA must be performed at normal load, but no particular load
level is required for the other tests. For each test, follow the
same basic procedures in section 4.1.1 of this appendix that were
used for initial certification.
* * * * *
7. Recordkeeping and Reporting
* * * * *
7.1.1.2.1 Electronic. The electronic monitoring plan records
must include the following: unit or stack ID number(s); monitoring
location(s); the Hg monitoring methodologies used; emissions
controls; Hg monitoring system information, including, but not
limited to: Unique system and component ID numbers; the make, model,
and serial number of the monitoring equipment; the sample
acquisition method; formulas used to calculate Hg emissions; and Hg
monitor span and range information. The electronic monitoring plan
shall be evaluated and submitted using the ECMPS Client Tool
provided by the Clean Air Markets Division in the Office of
Atmospheric Programs of the EPA.
* * * * *
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 section 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
17. Appendix B to subpart UUUUU is amended by:
0
a. Revising the heading and introductory text of section 2.3;
0
b. Revising 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;
[[Page 55767]]
0
c. Adding sections 10.1.8.1.4 through 10.1.8.1.12;
0
d. Revising sections 11.3.1, 11.4 introductory text, and 11.4.1;
0
e. Adding sections 11.4.1.1 through 11.4.1.9;
0
f. Revising section 11.4.2 introductory text;
0
g. Revising sections 11.4.3.11 and 11.4.3.12;
0
h. Re-designating section 11.4.3.13 as 11.4.3.14;
0
i. Adding new section 11.4.3.13;
0
j. Re-designating section 11.4.4 as 11.4.13;
0
k. 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; 11.4.12.1 through 11.4.12.9; and 11.4.13; and
revising 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 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, 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, 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 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, 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, 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 (ME) 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 ME at each
gas level and the related calculations. For ME 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 ME/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
[[Page 55768]]
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.
Keep records of the raw field data, relevant process operating data,
and the calculations used to determine the relative accuracy.
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 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 of initial certification testing of the CEMS.
Also submit the monitoring plan information in section 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;
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, report:
* * * * *
11.4.3.11 Standard deviation, using either Equation 2-4 in
section 12.3 of PS 2 in appendix B to part 60 of this chapter or
Equation 10 in section 12.6.5 of PS 18;
11.4.3.12 Confidence coefficient, using either Equation 2-5 in
section 12.4 of PS 2 in appendix B to part 60 of this chapter or
Equation 11 in section 12.6.6 of PS 18;
11.4.3.13 t-value; and
11.4.3.14 Relative Accuracy. For FTIR monitoring systems
following PS 15, calculate the relative accuracy using Equation 2-6
of PS 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,
calculate the relative accuracy according to section 12.6 of PS 18.
If applicable use a flag to indicate that the alternative relative
accuracy specification for low emitters has been applied.
11.4.4 For each 3-level ME 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;
11.4.4.6 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 PS 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 (temperature or pressure);
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:
[[Page 55769]]
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 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 (seven
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 RAA of an HCl monitor, report:
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 and CEMS values for each test
run, including the units of measure;
11.4.10.6 The mean reference method and CEMS values for the
three test runs;
11.4.10.7 The calculated relative accuracy, 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;
11.4.11.6 ME at each reference gas level; and
11.4.11.7 Reason for test.
11.4.12 For each quarterly DSA 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 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
18. Subpart UUUUU of part 63 is amended by adding appendix C 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 PM emissions from affected EGUs
under this subpart. A PM CEMS is used together with other CMS 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 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 section 75.24 of this chapter.
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, 40 CFR 63.10010(a) specifies the appropriate
location(s) at which to install CMS. These CMS installation
provisions apply to the PM CEMS and to the other CMS 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.
[[Page 55770]]
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 40 CFR 63.10010 and Section 2.4 of PS-11.
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 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
Table 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 CMS 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
the effective date of this subpart 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
section 75.20 of this chapter 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
section 75.20(b) of this chapter.
4.3 Development of a New or Revised Correlation Curve. You must
develop a new or revised correlation curve if:
4.3.1 An 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 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 PS 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 4 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, below). When a required annual RRA is done
within a grace period, the deadline for the next RRA is 4 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 12 calendar quarters. If a required RCA
is not completed within 12 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, below). When an RCA is done in
a grace period, the deadline for the next RCA shall be 12 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 1 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
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
[[Page 55771]]
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.
5.3.2.1 Daily, and Quarterly Quality Assurance 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 Caculations
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) of this chapter.
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) of this chapter.
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 40 CFR 75.10(d)(1) of
this chapter. 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 40 CFR 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 PM 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, below (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] TR09SE20.002
or
[GRAPHIC] [TIFF OMITTED] TR09SE20.003
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 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
[[Page 55772]]
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
section 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 40 CFR 63.10042 and
specified in 40 CFR 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) of this chapter, or a site-specific default moisture
value approved by the Administrator under section 75.66 of this
chapter.
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 to calculate the gross output-based PM
emission rate (if applicable). Use Equation C-4 if Cstd
is measured on a dry basis:
[GRAPHIC] [TIFF OMITTED] TR09SE20.004
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
or
[GRAPHIC] [TIFF OMITTED] TR09SE20.005
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 40 CFR 63.10021(b).
7. Recordkeeping and Reporting
7.1 Recordkeeping Provisions. For the PM CEMS and the other
necessary 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 40 CFR 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 (DAHS)) 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) of this chapter.
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); and
appropriate default values. Your electronic monitoring plan shall be
evaluated and submitted using the 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
1 hundredth to 1 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
[[Page 55773]]
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 of this
chapter.
7.1.4 Stack Gas Volumetric Flow Rate Records.
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) of this chapter.
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) of this
chapter.
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) of this
chapter.
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 40 CFR 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 40 CFR 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 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) of this chapter.
7.1.11 For each temperature measurement device (e.g., resistance
temperature detector or thermocouple) and pressure measurement
device used to convert measured PM concentrations to standard
conditions according to Equation C-1 or C-2, 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 quality assurance
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 40 CFR 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
[[Page 55774]]
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 quality assurance 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 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 quality assurance 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 quality assurance 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 until a successful quality assurance 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 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 section
72.2 of this chapter).
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 quality assurance
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
19. Subpart UUUUU of part 63 is amended by adding appendix D, 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 PM CPMS, for the purpose
of assessing continuous compliance with an applicable emissions
limit in Table 1 or Table 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 40 CFR
63.10010(h)(1)(i) through (iii) and 40 CFR 63.10023(b)(2)(iii) and
(iv). In addition, an automated 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 40 CFR
63.10010(a).
2.3 Determination of Operating Limits.
2.3.1 In accordance with 40 CFR 63.10007(a)(3), 40 CFR
63.10011(b), 40 CFR 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 Table 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 40 CFR 63.10005(d)(2)(i), you must
perform the initial stack test no later than the applicable date in
40 CFR 63.9984(f), and according to 40 CFR 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 40 CFR
63.10023(b)(1) for existing units, and 40 CFR 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 40 CFR 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 40 CFR
63.10010(h)(3) through (6), 40 CFR 63.10021(c), and Table 7 to this
subpart.
2.4.3 In accordance with 40 CFR 63.10005(d)(2)(ii), 40 CFR
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 40 CFR
63.10021(c)(1) and (2).
3. RECORDKEEPING AND REPORTING.
3.1 Recordkeeping Provisions. You must keep the applicable
records required under
[[Page 55775]]
40 CFR 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 40 CFR 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 63.10000(d).
3.1.1.2 In addition to the site-specific monitoring plan
required under 40 CFR 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 DAHS) 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 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
1 hundredth to 1 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 for the PM CPMS,
calculated in the manner established for SO2,
CO2, O2 or moisture monitoring systems
according to section 75.32 of this chapter.
3.1.4 Records of PM CPMS Audits and Out-of-Control Periods. In
accordance with 40 CFR 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 40 CFR 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 40 CFR 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 section 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 Table 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 40 CFR
63.10031(g); and
3.2.5.2 Provide a complete stack test report as a PDF file, in
accordance with 40 CFR 63.10031(f) or (h), as applicable.
0
20. Subpart UUUUU of part 63 is amended by adding appendix E, 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 40 CFR 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:
[[Page 55776]]
2.1 Energy Information Administration's Office of Regulatory
Information Systems (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 40
CFR 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
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 Quality Assurance Parameters: For key parameters that are
used to quality-assure the reference method data (including, as
applicable, filter temperature, percent isokinetic, leak check
results, percent breakthrough, percent 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 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 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. If subject to an emissions limit,
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;
11.4 New Fuel Type Indicator (if applicable); and
11.5 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 and Monitoring Downtime. If there were any
deviations or monitoring downtime 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;
13.2.6 Monitoring downtime incurred; or
13.2.7 Other requirement not met.
13.3 A description of the deviation, or monitoring downtime, 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 periods where valid monitoring data are not reported
during the reporting period, record the monitored parameter, the
total source operating time (hours), and the total number of hours
of monitoring deviation or downtime and other information, as
indicated, for:
13.3.3.1 Monitoring system malfunctions/repairs (deviation and
downtime);
13.3.3.2 Out-of-control periods/repairs (deviation and
downtime);
13.3.3.3 Non-monitoring equipment malfunctions (downtime);
13.3.3.4 QA/QC activities (excluding zero and span checks)
(downtime);
13.3.3.5 Routine maintenance (downtime);
13.3.3.6 Other known causes (downtime); and
13.3.3.7 Unknown causes (downtime).
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 and/or no monitoring downtime
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);
[[Page 55777]]
14.2 Each 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, RRA and each 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, 2, 3A, 4, 5, 5D, 6C,
26, 26A, 29, and/or 30B.
16.1 Application of EPA test Methods 1 and 2. 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 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 EPA test 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. 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 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.
16.3 Application of EPA test Method 4. 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 calculations (to determine the molecular
weight of the gas) and for the RATA of an Hg CEMS that measures on a
wet basis, when EPA test Method 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 EPA test Method 19 equations 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 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 is used, EPA test Method 4 must be performed separately.
16.4 Applications of EPA test Methods 5 and 5D. 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. 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 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. 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 PS 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. 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. 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
40 CFR 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. 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 test is conducted in order to convert a
pollutant concentration to the units of the applicable emission
standard given in Table 1 or Table 2 of 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;
[[Page 55778]]
17.13 EPA Facility Registration System Number;
17.14 Source Classification Code;
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, PM CPMS operating limits, if
applicable).
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.);
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. 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 HAP metals and total HAP metals, report only the run-
level data elements (19.1, 19.3 through 19.30, and 19.38 through
19.41), 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. 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 Methods 29 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, and the point-level data elements in Section 20. 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 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):
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 HAP 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 HAP 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 HAP metals in units of lbs/MMBtu or lbs/MW
(per Table 5):
21.9.1 Pollutant Name;
21.9.2 Pollutant Emission Rate; and
21.9.3 Pollutant Emission Rate Units of Measure.
21.10 Total HAP 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 HAP metals concentration
21.11.1 Pollutant Name;
21.11.2 Pollutant Concentration; and
21.11.3 Pollutant Concentration Units of Measure.
21.12 Total HAP metals Emission Rate in Units of the Standard:
[[Page 55779]]
21.12.1 Pollutant Name;
21.12.2 Pollutant Emission Rate; and
21.12.3 Pollutant Emission Rate Units of Measure.
21.13 Total HAP metals Emission Rate in lbs/MMBtu or lbs/MW (per
Table 5):
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. 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 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. 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 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. 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;
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. 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. 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 of 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 Span (High-Level) Gas Concentration;
26.14 Calibration High-Level Cylinder Expiration Date;
26.15 Low-Level Gas Response;
26.16 Low-Level Calibration Error;
26.17 Low-Level Alternate Performance Specification (APS) Flag;
26.18 Mid-Level Gas Response;
26.19 Mid-Level Calibration Error;
26.20 Mid-Level APS Flag;
26.21 High-Level Gas Response;
26.22 High-Level Calibration Error; and
26.23 High-Level APS Flag.
27.0 Run-Level Data Elements for EPA test Methods 3A and 6C. 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 of 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;
[[Page 55780]]
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;
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. 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., Data Element 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. 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. 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 40 CFR 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, quality assurance data (e.g. field recovery spikes) and
any required audit results and stack testers' credentials (if
applicable). The applicable data elements in 40 CFR
63.10031(f)(6)(i) through (xii) of this section must be entered into
ECMPS with each PDF submittal; the test number(s) (see 40 CFR
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. 2020-15950 Filed 9-8-20; 8:45 am]
BILLING CODE 6560-50-P