National Emission Standards for Hazardous Air Pollutants From Coal- and Oil-Fired Electric Utility Steam Generating Units and Standards of Performance for Fossil-Fuel-Fired Electric Utility, Industrial-Commercial-Institutional, and Small Industrial-Commercial-Institutional Steam Generating Units; Correction, 23399-23409 [2012-8703]
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Federal Register / Vol. 77, No. 76 / Thursday, April 19, 2012 / Rules and Regulations
(b) * * *
(L) State of Georgia: Georgia
Department of Natural Resources,
Environmental Protection Division, Air
Protection Branch, 4244 International
Parkway, Suite 120, Atlanta, Georgia
30354.
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(Z) State of Mississippi: Hand Deliver
or Courier: Mississippi Department of
Environmental Quality, Office of
Pollution Control, Air Division, 515 East
Amite Street, Jackson, Mississippi
39201, Mailing Address: Mississippi
Department of Environmental Quality,
Office of Pollution Control, Air
Division, P.O. Box 2261, Jackson,
Mississippi 39225.
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(II) State of North Carolina: North
Carolina Department of Environment
and Natural Resources, Division of Air
Quality, 1641 Mail Service Center,
Raleigh, North Carolina 27699–1641 or
local agencies, Forsyth County
Environmental Affairs, 201 North
Chestnut Street, Winston-Salem, North
Carolina 27101 or Forsyth County Air
Quality Section, 537 North Spruce
Street, Winston-Salem, North Carolina
27101; Mecklenburg County Land Use &
Environmental Services Agency, Air
Quality, 700 N. Tryon St., Suite 205,
Charlotte, North Carolina 28202–2236;
Western North Carolina Regional Air
Quality Agency, 49 Mount Carmel Road,
Asheville, North Carolina 28806.
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[FR Doc. 2012–9234 Filed 4–18–12; 8:45 am]
BILLING CODE 6560–50–P
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Parts 60 and 63
[EPA–HQ–OAR–2009–0234; EPA–HQ–OAR–
2011–0044; FRL–9654–8]
RIN 2060–AP52 and 2060–AR31
National Emission Standards for
Hazardous Air Pollutants From Coaland Oil-Fired Electric Utility Steam
Generating Units and Standards of
Performance for Fossil-Fuel-Fired
Electric Utility, Industrial-CommercialInstitutional, and Small IndustrialCommercial-Institutional Steam
Generating Units; Correction
Environmental Protection
Agency (EPA).
ACTION: Final rule; correction.
AGENCY:
This document corrects
certain preamble and regulatory text.
This action corrects typographical
errors, such as cross-reference errors
and certain preamble text that is not
consistent with the final regulatory text,
which published in the Federal Register
on Thursday, February 16, 2012 (77 FR
9304).
DATES: Effective date: April 19, 2012.
FOR FURTHER INFORMATION CONTACT: For
the NESHAP action: Mr. William
Maxwell, Energy Strategies Group,
Sector Policies and Programs Division,
(D243–01), Office of Air Quality
Planning and Standards, U.S.
Environmental Protection Agency,
Research Triangle Park, North Carolina
27711; Telephone number: (919) 541–
5430; Fax number (919) 541–5450;
email address: maxwell.bill@epa.gov.
For the new source performance
standard (NSPS) action: Mr. Christian
Fellner, Energy Strategies Group, Sector
Policies and Programs Division, (D243–
01), Office of Air Quality Planning and
Standards, U.S. Environmental
SUMMARY:
23399
Protection Agency, Research Triangle
Park, North Carolina 27711; Telephone
number: (919) 541–4003; Fax number
(919) 541–5450; email address:
fellner.christian@epa.gov.
This
document corrects certain preamble and
regulatory text. It is proper to issue this
final rule correction without notice and
comment. Section 553 of the
Administrative Procedure Act (APA), 5
U.S.C. 553(b)(B), provides that, when an
agency for good cause finds that notice
and public procedure are impracticable,
unnecessary, or contrary to the public
interest, the agency may issue a rule
without providing notice and an
opportunity for public comment. We
have determined that there is good
cause for making this action final
without prior proposal and opportunity
for comment because the changes to the
rule are minor technical corrections, are
noncontroversial, and do not
substantively change the agency actions
taken in the final rule. Notice and
comment is unnecessary, because these
changes do not affect the rights or
obligations of outside parties, and do
not alter the substantive requirements of
the code of federal regulations (CFR),
except to the extent that one regulatory
provision included an inadvertent
typographical error that EPA must
amend to align with the plain text of the
Clean Air Act (CAA). We find that this
constitutes good cause under 5 U.S.C.
553(b)(B).The corrections can be
categorized generally as follows:
Correction of typographical errors (e.g.,
cross-reference errors) and correction of
certain preamble text that does not
conform to the final regulatory text.
Below, we identify each technical
correction to the preamble and
regulatory text.
1. Table 5 on page 9368 is corrected
to read as follows:
SUPPLEMENTARY INFORMATION:
TABLE 5—ALTERNATE EMISSION LIMITATIONS FOR EXISTING COAL- AND OIL-FIRED EGUS
Subcategory/pollutant
Coal-fired EGUs
IGCC
Liquid oil, continental
Liquid oil, non-continental
Solid oil-derived
SO2 .............................
2.0E–1 lb/MMBtu
(1.5E0 lb/MWh).
5.0E–5 lb/MMBtu
(5.0E–1 lb/GWh).
8.0E–1 lb/TBtu
(8.0E–3 lb/GWh).
1.1E0 lb/TBtu (2.0E–
2 lb/GWh).
2.0E–1 lb/TBtu
(2.0E–3 lb/GWh).
3.0E–1 lb/TBtu
(3.0E–3 lb/GWh).
2.8E0 lb/TBtu (3.0E–
2 lb/GWh).
8.0E–1 lb/TBtu
(8.0E–3 lb/GWh).
NA ............................
NA ............................
NA ...................................
6.0E–5 lb/MMBtu
(5.0E–1 lb/GWh).
1.4E0 lb/TBtu (2.0E–
2 lb/GWh).
1.5E0 lb/TBtu (2.0E–
2 lb/GWh).
1.0E–1 lb/TBtu
(1.0E–3 lb/GWh).
1.5E–1 lb/TBtu
(2.0E–3 lb/GWh).
2.9E0 lb/TBtu (3.0E–
2 lb/GWh).
1.2E0 lb/TBtu (2.0E–
2 lb/GWh).
8.0E–4 lb/MMBtu
(8.0E–3 lb/MWh) a.
1.3E+1 lb/TBtu
(2.0E–1 lb/GWh).
2.8E0 lb/TBtu (3.0E–
2 lb/GWh).
2.0E–1 lb/TBtu
(2.0E–3 lb/GWh).
3.0E–1 lb/TBtu
2.0E–3 lb/GWh).
5.5E0 lb/TBtu (6.0E–
2 lb/GWh).
2.1E+1 lb/TBtu
(3.0E–1 lb/GWh).
6.0E–4 lb/MMBtu(7.0E–3
lb/MWh) a.
2.2E0 lb/TBtu (2.0E–2 lb/
GWh).
4.3E0 lb/TBtu (8.0E–2 lb/
GWh).
6.0E–1 lb/TBtu (3.0E–3
lb/GWh).
3.0E–1 lb/TBtu (3.0E–3
lb/GWh).
3.1E+1 lb/TBtu (3.0E–1
lb/GWh).
1.1E+2 lb/TBtu (1.4E0 lb/
GWh).
3.0E–1 lb/MMBtu
(2.0E0 lb/MWh).
4.0E–5 lb/MMBtu
(6.0E–1 lb/GWh).
8.0E–1 lb/TBtu
(7.0E–3 lb/GWh).
3.0E–1 lb/TBtu
(5.0E–3 lb/GWh).
6.0E–2 lb/TBtu
(5.0E–4 lb/GWh).
3.0E–1 lb/TBtu
(4.0E–3 lb/GWh).
8.0E–1 lb/TBtu
(2.0E–2 lb/GWh).
1.1E0 lb/TBtu (2.0E–
2 lb/GWh).
Total non-mercury
metals.
Antimony, Sb ..............
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Arsenic, As .................
Beryllium, Be ..............
Cadmium, Cd .............
Chromium, Cr .............
Cobalt, Co ..................
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Federal Register / Vol. 77, No. 76 / Thursday, April 19, 2012 / Rules and Regulations
TABLE 5—ALTERNATE EMISSION LIMITATIONS FOR EXISTING COAL- AND OIL-FIRED EGUS—Continued
Subcategory/pollutant
Coal-fired EGUs
IGCC
Liquid oil, continental
Liquid oil, non-continental
Solid oil-derived
Lead, Pb .....................
1.2E0 lb/TBtu (2.0E–
2 lb/GWh).
4.0E0 lb/TBtu (5.0E–
2 lb/GWh.
NA ............................
1.9E+2 lb/TBtu
(1.8E0 lb/GWh).
2.5E0 lb/TBtu (3.0E–
2 lb/GWh).
NA ............................
6.5E0 lb/TBtu (7.0E–
2 lb/GWh).
2.2E+1 lb/TBtu
(3.0E–1 lb/GWh).
4.9E0 lb/TBtu (8.0E–2 lb/
GWh).
2.0E+1 lb/TBtu (3.0E–1
lb/GWh).
4.0E–2 lb/TBtu (4.0E–4
lb/GWh).
4.7E+2 lb/TBtu (4.1E0 lb/
GWh).
9.8E0 lb/TBtu (2.0E–1 lb/
GWh).
8.0E–1 lb/TBtu
(2.0E–2 lb/GWh).
2.3E0 lb/TBtu (4.0E–
2 lb/GWh).
NA.
3.5E0 lb/TBtu (4.0E–
2 lb/GWh).
5.0E0 lb/TBtu (6.0E–
2 lb/GWh).
8.1E0 lb/TBtu (8.0E–
2 lb/GWh).
2.2E+1 lb/TBtu
(3.0E–1 lb/GWh).
2.0E–1 lb/TBtu
(2.0E–3 lb/GWh).
1.1E+2 lb/TBtu
(1.1E0 lb/GWh).
3.3E0 lb/TBtu (4.0E–
2 lb/GWh).
Manganese, Mn .........
Mercury, Hg ................
Nickel, Ni ....................
Selenium, Se ..............
9.0E0 lb/TBtu (2.0E–
1 lb/GWh).
1.2E0 lb/TBtu (2.0E–
2 lb/GWh).
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NA = Not applicable.
a Includes Hg.
The output-format values for the
antimony and beryllium emission limits
for existing solid oil-derived fuel-fired
units were incorrect as published in the
preamble to the final rule (i.e., the
incorrect ‘‘8.0E–3 lb/GWh’’ instead of
the correct ‘‘7.0E–3 lb/GWh’’ for
antimony and the incorrect ‘‘6.0E–4 lb/
GWh’’ instead of the correct ‘‘5.0E–4 lb/
GWh’’ for beryllium). In addition, the
format of the input- and output-based
lead emissions limits for existing IGCC
EGUs was incorrect as published in the
preamble to the final rule (i.e., the
incorrect ‘‘1.9E+2 lb/MMBtu or 1.8E0
lb/MWh’’ instead of the correct ‘‘1.9E+2
lb/TBtu or 1.8E0 lb/GWh’’). In each
case, the correct values are indicated in
the spreadsheets found in docket entry
EPA–HQ–OAR–2009–0234–20132 and
the published values were transcription
errors. This same correction is made to
the regulatory text later in this
document.
2. On page 9401, column 1, first full
paragraph, the fourth sentence is
corrected to read as follows: ‘‘This
subcategory applies only to oil-fired
EGUs that act as peaking units, as they
generally address reliability issues.’’
We are revising this sentence because
the original sentence in the preamble to
the final rule stated: ‘‘This subcategory
applies only to oil-fired EGUs that
operate on oil alone and act as peaking
units, as they generally address
reliability issues.’’ (emphasis added).
The italicized language is not consistent
with the regulatory definition of ‘‘oilfired EGU’’ or the definition of ‘‘limiteduse liquid oil-fired subcategory’’
because it incorrectly indicates that the
subcategory applies only to oil-fired
EGUs that operate on oil alone. See 40
CFR 63.10042.
3. The definition of ‘‘Boiler operating
day’’ in § 60.41Da Definitions, the date
‘‘February 29, 2005’’ is corrected to read
‘‘March 1, 2005’’ because there was no
February 29 in 2005.
4. Section 60.49Da(a)(4)(i) is revised
to correct the typographical error related
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to the incorrect cross reference to
section 60.51a(d) which does not exist.
The correct cross reference is to section
60.51Da(d).
5. Sections 63.9982(a)(1) and (a)(2) are
revised to include the ‘‘§’’ symbol
which was inadvertently left off of the
references to section 63.10042 (i.e.,
‘‘63.10042’’ vs. the correct ‘‘§ 63.10042’’.
6. Section 63.9982(d) is revised to
correct the typographical error which
left out the word ‘‘in’’ from the phrase
‘‘* * * change in process * * *’’
7. Section 63.9985(a)(2) is revised to
remove the words ‘‘or modification.’’
We erroneously included this language
in the final rule definition of a new
source for purposes of the NESHAP. The
language included in the final rule
comes from the CAA section 111
statutory definition for ‘‘new source,’’
instead of the CAA section 112
definition of ‘‘new source.’’ CAA section
112 does not include ‘‘modified’’
sources in the definition of new sources,
and, thus, the inclusion of such sources
in the definition was an inadvertent
drafting error.
8. Section 63.9991(c) is revised to
remove the term ‘‘coal-fired’’ from the
phrase ‘‘coal-fired EGU.’’ This section
expressly references Tables 1 and 2 of
this subpart and those tables include
alterative sulfur dioxide (SO2) limits for
all EGUs meeting the requirements of
section 63.9991(c), not just coal-fired
EGUs. Thus, the provision as written in
the final rule was incorrectly limited to
coal-fired EGUs.
9. Section 63.10000(c)(1) is revised to
include integrated gasification
combined cycle (IGCC) EGUs among the
subcategories listed. Section 63.10000(c)
addresses initial performance testing.
IGCC EGUs are included in the
requirements of section 63.10000(c)(1)(i)
(which deals with initial performance
testing for purposes of determining low
emitting EGU (LEE) status) and, thus,
the omission of IGCC EGUs from the
introductory language in section
63.10000(c)(1) was an inadvertent error.
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10. Section 63.10000(c)(1)(i)(B) is
revised to correct a typographical error
(‘‘* * * solid oil-derived fuel-fired
* * *’’ rather than the incorrect ‘‘* * *
solid oil-fired fuel-fired * * *’’).
11. Section 63.10000(c)(2)(iv) is
revised to correct a typographical error
and include ‘‘you’’ in the phrase ‘‘* * *
but you must * * *’’
12. Section 63.10000(d)(5)(i) is
revised to correct the typographical
error of including the incorrect term
‘‘CEMS’’ rather than the correct term
‘‘CMS.’’ The text of sections
63.10000(d)(2)(i), (3), and (4) all refer to
the broader ‘‘CMS’’ (which includes
both continuous parameter monitoring
system (CPMS) and continuous
emission monitoring system (CEMS)).
Thus, use of the narrower CEMS in
section 63.10000(d)(5)(i) was an
inadvertent error. Further, the term
‘‘CPMS’’ in the last sentence of the
section is corrected to read ‘‘PM CPMS’’
consistent with section 63.10010(h),
which section is referenced in section
63.10000(d)(5)(i) and specifically
addresses PM CPMS.
13. Section 63.10000(d)(5)(iv) is
revised to use language consistent with
section 63.8(d) (changing ‘‘ongoing data
quality assurance procedures’’ to
‘‘quality control program’’), as section
63.8 is cited in this section. The title of
section 63.8(d) is ‘‘quality control
program’’ and the phrase ‘‘ongoing data
quality assurance procedures’’ does not
appear in that provision.
14. Section 63.10000(f) is revised to
correct a typographical error by
replacing ‘‘distributions system’’ with
the correct ‘‘distribution system.’’
15. Section 63.10005(b)(2) is revised
to correct a typographical error by
changing ‘‘* * * valid data CMS data
* * *’’ to ‘‘valid CMS data’’.
16. Section 63.10005(d)(1) is revised
to correct a typographical error (the
correct ‘‘* * * Table 1 or 2 to this
* * *’’ rather than the incorrect ‘‘* * *
Table 1 or 2 of this * * *’’ in two
places).
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17. Section 63.10005(d)(4)(ii) is
revised to correct the typographical
error associated with the use of
‘‘corresponding’’ rather than the correct
word ‘‘corresponds.’’
18. Sections 63.10005(h)(3)(iii)(C)(1)
and (2) are revised to correct the
typographical errors associated with the
conversion factors from million British
thermal units per hour (MMBtu/hr) to
trillion Btu/hr (TBtu/hr) (i.e., the correct
10¥6 rather than the incorrect 106) and
from megawatts (MW) to gigawatts (GW)
(i.e., the correct 10¥3 rather than the
incorrect 103). The exponents as
published are technically incorrect and
the conversions would not work as
published.
19. Section 63.10006(a) is revised to
correct a typographical error.
Specifically, we inadvertently omitted
the word ‘‘fired’’ from the phrase
‘‘* * * solid oil-derived fuel- and
* * *’’ The phrase should read ‘‘* * *
solid oil-derived fuel-fired and * * *’’
20. Section 63.10007(c) is revised to
correct the typographical error
associated with the incorrect cross
reference to the non-existent section
63.10011(b)(5). The correct cross
reference is to section 63.10011(b).
21. Section 63.10009(g) is revised to
correct the typographical error related to
the incorrect cross reference to sections
63.10009(f)(1) through (3). Section
63.10009(g) deals with determining
weighted average emission rates, but
section 63.10009(f) deals with
demonstrating eligibility for an
emissions averaging group and is, thus,
an incorrect cross reference. The correct
cross reference is to sections
63.10009(g)(1) through (2), which
sections provide specific direction on
the manner in which sources establish
weighted average emission rates.
22. Section 63.10009(j)(2)(i)(A) is
revised to correct the typographical
error related to the incorrect cross
reference to section 63.10009(h)(1),
which does not exist. The correct cross
reference is to section 63.10009(j)(1).
23. Sections 63.10010(a)(6)(iii) and
(iv) are revised to correct the
typographical errors related to the
incorrect cross references to sections
63.10010(a)(5)(iii)(B) and (a)(5)(iii)(C),
which do not exist. The correct cross
references are to sections
63.10010(a)(6)(ii) and (iii), respectively.
24. Sections 63.10010(g),
63.10011(c)(1), 63.10021(b), and
63.10022(a)(1) are revised to correct the
inadvertent omission of the alternate 90day averaging period. The provisions as
included in the final rule only referred
to the 30-day averaging periods that are
generally utilized for determining
compliance with the final standards;
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however, as indicated in section
63.10009(a)(2), sources are also
authorized to use the alternate 90-day
averaging period for certain standards
when emissions averaging is employed
at a facility.
25. Section 63.10020(d) is revised to
correct a typographical error by
replacing ‘‘of’’ with ‘‘from’’ in the
phrase ‘‘* * * deviation from the
* * *’’
26. Section 63.10030(e)(7)(i) is revised
to correct the typographical error related
to the incorrect cross reference to
section 63.10006(i). Section 63.10006(i)
addresses the tune-up requirement, but
section 63.10030(e)(7)(i) concerns LEE
requirements, not tune-up requirements.
The correct cross reference is to section
63.10006(b), which addresses the
reduced performance (i.e., stack) testing
for LEE, which allows a source to test
every 3 years as discussed in section
63.10030(e)(7)(i).
27. Section 63.10031(c)(4) is revised
to correct an incorrect statement. The
final rule does not require annual
inspections; thus, the ‘‘annual’’ has been
replaced with ‘‘every 36 (or 48) months’’
to be consistent with other rule text.
28. The definitions of ‘‘Non-mercury
(Hg) HAP metals’’ and ‘‘Oil’’ in section
63.10042 are revised to correct the
typographical error that did not separate
the two definitions in the published
rule.
29. Table 2 to Subpart UUUUU of Part
63 is revised to correct the
typographical errors related to the lack
of a superscript for footnotes (‘‘2’’)
denoting ‘‘gross electric output’’ for
filterable particulate matter emissions
from ‘‘2. Coal-fired unit low rank virgin
coal,’’ ‘‘3. IGCC,’’ ‘‘4. Liquid oil-fired
unit—continental (excluding limiteduse liquid oil-fired subcategory units),’’
‘‘Liquid oil-fired unit—non-continental
(excluding limited-use liquid oil-fired
subcategory units),’’ and ‘‘6. Solid oilderived fuel-fired unit.’’
In addition, the format of the inputand output-based lead emissions limits
for ‘‘3. IGCC unit’’ was incorrect as
published (i.e., the incorrect ‘‘1.9E+2 lb/
MMBtu or 1.8E0 lb/MWh’’ instead of
the correct ‘‘1.9E+2 lb/TBtu or 1.8E0 lb/
GWh’’). Further, the output-format
values for the antimony and beryllium
emission limits for ‘‘6. Solid oil-derived
fuel-fired unit’’ were incorrect as
published (i.e., the incorrect ‘‘8.0E–3 lb/
GWh’’ instead of the correct ‘‘7.0E–3 lb/
GWh’’ for antimony and the incorrect
‘‘6.0E–4 lb/GWh’’ instead of the correct
‘‘5.0E–4 lb/GWh’’ for beryllium). In each
case, the correct values are indicated in
the spreadsheets found in docket entry
EPA–HQ–OAR–2009–0234–20132 and
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23401
the published values are transcription
errors.
30. For the reasons described in
Paragraph 24 above, Table 7 to Subpart
UUUUU of Part 63 is revised to address
the inadvertent omission of the alternate
90-day averaging period that is
available.
31. For the reasons described in
Paragraph 24 above, Paragraphs 6.2.1.4
and 6.2.2.3 to Appendix A to Subpart
UUUUU of Part 63 are revised to
address the inadvertent omission of the
alternate 90-day averaging period that is
available.
32. Paragraph 7.2.4 to Appendix A to
Subpart UUUUU of Part 63 is revised to
correct the typographical error related to
the incorrect cross reference to
paragraphs 7.1.10.1 through 7.1.10.7;
these paragraphs do not exist, however.
The correct cross reference is
paragraphs 7.1.9.1 through 7.1.9.7.
33. Paragraph 7.2.5.3.4 to Appendix A
to Subpart UUUUU of Part 63 is revised
to correct the typographical error related
to the incorrect cross reference to
paragraph 7.1.90.1; this paragraph does
not exist, however. The correct cross
reference is paragraph 7.1.9.1.
Statutory and Executive Order Reviews
Under Executive Order (EO) 12866,
Regulatory Planning and Review (58 FR
51735, October 4, 1993), this action is
not a ‘‘significant regulatory action’’ and
is therefore not subject to review by the
Office of Management and Budget
(OMB). This action is not a ‘‘major rule’’
as defined by 5 U.S.C. 804(2). The
technical corrections do not impose an
information collection burden under the
provisions of the Paperwork Reduction
Act of 1995 (44 U.S.C. 3501 et seq.).
Because EPA has made a ‘‘good
cause’’ finding that this action is not
subject to notice and comment
requirements under the APA or any
other statute, it is not subject to the
regulatory flexibility provisions of the
Regulatory Flexibility Act (5 U.S.C. 601
et seq.), or to sections 202 and 205 of the
Unfunded Mandates Reform Act of 1995
(UMRA) (Pub. L. 104–4). In addition,
this action does not significantly or
uniquely affect small governments or
impose a significant intergovernmental
mandate, as described in sections 203
and 204 of the UMRA.
The corrections do not have
substantial direct effects on the states, or
on the relationship between the national
government and the states, or on the
distribution of power and
responsibilities among the various
levels of government, as specified in EO
13132, Federalism (64 FR 43255, August
10, 1999).
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This action also does not significantly
or uniquely affect the communities of
tribal governments, as specified by EO
13175, Consultation and Coordination
with Indian Tribal Governments (65 FR
67249, November 9, 2000). The
technical corrections also are not subject
to EO 13045, Protection of Children
from Environmental Health and Safety
Risks (62 FR 19885, April 23, 1997)
because this action is not economically
significant.
The corrections are not subject to EO
13211, Actions Concerning Regulations
That Significantly Affect Energy Supply,
Distribution, or Use (66 FR 28355, May
22, 2001) because this action is not a
significant regulatory action under EO
12866.
The corrections do not involve
changes to the technical standards
related to test methods or monitoring
methods; thus, the requirements of
section 12(d) of the National
Technology Transfer and Advancement
Act of 1995 (15 U.S.C. 272) do not
apply.
The corrections also do not involve
special consideration of environmental
justice-related issues as required by EO
12898, Federal Actions to Address
Environmental Justice in Minority
Populations and Low-Income
Populations (59 FR 7629, February 16,
1994).
The Congressional Review Act, 5
U.S.C. 801 et seq., as added by the Small
Business Regulatory Enforcement
Fairness Act of 1996 (SBREFA),
generally provides that before a rule
may take effect, the agency
promulgating the rule must submit a
rule report, which includes a copy of
the rule, to each House of the Congress
and to the Comptroller General of the
U.S. The EPA submitted a report
containing the final action and other
required information to the U.S. Senate,
the U.S. House of Representatives, and
the Comptroller General of the U.S. This
action is not a ‘‘major rule’’ as defined
by 5 U.S.C. 804(2). The final rule will
be effective on April 16, 2012.
The EPA’s compliance with the above
statutes and EOs for the underlying rule
is discussed in the February 16, 2012,
Federal Register document containing
‘‘National Emission Standards for
Hazardous Air Pollutants from Coaland Oil-fired Electric Utility Steam
Generating Units and Standards of
Performance for Fossil-Fuel-Fired
Electric Utility, Industrial-CommercialInstitutional, and Small IndustrialCommercial-Institutional Steam
Generating Units.’’
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16:05 Apr 18, 2012
Jkt 226001
List of Subjects
40 CFR Part 60
Environmental protection,
Administrative practice and procedure,
Air pollution control, Incorporation by
reference, Intergovernmental relations,
Reporting and recordkeeping
requirements.
40 CFR Part 63
Environmental protection,
Administrative practice and procedure,
Air pollution control, Hazardous
substances, Incorporation by reference,
Intergovernmental relations, Reporting
and recordkeeping requirements.
5. Revise § 63.9982(a)(1), (a)(2), and
(d) to read as follows:
PART 60—[AMENDED]
1. The authority citation for part 60
continues to read as follows:
■
Authority: 42 U.S.C. 7401 et seq.
2. In § 60.41Da, revise the definition
of ‘‘Boiler operating day’’ to read as
follows:
■
Definitions.
*
*
*
*
*
Boiler operating day for units
constructed, reconstructed, or modified
before March 1, 2005, means a 24-hour
period during which fossil fuel is
combusted in a steam-generating unit
for the entire 24 hours. For units
constructed, reconstructed, or modified
after February 28, 2005, boiler operating
day means a 24-hour period between 12
midnight and the following midnight
during which any fuel is combusted at
any time in the steam-generating unit. It
is not necessary for fuel to be combusted
the entire 24-hour period.
*
*
*
*
*
■ 3. Revise § 60.49Da(a)(4)(i) to read as
follows:
Emission monitoring.
(a) * * *
(4) * * *
(i) The affected facility combusts only
gaseous fuels and/or liquid fuels
(excluding residue oil) with a potential
SO2 emissions rate no greater than 26
ng/J (0.060 lb/MMBtu), and the unit
operates according to a written sitespecific monitoring plan approved by
the permitting authority. This
monitoring plan must include
procedures and criteria for establishing
and monitoring specific parameters for
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4. The authority citation for 40 CFR
Part 63 continues to read as follows:
■
■
Accordingly, title 40, chapter I, of the
Code of the Federal Regulations is
amended by making the following
correcting amendments:
§ 60.49Da
PART 63—[AMENDED]
Authority: 42 U.S.C. 7401, et seq.
Dated: March 27, 2012.
Lisa P. Jackson,
Administrator.
§ 60.41Da
the affected facility indicative of
compliance with the opacity standard.
For testing performed as part of this sitespecific monitoring plan, the permitting
authority may require as an alternative
to the notification and reporting
requirements specified in §§ 60.8 and
60.11 that the owner or operator submit
any deviations with the excess
emissions report required under
§ 60.51Da(d).
*
*
*
*
*
§ 60.9982 What is the affected source of
this subpart?
(a) * * *
(1) The affected source of this subpart
is the collection of all existing coal- or
oil-fired EGUs, as defined in § 63.10042,
within a subcategory.
(2) The affected source of this subpart
is each new or reconstructed coal- or
oil-fired EGU as defined in § 63.10042.
*
*
*
*
*
(d) An EGU is existing if it is not new
or reconstructed. An existing electric
steam generating unit that meets the
applicability requirements after the
effective date of this final rule due to a
change in process (e.g., fuel or
utilization) is considered to be an
existing source under this subpart.
*
*
*
*
*
■ 6. Revise § 63.9985(a)(2) to read as
follows:
§ 63.9985
What is a new EGU?
(a) * * *
(2) An EGU that commenced
reconstruction after May 3, 2011.
*
*
*
*
*
■ 7. In § 63.9991, revise paragraph(c)
introductory text to read as follows:
§ 63.9991 What emission limitations, work
practice standards, and operating limits
must I meet?
*
*
*
*
*
(c) You may use the alternate SO2
limit in Tables 1 and 2 to this subpart
only if your EGU:
*
*
*
*
*
■ 8. In § 63.10000, revise
paragraphs(c)(1) introductory text,
(c)(1)(i)(B), (c)(2)(iv), (d)(5)(i), (d)(5)(iv)
and (f) to read as follows:
§ 63.10000 What are my general
requirements for complying with this
subpart?
*
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*
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*
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(c)(1) For coal-fired units, IGCC units,
and solid oil-derived fuel-fired units,
initial performance testing is required
for all pollutants, to demonstrate
compliance with the applicable
emission limits.
(i) * * *
(B) You may not pursue the LEE
option for Hg if your coal-fired, solid
oil-derived fuel-fired EGU or IGCC EGU
is new.
*
*
*
*
*
(2) * * *
(iv) If your unit qualifies as a limiteduse liquid oil-fired as defined in
§ 63.10042, then you are not subject to
the emission limits in Tables 1 and 2,
but you must comply with the
performance tune-up work practice
requirements in Table 3.
*
*
*
*
*
(d) * * *
(5) * * *
(i) Installation of the CMS or sorbent
trap monitoring system sampling probe
or other interface at a measurement
location relative to each affected process
unit such that the measurement is
representative of control of the exhaust
emissions (e.g., on or downstream of the
last control device). See § 63.10010(a)
for further details. For PM CPMS
installations, follow the procedures in
§ 63.10010(h).
*
*
*
*
*
(iv) Performance evaluation
procedures and acceptance criteria (e.g.,
calibrations), including the quality
control program in accordance with the
general requirements of § 63.8(d).
*
*
*
*
*
(f) You are subject to the requirements
of this subpart for at least 6 months
following the last date you met the
definition of an EGU subject to this
subpart (e.g., 6 months after a
cogeneration unit provided more than
one third of its potential electrical
output capacity and more than 25
megawatts electrical output to any
power distribution system for sale). You
may opt to remain subject to the
provisions of this subpart beyond 6
months after the last date you met the
definition of an EGU subject to this
subpart, unless you are a solid waste
incineration unit subject to standards
under CAA section 129 (e.g., 40 CFR
Part 60, Subpart CCCC (New Source
Performance Standards (NSPS) for
Commercial and Industrial Solid Waste
Incineration Units, or Subpart DDDD
(Emissions Guidelines (EG) for Existing
Commercial and Industrial Solid Waste
Incineration Units). Notwithstanding
the provisions of this subpart, an EGU
that starts combusting solid waste is
immediately subject to standards under
VerDate Mar<15>2010
16:05 Apr 18, 2012
Jkt 226001
CAA section 129 and the EGU remains
subject to those standards until the EGU
no longer meets the definition of a solid
waste incineration unit consistent with
the provisions of the applicable CAA
section 129 standards.
*
*
*
*
*
■ 9. Revise § 63.10005(b)(2), (d)(1),
(d)(4)(ii), and (h)(3)(iii)(C)(1) and (2) to
read as follows:
§ 63.10005 What are my initial compliance
requirements and by what date must I
conduct them?
*
*
*
*
*
(b) * * *
(2) For a performance test based on
data from a certified CEMS or sorbent
trap monitoring system, the test consists
of all valid CMS data recorded in the 30
boiler operating days immediately
preceding that date;
*
*
*
*
*
(d) * * *
(1) For an affected coal-fired, solid oilderived fuel-fired, or liquid oil-fired
EGU, you may demonstrate initial
compliance with the applicable SO2,
HCl, or HF emissions limit in Table 1
or 2 to this subpart through use of an
SO2, HCl, or HF CEMS installed and
operated in accordance with Part 75 of
this chapter or Appendix B to this
subpart, as applicable. You may also
demonstrate compliance with a
filterable PM emission limit in Table 1
or 2 to this subpart through use of a PM
CEMS installed, certified, and operated
in accordance with § 63.10010(i). Initial
compliance is achieved if the arithmetic
average of 30-boiler operating days of
quality-assured CEMS data, expressed
in units of the standard (see
§ 63.10007(e)), meets the applicable
SO2, PM, HCl, or HF emissions limit in
Table 1 or 2 to this subpart. Use
Equation 19–19 of Method 19 in
appendix A–7 to Part 60 of this chapter
to calculate the 30-boiler operating day
average emissions rate. (Note: For this
calculation, the term Ehj in Equation 19–
19 must be in the same units of measure
as the applicable HCl or HF emission
limit in Table 1 or 2 to this subpart).
*
*
*
*
*
(4) * * *
(i) * * *
(ii) You must demonstrate continuous
compliance with the CMS site-specific
operating limit that corresponds to the
results of the performance test
demonstrating compliance with the HCl
or HF emissions limit.
*
*
*
*
*
(h) * * *
(3) * * *
(iii) * * *
(C) * * *
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23403
(1) Multiply the average lb/TBtu Hg
emission rate (determined according to
paragraph (h)(3)(iii)(A) of this section)
by the maximum potential annual heat
input to the unit (TBtu), which is equal
to the maximum rated unit heat input
(TBtu/hr) times 8,760 hours. If the
maximum rated heat input value is
expressed in units of MMBtu/hr,
multiply it by 10 ¥6 to convert it to
TBtu/hr; or
(2) Multiply the average lb/GWh Hg
emission rate (determined according to
paragraph (h)(3)(iii)(B) of this section)
by the maximum potential annual
electricity generation (GWh), which is
equal to the maximum rated electrical
output of the unit (GW) times 8,760
hours. If the maximum rated electrical
output value is expressed in units of
MW, multiply it by 10 ¥3 to convert it
to GW; or
*
*
*
*
*
■ 10. Revise § 63.10006(a) to read as
follows:
§ 63.10006 When must I conduct
subsequent performance tests or tune-ups?
(a) For liquid oil-fired, solid oilderived fuel-fired and coal-fired EGUs
and IGCC units using PM CPMS to
monitor continuous performance with
an applicable emission limit as
provided for under § 63.10000(c), you
must conduct all applicable
performance tests according to Table 5
to this subpart and § 63.10007 at least
every year.
*
*
*
*
*
■ 11. Revise § 63.10007(c) to read as
follows:
§ 63.10007 What methods and other
procedures must I use for the performance
tests?
*
*
*
*
*
(c) If you choose to comply with the
filterable PM emission limit and
demonstrate continuous performance
using a PM CPMS for an applicable
emission limit as provided for in
§ 63.10000(c), you must also establish
an operating limit according to
§ 63.10011(b) and Tables 4 and 6 to this
subpart. Should you desire to have
operating limits that correspond to loads
other than maximum normal operating
load, you must conduct testing at those
other loads to determine the additional
operating limits.
*
*
*
*
*
■ 12. In § 63.10009, revise paragraphs
(g) introductory text and (j)(2)(i)(A) to
read as follows:
§ 63.10009 May I use emissions averaging
to comply with this subpart?
*
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*
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Federal Register / Vol. 77, No. 76 / Thursday, April 19, 2012 / Rules and Regulations
(g) You must determine the weighted
average emissions rate in units of the
applicable emissions limit on a 30 day
rolling average (90 day rolling average
for Hg) basis according to paragraphs
(g)(1) through (2) of this section. The
first averaging period begins on 30 (or
90 for Hg) days after February 16, 2015
or the date that you begin emissions
averaging, whichever is earlier.
*
*
*
*
*
(j) * * *
(2) * * *
(i) * * *
(A) Whether the content of the plan
includes all of the information specified
in paragraph (j)(1) of this section; and
*
*
*
*
*
■ 13. In § 63.10010, revise paragraphs
(a)(6)(iii), (a)(6)(iv) and (g) to read as
follows:
§ 63.10010 What are my monitoring,
installation, operation, and maintenance
requirements?
(a) * * *
(6) * * *
(iii) Sum the products determined
under paragraph (a)(6)(ii) of this section;
and
(iv) Divide the result obtained in
paragraph (a)(6)(iii) of this section by
the total hourly stack gas flow rate for
the unit, summed across all of the stacks
or ducts.
*
*
*
*
*
(g) If you use a Hg CEMS or a sorbent
trap monitoring system, you must
install, certify, operate, maintain and
quality-assure the data from the
monitoring system in accordance with
appendix A to this subpart. You must
calculate and record a 30- (or, if
alternate emissions averaging is used,
90-) boiler operating day rolling average
Hg emission rate, in units of the
Where:
Heri is the hourly emissions rate for hour i
and n is the number of hourly emissions
rate values collected over 30- (or, if
applicable, 90-) boiler operating days.
*
*
*
*
*
17. Revise § 63.10022(a)(1) to read as
follows:
srobinson on DSK4SPTVN1PROD with RULES
■
(a) * * *
(1) For each 30- (or 90-) day rolling
average period, demonstrate compliance
with the average weighted emissions
limit for the existing units participating
18:20 Apr 18, 2012
Jkt 226001
§ 63.10011 How do I demonstrate initial
compliance with the emissions limits and
work practice standards?
*
*
*
*
*
(c)(1) If you use CEMS or sorbent trap
monitoring systems to measure a HAP
(e.g., Hg or HCl) directly, the first 30boiler operating day (or, if alternate
emissions averaging is used for Hg, the
90-boiler operating day) rolling average
emission rate obtained with certified
CEMS after the applicable date in
§ 63.9984 (or, if applicable, prior to that
date, as described in § 63.10005(b)(2)),
expressed in units of the standard, is the
initial performance test. Initial
compliance is demonstrated if the
results of the performance test meet the
applicable emission limit in Table 1 or
2 to this subpart.
*
*
*
*
*
■ 15. Revise § 63.10020(d) to read as
follows:
§ 63.10020 How do I monitor and collect
data to demonstrate continuous
compliance?
*
*
*
*
*
in the emissions averaging option as
determined in § 63.10009(f) and (g);
*
*
*
*
*
■ 18. Revise § 63.10030(e)(7)(i) to read
as follows:
§ 63.10030 What notifications must I
submit and when?
*
§ 63.10022 How do I demonstrate
continuous compliance under the
emissions averaging provision?
VerDate Mar<15>2010
standard, updated after each new boiler
operating day. Each 30- (or, if alternate
emissions averaging is used, 90-) boiler
operating day rolling average emission
rate, calculated according to section 6.2
of appendix A to the subpart, is the
average of all of the valid hourly Hg
emission rates in the preceding 30- (or,
if alternate emissions averaging is used,
a 90-) boiler operating days. Section
7.1.4.3 of appendix A to this subpart
explains how to reduce sorbent trap
monitoring system data to an hourly
basis.
*
*
*
*
*
■ 14. Revise § 63.10011(c)(1) to read as
follows:
*
*
*
*
(e) * * *
(7) * * *
(i) A summary of the results of the
annual performance tests and
documentation of any operating limits
that were reestablished during this test,
if applicable. If you are conducting stack
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(d) Except for periods of monitoring
system malfunctions or monitoring
system out-of-control periods, repairs
associated with monitoring system
malfunctions or monitoring system outof-control periods, and required
monitoring system quality assurance or
quality control activities including, as
applicable, calibration checks and
required zero and span adjustments),
failure to collect required data is a
deviation from the monitoring
requirements.
*
*
*
*
*
16. Revise § 63.10021(b) to read as
follows:
■
§ 63.10021 How do I demonstrate
continuous compliance with the emission
limitations, operating limits, and work
practice standards?
*
*
*
*
*
(b) Except as otherwise provided in
§ 63.10020(c), if you use a CEMS to
measure SO2, PM, HCl, HF, or Hg
emissions, or using a sorbent trap
monitoring system to measure Hg
emissions, you must demonstrate
continuous compliance by using all
quality-assured hourly data recorded by
the CEMS (or sorbent trap monitoring
system) and the other required
monitoring systems (e.g., flow rate, CO2,
O2, or moisture systems) to calculate the
arithmetic average emissions rate in
units of the standard on a continuous
30-boiler operating day (or, if alternate
emissions averaging is used for Hg, 90boiler operating day) rolling average
basis, updated at the end of each new
boiler operating day. Use Equation 8 to
determine the 30- (or, if applicable,
90-) boiler operating day rolling average.
tests once every 3 years consistent with
§ 63.10006(b), the date of the last three
stack tests, a comparison of the emission
level you achieved in the last three stack
tests to the 50 percent emission limit
threshold required in § 63.10006(i), and
a statement as to whether there have
been any operational changes since the
last stack test that could increase
emissions.
*
*
*
*
*
19. Revise § 63.10031(c)(4) to read as
follows:
■
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Federal Register / Vol. 77, No. 76 / Thursday, April 19, 2012 / Rules and Regulations
§ 63.10031
when?
What reports must I submit and
*
*
*
*
*
(c) * * *
(4) Include the date of the most recent
tune-up for each unit subject to the
requirement to conduct a performance
tune-up according to § 63.10021(e).
Include the date of the most recent
burner inspection if it was not done
every 36 (or 48) months and was
delayed until the next scheduled unit
shutdown.
*
*
*
*
*
20. In § 63.10042, revise the definition
‘‘Non-mercury (Hg) HAP metals’’ and
add the definition ‘‘Oil’’ to read as
follows:
■
§ 63.10042
subpart?
What definitions apply to this
*
*
*
*
*
Non-mercury (Hg) HAP metals means
Antimony (Sb), Arsenic (As), Beryllium
(Be), Cadmium (Cd), Chromium (Cr),
Cobalt (Co), Lead (Pb), Manganese (Mn),
Nickel (Ni), and Selenium (Se).
23405
Oil means crude oil or petroleum or
a fuel derived from crude oil or
petroleum, including distillate and
residual oil, solid oil-derived fuel (e.g.,
petroleum coke) and gases derived from
solid oil-derived fuels (not meeting the
definition of natural gas).
*
*
*
*
*
■ 22. Revise table 2 and table 7 to
Subpart UUUUU of Part 63 to read as
follows:
Tables to Subpart UUUUU of Part 63
*
*
*
*
*
TABLE 2 TO SUBPART UUUUU OF PART 63—EMISSION LIMITS FOR EXISTING EGUS
[As stated in § 63.9991, you must comply with the following applicable emission limits] 1
If your EGU is in this subcategory
. . .
For the following pollutants . . .
1. Coal-fired unit not low rank virgin coal.
a.
Filterable particulate matter
(PM).
OR
Total non-Hg HAP metals ............
OR
Individual HAP metals:
OR
Sulfur dioxide (SO2) 4 ...................
c. Mercury (Hg) .............................
a.
Filterable particulate matter
(PM).
OR
Total non-Hg HAP metals ............
srobinson on DSK4SPTVN1PROD with RULES
OR
Individual HAP metals:
16:05 Apr 18, 2012
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Collect a minimum of 1 dscm per
run.
Collect a minimum of 1 dscm per
run.
8.0E–1 lb/TBtu or 8.0E–3 lb/GWh.
1.1E0 lb/TBtu or 2.0E–2 lb/GWh.
2.0E–1 lb/TBtu or 2.0E–3 lb/GWh.
3.0E–1 lb/TBtu or 3.0E–3 lb/GWh.
2.8E0 lb/TBtu or 3.0E–2 lb/GWh.
8.0E–1 lb/TBtu or 8.0E–3 lb/GWh.
1.2E0 lb/TBtu or 2.0E–2 lb/GWh.
4.0E0 lb/TBtu or 5.0E–2 lb/GWh.
3.5E0 lb/TBtu or 4.0E–2 lb/GWh.
5.0E0 lb/TBtu or 6.0E–2 lb/GWh.
2.0E–3 lb/MMBtu or 2.0E–2 lb/
MWh.
2.0E–1 lb/MMBtu or 1.5E0 lb/
MWh.
1.2E0 lb/TBtu or 1.3E–2 lb/GWh ..
3.0E–2 lb/MMBtu or 3.0E–1 lb/
MWh.2
OR
5.0E–5 lb/MMBtu or 5.0E–1 lb/
GWh.
OR
For Method 26A, collect a minimum of 0.75 dscm per run; for
Method 26, collect a minimum
of 120 liters per run.
For ASTM D6348–03 3 or Method
320, sample for a minimum of 1
hour.
SO2 CEMS.
LEE Testing for 30 days with 10
days maximum per Method 30B
run or Hg CEMS or sorbent trap
monitoring system only.
Collect a minimum of 1 dscm per
run.
Collect a minimum of 1 dscm per
run.
Collect a minimum of 3 dscm per
run.
Antimony (Sb) ...............................
Arsenic (As) ..................................
Beryllium (Be) ...............................
Cadmium (Cd) ..............................
Chromium (Cr) ..............................
Cobalt (Co) ...................................
Lead (Pb) ......................................
Manganese (Mn) ..........................
Nickel (Ni) .....................................
Selenium (Se) ...............................
VerDate Mar<15>2010
3.0E–2 lb/MMBtu or 3.0E–1 lb/
MWh.2
OR
5.0E–5 lb/MMBtu or 5.0E–1 lb/
GWh.
OR
Using these requirements, as appropriate (e.g., specified sampling
volume or test run duration) and
limitations with the test methods
in Table 5 . . .
Collect a minimum of 3 dscm per
run.
Antimony (Sb) ...............................
Arsenic (As) ..................................
Beryllium (Be) ...............................
Cadmium (Cd) ..............................
Chromium (Cr) ..............................
Cobalt (Co) ...................................
Lead (Pb) ......................................
Manganese (Mn) ..........................
Nickel (Ni) .....................................
Selenium (Se) ...............................
b. Hydrogen chloride (HCl) ...........
2. Coal-fired unit low rank virgin
coal.
You must meet the following
emission limits and work practice
standards . . .
Fmt 4700
8.0E–1 lb/TBtu or 8.0E–3 lb/GWh.
1.1E0 lb/TBtu or 2.0E–2 lb/GWh.
2.0E–1 lb/TBtu or 2.0E–3 lb/GWh.
3.0E–1 lb/TBtu or 3.0E–3 lb/GWh.
2.8E0 lb/TBtu or 3.0E–2 lb/GWh.
8.0E–1 lb/TBtu or 8.0E–3 lb/GWh.
1.2E0 lb/TBtu or 2.0E–2 lb/GWh.
4.0E0 lb/TBtu or 5.0E–2 lb/GWh.
3.5E0 lb/TBtu or 4.0E–2 lb/GWh.
5.0E0 lb/TBtu or 6.0E–2 lb/GWh.
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TABLE 2 TO SUBPART UUUUU OF PART 63—EMISSION LIMITS FOR EXISTING EGUS—Continued
[As stated in § 63.9991, you must comply with the following applicable emission limits] 1
Using these requirements, as appropriate (e.g., specified sampling
volume or test run duration) and
limitations with the test methods
in Table 5 . . .
For the following pollutants . . .
You must meet the following
emission limits and work practice
standards . . .
b. Hydrogen chloride (HCl) ...........
If your EGU is in this subcategory
. . .
2.0E–3 lb/MMBtu or 2.0E–2 lb/
MWh.
For Method 26A, collect a minimum of 0.75 dscm per run; for
Method 26, collect a minimum
of 120 liters per run.
For ASTM D6348–03 3 or Method
320, sample for a minimum of 1
hour.
2.0E–1 lb/MMBtu or 1.5E0 lb/
MWh.
4.0E0 lb/TBtu or 4.0E–2 lb/GWh ..
SO2 CEMS.
OR
Sulfur dioxide (SO2) 4 ...................
c. Mercury (Hg) .............................
3. IGCC unit ...................................
a.
Filterable particulate matter
(PM).
OR
Total non-Hg HAP metals ............
OR
Individual HAP metals:
4.0E–2 lb/MMBtu or 4.0E–1 lb/
MWh.2
OR
6.0E–5 lb/MMBtu or 5.0E–1 lb/
GWh.
OR
1.4E0 lb/TBtu or 2.0E–2 lb/GWh.
1.5E0 lb/TBtu or 2.0E–2 lb/GWh.
1.0E–1 lb/TBtu or 1.0E–3 lb/GWh.
1.5E–1 lb/TBtu or 2.0E–3 lb/GWh.
2.9E0 lb/TBtu or 3.0E–2 lb/GWh.
1.2E0 lb/TBtu or 2.0E–2 lb/GWh.
1.9E+2 lb/TBtu or 1.8E0 lb/GWh.
2.5E0 lb/TBtu or 3.0E–2 lb/GWh.
6.5E0 lb/TBtu or 7.0E–2 lb/GWh.
2.2E+1 lb/TBtu or 3.0E–1 lb/GWh.
5.0E–4 lb/MMBtu or 5.0E–3 lb/
MWh.
c. Mercury (Hg) .............................
2.5E0 lb/TBtu or 3.0E–2 lb/GWh ..
a.
matter
3.0E–2 lb/MMBtu or 3.0E–1 lb/
MWh.2
OR
Total HAP metals .........................
OR
8.0E–4 lb/MMBtu or 8.0E–3 lb/
MWh.
OR
Filterable
(PM).
particulate
srobinson on DSK4SPTVN1PROD with RULES
OR
Individual HAP metals:
16:05 Apr 18, 2012
Jkt 226001
PO 00000
Frm 00034
For Method 26A, collect a minimum of 1 dscm per run; for
Method 26, collect a minimum
of 120 liters per run.
For ASTM D6348–03 3 or Method
320, sample for a minimum of 1
hour.
LEE Testing for 30 days with 10
days maximum per Method 30B
run or Hg CEMS or sorbent trap
monitoring system only.
Collect a minimum of 1 dscm per
run.
Collect a minimum of 1 dscm per
run.
Collect a minimum of 1 dscm per
run.
Antimony (Sb) ...............................
Arsenic (As) ..................................
Beryllium (Be) ...............................
Cadmium (Cd) ..............................
Chromium (Cr) ..............................
Cobalt (Co) ...................................
Lead (Pb) ......................................
Manganese (Mn) ..........................
Nickel (Ni) .....................................
Selenium (Se) ...............................
Mercury (Hg) .................................
VerDate Mar<15>2010
Collect a minimum of 1 dscm per
run.
Collect a minimum of 2 dscm per
run.
Antimony (Sb) ...............................
Arsenic (As) ..................................
Beryllium (Be) ...............................
Cadmium (Cd) ..............................
Chromium (Cr) ..............................
Cobalt (Co) ...................................
Lead (Pb) ......................................
Manganese (Mn) ..........................
Nickel (Ni) .....................................
Selenium (Se) ...............................
b. Hydrogen chloride (HCl) ...........
4. Liquid oil-fired unit—continental
(excluding limited-use liquid oilfired subcategory units).
LEE Testing for 30 days with 10
days maximum per Method 30B
run or Hg CEMS or sorbent trap
monitoring system only.
Collect a minimum of 1 dscm per
run.
Fmt 4700
1.3E+1 lb/TBtu or 2.0E–1 lb/GWh.
2.8E0 lb/TBtu or 3.0E–2 lb/GWh.
2.0E–1 lb/TBtu or 2.0E–3 lb/GWh.
3.0E–1 lb/TBtu or 2.0E–3 lb/GWh.
5.5E0 lb/TBtu or 6.0E–2 lb/GWh.
2.1E+1 lb/TBtu or 3.0E–1 lb/GWh.
8.1E0 lb/TBtu or 8.0E–2 lb/GWh.
2.2E+1 lb/TBtu or 3.0E–1 lb/GWh.
1.1E+2 lb/TBtu or 1.1E0 lb/GWh.
3.3E0 lb/TBtu or 4.0E–2 lb/GWh.
2.0E–1 lb/TBtu or 2.0E–3 lb/GWh.
Sfmt 4700
E:\FR\FM\19APR1.SGM
For Method 30B sample volume
determination (Section 8.2.4),
the estimated Hg concentration
should nominally be <1⁄2; the
standard.
19APR1
Federal Register / Vol. 77, No. 76 / Thursday, April 19, 2012 / Rules and Regulations
23407
TABLE 2 TO SUBPART UUUUU OF PART 63—EMISSION LIMITS FOR EXISTING EGUS—Continued
[As stated in § 63.9991, you must comply with the following applicable emission limits] 1
2.0E–3 lb/MMBtu or 1.0E–2 lb/
MWh.
c. Hydrogen fluoride (HF) .............
5. Liquid oil-fired unit—non-continental (excluding limited-use liquid oil-fired subcategory units).
For the following pollutants . . .
You must meet the following
emission limits and work practice
standards . . .
b. Hydrogen chloride (HCl) ...........
If your EGU is in this subcategory
. . .
4.0E–4 lb/MMBtu or 4.0E–3 lb/
MWh.
a.
3.0E–2 lb/MMBtu or 3.0E–1 lb/
MWh.2
Filterable
(PM).
particulate
matter
OR
Total HAP metals
OR
6.0E–4 lb/MMBtu or 7.0E–3 lb/
MWh.
OR
OR
Individual HAP metals:
2.2E0 lb/TBtu or 2.0E–2 lb/GWh.
4.3E0 lb/TBtu or 8.0E–2 lb/GWh.
6.0E–1 lb/TBtu or 3.0E–3 lb/GWh.
3.0E–1 lb/TBtu or 3.0E–3 lb/GWh.
3.1E+1 lb/TBtu or 3.0E–1 lb/GWh.
1.1E+2 lb/TBtu or 1.4E0 lb/GWh.
4.9E0 lb/TBtu or 8.0E–2 lb/GWh.
2.0E+1 lb/TBtu or 3.0E–1 lb/GWh.
4.7E+2 lb/TBtu or 4.1E0 lb/GWh.
9.8E0 lb/TBtu or 2.0E–1 lb/GWh.
4.0E–2 lb/TBtu or 4.0E–4 lb/GWh.
b. Hydrogen chloride (HCl) ...........
2.0E–4 lb/MMBtu or 2.0E–3 lb/
MWh.
c. Hydrogen fluoride (HF) .............
6.0E–5 lb/MMBtu or 5.0E–4 lb/
MWh.
a.
8.0E–3 lb/MMBtu or 9.0E–2 lb/
MWh.2
OR
4.0E–5 lb/MMBtu or 6.0E–1 lb/
GWh.
OR
Collect a minimum of 3 dscm per
run.
8.0E–1 lb/TBtu or 7.0E–3 lb/GWh.
3.0E–1 lb/TBtu or 5.0E–3 lb/GWh.
6.0E–2 lb/TBtu or 5.0E–4 lb/GWh.
3.0E–1 lb/TBtu or 4.0E–3 lb/GWh.
8.0E–1 lb/TBtu or 2.0E–2 lb/GWh.
1.1E0 lb/TBtu or 2.0E–2 lb/GWh.
8.0E–1 lb/TBtu or 2.0E–2 lb/GWh.
2.3E0 lb/TBtu or 4.0E–2 lb/GWh.
9.0E0 lb/TBtu or 2.0E–1 lb/GWh.
Filterable particulate matter
(PM).
OR
Total non-Hg HAP metals ............
srobinson on DSK4SPTVN1PROD with RULES
OR
Individual HAP metals ..................
Antimony (Sb) ...............................
Arsenic (As) ..................................
Beryllium (Be) ...............................
Cadmium (Cd) ..............................
Chromium (Cr) ..............................
Cobalt (Co) ...................................
Lead (Pb) ......................................
Manganese (Mn) ..........................
Nickel (Ni) .....................................
VerDate Mar<15>2010
16:05 Apr 18, 2012
Jkt 226001
PO 00000
Frm 00035
For Method 26A, collect a minimum of 1 dscm per Run; for
Method 26, collect a minimum
of 120 liters per run.
For ASTM D6348–03 3 or Method
320, sample for a minimum of 1
hour.
For Method 26A, collect a minimum of 1 dscm per run; for
Method 26, collect a minimum
of 120 liters per run.
For ASTM D6348–03 3 or Method
320, sample for a minimum of 1
hour.
Collect a minimum of 1 dscm per
run.
Collect a minimum of 1 dscm per
run.
Collect a minimum of 2 dscm per
run.
Antimony (Sb) ...............................
Arsenic (As) ..................................
Beryllium (Be) ...............................
Cadmium (Cd) ..............................
Chromium (Cr) ..............................
Cobalt (Co) ...................................
Lead (Pb) ......................................
Manganese (Mn) ..........................
Nickel (Ni) .....................................
Selenium (Se) ...............................
Mercury (Hg) .................................
6. Solid oil-derived fuel-fired unit ...
Using these requirements, as appropriate (e.g., specified sampling
volume or test run duration) and
limitations with the test methods
in Table 5 . . .
Fmt 4700
Sfmt 4700
E:\FR\FM\19APR1.SGM
For Method 30B sample volume
determination (Section 8.2.4),
the estimated Hg concentration
should nominally be <1⁄2; the
standard.
For Method 26A, collect a minimum of 1 dscm per run; for
Method 26, collect a minimum
of 120 liters per run.
For ASTM D6348–03 3 or Method
320, sample for a minimum of 2
hours.
For Method 26A, collect a minimum of 3 dscm per run.
For ASTM D6348–03 3 or Method
320, sample for a minimum of 2
hours.
Collect a minimum of 1 dscm per
run.
Collect a minimum of 1 dscm per
run.
19APR1
23408
Federal Register / Vol. 77, No. 76 / Thursday, April 19, 2012 / Rules and Regulations
TABLE 2 TO SUBPART UUUUU OF PART 63—EMISSION LIMITS FOR EXISTING EGUS—Continued
[As stated in § 63.9991, you must comply with the following applicable emission limits] 1
For the following pollutants . . .
You must meet the following
emission limits and work practice
standards . . .
Selenium (Se) ...............................
b. Hydrogen chloride (HCl) ...........
If your EGU is in this subcategory
. . .
1.2E0 lb/TBtu or 2.0E–2 lb/GWh.
5.0E–3 lb/MMBtu or 8.0E–2 lb/
MWh.
OR
Sulfur dioxide (SO2) 4 ...................
c. Mercury (Hg) .............................
3.0E–1 lb/MMBtu or 2.0E0 lb/
MWh.
2.0E–1 lb/TBtu or 2.0E–3 lb/GWh.
Using these requirements, as appropriate (e.g., specified sampling
volume or test run duration) and
limitations with the test methods
in Table 5 . . .
For Method 26A, collect a minimum of 0.75 dscm per run; for
Method 26, collect a minimum
of 120 liters per run.
For ASTM D6348–03 3 or Method
320, sample for a minimum of 1
hour.
SO2 CEMS.
LEE Testing for 30 days with 10
days maximum per Method 30B
run or Hg CEMS or Sorbent
trap monitoring system only.
1 For LEE emissions testing for total PM, total HAP metals, individual HAP metals, HCl, and HF, the required minimum sampling volume must
be increased nominally by a factor of two.
2 Gross electric output.
3 Incorporated by reference, see § 63.14.
4 You may not use the alternate SO limit if your EGU does not have some form of FGD system and SO CEMS installed.
2
2
*
*
*
*
*
TABLE 7 TO SUBPART UUUUU OF PART 63—DEMONSTRATING CONTINUOUS COMPLIANCE
[As stated in § 63.10021, you must show continuous compliance with the emission limitations for affected sources according to the following]
If you use one of the following to meet applicable emissions limits, operating limits, or work practice standards . . .
You demonstrate continuous compliance by . . .
1. CEMS to measure filterable PM, SO2, HCl, HF, or Hg emissions, or
using a sorbent trap monitoring system to measure Hg.
Calculating the 30- (or 90-) boiler operating day rolling arithmetic average emissions rate in units of the applicable emissions standard
basis at the end of each boiler operating day using all of the quality
assured hourly average CEMS or sorbent trap data for the previous
30-boiler operating days, excluding data recorded during periods of
startup or shutdown.
Calculating the arithmetic 30-boiler operating day rolling average of all
of the quality assured hourly average PM CPMS output data (e.g.,
milliamps, PM concentration, raw data signal) collected for all operating hours for the previous 30 boiler operating days, excluding data
recorded during periods of startup or shutdown.
If applicable, by conducting the monitoring in accordance with an approved site-specific monitoring plan.
Calculating the results of the testing in units of the applicable emissions standard.
2. PM CPMS to measure compliance with a parametric operating limit
3. Site-specific monitoring for liquid oil-fired units for HCl and HF emission limit monitoring.
4. Quarterly performance testing for coal-fired, solid oil derived fired, or
liquid oil-fired units to measure compliance with one or more applicable emissions limit in Table 1 or 2.
5. Conducting periodic performance tune-ups of your EGU(s) ...............
6. Work practice standards for coal-fired, liquid oil-fired, or solid oil-derived fuel-fired EGUs during startup.
7. Work practice standards for coal-fired, liquid oil-fired, or solid oil-derived fuel-fired EGUs during shutdown.
*
*
*
*
*
23. In Appendix A to Subpart
UUUUU of Part 63, revise paragraphs
6.2.1.4, 6.2.2.3, 7.2.4, 7.2.5.3.4, to read
as follows:
srobinson on DSK4SPTVN1PROD with RULES
■
Appendix A to Subpart UUUUU—Hg
Monitoring Provisions
*
*
*
VerDate Mar<15>2010
*
*
16:05 Apr 18, 2012
Jkt 226001
Conducting periodic performance tune-ups of your EGU(s), as specified in § 63.10021(e).
Operating in accordance with Table 3.
Operating in accordance with Table 3.
6.2.1.4 The heat input-based Hg emission
rate limit in Table 2 to this subpart must be
met on a 30 boiler operating day rolling
average basis, except as otherwise provided
in § 63.10009(a)(2). Use Equation 19–19 in
EPA Method 19 to calculate the Hg emission
rate for each averaging period. The term Ehj
in Equation 19–19 must be in the units of the
applicable emission limit. Do not include
PO 00000
Frm 00036
Fmt 4700
Sfmt 4700
non-operating hours with zero emissions in
the average.
*
*
*
*
*
6.2.2.3 The applicable electrical outputbased Hg emission rate limit in Table 1 or 2
to this subpart must be met on a 30-boiler
operating day rolling average basis, except as
otherwise provided in § 63.10009(a)(2). Use
Equation A–5 of this section to calculate the
Hg emission rate for each averaging period.
E:\FR\FM\19APR1.SGM
19APR1
Federal Register / Vol. 77, No. 76 / Thursday, April 19, 2012 / Rules and Regulations
*
*
*
*
*
7.2.4 Certification, Recertification,
and Quality-Assurance Test Reporting.
Except for daily QA tests of the required
monitoring systems (i.e., calibration
error tests and flow monitor interference
checks), the results of all required
certification, recertification, and qualityassurance tests described in paragraphs
7.1.9.1 through 7.1.9.7 of this section
(except for test results previously
submitted, e.g., under the ARP) shall be
submitted electronically, using the
ECMPS Client Tool, either prior to or
concurrent with the relevant quarterly
electronic emissions report.
*
*
*
*
*
7.2.5.3.4 The results of all daily
calibration error tests of the Hg CEMS,
as described in paragraph 7.1.9.1 of this
section and (if applicable) the results of
all daily flow monitor interference
checks.
*
*
*
*
*
[FR Doc. 2012–8703 Filed 4–18–12; 8:45 am]
BILLING CODE 6560–50–P
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 372
[EPA–HQ–OEI–2011–0196; FRL–9660–9]
RIN 2025–AA31
srobinson on DSK4SPTVN1PROD with RULES
Environmental Protection
Agency (EPA).
ACTION: Final rule.
AGENCY:
16:32 Apr 18, 2012
This final rule is effective April
19, 2012. The requirement of facilities
located in Indian country to report to
tribal governments is applicable
beginning with TRI reporting year 2012
(TRI reports due by July 1, 2013).
ADDRESSES: EPA has established a
docket for this action under Docket ID
No. EPA–HQ–OEI–2011–0196. All
documents in the docket are listed on
the www.regulations.gov Web site.
Although listed in the index, some
DATES:
Toxics Release Inventory (TRI)
Reporting for Facilities Located in
Indian Country and Clarification of
Additional Opportunities Available to
Tribal Governments Under the TRI
Program
VerDate Mar<15>2010
EPA is announcing new
opportunities for tribal participation
and engagement in the TRI Program.
Under this final rule, TRI reporting
facilities located in Indian country are
required to report to the appropriate
tribal government of their relevant area
instead of the State. This rule also
improves and clarifies certain
opportunities allowing tribal
governments to participate more fully in
the TRI Program. Further, because tribal
governmental structures may vary, EPA
is updating its terminology to refer to
the principal elected official of the Tribe
as the ‘‘Tribal Chairperson or equivalent
elected official.’’ EPA is also amending
its definition of ‘‘State’’ for purposes of
40 CFR part 372 to no longer include
Indian country, so as to avoid any
confusing overlap in terminology for
facilities located in Indian country.
With regard to the procedures for EPA
to modify the list of covered chemicals
and TRI reporting facilities, today’s rule
clarifies the opportunities available to
tribal governments. In particular, EPA is
including within the relevant provision
an opportunity for the Tribal
Chairperson or equivalent elected
official to request that EPA apply the
TRI reporting requirements to a specific
facility located within the Tribe’s Indian
country. Secondly, EPA is clarifying in
this rule that the Tribal Chairperson or
equivalent elected official may petition
EPA to add or delete a particular
chemical respectively to or from the list
of chemicals covered by TRI. In
finalizing the actions described, EPA is
helping to increase awareness of toxic
releases within tribal communities,
thereby increasing the understanding of
potential human health and ecological
impacts from these hazardous
chemicals.
SUMMARY:
Jkt 226001
PO 00000
Frm 00037
Fmt 4700
Sfmt 4700
information is not publicly available,
e.g., CBI 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 either electronically through
www.regulations.gov or in hard copy at
the OEI Docket, EPA/DC, EPA West,
Room 3334, 1301 Constitution Ave.
NW., Washington, DC. The Public
Reading Room is open from 8:30 a.m. to
4:30 p.m., Monday through Friday,
excluding legal holidays. The telephone
number for the Public Reading Room is
(202) 566–1744, and the telephone
number for the EPA Docket Center is
(202) 566–1752.
FOR FURTHER INFORMATION CONTACT:
Louise Camalier, Environmental
Analysis Division, Office of
Environmental Information (2842T),
Environmental Protection Agency, 1200
Pennsylvania Ave. NW., Washington,
DC 20460; telephone number: (202)
566–0503; fax number: (202) 566–0677;
email address: Camalier.louise@epa.gov,
for specific information on this notice.
For general information on EPCRA
Section 313, contact the Superfund, TRI,
EPCRA, RMP & Oil Information Center
toll free at (800) 424–9346, (703) 412–
9810 in the Washington, DC
metropolitan area, toll free TDD at (800)
553–7672, or visit the Web site at
https://www.epa.gov/superfund/
contacts/infocenter.
SUPPLEMENTARY INFORMATION:
I. General Information
Does this action apply to me?
You may be affected by this action if
you own or operate a facility located in
Indian country (see 40 CFR 372.3 for a
definition of Indian country) with a
toxic chemical(s) known by the owner
or operator to be manufactured
(including imported), processed, or
otherwise used in excess of an
applicable threshold quantity, as
referenced in 40 CFR 372.25, 372.27, or
372.28, at its covered facility described
in § 372.22. Potentially affected
categories and entities may include, but
are not limited to:
E:\FR\FM\19APR1.SGM
19APR1
ER19AP12.003</GPH>
Where:
¯
Eo = Hg emission rate for the averaging
period (lb/GWh).
Echo = Electrical output-based hourly Hg
emission rate for unit or stack operating
hour ‘‘h’’ in the averaging period, from
Equation A–4 of this section (lb/GWh).
n = Number of unit or stack operating hours
in the averaging period in which valid
data were obtained for all parameters.
(Note: Do not include non-operating hours
with zero emission rates in the average).
23409
]]>Agencies
[Federal Register Volume 77, Number 76 (Thursday, April 19, 2012)]
[Rules and Regulations]
[Pages 23399-23409]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 2012-8703]
-----------------------------------------------------------------------
ENVIRONMENTAL PROTECTION AGENCY
40 CFR Parts 60 and 63
[EPA-HQ-OAR-2009-0234; EPA-HQ-OAR-2011-0044; FRL-9654-8]
RIN 2060-AP52 and 2060-AR31
National Emission Standards for Hazardous Air Pollutants From
Coal- and Oil-Fired Electric Utility Steam Generating Units and
Standards of Performance for Fossil-Fuel-Fired Electric Utility,
Industrial-Commercial-Institutional, and Small Industrial-Commercial-
Institutional Steam Generating Units; Correction
AGENCY: Environmental Protection Agency (EPA).
ACTION: Final rule; correction.
-----------------------------------------------------------------------
SUMMARY: This document corrects certain preamble and regulatory text.
This action corrects typographical errors, such as cross-reference
errors and certain preamble text that is not consistent with the final
regulatory text, which published in the Federal Register on Thursday,
February 16, 2012 (77 FR 9304).
DATES: Effective date: April 19, 2012.
FOR FURTHER INFORMATION CONTACT: For the NESHAP action: Mr. William
Maxwell, Energy Strategies Group, Sector Policies and Programs
Division, (D243-01), Office of Air Quality Planning and Standards, U.S.
Environmental Protection Agency, Research Triangle Park, North Carolina
27711; Telephone number: (919) 541-5430; Fax number (919) 541-5450;
email address: maxwell.bill@epa.gov. For the new source performance
standard (NSPS) action: Mr. Christian Fellner, Energy Strategies Group,
Sector Policies and Programs Division, (D243-01), Office of Air Quality
Planning and Standards, U.S. Environmental Protection Agency, Research
Triangle Park, North Carolina 27711; Telephone number: (919) 541-4003;
Fax number (919) 541-5450; email address: fellner.christian@epa.gov.
SUPPLEMENTARY INFORMATION: This document corrects certain preamble and
regulatory text. It is proper to issue this final rule correction
without notice and comment. Section 553 of the Administrative Procedure
Act (APA), 5 U.S.C. 553(b)(B), provides that, when an agency for good
cause finds that notice and public procedure are impracticable,
unnecessary, or contrary to the public interest, the agency may issue a
rule without providing notice and an opportunity for public comment. We
have determined that there is good cause for making this action final
without prior proposal and opportunity for comment because the changes
to the rule are minor technical corrections, are noncontroversial, and
do not substantively change the agency actions taken in the final rule.
Notice and comment is unnecessary, because these changes do not affect
the rights or obligations of outside parties, and do not alter the
substantive requirements of the code of federal regulations (CFR),
except to the extent that one regulatory provision included an
inadvertent typographical error that EPA must amend to align with the
plain text of the Clean Air Act (CAA). We find that this constitutes
good cause under 5 U.S.C. 553(b)(B).The corrections can be categorized
generally as follows: Correction of typographical errors (e.g., cross-
reference errors) and correction of certain preamble text that does not
conform to the final regulatory text. Below, we identify each technical
correction to the preamble and regulatory text.
1. Table 5 on page 9368 is corrected to read as follows:
Table 5--Alternate Emission Limitations for Existing Coal- and Oil-Fired EGUS
--------------------------------------------------------------------------------------------------------------------------------------------------------
Liquid oil, Liquid oil, non-
Subcategory/pollutant Coal-fired EGUs IGCC continental continental Solid oil-derived
--------------------------------------------------------------------------------------------------------------------------------------------------------
SO2................................ 2.0E-1 lb/MMBtu (1.5E0 NA.................... NA................... NA................... 3.0E-1 lb/MMBtu
lb/MWh). (2.0E0 lb/MWh).
Total non-mercury metals........... 5.0E-5 lb/MMBtu (5.0E- 6.0E-5 lb/MMBtu (5.0E- 8.0E-4 lb/MMBtu (8.0E- 6.0E-4 lb/MMBtu(7.0E- 4.0E-5 lb/MMBtu (6.0E-
1 lb/GWh). 1 lb/GWh). 3 lb/MWh) a. 3 lb/MWh) a. 1 lb/GWh).
Antimony, Sb....................... 8.0E-1 lb/TBtu (8.0E-3 1.4E0 lb/TBtu (2.0E-2 1.3E+1 lb/TBtu (2.0E- 2.2E0 lb/TBtu (2.0E-2 8.0E-1 lb/TBtu (7.0E-
lb/GWh). lb/GWh). 1 lb/GWh). lb/GWh). 3 lb/GWh).
Arsenic, As........................ 1.1E0 lb/TBtu (2.0E-2 1.5E0 lb/TBtu (2.0E-2 2.8E0 lb/TBtu (3.0E-2 4.3E0 lb/TBtu (8.0E-2 3.0E-1 lb/TBtu (5.0E-
lb/GWh). lb/GWh). lb/GWh). lb/GWh). 3 lb/GWh).
Beryllium, Be...................... 2.0E-1 lb/TBtu (2.0E-3 1.0E-1 lb/TBtu (1.0E-3 2.0E-1 lb/TBtu (2.0E- 6.0E-1 lb/TBtu (3.0E- 6.0E-2 lb/TBtu (5.0E-
lb/GWh). lb/GWh). 3 lb/GWh). 3 lb/GWh). 4 lb/GWh).
Cadmium, Cd........................ 3.0E-1 lb/TBtu (3.0E-3 1.5E-1 lb/TBtu (2.0E-3 3.0E-1 lb/TBtu 2.0E-3 3.0E-1 lb/TBtu (3.0E- 3.0E-1 lb/TBtu (4.0E-
lb/GWh). lb/GWh). lb/GWh). 3 lb/GWh). 3 lb/GWh).
Chromium, Cr....................... 2.8E0 lb/TBtu (3.0E-2 2.9E0 lb/TBtu (3.0E-2 5.5E0 lb/TBtu (6.0E-2 3.1E+1 lb/TBtu (3.0E- 8.0E-1 lb/TBtu (2.0E-
lb/GWh). lb/GWh). lb/GWh). 1 lb/GWh). 2 lb/GWh).
Cobalt, Co......................... 8.0E-1 lb/TBtu (8.0E-3 1.2E0 lb/TBtu (2.0E-2 2.1E+1 lb/TBtu (3.0E- 1.1E+2 lb/TBtu (1.4E0 1.1E0 lb/TBtu (2.0E-2
lb/GWh). lb/GWh). 1 lb/GWh). lb/GWh). lb/GWh).
[[Page 23400]]
Lead, Pb........................... 1.2E0 lb/TBtu (2.0E-2 1.9E+2 lb/TBtu (1.8E0 8.1E0 lb/TBtu (8.0E-2 4.9E0 lb/TBtu (8.0E-2 8.0E-1 lb/TBtu (2.0E-
lb/GWh). lb/GWh). lb/GWh). lb/GWh). 2 lb/GWh).
Manganese, Mn...................... 4.0E0 lb/TBtu (5.0E-2 2.5E0 lb/TBtu (3.0E-2 2.2E+1 lb/TBtu (3.0E- 2.0E+1 lb/TBtu (3.0E- 2.3E0 lb/TBtu (4.0E-2
lb/GWh. lb/GWh). 1 lb/GWh). 1 lb/GWh). lb/GWh).
Mercury, Hg........................ NA.................... NA.................... 2.0E-1 lb/TBtu (2.0E- 4.0E-2 lb/TBtu (4.0E- NA.
3 lb/GWh). 4 lb/GWh).
Nickel, Ni......................... 3.5E0 lb/TBtu (4.0E-2 6.5E0 lb/TBtu (7.0E-2 1.1E+2 lb/TBtu (1.1E0 4.7E+2 lb/TBtu (4.1E0 9.0E0 lb/TBtu (2.0E-1
lb/GWh). lb/GWh). lb/GWh). lb/GWh). lb/GWh).
Selenium, Se....................... 5.0E0 lb/TBtu (6.0E-2 2.2E+1 lb/TBtu (3.0E-1 3.3E0 lb/TBtu (4.0E-2 9.8E0 lb/TBtu (2.0E-1 1.2E0 lb/TBtu (2.0E-2
lb/GWh). lb/GWh). lb/GWh). lb/GWh). lb/GWh).
--------------------------------------------------------------------------------------------------------------------------------------------------------
NA = Not applicable.
\a\ Includes Hg.
The output-format values for the antimony and beryllium emission
limits for existing solid oil-derived fuel-fired units were incorrect
as published in the preamble to the final rule (i.e., the incorrect
``8.0E-3 lb/GWh'' instead of the correct ``7.0E-3 lb/GWh'' for antimony
and the incorrect ``6.0E-4 lb/GWh'' instead of the correct ``5.0E-4 lb/
GWh'' for beryllium). In addition, the format of the input- and output-
based lead emissions limits for existing IGCC EGUs was incorrect as
published in the preamble to the final rule (i.e., the incorrect
``1.9E+2 lb/MMBtu or 1.8E0 lb/MWh'' instead of the correct ``1.9E+2 lb/
TBtu or 1.8E0 lb/GWh''). In each case, the correct values are indicated
in the spreadsheets found in docket entry EPA-HQ-OAR-2009-0234-20132
and the published values were transcription errors. This same
correction is made to the regulatory text later in this document.
2. On page 9401, column 1, first full paragraph, the fourth
sentence is corrected to read as follows: ``This subcategory applies
only to oil-fired EGUs that act as peaking units, as they generally
address reliability issues.''
We are revising this sentence because the original sentence in the
preamble to the final rule stated: ``This subcategory applies only to
oil-fired EGUs that operate on oil alone and act as peaking units, as
they generally address reliability issues.'' (emphasis added). The
italicized language is not consistent with the regulatory definition of
``oil-fired EGU'' or the definition of ``limited-use liquid oil-fired
subcategory'' because it incorrectly indicates that the subcategory
applies only to oil-fired EGUs that operate on oil alone. See 40 CFR
63.10042.
3. The definition of ``Boiler operating day'' in Sec. 60.41Da
Definitions, the date ``February 29, 2005'' is corrected to read
``March 1, 2005'' because there was no February 29 in 2005.
4. Section 60.49Da(a)(4)(i) is revised to correct the typographical
error related to the incorrect cross reference to section 60.51a(d)
which does not exist. The correct cross reference is to section
60.51Da(d).
5. Sections 63.9982(a)(1) and (a)(2) are revised to include the
``Sec. '' symbol which was inadvertently left off of the references to
section 63.10042 (i.e., ``63.10042'' vs. the correct ``Sec.
63.10042''.
6. Section 63.9982(d) is revised to correct the typographical error
which left out the word ``in'' from the phrase ``* * * change in
process * * *''
7. Section 63.9985(a)(2) is revised to remove the words ``or
modification.'' We erroneously included this language in the final rule
definition of a new source for purposes of the NESHAP. The language
included in the final rule comes from the CAA section 111 statutory
definition for ``new source,'' instead of the CAA section 112
definition of ``new source.'' CAA section 112 does not include
``modified'' sources in the definition of new sources, and, thus, the
inclusion of such sources in the definition was an inadvertent drafting
error.
8. Section 63.9991(c) is revised to remove the term ``coal-fired''
from the phrase ``coal-fired EGU.'' This section expressly references
Tables 1 and 2 of this subpart and those tables include alterative
sulfur dioxide (SO2) limits for all EGUs meeting the
requirements of section 63.9991(c), not just coal-fired EGUs. Thus, the
provision as written in the final rule was incorrectly limited to coal-
fired EGUs.
9. Section 63.10000(c)(1) is revised to include integrated
gasification combined cycle (IGCC) EGUs among the subcategories listed.
Section 63.10000(c) addresses initial performance testing. IGCC EGUs
are included in the requirements of section 63.10000(c)(1)(i) (which
deals with initial performance testing for purposes of determining low
emitting EGU (LEE) status) and, thus, the omission of IGCC EGUs from
the introductory language in section 63.10000(c)(1) was an inadvertent
error.
10. Section 63.10000(c)(1)(i)(B) is revised to correct a
typographical error (``* * * solid oil-derived fuel-fired * * *''
rather than the incorrect ``* * * solid oil-fired fuel-fired * * *'').
11. Section 63.10000(c)(2)(iv) is revised to correct a
typographical error and include ``you'' in the phrase ``* * * but you
must * * *''
12. Section 63.10000(d)(5)(i) is revised to correct the
typographical error of including the incorrect term ``CEMS'' rather
than the correct term ``CMS.'' The text of sections 63.10000(d)(2)(i),
(3), and (4) all refer to the broader ``CMS'' (which includes both
continuous parameter monitoring system (CPMS) and continuous emission
monitoring system (CEMS)). Thus, use of the narrower CEMS in section
63.10000(d)(5)(i) was an inadvertent error. Further, the term ``CPMS''
in the last sentence of the section is corrected to read ``PM CPMS''
consistent with section 63.10010(h), which section is referenced in
section 63.10000(d)(5)(i) and specifically addresses PM CPMS.
13. Section 63.10000(d)(5)(iv) is revised to use language
consistent with section 63.8(d) (changing ``ongoing data quality
assurance procedures'' to ``quality control program''), as section 63.8
is cited in this section. The title of section 63.8(d) is ``quality
control program'' and the phrase ``ongoing data quality assurance
procedures'' does not appear in that provision.
14. Section 63.10000(f) is revised to correct a typographical error
by replacing ``distributions system'' with the correct ``distribution
system.''
15. Section 63.10005(b)(2) is revised to correct a typographical
error by changing ``* * * valid data CMS data * * *'' to ``valid CMS
data''.
16. Section 63.10005(d)(1) is revised to correct a typographical
error (the correct ``* * * Table 1 or 2 to this * * *'' rather than the
incorrect ``* * * Table 1 or 2 of this * * *'' in two places).
[[Page 23401]]
17. Section 63.10005(d)(4)(ii) is revised to correct the
typographical error associated with the use of ``corresponding'' rather
than the correct word ``corresponds.''
18. Sections 63.10005(h)(3)(iii)(C)(1) and (2) are revised to
correct the typographical errors associated with the conversion factors
from million British thermal units per hour (MMBtu/hr) to trillion Btu/
hr (TBtu/hr) (i.e., the correct 10-6 rather than the
incorrect 10\6\) and from megawatts (MW) to gigawatts (GW) (i.e., the
correct 10-3 rather than the incorrect 10\3\). The exponents
as published are technically incorrect and the conversions would not
work as published.
19. Section 63.10006(a) is revised to correct a typographical
error. Specifically, we inadvertently omitted the word ``fired'' from
the phrase ``* * * solid oil-derived fuel- and * * *'' The phrase
should read ``* * * solid oil-derived fuel-fired and * * *''
20. Section 63.10007(c) is revised to correct the typographical
error associated with the incorrect cross reference to the non-existent
section 63.10011(b)(5). The correct cross reference is to section
63.10011(b).
21. Section 63.10009(g) is revised to correct the typographical
error related to the incorrect cross reference to sections
63.10009(f)(1) through (3). Section 63.10009(g) deals with determining
weighted average emission rates, but section 63.10009(f) deals with
demonstrating eligibility for an emissions averaging group and is,
thus, an incorrect cross reference. The correct cross reference is to
sections 63.10009(g)(1) through (2), which sections provide specific
direction on the manner in which sources establish weighted average
emission rates.
22. Section 63.10009(j)(2)(i)(A) is revised to correct the
typographical error related to the incorrect cross reference to section
63.10009(h)(1), which does not exist. The correct cross reference is to
section 63.10009(j)(1).
23. Sections 63.10010(a)(6)(iii) and (iv) are revised to correct
the typographical errors related to the incorrect cross references to
sections 63.10010(a)(5)(iii)(B) and (a)(5)(iii)(C), which do not exist.
The correct cross references are to sections 63.10010(a)(6)(ii) and
(iii), respectively.
24. Sections 63.10010(g), 63.10011(c)(1), 63.10021(b), and
63.10022(a)(1) are revised to correct the inadvertent omission of the
alternate 90-day averaging period. The provisions as included in the
final rule only referred to the 30-day averaging periods that are
generally utilized for determining compliance with the final standards;
however, as indicated in section 63.10009(a)(2), sources are also
authorized to use the alternate 90-day averaging period for certain
standards when emissions averaging is employed at a facility.
25. Section 63.10020(d) is revised to correct a typographical error
by replacing ``of'' with ``from'' in the phrase ``* * * deviation from
the * * *''
26. Section 63.10030(e)(7)(i) is revised to correct the
typographical error related to the incorrect cross reference to section
63.10006(i). Section 63.10006(i) addresses the tune-up requirement, but
section 63.10030(e)(7)(i) concerns LEE requirements, not tune-up
requirements. The correct cross reference is to section 63.10006(b),
which addresses the reduced performance (i.e., stack) testing for LEE,
which allows a source to test every 3 years as discussed in section
63.10030(e)(7)(i).
27. Section 63.10031(c)(4) is revised to correct an incorrect
statement. The final rule does not require annual inspections; thus,
the ``annual'' has been replaced with ``every 36 (or 48) months'' to be
consistent with other rule text.
28. The definitions of ``Non-mercury (Hg) HAP metals'' and ``Oil''
in section 63.10042 are revised to correct the typographical error that
did not separate the two definitions in the published rule.
29. Table 2 to Subpart UUUUU of Part 63 is revised to correct the
typographical errors related to the lack of a superscript for footnotes
(``\2\'') denoting ``gross electric output'' for filterable particulate
matter emissions from ``2. Coal-fired unit low rank virgin coal,'' ``3.
IGCC,'' ``4. Liquid oil-fired unit--continental (excluding limited-use
liquid oil-fired subcategory units),'' ``Liquid oil-fired unit--non-
continental (excluding limited-use liquid oil-fired subcategory
units),'' and ``6. Solid oil-derived fuel-fired unit.''
In addition, the format of the input- and output-based lead
emissions limits for ``3. IGCC unit'' was incorrect as published (i.e.,
the incorrect ``1.9E+2 lb/MMBtu or 1.8E0 lb/MWh'' instead of the
correct ``1.9E+2 lb/TBtu or 1.8E0 lb/GWh''). Further, the output-format
values for the antimony and beryllium emission limits for ``6. Solid
oil-derived fuel-fired unit'' were incorrect as published (i.e., the
incorrect ``8.0E-3 lb/GWh'' instead of the correct ``7.0E-3 lb/GWh''
for antimony and the incorrect ``6.0E-4 lb/GWh'' instead of the correct
``5.0E-4 lb/GWh'' for beryllium). In each case, the correct values are
indicated in the spreadsheets found in docket entry EPA-HQ-OAR-2009-
0234-20132 and the published values are transcription errors.
30. For the reasons described in Paragraph 24 above, Table 7 to
Subpart UUUUU of Part 63 is revised to address the inadvertent omission
of the alternate 90-day averaging period that is available.
31. For the reasons described in Paragraph 24 above, Paragraphs
6.2.1.4 and 6.2.2.3 to Appendix A to Subpart UUUUU of Part 63 are
revised to address the inadvertent omission of the alternate 90-day
averaging period that is available.
32. Paragraph 7.2.4 to Appendix A to Subpart UUUUU of Part 63 is
revised to correct the typographical error related to the incorrect
cross reference to paragraphs 7.1.10.1 through 7.1.10.7; these
paragraphs do not exist, however. The correct cross reference is
paragraphs 7.1.9.1 through 7.1.9.7.
33. Paragraph 7.2.5.3.4 to Appendix A to Subpart UUUUU of Part 63
is revised to correct the typographical error related to the incorrect
cross reference to paragraph 7.1.90.1; this paragraph does not exist,
however. The correct cross reference is paragraph 7.1.9.1.
Statutory and Executive Order Reviews
Under Executive Order (EO) 12866, Regulatory Planning and Review
(58 FR 51735, October 4, 1993), this action is not a ``significant
regulatory action'' and is therefore not subject to review by the
Office of Management and Budget (OMB). This action is not a ``major
rule'' as defined by 5 U.S.C. 804(2). The technical corrections do not
impose an information collection burden under the provisions of the
Paperwork Reduction Act of 1995 (44 U.S.C. 3501 et seq.).
Because EPA has made a ``good cause'' finding that this action is
not subject to notice and comment requirements under the APA or any
other statute, it is not subject to the regulatory flexibility
provisions of the Regulatory Flexibility Act (5 U.S.C. 601 et seq.), or
to sections 202 and 205 of the Unfunded Mandates Reform Act of 1995
(UMRA) (Pub. L. 104-4). In addition, this action does not significantly
or uniquely affect small governments or impose a significant
intergovernmental mandate, as described in sections 203 and 204 of the
UMRA.
The corrections do not have substantial direct effects on the
states, or on the relationship between the national government and the
states, or on the distribution of power and responsibilities among the
various levels of government, as specified in EO 13132, Federalism (64
FR 43255, August 10, 1999).
[[Page 23402]]
This action also does not significantly or uniquely affect the
communities of tribal governments, as specified by EO 13175,
Consultation and Coordination with Indian Tribal Governments (65 FR
67249, November 9, 2000). The technical corrections also are not
subject to EO 13045, Protection of Children from Environmental Health
and Safety Risks (62 FR 19885, April 23, 1997) because this action is
not economically significant.
The corrections are not subject to EO 13211, Actions Concerning
Regulations That Significantly Affect Energy Supply, Distribution, or
Use (66 FR 28355, May 22, 2001) because this action is not a
significant regulatory action under EO 12866.
The corrections do not involve changes to the technical standards
related to test methods or monitoring methods; thus, the requirements
of section 12(d) of the National Technology Transfer and Advancement
Act of 1995 (15 U.S.C. 272) do not apply.
The corrections also do not involve special consideration of
environmental justice-related issues as required by EO 12898, Federal
Actions to Address Environmental Justice in Minority Populations and
Low-Income Populations (59 FR 7629, February 16, 1994).
The Congressional Review Act, 5 U.S.C. 801 et seq., as added by the
Small Business Regulatory Enforcement Fairness Act of 1996 (SBREFA),
generally provides that before a rule may take effect, the agency
promulgating the rule must submit a rule report, which includes a copy
of the rule, to each House of the Congress and to the Comptroller
General of the U.S. The EPA submitted a report containing the final
action and other required information to the U.S. Senate, the U.S.
House of Representatives, and the Comptroller General of the U.S. This
action is not a ``major rule'' as defined by 5 U.S.C. 804(2). The final
rule will be effective on April 16, 2012.
The EPA's compliance with the above statutes and EOs for the
underlying rule is discussed in the February 16, 2012, Federal Register
document containing ``National Emission Standards for Hazardous Air
Pollutants from Coal- and Oil-fired Electric Utility Steam Generating
Units and Standards of Performance for Fossil-Fuel-Fired Electric
Utility, Industrial-Commercial-Institutional, and Small Industrial-
Commercial-Institutional Steam Generating Units.''
List of Subjects
40 CFR Part 60
Environmental protection, Administrative practice and procedure,
Air pollution control, Incorporation by reference, Intergovernmental
relations, Reporting and recordkeeping requirements.
40 CFR Part 63
Environmental protection, Administrative practice and procedure,
Air pollution control, Hazardous substances, Incorporation by
reference, Intergovernmental relations, Reporting and recordkeeping
requirements.
Dated: March 27, 2012.
Lisa P. Jackson,
Administrator.
Accordingly, title 40, chapter I, of the Code of the Federal
Regulations is amended by making the following correcting amendments:
PART 60--[AMENDED]
0
1. The authority citation for part 60 continues to read as follows:
Authority: 42 U.S.C. 7401 et seq.
0
2. In Sec. 60.41Da, revise the definition of ``Boiler operating day''
to read as follows:
Sec. 60.41Da Definitions.
* * * * *
Boiler operating day for units constructed, reconstructed, or
modified before March 1, 2005, means a 24-hour period during which
fossil fuel is combusted in a steam-generating unit for the entire 24
hours. For units constructed, reconstructed, or modified after February
28, 2005, boiler operating day means a 24-hour period between 12
midnight and the following midnight during which any fuel is combusted
at any time in the steam-generating unit. It is not necessary for fuel
to be combusted the entire 24-hour period.
* * * * *
0
3. Revise Sec. 60.49Da(a)(4)(i) to read as follows:
Sec. 60.49Da Emission monitoring.
(a) * * *
(4) * * *
(i) The affected facility combusts only gaseous fuels and/or liquid
fuels (excluding residue oil) with a potential SO2 emissions
rate no greater than 26 ng/J (0.060 lb/MMBtu), and the unit operates
according to a written site-specific monitoring plan approved by the
permitting authority. This monitoring plan must include procedures and
criteria for establishing and monitoring specific parameters for the
affected facility indicative of compliance with the opacity standard.
For testing performed as part of this site-specific monitoring plan,
the permitting authority may require as an alternative to the
notification and reporting requirements specified in Sec. Sec. 60.8
and 60.11 that the owner or operator submit any deviations with the
excess emissions report required under Sec. 60.51Da(d).
* * * * *
PART 63--[AMENDED]
0
4. The authority citation for 40 CFR Part 63 continues to read as
follows:
Authority: 42 U.S.C. 7401, et seq.
0
5. Revise Sec. 63.9982(a)(1), (a)(2), and (d) to read as follows:
Sec. 60.9982 What is the affected source of this subpart?
(a) * * *
(1) The affected source of this subpart is the collection of all
existing coal- or oil-fired EGUs, as defined in Sec. 63.10042, within
a subcategory.
(2) The affected source of this subpart is each new or
reconstructed coal- or oil-fired EGU as defined in Sec. 63.10042.
* * * * *
(d) An EGU is existing if it is not new or reconstructed. An
existing electric steam generating unit that meets the applicability
requirements after the effective date of this final rule due to a
change in process (e.g., fuel or utilization) is considered to be an
existing source under this subpart.
* * * * *
0
6. Revise Sec. 63.9985(a)(2) to read as follows:
Sec. 63.9985 What is a new EGU?
(a) * * *
(2) An EGU that commenced reconstruction after May 3, 2011.
* * * * *
0
7. In Sec. 63.9991, revise paragraph(c) introductory text to read as
follows:
Sec. 63.9991 What emission limitations, work practice standards, and
operating limits must I meet?
* * * * *
(c) You may use the alternate SO2 limit in Tables 1 and
2 to this subpart only if your EGU:
* * * * *
0
8. In Sec. 63.10000, revise paragraphs(c)(1) introductory text,
(c)(1)(i)(B), (c)(2)(iv), (d)(5)(i), (d)(5)(iv) and (f) to read as
follows:
Sec. 63.10000 What are my general requirements for complying with
this subpart?
* * * * *
[[Page 23403]]
(c)(1) For coal-fired units, IGCC units, and solid oil-derived
fuel-fired units, initial performance testing is required for all
pollutants, to demonstrate compliance with the applicable emission
limits.
(i) * * *
(B) You may not pursue the LEE option for Hg if your coal-fired,
solid oil-derived fuel-fired EGU or IGCC EGU is new.
* * * * *
(2) * * *
(iv) If your unit qualifies as a limited-use liquid oil-fired as
defined in Sec. 63.10042, then you are not subject to the emission
limits in Tables 1 and 2, but you must comply with the performance
tune-up work practice requirements in Table 3.
* * * * *
(d) * * *
(5) * * *
(i) Installation of the CMS or sorbent trap monitoring system
sampling probe or other interface at a measurement location relative to
each affected process unit such that the measurement is representative
of control of the exhaust emissions (e.g., on or downstream of the last
control device). See Sec. 63.10010(a) for further details. For PM CPMS
installations, follow the procedures in Sec. 63.10010(h).
* * * * *
(iv) Performance evaluation procedures and acceptance criteria
(e.g., calibrations), including the quality control program in
accordance with the general requirements of Sec. 63.8(d).
* * * * *
(f) You are subject to the requirements of this subpart for at
least 6 months following the last date you met the definition of an EGU
subject to this subpart (e.g., 6 months after a cogeneration unit
provided more than one third of its potential electrical output
capacity and more than 25 megawatts electrical output to any power
distribution system for sale). You may opt to remain subject to the
provisions of this subpart beyond 6 months after the last date you met
the definition of an EGU subject to this subpart, unless you are a
solid waste incineration unit subject to standards under CAA section
129 (e.g., 40 CFR Part 60, Subpart CCCC (New Source Performance
Standards (NSPS) for Commercial and Industrial Solid Waste Incineration
Units, or Subpart DDDD (Emissions Guidelines (EG) for Existing
Commercial and Industrial Solid Waste Incineration Units).
Notwithstanding the provisions of this subpart, an EGU that starts
combusting solid waste is immediately subject to standards under CAA
section 129 and the EGU remains subject to those standards until the
EGU no longer meets the definition of a solid waste incineration unit
consistent with the provisions of the applicable CAA section 129
standards.
* * * * *
0
9. Revise Sec. 63.10005(b)(2), (d)(1), (d)(4)(ii), and
(h)(3)(iii)(C)(1) and (2) to read as follows:
Sec. 63.10005 What are my initial compliance requirements and by what
date must I conduct them?
* * * * *
(b) * * *
(2) For a performance test based on data from a certified CEMS or
sorbent trap monitoring system, the test consists of all valid CMS data
recorded in the 30 boiler operating days immediately preceding that
date;
* * * * *
(d) * * *
(1) For an affected coal-fired, solid oil-derived fuel-fired, or
liquid oil-fired EGU, you may demonstrate initial compliance with the
applicable SO2, HCl, or HF emissions limit in Table 1 or 2
to this subpart through use of an SO2, HCl, or HF CEMS
installed and operated in accordance with Part 75 of this chapter or
Appendix B to this subpart, as applicable. You may also demonstrate
compliance with a filterable PM emission limit in Table 1 or 2 to this
subpart through use of a PM CEMS installed, certified, and operated in
accordance with Sec. 63.10010(i). Initial compliance is achieved if
the arithmetic average of 30-boiler operating days of quality-assured
CEMS data, expressed in units of the standard (see Sec. 63.10007(e)),
meets the applicable SO2, PM, HCl, or HF emissions limit in
Table 1 or 2 to this subpart. Use Equation 19-19 of Method 19 in
appendix A-7 to Part 60 of this chapter to calculate the 30-boiler
operating day average emissions rate. (Note: For this calculation, the
term Ehj in Equation 19-19 must be in the same units of
measure as the applicable HCl or HF emission limit in Table 1 or 2 to
this subpart).
* * * * *
(4) * * *
(i) * * *
(ii) You must demonstrate continuous compliance with the CMS site-
specific operating limit that corresponds to the results of the
performance test demonstrating compliance with the HCl or HF emissions
limit.
* * * * *
(h) * * *
(3) * * *
(iii) * * *
(C) * * *
(1) Multiply the average lb/TBtu Hg emission rate (determined
according to paragraph (h)(3)(iii)(A) of this section) by the maximum
potential annual heat input to the unit (TBtu), which is equal to the
maximum rated unit heat input (TBtu/hr) times 8,760 hours. If the
maximum rated heat input value is expressed in units of MMBtu/hr,
multiply it by 10 -6 to convert it to TBtu/hr; or
(2) Multiply the average lb/GWh Hg emission rate (determined
according to paragraph (h)(3)(iii)(B) of this section) by the maximum
potential annual electricity generation (GWh), which is equal to the
maximum rated electrical output of the unit (GW) times 8,760 hours. If
the maximum rated electrical output value is expressed in units of MW,
multiply it by 10 -3 to convert it to GW; or
* * * * *
0
10. Revise Sec. 63.10006(a) to read as follows:
Sec. 63.10006 When must I conduct subsequent performance tests or
tune-ups?
(a) For liquid oil-fired, solid oil-derived fuel-fired and coal-
fired EGUs and IGCC units using PM CPMS to monitor continuous
performance with an applicable emission limit as provided for under
Sec. 63.10000(c), you must conduct all applicable performance tests
according to Table 5 to this subpart and Sec. 63.10007 at least every
year.
* * * * *
0
11. Revise Sec. 63.10007(c) to read as follows:
Sec. 63.10007 What methods and other procedures must I use for the
performance tests?
* * * * *
(c) If you choose to comply with the filterable PM emission limit
and demonstrate continuous performance using a PM CPMS for an
applicable emission limit as provided for in Sec. 63.10000(c), you
must also establish an operating limit according to Sec. 63.10011(b)
and Tables 4 and 6 to this subpart. Should you desire to have operating
limits that correspond to loads other than maximum normal operating
load, you must conduct testing at those other loads to determine the
additional operating limits.
* * * * *
0
12. In Sec. 63.10009, revise paragraphs (g) introductory text and
(j)(2)(i)(A) to read as follows:
Sec. 63.10009 May I use emissions averaging to comply with this
subpart?
* * * * *
[[Page 23404]]
(g) You must determine the weighted average emissions rate in units
of the applicable emissions limit on a 30 day rolling average (90 day
rolling average for Hg) basis according to paragraphs (g)(1) through
(2) of this section. The first averaging period begins on 30 (or 90 for
Hg) days after February 16, 2015 or the date that you begin emissions
averaging, whichever is earlier.
* * * * *
(j) * * *
(2) * * *
(i) * * *
(A) Whether the content of the plan includes all of the information
specified in paragraph (j)(1) of this section; and
* * * * *
0
13. In Sec. 63.10010, revise paragraphs (a)(6)(iii), (a)(6)(iv) and
(g) to read as follows:
Sec. 63.10010 What are my monitoring, installation, operation, and
maintenance requirements?
(a) * * *
(6) * * *
(iii) Sum the products determined under paragraph (a)(6)(ii) of
this section; and
(iv) Divide the result obtained in paragraph (a)(6)(iii) of this
section by the total hourly stack gas flow rate for the unit, summed
across all of the stacks or ducts.
* * * * *
(g) If you use a Hg CEMS or a sorbent trap monitoring system, you
must install, certify, operate, maintain and quality-assure the data
from the monitoring system in accordance with appendix A to this
subpart. You must calculate and record a 30- (or, if alternate
emissions averaging is used, 90-) boiler operating day rolling average
Hg emission rate, in units of the standard, updated after each new
boiler operating day. Each 30- (or, if alternate emissions averaging is
used, 90-) boiler operating day rolling average emission rate,
calculated according to section 6.2 of appendix A to the subpart, is
the average of all of the valid hourly Hg emission rates in the
preceding 30- (or, if alternate emissions averaging is used, a 90-)
boiler operating days. Section 7.1.4.3 of appendix A to this subpart
explains how to reduce sorbent trap monitoring system data to an hourly
basis.
* * * * *
0
14. Revise Sec. 63.10011(c)(1) to read as follows:
Sec. 63.10011 How do I demonstrate initial compliance with the
emissions limits and work practice standards?
* * * * *
(c)(1) If you use CEMS or sorbent trap monitoring systems to
measure a HAP (e.g., Hg or HCl) directly, the first 30-boiler operating
day (or, if alternate emissions averaging is used for Hg, the 90-boiler
operating day) rolling average emission rate obtained with certified
CEMS after the applicable date in Sec. 63.9984 (or, if applicable,
prior to that date, as described in Sec. 63.10005(b)(2)), expressed in
units of the standard, is the initial performance test. Initial
compliance is demonstrated if the results of the performance test meet
the applicable emission limit in Table 1 or 2 to this subpart.
* * * * *
0
15. Revise Sec. 63.10020(d) to read as follows:
Sec. 63.10020 How do I monitor and collect data to demonstrate
continuous compliance?
* * * * *
(d) Except for 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 including, as applicable, calibration checks and
required zero and span adjustments), failure to collect required data
is a deviation from the monitoring requirements.
* * * * *
0
16. Revise Sec. 63.10021(b) to read as follows:
Sec. 63.10021 How do I demonstrate continuous compliance with the
emission limitations, operating limits, and work practice standards?
* * * * *
(b) Except as otherwise provided in Sec. 63.10020(c), if you use a
CEMS to measure SO2, PM, HCl, HF, or Hg emissions, or using
a sorbent trap monitoring system to measure Hg emissions, you must
demonstrate continuous compliance by using all quality-assured hourly
data recorded by the CEMS (or sorbent trap monitoring system) and the
other required monitoring systems (e.g., flow rate, CO2,
O2, or moisture systems) to calculate the arithmetic average
emissions rate in units of the standard on a continuous 30-boiler
operating day (or, if alternate emissions averaging is used for Hg, 90-
boiler operating day) rolling average basis, updated at the end of each
new boiler operating day. Use Equation 8 to determine the 30- (or, if
applicable, 90-) boiler operating day rolling average.
[GRAPHIC] [TIFF OMITTED] TR19AP12.002
Where:
Heri is the hourly emissions rate for hour i and n is the
number of hourly emissions rate values collected over 30- (or, if
applicable, 90-) boiler operating days.
* * * * *
0
17. Revise Sec. 63.10022(a)(1) to read as follows:
Sec. 63.10022 How do I demonstrate continuous compliance under the
emissions averaging provision?
(a) * * *
(1) For each 30- (or 90-) day rolling average period, demonstrate
compliance with the average weighted emissions limit for the existing
units participating in the emissions averaging option as determined in
Sec. 63.10009(f) and (g);
* * * * *
0
18. Revise Sec. 63.10030(e)(7)(i) to read as follows:
Sec. 63.10030 What notifications must I submit and when?
* * * * *
(e) * * *
(7) * * *
(i) A summary of the results of the annual performance tests and
documentation of any operating limits that were reestablished during
this test, if applicable. If you are conducting stack tests once every
3 years consistent with Sec. 63.10006(b), the date of the last three
stack tests, a comparison of the emission level you achieved in the
last three stack tests to the 50 percent emission limit threshold
required in Sec. 63.10006(i), and a statement as to whether there have
been any operational changes since the last stack test that could
increase emissions.
* * * * *
0
19. Revise Sec. 63.10031(c)(4) to read as follows:
[[Page 23405]]
Sec. 63.10031 What reports must I submit and when?
* * * * *
(c) * * *
(4) Include the date of the most recent tune-up for each unit
subject to the requirement to conduct a performance tune-up according
to Sec. 63.10021(e). Include the date of the most recent burner
inspection if it was not done every 36 (or 48) months and was delayed
until the next scheduled unit shutdown.
* * * * *
0
20. In Sec. 63.10042, revise the definition ``Non-mercury (Hg) HAP
metals'' and add the definition ``Oil'' to read as follows:
Sec. 63.10042 What definitions apply to this subpart?
* * * * *
Non-mercury (Hg) HAP metals means Antimony (Sb), Arsenic (As),
Beryllium (Be), Cadmium (Cd), Chromium (Cr), Cobalt (Co), Lead (Pb),
Manganese (Mn), Nickel (Ni), and Selenium (Se).
Oil means crude oil or petroleum or a fuel derived from crude oil
or petroleum, including distillate and residual oil, solid oil-derived
fuel (e.g., petroleum coke) and gases derived from solid oil-derived
fuels (not meeting the definition of natural gas).
* * * * *
0
22. Revise table 2 and table 7 to Subpart UUUUU of Part 63 to read as
follows:
Tables to Subpart UUUUU of Part 63
* * * * *
Table 2 to Subpart UUUUU of Part 63--Emission Limits for Existing EGUs
[As stated in Sec. 63.9991, you must comply with the following applicable emission limits] \1\
----------------------------------------------------------------------------------------------------------------
Using these
requirements, as
appropriate (e.g.,
You must meet the specified sampling
If your EGU is in this subcategory . For the following following emission volume or test run
. . pollutants . . . limits and work practice duration) and
standards . . . limitations with the
test methods in Table 5
. . .
----------------------------------------------------------------------------------------------------------------
1. Coal-fired unit not low rank a. Filterable 3.0E-2 lb/MMBtu or 3.0E- Collect a minimum of 1
virgin coal. particulate matter 1 lb/MWh.\2\ dscm per run.
(PM).
OR OR .......................
Total non-Hg HAP metals 5.0E-5 lb/MMBtu or 5.0E- Collect a minimum of 1
1 lb/GWh. dscm per run.
OR OR .......................
Individual HAP metals: ........................ Collect a minimum of 3
dscm per run.
Antimony (Sb).......... 8.0E-1 lb/TBtu or 8.0E-3
lb/GWh.
Arsenic (As)........... 1.1E0 lb/TBtu or 2.0E-2
lb/GWh.
Beryllium (Be)......... 2.0E-1 lb/TBtu or 2.0E-3
lb/GWh.
Cadmium (Cd)........... 3.0E-1 lb/TBtu or 3.0E-3
lb/GWh.
Chromium (Cr).......... 2.8E0 lb/TBtu or 3.0E-2
lb/GWh.
Cobalt (Co)............ 8.0E-1 lb/TBtu or 8.0E-3
lb/GWh.
Lead (Pb).............. 1.2E0 lb/TBtu or 2.0E-2
lb/GWh.
Manganese (Mn)......... 4.0E0 lb/TBtu or 5.0E-2
lb/GWh.
Nickel (Ni)............ 3.5E0 lb/TBtu or 4.0E-2
lb/GWh.
Selenium (Se).......... 5.0E0 lb/TBtu or 6.0E-2
lb/GWh.
b. Hydrogen chloride 2.0E-3 lb/MMBtu or 2.0E- For Method 26A, collect
(HCl). 2 lb/MWh. a minimum of 0.75 dscm
per run; for Method
26, collect a minimum
of 120 liters per run.
For ASTM D6348-03 \3\
or Method 320, sample
for a minimum of 1
hour.
OR ........................ .......................
Sulfur dioxide (SO2) 2.0E-1 lb/MMBtu or 1.5E0 SO2 CEMS.
\4\. lb/MWh.
c. Mercury (Hg)........ 1.2E0 lb/TBtu or 1.3E-2 LEE Testing for 30 days
lb/GWh with 10 days maximum
per Method 30B run or
Hg CEMS or sorbent
trap monitoring system
only.
2. Coal-fired unit low rank virgin a. Filterable 3.0E-2 lb/MMBtu or 3.0E- Collect a minimum of 1
coal. particulate matter 1 lb/MWh.\2\ dscm per run.
(PM).
OR OR .......................
Total non-Hg HAP metals 5.0E-5 lb/MMBtu or 5.0E- Collect a minimum of 1
1 lb/GWh. dscm per run.
OR OR .......................
Individual HAP metals: ........................ Collect a minimum of 3
dscm per run.
Antimony (Sb).......... 8.0E-1 lb/TBtu or 8.0E-3
lb/GWh.
Arsenic (As)........... 1.1E0 lb/TBtu or 2.0E-2
lb/GWh.
Beryllium (Be)......... 2.0E-1 lb/TBtu or 2.0E-3
lb/GWh.
Cadmium (Cd)........... 3.0E-1 lb/TBtu or 3.0E-3
lb/GWh.
Chromium (Cr).......... 2.8E0 lb/TBtu or 3.0E-2
lb/GWh.
Cobalt (Co)............ 8.0E-1 lb/TBtu or 8.0E-3
lb/GWh.
Lead (Pb).............. 1.2E0 lb/TBtu or 2.0E-2
lb/GWh.
Manganese (Mn)......... 4.0E0 lb/TBtu or 5.0E-2
lb/GWh.
Nickel (Ni)............ 3.5E0 lb/TBtu or 4.0E-2
lb/GWh.
Selenium (Se).......... 5.0E0 lb/TBtu or 6.0E-2
lb/GWh.
[[Page 23406]]
b. Hydrogen chloride 2.0E-3 lb/MMBtu or 2.0E- For Method 26A, collect
(HCl). 2 lb/MWh. a minimum of 0.75 dscm
per run; for Method
26, collect a minimum
of 120 liters per run.
For ASTM D6348-03 \3\
or Method 320, sample
for a minimum of 1
hour.
OR
Sulfur dioxide (SO2) 2.0E-1 lb/MMBtu or 1.5E0 SO2 CEMS.
\4\. lb/MWh.
c. Mercury (Hg)........ 4.0E0 lb/TBtu or 4.0E-2 LEE Testing for 30 days
lb/GWh with 10 days maximum
per Method 30B run or
Hg CEMS or sorbent
trap monitoring system
only.
3. IGCC unit........................ a. Filterable 4.0E-2 lb/MMBtu or 4.0E- Collect a minimum of 1
particulate matter 1 lb/MWh.\2\ dscm per run.
(PM).
OR OR .......................
Total non-Hg HAP metals 6.0E-5 lb/MMBtu or 5.0E- Collect a minimum of 1
1 lb/GWh. dscm per run.
OR OR .......................
Individual HAP metals: ........................ Collect a minimum of 2
dscm per run.
Antimony (Sb).......... 1.4E0 lb/TBtu or 2.0E-2
lb/GWh.
Arsenic (As)........... 1.5E0 lb/TBtu or 2.0E-2
lb/GWh.
Beryllium (Be)......... 1.0E-1 lb/TBtu or 1.0E-3
lb/GWh.
Cadmium (Cd)........... 1.5E-1 lb/TBtu or 2.0E-3
lb/GWh.
Chromium (Cr).......... 2.9E0 lb/TBtu or 3.0E-2
lb/GWh.
Cobalt (Co)............ 1.2E0 lb/TBtu or 2.0E-2
lb/GWh.
Lead (Pb).............. 1.9E+2 lb/TBtu or 1.8E0
lb/GWh.
Manganese (Mn)......... 2.5E0 lb/TBtu or 3.0E-2
lb/GWh.
Nickel (Ni)............ 6.5E0 lb/TBtu or 7.0E-2
lb/GWh.
Selenium (Se).......... 2.2E+1 lb/TBtu or 3.0E-1
lb/GWh.
b. Hydrogen chloride 5.0E-4 lb/MMBtu or 5.0E- For Method 26A, collect
(HCl). 3 lb/MWh. a minimum of 1 dscm
per run; for Method
26, collect a minimum
of 120 liters per run.
For ASTM D6348-03 \3\
or Method 320, sample
for a minimum of 1
hour.
c. Mercury (Hg)........ 2.5E0 lb/TBtu or 3.0E-2 LEE Testing for 30 days
lb/GWh with 10 days maximum
per Method 30B run or
Hg CEMS or sorbent
trap monitoring system
only.
4. Liquid oil-fired unit-- a. Filterable 3.0E-2 lb/MMBtu or 3.0E- Collect a minimum of 1
continental (excluding limited-use particulate matter 1 lb/MWh.\2\ dscm per run.
liquid oil-fired subcategory units). (PM).
OR OR .......................
Total HAP metals....... 8.0E-4 lb/MMBtu or 8.0E- Collect a minimum of 1
3 lb/MWh. dscm per run.
OR OR .......................
Individual HAP metals: ........................ Collect a minimum of 1
dscm per run.
Antimony (Sb).......... 1.3E+1 lb/TBtu or 2.0E-1
lb/GWh.
Arsenic (As)........... 2.8E0 lb/TBtu or 3.0E-2
lb/GWh.
Beryllium (Be)......... 2.0E-1 lb/TBtu or 2.0E-3
lb/GWh.
Cadmium (Cd)........... 3.0E-1 lb/TBtu or 2.0E-3
lb/GWh.
Chromium (Cr).......... 5.5E0 lb/TBtu or 6.0E-2
lb/GWh.
Cobalt (Co)............ 2.1E+1 lb/TBtu or 3.0E-1
lb/GWh.
Lead (Pb).............. 8.1E0 lb/TBtu or 8.0E-2
lb/GWh.
Manganese (Mn)......... 2.2E+1 lb/TBtu or 3.0E-1
lb/GWh.
Nickel (Ni)............ 1.1E+2 lb/TBtu or 1.1E0
lb/GWh.
Selenium (Se).......... 3.3E0 lb/TBtu or 4.0E-2
lb/GWh.
Mercury (Hg)........... 2.0E-1 lb/TBtu or 2.0E-3 For Method 30B sample
lb/GWh. volume determination
(Section 8.2.4), the
estimated Hg
concentration should
nominally be <\1/2\;
the standard.
[[Page 23407]]
b. Hydrogen chloride 2.0E-3 lb/MMBtu or 1.0E- For Method 26A, collect
(HCl). 2 lb/MWh. a minimum of 1 dscm
per Run; for Method
26, collect a minimum
of 120 liters per run.
For ASTM D6348-03 \3\
or Method 320, sample
for a minimum of 1
hour.
c. Hydrogen fluoride 4.0E-4 lb/MMBtu or 4.0E- For Method 26A, collect
(HF). 3 lb/MWh. a minimum of 1 dscm
per run; for Method
26, collect a minimum
of 120 liters per run.
For ASTM D6348-03 \3\
or Method 320, sample
for a minimum of 1
hour.
5. Liquid oil-fired unit--non- a. Filterable 3.0E-2 lb/MMBtu or 3.0E- Collect a minimum of 1
continental (excluding limited-use particulate matter 1 lb/MWh.\2\ dscm per run.
liquid oil-fired subcategory units). (PM).
OR OR .......................
Total HAP metals 6.0E-4 lb/MMBtu or 7.0E- Collect a minimum of 1
3 lb/MWh. dscm per run.
OR OR .......................
Individual HAP metals: ........................ Collect a minimum of 2
dscm per run.
Antimony (Sb).......... 2.2E0 lb/TBtu or 2.0E-2
lb/GWh.
Arsenic (As)........... 4.3E0 lb/TBtu or 8.0E-2
lb/GWh.
Beryllium (Be)......... 6.0E-1 lb/TBtu or 3.0E-3
lb/GWh.
Cadmium (Cd)........... 3.0E-1 lb/TBtu or 3.0E-3
lb/GWh.
Chromium (Cr).......... 3.1E+1 lb/TBtu or 3.0E-1
lb/GWh.
Cobalt (Co)............ 1.1E+2 lb/TBtu or 1.4E0
lb/GWh.
Lead (Pb).............. 4.9E0 lb/TBtu or 8.0E-2
lb/GWh.
Manganese (Mn)......... 2.0E+1 lb/TBtu or 3.0E-1
lb/GWh.
Nickel (Ni)............ 4.7E+2 lb/TBtu or 4.1E0
lb/GWh.
Selenium (Se).......... 9.8E0 lb/TBtu or 2.0E-1
lb/GWh.
Mercury (Hg)........... 4.0E-2 lb/TBtu or 4.0E-4 For Method 30B sample
lb/GWh. volume determination
(Section 8.2.4), the
estimated Hg
concentration should
nominally be <\1/2\;
the standard.
b. Hydrogen chloride 2.0E-4 lb/MMBtu or 2.0E- For Method 26A, collect
(HCl). 3 lb/MWh. a minimum of 1 dscm
per run; for Method
26, collect a minimum
of 120 liters per run.
For ASTM D6348-03 \3\
or Method 320, sample
for a minimum of 2
hours.
c. Hydrogen fluoride 6.0E-5 lb/MMBtu or 5.0E- For Method 26A, collect
(HF). 4 lb/MWh. a minimum of 3 dscm
per run.
For ASTM D6348-03 \3\
or Method 320, sample
for a minimum of 2
hours.
6. Solid oil-derived fuel-fired unit a. Filterable 8.0E-3 lb/MMBtu or 9.0E- Collect a minimum of 1
particulate matter 2 lb/MWh.\2\ dscm per run.
(PM).
OR OR .......................
Total non-Hg HAP metals 4.0E-5 lb/MMBtu or 6.0E- Collect a minimum of 1
1 lb/GWh. dscm per run.
OR OR .......................
Individual HAP metals.. Collect a minimum of 3
dscm per run.
Antimony (Sb).......... 8.0E-1 lb/TBtu or 7.0E-3
lb/GWh.
Arsenic (As)........... 3.0E-1 lb/TBtu or 5.0E-3
lb/GWh.
Beryllium (Be)......... 6.0E-2 lb/TBtu or 5.0E-4
lb/GWh.
Cadmium (Cd)........... 3.0E-1 lb/TBtu or 4.0E-3
lb/GWh.
Chromium (Cr).......... 8.0E-1 lb/TBtu or 2.0E-2
lb/GWh.
Cobalt (Co)............ 1.1E0 lb/TBtu or 2.0E-2
lb/GWh.
Lead (Pb).............. 8.0E-1 lb/TBtu or 2.0E-2
lb/GWh.
Manganese (Mn)......... 2.3E0 lb/TBtu or 4.0E-2
lb/GWh.
Nickel (Ni)............ 9.0E0 lb/TBtu or 2.0E-1
lb/GWh.
[[Page 23408]]
Selenium (Se).......... 1.2E0 lb/TBtu or 2.0E-2
lb/GWh.
b. Hydrogen chloride 5.0E-3 lb/MMBtu or 8.0E- For Method 26A, collect
(HCl). 2 lb/MWh. a minimum of 0.75 dscm
per run; for Method
26, collect a minimum
of 120 liters per run.
For ASTM D6348-03 \3\
or Method 320, sample
for a minimum of 1
hour.
OR .......................
Sulfur dioxide (SO2) 3.0E-1 lb/MMBtu or 2.0E0 SO2 CEMS.
\4\. lb/MWh.
c. Mercury (Hg)........ 2.0E-1 lb/TBtu or 2.0E-3 LEE Testing for 30 days
lb/GWh. with 10 days maximum
per Method 30B run or
Hg CEMS or Sorbent
trap monitoring system
only.
----------------------------------------------------------------------------------------------------------------
\1\ For LEE emissions testing for total PM, total HAP metals, individual HAP metals, HCl, and HF, the required
minimum sampling volume must be increased nominally by a factor of two.
\2\ Gross electric output.
\3\ Incorporated by reference, see Sec. 63.14.
\4\ You may not use the alternate SO2 limit if your EGU does not have some form of FGD system and SO2 CEMS
installed.
* * * * *
Table 7 to Subpart UUUUU of Part 63--Demonstrating Continuous Compliance
[As stated in Sec. 63.10021, you must show continuous compliance with
the emission limitations for affected sources according to the
following]
------------------------------------------------------------------------
If you use one of the following to meet
applicable emissions limits, operating You demonstrate continuous
limits, or work practice standards . . compliance by . . .
.
------------------------------------------------------------------------
1. CEMS to measure filterable PM, SO2, Calculating the 30- (or 90-)
HCl, HF, or Hg emissions, or using a boiler operating day rolling
sorbent trap monitoring system to arithmetic average emissions
measure Hg. rate in units of the
applicable emissions standard
basis at the end of each
boiler operating day using all
of the quality assured hourly
average CEMS or sorbent trap
data for the previous 30-
boiler operating days,
excluding data recorded during
periods of startup or
shutdown.
2. PM CPMS to measure compliance with a Calculating the arithmetic 30-
parametric operating limit. boiler operating day rolling
average of all of the quality
assured hourly average PM CPMS
output data (e.g., milliamps,
PM concentration, raw data
signal) collected for all
operating hours for the
previous 30 boiler operating
days, excluding data recorded
during periods of startup or
shutdown.
3. Site-specific monitoring for liquid If applicable, by conducting
oil-fired units for HCl and HF the monitoring in accordance
emission limit monitoring. with an approved site-specific
monitoring plan.
4. Quarterly performance testing for Calculating the results of the
coal-fired, solid oil derived fired, testing in units of the
or liquid oil-fired units to measure applicable emissions standard.
compliance with one or more applicable
emissions limit in Table 1 or 2.
5. Conducting periodic performance tune- Conducting periodic performance
ups of your EGU(s). tune-ups of your EGU(s), as
specified in Sec.
63.10021(e).
6. Work practice standards for coal- Operating in accordance with
fired, liquid oil-fired, or solid oil- Table 3.
derived fuel-fired EGUs during startup.
7. Work practice standards for coal- Operating in accordance with
fired, liquid oil-fired, or solid oil- Table 3.
derived fuel-fired EGUs during
shutdown.
------------------------------------------------------------------------
* * * * *
0
23. In Appendix A to Subpart UUUUU of Part 63, revise paragraphs
6.2.1.4, 6.2.2.3, 7.2.4, 7.2.5.3.4, to read as follows:
Appendix A to Subpart UUUUU--Hg Monitoring Provisions
* * * * *
6.2.1.4 The heat input-based Hg emission rate limit in Table 2
to this subpart must be met on a 30 boiler operating day rolling
average basis, except as otherwise provided in Sec. 63.10009(a)(2).
Use Equation 19-19 in EPA Method 19 to calculate the Hg emission
rate for each averaging period. The term Ehj in Equation
19-19 must be in the units of the applicable emission limit. Do not
include non-operating hours with zero emissions in the average.
* * * * *
6.2.2.3 The applicable electrical output-based Hg emission rate
limit in Table 1 or 2 to this subpart must be met on a 30-boiler
operating day rolling average basis, except as otherwise provided in
Sec. 63.10009(a)(2). Use Equation A-5 of this section to calculate
the Hg emission rate for each averaging period.
[[Page 23409]]
[GRAPHIC] [TIFF OMITTED] TR19AP12.003
Where:
Eo = Hg emission rate for the averaging period (lb/GWh).
Echo = Electrical output-based hourly Hg emission rate
for unit or stack operating hour ``h'' in the averaging period, from
Equation A-4 of this section (lb/GWh).
n = Number of unit or stack operating hours in the averaging period
in which valid data were obtained for all parameters.
(Note: Do not include non-operating hours with zero emission rates
in the average).
* * * * *
7.2.4 Certification, Recertification, and Quality-Assurance Test
Reporting. Except for daily QA tests of the required monitoring systems
(i.e., calibration error tests and flow monitor interference checks),
the results of all required certification, recertification, and
quality-assurance tests described in paragraphs 7.1.9.1 through 7.1.9.7
of this section (except for test results previously submitted, e.g.,
under the ARP) shall be submitted electronically, using the ECMPS
Client Tool, either prior to or concurrent with the relevant quarterly
electronic emissions report.
* * * * *
7.2.5.3.4 The results of all daily calibration error tests of the
Hg CEMS, as described in paragraph 7.1.9.1 of this section and (if
applicable) the results of all daily flow monitor interference checks.
* * * * *
[FR Doc. 2012-8703 Filed 4-18-12; 8:45 am]
BILLING CODE 6560-50-P
