January 2013 final Boiler MACT. Thus, Executive Order 13175 does not
apply to this action.

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

    The EPA interprets Executive Order 13045 as applying only to those
regulatory actions that concern environmental health or safety risks
that the EPA has reason to believe may disproportionately affect
children, per the definition of ``covered regulatory action'' in
section 2-202 of the Executive Order. This action is not subject to
Executive Order 13045 because it does not concern any such
environmental health risks or safety risks.

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

    This action is not subject to Executive Order 13211 because it is
not a significant regulatory action under Executive Order 12866.

I. National Technology Transfer and Advancement Act (NTTAA)

    This action does not involve any new technical standards from those
contained in the March 21, 2011, final rule. Therefore, the EPA did not
consider the use of any voluntary consensus standards. See 76 FR 15660-
15662 for the NTTAA discussion in the March 21, 2011, final rule.

J. Executive Order 12898: Federal Actions to Address Environmental
Justice in Minority Populations and Low-Income Populations

    The EPA believes the human health or environmental risk addressed
by this action will not have potential disproportionately high and
adverse human health or environmental effects on minority, low-income,
or indigenous populations because it does not affect the level of
protection provided to human health or the environment.
    The environmental justice finding in the January 2013 final
amendments to the Boiler MACT remain relevant in this action, which
finalizes three aspects of the Boiler MACT as well as finalizing minor
changes to the rule to correct and clarify implementation issues raised
by stakeholders.

K. Congressional Review Act (CRA)

    This action is subject to the CRA, and the EPA will submit a rule
report to each House of the Congress and to the Comptroller General of
the United States. This action is not a ``major rule'' as defined by 5
U.S.C. 804(2).

List of Subjects in 40 CFR Part 60

    Environmental protection, Administrative practice and procedure,
Air pollution control, Hazardous substances.

    Dated: November 5, 2015.
Gina McCarthy,
Administrator.

    For the reasons cited in the preamble, title 40, chapter I, part 63
of the Code of Federal Regulations is amended as follows:

PART 63--NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS
FOR SOURCE CATEGORIES

0
1. The authority for part 63 continues to read as follows:

    Authority: 42 U.S.C. 7401, et seq.

Subpart DDDDD--[Amended]

0
2. Section 63.7491 is amended by revising paragraphs (a), (j), and (l)
and adding paragraph (n) to read as follows:

Sec.  63.7491  Are any boilers or process heaters not subject to this
subpart?

* * * * *
    (a) An electric utility steam generating unit (EGU) covered by
subpart UUUUU of this part or a natural gas-fired EGU as defined in
subpart UUUUU of this part firing at least 85 percent natural gas on an
annual heat input basis.
* * * * *
    (j) Temporary boilers and process heaters as defined in this
subpart.
* * * * *
    (l) Any boiler or process heater specifically listed as an affected
source in any standard(s) established under section 129 of the Clean
Air Act.
* * * * *
    (n) Residential boilers as defined in this subpart.

0
3. Section 63.7495 is amended by revising paragraphs (a), (e), and (f)
and adding paragraphs (h) and (i) to read as follows:

Sec.  63.7495  When do I have to comply with this subpart?

    (a) If you have a new or reconstructed boiler or process heater,
you must comply with this subpart by April 1, 2013, or upon startup of
your boiler or process heater, whichever is later.
* * * * *
    (e) If you own or operate an industrial, commercial, or
institutional boiler or process heater and would be subject to this
subpart except for the exemption in Sec.  63.7491(l) for commercial and
industrial solid waste incineration units covered by part 60, subpart
CCCC or subpart DDDD, and you cease combusting solid waste, you must be
in compliance with this subpart and are no longer subject to part 60,
subparts CCCC or DDDD beginning on the effective date of the switch as
identified under the provisions of Sec.  60.2145(a)(2) and (3) or Sec.
60.2710(a)(2) and (3).
    (f) If you own or operate an existing EGU that becomes subject to
this subpart after January 31, 2016, you must be in compliance with the
applicable existing source provisions of this subpart on the effective
date such unit becomes subject to this subpart.
* * * * *
    (h) If you own or operate an existing industrial, commercial, or
institutional boiler or process heater and have switched fuels or made
a physical change to the boiler or process heater that resulted in the
applicability of a different subcategory after the compliance date of
this subpart, you must be in compliance with the applicable existing
source provisions of this subpart on the effective date of the fuel
switch or physical change.
    (i) If you own or operate a new industrial, commercial, or
institutional boiler or process heater and have switched fuels or made
a physical change to the boiler or process heater that resulted in the
applicability of a different subcategory, you must be in compliance
with the applicable new source provisions of this subpart on the
effective date of the fuel switch or physical change.

0
4. Section 63.7500 is amended by revising paragraphs (a)(1)
introductory text, (a)(1)(ii), (a)(1)(iii), and (f) to read as follows:

Sec.  63.7500  What emission limitations, work practice standards, and
operating limits must I meet?

    (a) * * *
    (1) You must meet each emission limit and work practice standard in
Tables 1 through 3, and 11 through 13 to this subpart that applies to
your boiler or process heater, for each boiler or process heater at
your source, except as provided under Sec.  63.7522. The output-based
emission limits, in units of pounds per million Btu of steam output, in
Tables 1 or 2 to this subpart are an alternative applicable only to
boilers and process heaters that generate either steam, cogenerate
steam with electricity, or both. The output-based emission limits, in
units of pounds per megawatt-hour, in Tables 1 or 2 to this subpart are
an alternative applicable only to boilers that generate only
electricity. Boilers that perform multiple functions (cogeneration and
electricity generation) or supply steam to common headers would
calculate a total steam energy output using equation 21 of Sec.
63.7575 to demonstrate compliance with the output-based emission
limits, in units of pounds per million Btu of steam output, in Tables 1
or 2 to this subpart. If you operate a new boiler or process heater,
you can choose to comply with alternative limits as discussed in
paragraphs (a)(1)(i) through (iii) of this section, but on or after
January 31, 2016, you must comply with the emission limits in Table 1
to this subpart.
* * * * *
    (ii) If your boiler or process heater commenced construction or
reconstruction on or after May 20, 2011 and before December 23, 2011,
you may comply with the emission limits in Table 1 or 12 to this
subpart until January 31, 2016.
    (iii) If your boiler or process heater commenced construction or
reconstruction on or after December 23, 2011 and before April 1, 2013,
you may comply with the emission limits in Table 1 or 13 to this
subpart until January 31, 2016.
* * * * *
    (f) These standards apply at all times the affected unit is
operating, except during periods of startup and shutdown during which
time you must comply only with items 5 and 6 of Table 3 to this
subpart.

Sec.  63.7501  [Removed and Reserved]

0
5. Section 63.7501 is removed and reserved.

0
6. Section 63.7505 is amended by revising paragraphs (a), (c), and (d)
introductory text and adding paragraph (e) to read as follows:

Sec.  63.7505  What are my general requirements for complying with this
subpart?

    (a) You must be in compliance with the emission limits, work
practice standards, and operating limits in this subpart. These
emission and operating limits apply to you at all times the affected
unit is operating except for the periods noted in Sec.  63.7500(f).
* * * * *
    (c) You must demonstrate compliance with all applicable emission
limits using performance stack testing, fuel analysis, or continuous
monitoring systems (CMS), including a continuous emission monitoring
system (CEMS), or particulate matter continuous parameter monitoring
system (PM CPMS), where applicable. You may demonstrate compliance with
the applicable emission limit for hydrogen chloride (HCl), mercury, or
total selected metals (TSM) using fuel analysis if the emission rate
calculated according to Sec.  63.7530(c) is less than the applicable
emission limit. (For gaseous fuels, you may not use fuel analyses to
comply with the TSM alternative standard or the HCl standard.)
Otherwise, you must demonstrate compliance for HCl, mercury, or TSM
using performance stack testing, if subject to an applicable emission
limit listed in Tables 1, 2, or 11 through 13 to this subpart.
    (d) If you demonstrate compliance with any applicable emission
limit through performance testing and subsequent compliance with
operating limits through the use of CPMS, or with a CEMS or COMS, you
must develop a site-specific monitoring plan according to the
requirements in paragraphs (d)(1) through (4) of this section for the
use of any CEMS, COMS, or CPMS. This requirement also applies to you if
you petition the EPA Administrator for alternative monitoring
parameters under Sec.  63.8(f).
* * * * *

    (e) If you have an applicable emission limit, and you choose to
comply using definition (2) of ``startup'' in Sec.  63.7575, you must
develop and implement a written startup and shutdown plan (SSP)
according to the requirements in Table 3 to this subpart. The SSP must
be maintained onsite and available upon request for public inspection.

0
7. Section 63.7510 is amended by revising paragraphs (a) introductory
text, (a)(2)(ii), (c), (e), (g), and (i) and adding paragraph (k) to
read as follows:

Sec.  63.7510  What are my initial compliance requirements and by what
date must I conduct them?

    (a) For each boiler or process heater that is required or that you
elect to demonstrate compliance with any of the applicable emission
limits in Tables 1 or 2 or 11 through 13 of this subpart through
performance (stack) testing, your initial compliance requirements
include all the following:
* * * * *
    (2) * * *
    (ii) When natural gas, refinery gas, or other gas 1 fuels are co-
fired with other fuels, you are not required to conduct a fuel analysis
of those Gas 1 fuels according to Sec.  63.7521 and Table 6 to this
subpart. If gaseous fuels other than natural gas, refinery gas, or
other gas 1 fuels are co-fired with other fuels and those non-Gas 1
gaseous fuels are subject to another subpart of this part, part 60,
part 61, or part 65, you are not required to conduct a fuel analysis of
those non-Gas 1 fuels according to Sec.  63.7521 and Table 6 to this
subpart.
* * * * *
    (c) If your boiler or process heater is subject to a carbon
monoxide (CO) limit, your initial compliance demonstration for CO is to
conduct a performance test for CO according to Table 5 to this subpart
or conduct a performance evaluation of your continuous CO monitor, if
applicable, according to Sec.  63.7525(a). Boilers and process heaters
that use a CO CEMS to comply with the applicable alternative CO CEMS
emission standard listed in Tables 1, 2, or 11 through 13 to this
subpart, as specified in Sec.  63.7525(a), are exempt from the initial
CO performance testing and oxygen concentration operating limit
requirements specified in paragraph (a) of this section.
* * * * *
    (e) For existing affected sources (as defined in Sec.  63.7490),
you must complete the initial compliance demonstrations, as specified
in paragraphs (a) through (d) of this section, no later than 180 days
after the compliance date that is specified for your source in Sec.
63.7495 and according to the applicable provisions in Sec.  63.7(a)(2)
as cited in Table 10 to this subpart, except as specified in paragraph
(j) of this section. You must complete an initial tune-up by following
the procedures described in Sec.  63.7540(a)(10)(i) through (vi) no
later than the compliance date specified in Sec.  63.7495, except as
specified in paragraph (j) of this section. You must complete the one-
time energy assessment specified in Table 3 to this subpart no later
than the compliance date specified in Sec.  63.7495.
* * * * *
    (g) For new or reconstructed affected sources (as defined in Sec.
63.7490), you must demonstrate initial compliance with the applicable
work practice standards in Table 3 to this subpart within the
applicable annual, biennial, or 5-year schedule as specified in Sec.
63.7515(d) following the initial compliance date specified in Sec.
63.7495(a). Thereafter, you are required to complete the applicable
annual, biennial, or 5-year tune-up as specified in Sec.  63.7515(d).
* * * * *
    (i) For an existing EGU that becomes subject after January 31,
2016, you must demonstrate compliance within 180 days after becoming an
affected source.
* * * * *
    (k) For affected sources, as defined in Sec.  63.7490, that switch
subcategories consistent with Sec.  63.7545(h) after the initial
compliance date, you must demonstrate compliance within 60 days of the
effective date of the switch, unless you had previously conducted your
compliance demonstration for this subcategory within the previous 12
months.

0
8. Section 63.7515 is amended by revising paragraphs (d), (e), and (h)
to read as follows:

Sec.  63.7515  When must I conduct subsequent performance tests, fuel
analyses, or tune-ups?

* * * * *
    (d) If you are required to meet an applicable tune-up work practice
standard, you must conduct an annual, biennial, or 5-year performance
tune-up according to Sec.  63.7540(a)(10), (11), or (12), respectively.
Each annual tune-up specified in Sec.  63.7540(a)(10) must be no more
than 13 months after the previous tune-up. Each biennial tune-up
specified in Sec.  63.7540(a)(11) must be conducted no more than 25
months after the previous tune-up. Each 5-year tune-up specified in
Sec.  63.7540(a)(12) must be conducted no more than 61 months after the
previous tune-up. For a new or reconstructed affected source (as
defined in Sec.  63.7490), the first annual, biennial, or 5-year tune-
up must be no later than 13 months, 25 months, or 61 months,
respectively, after April 1, 2013 or the initial startup of the new or
reconstructed affected source, whichever is later.
    (e) If you demonstrate compliance with the mercury, HCl, or TSM
based on fuel analysis, you must conduct a monthly fuel analysis
according to Sec.  63.7521 for each type of fuel burned that is subject
to an emission limit in Tables 1, 2, or 11 through 13 to this subpart.
You may comply with this monthly requirement by completing the fuel
analysis any time within the calendar month as long as the analysis is
separated from the previous analysis by at least 14 calendar days. If
you burn a new type of fuel, you must conduct a fuel analysis before
burning the new type of fuel in your boiler or process heater. You must
still meet all applicable continuous compliance requirements in Sec.
63.7540. If each of 12 consecutive monthly fuel analyses demonstrates
75 percent or less of the compliance level, you may decrease the fuel
analysis frequency to quarterly for that fuel. If any quarterly sample
exceeds 75 percent of the compliance level or you begin burning a new
type of fuel, you must return to monthly monitoring for that fuel,
until 12 months of fuel analyses are again less than 75 percent of the
compliance level. If sampling is conducted on one day per month,
samples should be no less than 14 days apart, but if multiple samples
are taken per month, the 14-day restriction does not apply.
* * * * *
    (h) If your affected boiler or process heater is in the unit
designed to burn light liquid subcategory and you combust ultra-low
sulfur liquid fuel, you do not need to conduct further performance
tests (stack tests or fuel analyses) if the pollutants measured during
the initial compliance performance tests meet the emission limits in
Tables 1 or 2 of this subpart providing you demonstrate ongoing
compliance with the emissions limits by monitoring and recording the
type of fuel combusted on a monthly basis. If you intend to use a fuel
other than ultra-low sulfur liquid fuel, natural gas, refinery gas, or
other gas 1 fuel, you must conduct new performance tests within 60 days
of burning the new fuel type.
* * * * *

0
9. Section 63.7521 is amended by:
0
a. Revising paragraph (a).

0
b. Revising paragraph (c) introductory text.
0
c. Revising paragraph (c)(1)(ii).
0
d. Revising paragraph (f) introductory text.
0
e. Revising paragraphs (g) introductory text, (g)(2)(ii), and
(g)(2)(vi).
0
f. Revising paragraph (h).
    The revisions read as follows:

Sec.  63.7521  What fuel analyses, fuel specification, and procedures
must I use?

    (a) For solid and liquid fuels, you must conduct fuel analyses for
chloride and mercury according to the procedures in paragraphs (b)
through (e) of this section and Table 6 to this subpart, as applicable.
For solid fuels and liquid fuels, you must also conduct fuel analyses
for TSM if you are opting to comply with the TSM alternative standard.
For gas 2 (other) fuels, you must conduct fuel analyses for mercury
according to the procedures in paragraphs (b) through (e) of this
section and Table 6 to this subpart, as applicable. (For gaseous fuels,
you may not use fuel analyses to comply with the TSM alternative
standard or the HCl standard.) For purposes of complying with this
section, a fuel gas system that consists of multiple gaseous fuels
collected and mixed with each other is considered a single fuel type
and sampling and analysis is only required on the combined fuel gas
system that will feed the boiler or process heater. Sampling and
analysis of the individual gaseous streams prior to combining is not
required. You are not required to conduct fuel analyses for fuels used
for only startup, unit shutdown, and transient flame stability
purposes. You are required to conduct fuel analyses only for fuels and
units that are subject to emission limits for mercury, HCl, or TSM in
Tables 1 and 2 or 11 through 13 to this subpart. Gaseous and liquid
fuels are exempt from the sampling requirements in paragraphs (c) and
(d) of this section.
* * * * *
    (c) You must obtain composite fuel samples for each fuel type
according to the procedures in paragraph (c)(1) or (2) of this section,
or the methods listed in Table 6 to this subpart, or use an automated
sampling mechanism that provides representative composite fuel samples
for each fuel type that includes both coarse and fine material. At a
minimum, for demonstrating initial compliance by fuel analysis, you
must obtain three composite samples. For monthly fuel analyses, at a
minimum, you must obtain a single composite sample. For fuel analyses
as part of a performance stack test, as specified in Sec.  63.7510(a),
you must obtain a composite fuel sample during each performance test
run.
    (1) * * *
    (ii) Each composite sample will consist of a minimum of three
samples collected at approximately equal one-hour intervals during the
testing period for sampling during performance stack testing.
* * * * *
    (f) To demonstrate that a gaseous fuel other than natural gas or
refinery gas qualifies as an other gas 1 fuel, as defined in Sec.
63.7575, you must conduct a fuel specification analyses for mercury
according to the procedures in paragraphs (g) through (i) of this
section and Table 6 to this subpart, as applicable, except as specified
in paragraph (f)(1) through (4) of this section, or as an alternative
where fuel specification analysis is not practical, you must measure
mercury concentration in the exhaust gas when firing only the gaseous
fuel to be demonstrated as an other gas 1 fuel in the boiler or process
heater according to the procedures in Table 6 to this subpart.
* * * * *
    (g) You must develop a site-specific fuel analysis plan for other
gas 1 fuels according to the following procedures and requirements in
paragraphs (g)(1) and (2) of this section.
* * * * *
    (2) * * *
    (ii) For each anticipated fuel type, the identification of whether
you or a fuel supplier will be conducting the fuel specification
analysis.
* * * * *
    (vi) If you will be using fuel analysis from a fuel supplier in
lieu of site-specific sampling and analysis, the fuel supplier must use
the analytical methods required by Table 6 to this subpart. When using
a fuel supplier's fuel analysis, the owner or operator is not required
to submit the information in Sec.  63.7521(g)(2)(iii).
    (h) You must obtain a single fuel sample for each fuel type for
fuel specification of gaseous fuels.
* * * * *

0
10. Section 63.7522 is amended by:
0
a. Revising paragraphs (c), (d), (f)(1) introductory text, (g)(1),
(g)(3) introductory text, and (i).
0
b. Revising parameters ``En'' and ``ELi'' of Equation 6 in paragraph
(j)(1).
    The revisions read as follows:

Sec.  63.7522  Can I use emissions averaging to comply with this
subpart?

* * * * *
    (c) For each existing boiler or process heater in the averaging
group, the emission rate achieved during the initial compliance test
for the HAP being averaged must not exceed the emission level that was
being achieved on April 1, 2013 or the control technology employed
during the initial compliance test must not be less effective for the
HAP being averaged than the control technology employed on April 1,
2013.
    (d) The averaged emissions rate from the existing boilers and
process heaters participating in the emissions averaging option must
not exceed 90 percent of the limits in Table 2 to this subpart at all
times the affected units are subject to numeric emission limits
following the compliance date specified in Sec.  63.7495.
* * * * *
    (f) * * *
    (1) For each calendar month, you must use Equation 3a or 3b or 3c
of this section to calculate the average weighted emission rate for
that month. Use Equation 3a and the actual heat input for the month for
each existing unit participating in the emissions averaging option if
you are complying with emission limits on a heat input basis. Use
Equation 3b and the actual steam generation for the month if you are
complying with the emission limits on a steam generation (output)
basis. Use Equation 3c and the actual electrical generation for the
month if you are complying with the emission limits on an electrical
generation (output) basis.
* * * * *
    (g) * * *
    (1) If requested, you must submit the implementation plan no later
than 180 days before the date that the facility intends to demonstrate
compliance using the emission averaging option.
* * * * *
    (3) If submitted upon request, the Administrator shall review and
approve or disapprove the plan according to the following criteria:
* * * * *
    (i) For a group of two or more existing units in the same
subcategory, each of which vents through a common emissions control
system to a common stack, that does not receive emissions from units in
other subcategories or categories, you may treat such averaging group
as a single existing unit for purposes of this subpart and comply with
the requirements of this subpart as if the group were a single unit.
    (j) * * *
    (1) * * *
* * * * *

En = HAP emission limit, pounds per million British thermal units (lb/
MMBtu) or parts per million (ppm).
Eli = Appropriate emission limit from Table 2 to this subpart for unit
i, in units of lb/MMBtu or ppm.
* * * * *

0
11. Section 63.7525 is amended by:
0
a. Revising paragraphs (a) introductory text, (a)(1), (a)(2)
introductory text, (a)(3), and (a)(5).
0
b. Adding paragraph (a)(2)(vi).
0
c. Revising paragraphs (b) introductory text, (b)(1) introductory text,
and (b)(1)(iii).
0
d. Revising paragraphs (g)(3) and (4).
0
e. Revising paragraphs (m) introductory text and (m)(2).
    The revisions and addition read as follows:

Sec.  63.7525  What are my monitoring, installation, operation, and
maintenance requirements?

    (a) If your boiler or process heater is subject to a CO emission
limit in Tables 1, 2, or 11 through 13 to this subpart, you must
install, operate, and maintain an oxygen analyzer system, as defined in
Sec.  63.7575, or install, certify, operate and maintain continuous
emission monitoring systems for CO and oxygen (or carbon dioxide
(CO2)) according to the procedures in paragraphs (a)(1)
through (6) of this section.
    (1) Install the CO CEMS and oxygen (or CO2) analyzer by
the compliance date specified in Sec.  63.7495. The CO and oxygen (or
CO2) levels shall be monitored at the same location at the
outlet of the boiler or process heater. An owner or operator may
request an alternative test method under Sec.  63.7 of this chapter, in
order that compliance with the CO emissions limit be determined using
CO2 as a diluent correction in place of oxygen at 3 percent.
EPA Method 19 F-factors and EPA Method 19 equations must be used to
generate the appropriate CO2 correction percentage for the
fuel type burned in the unit, and must also take into account that the
3 percent oxygen correction is to be done on a dry basis. The
alternative test method request must account for any CO2
being added to, or removed from, the emissions gas stream as a result
of limestone injection, scrubber media, etc.
    (2) To demonstrate compliance with the applicable alternative CO
CEMS emission standard listed in Tables 1, 2, or 11 through 13 to this
subpart, you must install, certify, operate, and maintain a CO CEMS and
an oxygen analyzer according to the applicable procedures under
Performance Specification 4, 4A, or 4B at 40 CFR part 60, appendix B;
part 75 of this chapter (if an CO2 analyzer is used); the
site-specific monitoring plan developed according to Sec.  63.7505(d);
and the requirements in Sec.  63.7540(a)(8) and paragraph (a) of this
section. Any boiler or process heater that has a CO CEMS that is
compliant with Performance Specification 4, 4A, or 4B at 40 CFR part
60, appendix B, a site-specific monitoring plan developed according to
Sec.  63.7505(d), and the requirements in Sec.  63.7540(a)(8) and
paragraph (a) of this section must use the CO CEMS to comply with the
applicable alternative CO CEMS emission standard listed in Tables 1, 2,
or 11 through 13 to this subpart.
* * * * *
    (vi) When CO2 is used to correct CO emissions and
CO2 is measured on a wet basis, correct for moisture as
follows: Install, operate, maintain, and quality assure a continuous
moisture monitoring system for measuring and recording the moisture
content of the flue gases, in order to correct the measured hourly
volumetric flow rates for moisture when calculating CO concentrations.
The following continuous moisture monitoring systems are acceptable: A
continuous moisture sensor; an oxygen analyzer (or analyzers) capable
of measuring O2 both on a wet basis and on a dry basis; or a
stack temperature sensor and a moisture look-up table, i.e., a
psychrometric chart (for saturated gas streams following wet scrubbers
or other demonstrably saturated gas streams, only). The moisture
monitoring system shall include as a component the automated data
acquisition and handling system (DAHS) for recording and reporting both
the raw data (e.g., hourly average wet-and dry basis O2
values) and the hourly average values of the stack gas moisture content
derived from those data. When a moisture look-up table is used, the
moisture monitoring system shall be represented as a single component,
the certified DAHS, in the monitoring plan for the unit or common
stack.
    (3) Complete a minimum of one cycle of CO and oxygen (or
CO2) CEMS operation (sampling, analyzing, and data
recording) for each successive 15-minute period. Collect CO and oxygen
(or CO2) data concurrently. Collect at least four CO and
oxygen (or CO2) CEMS data values representing the four 15-
minute periods in an hour, or at least two 15-minute data values during
an hour when CEMS calibration, quality assurance, or maintenance
activities are being performed.
* * * * *
    (5) Calculate one-hour arithmetic averages, corrected to 3 percent
oxygen (or corrected to an CO2 percentage determined to be
equivalent to 3 percent oxygen) from each hour of CO CEMS data in parts
per million CO concentration. The one-hour arithmetic averages required
shall be used to calculate the 30-day or 10-day rolling average
emissions. Use Equation 19-19 in section 12.4.1 of Method 19 of 40 CFR
part 60, appendix A-7 for calculating the average CO concentration from
the hourly values.
* * * * *
    (b) If your boiler or process heater is in the unit designed to
burn coal/solid fossil fuel subcategory or the unit designed to burn
heavy liquid subcategory and has an average annual heat input rate
greater than 250 MMBtu per hour from solid fossil fuel and/or heavy
liquid, and you demonstrate compliance with the PM limit instead of the
alternative TSM limit, you must install, maintain, and operate a PM
CPMS monitoring emissions discharged to the atmosphere and record the
output of the system as specified in paragraphs (b)(1) through (4) of
this section. As an alternative to use of a PM CPMS to demonstrate
compliance with the PM limit, you may choose to use a PM CEMS. If you
choose to use a PM CEMS to demonstrate compliance with the PM limit
instead of the alternative TSM limit, you must install, certify,
maintain, and operate a PM CEMS monitoring emissions discharged to the
atmosphere and record the output of the system as specified in
paragraph (b)(5) through (8) of this section. For other boilers or
process heaters, you may elect to use a PM CPMS or PM CEMS operated in
accordance with this section in lieu of using other CMS for monitoring
PM compliance (e.g., bag leak detectors, ESP secondary power, and PM
scrubber pressure). Owners of boilers and process heaters who elect to
comply with the alternative TSM limit are not required to install a PM
CPMS.
    (1) Install, operate, and maintain your PM CPMS according to the
procedures in your approved site-specific monitoring plan developed in
accordance with Sec.  63.7505(d), the requirements in Sec.
63.7540(a)(9), and paragraphs (b)(1)(i) through (iii) of this section.
* * * * *
    (iii) The PM CPMS must have a documented detection limit of 0.5
milligram per actual cubic meter, or less.
* * * * *
    (g) * * *
    (3) Calibrate the pH monitoring system in accordance with your
monitoring plan and according to the

manufacturer's instructions. Clean the pH probe at least once each
process operating day. Maintain on-site documentation that your
calibration frequency is sufficient to maintain the specified accuracy
of your device.
    (4) Conduct a performance evaluation (including a two-point
calibration with one of the two buffer solutions having a pH within 1
of the pH of the operating limit) of the pH monitoring system in
accordance with your monitoring plan at the time of each performance
test but no less frequently than annually.
* * * * *
    (m) If your unit is subject to a HCl emission limit in Tables 1, 2,
or 11 through 13 of this subpart and you have an acid gas wet scrubber
or dry sorbent injection control technology and you elect to use an
SO2 CEMS to demonstrate continuous compliance with the HCl
emission limit, you must install the monitor at the outlet of the
boiler or process heater, downstream of all emission control devices,
and you must install, certify, operate, and maintain the CEMS according
to either part 60 or part 75 of this chapter.
* * * * *
    (2) For on-going quality assurance (QA), the SO2 CEMS
must meet either the applicable daily and quarterly requirements in
Procedure 1 of appendix F of part 60 or the applicable daily,
quarterly, and semiannual or annual requirements in sections 2.1
through 2.3 of appendix B to part 75 of this chapter, with the
following addition: You must perform the linearity checks required in
section 2.2 of appendix B to part 75 of this chapter if the
SO2 CEMS has a span value of 30 ppm or less.
* * * * *

0
12. Section 63.7530 is amended by:
0
a. Revising paragraph (a) and paragraph (b) introductory text.
0
b. Revising parameter ``Qi'' of Equation 7 in paragraph (b)(1)(iii),
Equation 8 in paragraph (b)(2)(iii), and Equation 9 in paragraph
(b)(3)(iii).
0
c. Revising parameter ``n'' of Equation 14 in paragraph (b)(4)(ii)(D).
0
d. Revising paragraph (b)(4)(ii)(F).
0
e. Redesignating paragraphs (b)(4)(iii) through (viii) as paragraphs
(b)(4)(iv) through (ix) and adding new paragraph (b)(4)(iii).
0
f. Revising parameters ``Ci90'' and ``Qi'' of Equation 16 in paragraph
(c)(3), parameters ``Hgi90'' and ``Qi'' of Equation 17 in paragraph
(c)(4), and parameters ``TSMi90'' and ``Qi'' of Equation 18 in
paragraph (c)(5).
0
g. Removing and reserving paragraph (d).
0
h. Revising paragraphs (e), (h), and (i)(3).
    The revisions and additions read as follows:

Sec.  63.7530  How do I demonstrate initial compliance with the
emission limitations, fuel specifications and work practice standards?

    (a) You must demonstrate initial compliance with each emission
limit that applies to you by conducting initial performance tests and
fuel analyses and establishing operating limits, as applicable,
according to Sec.  63.7520, paragraphs (b) and (c) of this section, and
Tables 5 and 7 to this subpart. The requirement to conduct a fuel
analysis is not applicable for units that burn a single type of fuel,
as specified by Sec.  63.7510(a)(2). If applicable, you must also
install, operate, and maintain all applicable CMS (including CEMS,
COMS, and CPMS) according to Sec.  63.7525.
    (b) If you demonstrate compliance through performance stack
testing, you must establish each site-specific operating limit in Table
4 to this subpart that applies to you according to the requirements in
Sec.  63.7520, Table 7 to this subpart, and paragraph (b)(4) of this
section, as applicable. You must also conduct fuel analyses according
to Sec.  63.7521 and establish maximum fuel pollutant input levels
according to paragraphs (b)(1) through (3) of this section, as
applicable, and as specified in Sec.  63.7510(a)(2). (Note that Sec.
63.7510(a)(2) exempts certain fuels from the fuel analysis
requirements.) However, if you switch fuel(s) and cannot show that the
new fuel(s) does (do) not increase the chlorine, mercury, or TSM input
into the unit through the results of fuel analysis, then you must
repeat the performance test to demonstrate compliance while burning the
new fuel(s).
    (1) * * *
    (iii) * * *

Qi = Fraction of total heat input from fuel type, i, based on the fuel
mixture that has the highest content of chlorine during the initial
compliance test. If you do not burn multiple fuel types during the
performance testing, it is not necessary to determine the value of this
term. Insert a value of ``1'' for Qi. For continuous compliance
demonstration, the actual fraction of the fuel burned during the month
should be used.
* * * * *
    (2) * * *
    (iii) * * *
Qi = Fraction of total heat input from fuel type, i, based on the fuel
mixture that has the highest mercury content during the initial
compliance test. If you do not burn multiple fuel types during the
performance test, it is not necessary to determine the value of this
term. Insert a value of ``1'' for Qi. For continuous compliance
demonstration, the actual fraction of the fuel burned during the month
should be used.
* * * * *
    (3) * * *
    (iii) * * *

Qi = Fraction of total heat input from fuel type, i, based on the fuel
mixture that has the highest content of TSM during the initial
compliance test. If you do not burn multiple fuel types during the
performance testing, it is not necessary to determine the value of this
term. Insert a value of ``1'' for Qi. For continuous compliance
demonstration, the actual fraction of the fuel burned during the month
should be used.
* * * * *
    (4) * * *
    (ii) * * *
    (D) * * *
n = is the number of valid hourly parameter values collected over the
previous 30 operating days.
* * * * *
    (F) For PM performance test reports used to set a PM CPMS operating
limit, the electronic submission of the test report must also include
the make and model of the PM CPMS instrument, serial number of the
instrument, analytical principle of the instrument (e.g. beta
attenuation), span of the instruments primary analytical range,
milliamp value equivalent to the instrument zero output, technique by
which this zero value was determined, and the average milliamp signals
corresponding to each PM compliance test run.
    (iii) For a particulate wet scrubber, you must establish the
minimum pressure drop and liquid flow rate as defined in Sec.  63.7575,
as your operating limits during the three-run performance test during
which you demonstrate compliance with your applicable limit. If you use
a wet scrubber and you conduct separate performance tests for PM and
TSM emissions, you must establish one set of minimum scrubber liquid
flow rate and pressure drop operating limits. The minimum scrubber
effluent pH operating limit must be established during the HCl
performance test. If you conduct multiple performance tests, you must
set the minimum liquid flow rate and pressure

drop operating limits at the higher of the minimum values established
during the performance tests.
    (iv) For an electrostatic precipitator (ESP) operated with a wet
scrubber, you must establish the minimum total secondary electric power
input, as defined in Sec.  63.7575, as your operating limit during the
three-run performance test during which you demonstrate compliance with
your applicable limit. (These operating limits do not apply to ESP that
are operated as dry controls without a wet scrubber.)
    (v) For a dry scrubber, you must establish the minimum sorbent
injection rate for each sorbent, as defined in Sec.  63.7575, as your
operating limit during the three-run performance test during which you
demonstrate compliance with your applicable limit.
    (vi) For activated carbon injection, you must establish the minimum
activated carbon injection rate, as defined in Sec.  63.7575, as your
operating limit during the three-run performance test during which you
demonstrate compliance with your applicable limit.
    (vii) The operating limit for boilers or process heaters with
fabric filters that demonstrate continuous compliance through bag leak
detection systems is that a bag leak detection system be installed
according to the requirements in Sec.  63.7525, and that each fabric
filter must be operated such that the bag leak detection system alert
is not activated more than 5 percent of the operating time during a 6-
month period.
    (viii) For a minimum oxygen level, if you conduct multiple
performance tests, you must set the minimum oxygen level at the lower
of the minimum values established during the performance tests.
    (ix) The operating limit for boilers or process heaters that
demonstrate continuous compliance with the HCl emission limit using a
SO2 CEMS is to install and operate the SO2
according to the requirements in Sec.  63.7525(m) establish a maximum
SO2 emission rate equal to the highest hourly average
SO2 measurement during the most recent three-run performance
test for HCl.
    (c) * * *
    (3) * * *
Ci90 = 90th percentile confidence level concentration of chlorine in
fuel type, i, in units of pounds per million Btu as calculated
according to Equation 15 of this section.
Qi = Fraction of total heat input from fuel type, i, based on the fuel
mixture that has the highest content of chlorine. If you do not burn
multiple fuel types, it is not necessary to determine the value of this
term. Insert a value of ``1'' for Qi. For continuous compliance
demonstration, the actual fraction of the fuel burned during the month
should be used.
* * * * *
    (4) * * *
Hgi90 = 90th percentile confidence level concentration of mercury in
fuel, i, in units of pounds per million Btu as calculated according to
Equation 15 of this section.
Qi = Fraction of total heat input from fuel type, i, based on the fuel
mixture that has the highest mercury content. If you do not burn
multiple fuel types, it is not necessary to determine the value of this
term. Insert a value of ``1'' for Qi. For continuous compliance
demonstration, the actual fraction of the fuel burned during the month
should be used.
* * * * *
    (5) * * *
TSMi90 = 90th percentile confidence level concentration of TSM in fuel,
i, in units of pounds per million Btu as calculated according to
Equation 15 of this section.
Qi = Fraction of total heat input from fuel type, i, based on the fuel
mixture that has the highest TSM content. If you do not burn multiple
fuel types, it is not necessary to determine the value of this term.
Insert a value of ``1'' for Qi. For continuous compliance
demonstration, the actual fraction of the fuel burned during the month
should be used.
* * * * *
    (e) You must include with the Notification of Compliance Status a
signed certification that either the energy assessment was completed
according to Table 3 to this subpart, and that the assessment is an
accurate depiction of your facility at the time of the assessment, or
that the maximum number of on-site technical hours specified in the
definition of energy assessment applicable to the facility has been
expended.
* * * * *
    (h) If you own or operate a unit subject to emission limits in
Tables 1 or 2 or 11 through 13 to this subpart, you must meet the work
practice standard according to Table 3 of this subpart. During startup
and shutdown, you must only follow the work practice standards
according to items 5 and 6 of Table 3 of this subpart.
    (i) * * *
    (3) You establish a unit-specific maximum SO2 operating
limit by collecting the maximum hourly SO2 emission rate on
the SO2 CEMS during the paired 3-run test for HCl. The
maximum SO2 operating limit is equal to the highest hourly
average SO2 concentration measured during the HCl
performance test.

0
13. Section 63.7533 is amended by revising paragraph (e) to read as
follows:

Sec.  63.7533  Can I use efficiency credits earned from implementation
of energy conservation measures to comply with this subpart?

* * * * *
    (e) The emissions rate as calculated using Equation 20 of this
section from each existing boiler participating in the efficiency
credit option must be in compliance with the limits in Table 2 to this
subpart at all times the affected unit is subject to numeric emission
limits, following the compliance date specified in Sec.  63.7495.
* * * * *
0
14. Section 63.7535 is amended by revising paragraphs (c) and (d) to
read as follows:

Sec.  63.7535  Is there a minimum amount of monitoring data I must
obtain?

* * * * *
    (c) You may not use data recorded during periods of startup and
shutdown, monitoring system malfunctions or out-of-control periods,
repairs associated with monitoring system malfunctions or out-of-
control periods, or required monitoring system quality assurance or
control activities in data averages and calculations used to report
emissions or operating levels. You must record and make available upon
request results of CMS performance audits and dates and duration of
periods when the CMS is out of control to completion of the corrective
actions necessary to return the CMS to operation consistent with your
site-specific monitoring plan. You must use all the data collected
during all other periods in assessing compliance and the operation of
the control device and associated control system.
    (d) Except for periods of monitoring system malfunctions, repairs
associated with monitoring system malfunctions, and required monitoring
system quality assurance or quality control activities (including, as
applicable, system accuracy audits, calibration checks, and required
zero and span adjustments), failure to collect required data is a
deviation of the monitoring requirements. In calculating monitoring
results, do not use any data collected during periods of startup and
shutdown, when the monitoring system is out of control as specified in
your site-specific monitoring plan, while conducting repairs associated
with periods when

the monitoring system is out of control, or while conducting required
monitoring system quality assurance or quality control activities. You
must calculate monitoring results using all other monitoring data
collected while the process is operating. You must report all periods
when the monitoring system is out of control in your semi-annual
report.

0
15. Section 63.7540 is amended by:
0
a. Revising paragraph (a)(2).
0
b. Revising paragraphs (a)(3) introductory text and (a)(3)(iii).
0
c. Revising paragraphs (a)(5) introductory text and (a)(5)(iii).
0
d. Revising paragraph (a)(8)(ii).
0
e. Revising paragraph (a)(10) introductory text.
0
f. Revising paragraph (a)(10)(i).
0
g. Revising paragraph (a)(10)(vi) introductory text.
0
h. Revising paragraphs (a)(12).
0
i. Revising paragraphs (a)(14)(i) and (a)(15)(i).
0
j. Revising paragraphs (a)(17) introductory text and (a)(17)(iii).
0
k. Revising paragraph (a)(18)(i).
0
l. Revising paragraph (a)(19)(iii).
0
m. Revising paragraph (d).
    The revisions read as follows:

Sec.  63.7540  How do I demonstrate continuous compliance with the
emission limitations, fuel specifications and work practice standards?

    (a) * * *
    (2) As specified in Sec.  63.7555(d), you must keep records of the
type and amount of all fuels burned in each boiler or process heater
during the reporting period to demonstrate that all fuel types and
mixtures of fuels burned would result in either of the following:
    (i) Equal to or lower emissions of HCl, mercury, and TSM than the
applicable emission limit for each pollutant, if you demonstrate
compliance through fuel analysis.
    (ii) Equal to or lower fuel input of chlorine, mercury, and TSM
than the maximum values calculated during the last performance test, if
you demonstrate compliance through performance testing.
    (3) If you demonstrate compliance with an applicable HCl emission
limit through fuel analysis for a solid or liquid fuel and you plan to
burn a new type of solid or liquid fuel, you must recalculate the HCl
emission rate using Equation 16 of Sec.  63.7530 according to
paragraphs (a)(3)(i) through (iii) of this section. You are not
required to conduct fuel analyses for the fuels described in Sec.
63.7510(a)(2)(i) through (iii). You may exclude the fuels described in
Sec.  63.7510(a)(2)(i) through (iii) when recalculating the HCl
emission rate.
* * * * *
    (iii) Recalculate the HCl emission rate from your boiler or process
heater under these new conditions using Equation 16 of Sec.  63.7530.
The recalculated HCl emission rate must be less than the applicable
emission limit.
* * * * *
    (5) If you demonstrate compliance with an applicable mercury
emission limit through fuel analysis, and you plan to burn a new type
of fuel, you must recalculate the mercury emission rate using Equation
17 of Sec.  63.7530 according to the procedures specified in paragraphs
(a)(5)(i) through (iii) of this section. You are not required to
conduct fuel analyses for the fuels described in Sec.  63.7510(a)(2)(i)
through (iii). You may exclude the fuels described in Sec.
63.7510(a)(2)(i) through (iii) when recalculating the mercury emission
rate.
* * * * *
    (iii) Recalculate the mercury emission rate from your boiler or
process heater under these new conditions using Equation 17 of Sec.
63.7530. The recalculated mercury emission rate must be less than the
applicable emission limit.
* * * * *
    (8) * * *
    (ii) Maintain a CO emission level below or at your applicable
alternative CO CEMS-based standard in Tables 1 or 2 or 11 through 13 to
this subpart at all times the affected unit is subject to numeric
emission limits.
* * * * *
    (10) If your boiler or process heater has a heat input capacity of
10 million Btu per hour or greater, you must conduct an annual tune-up
of the boiler or process heater to demonstrate continuous compliance as
specified in paragraphs (a)(10)(i) through (vi) of this section. You
must conduct the tune-up while burning the type of fuel (or fuels in
case of units that routinely burn a mixture) that provided the majority
of the heat input to the boiler or process heater over the 12 months
prior to the tune-up. This frequency does not apply to limited-use
boilers and process heaters, as defined in Sec.  63.7575, or units with
continuous oxygen trim systems that maintain an optimum air to fuel
ratio.
    (i) As applicable, inspect the burner, and clean or replace any
components of the burner as necessary (you may perform the burner
inspection any time prior to the tune-up or delay the burner inspection
until the next scheduled unit shutdown). Units that produce electricity
for sale may delay the burner inspection until the first outage, not to
exceed 36 months from the previous inspection. At units where entry
into a piece of process equipment or into a storage vessel is required
to complete the tune-up inspections, inspections are required only
during planned entries into the storage vessel or process equipment;
* * * * *
    (vi) Maintain on-site and submit, if requested by the
Administrator, a report containing the information in paragraphs
(a)(10)(vi)(A) through (C) of this section,
* * * * *
    (12) If your boiler or process heater has a continuous oxygen trim
system that maintains an optimum air to fuel ratio, or a heat input
capacity of less than or equal to 5 million Btu per hour and the unit
is in the units designed to burn gas 1; units designed to burn gas 2
(other); or units designed to burn light liquid subcategories, or meets
the definition of limited-use boiler or process heater in Sec.
63.7575, you must conduct a tune-up of the boiler or process heater
every 5 years as specified in paragraphs (a)(10)(i) through (vi) of
this section to demonstrate continuous compliance. You may delay the
burner inspection specified in paragraph (a)(10)(i) of this section
until the next scheduled or unscheduled unit shutdown, but you must
inspect each burner at least once every 72 months. If an oxygen trim
system is utilized on a unit without emission standards to reduce the
tune-up frequency to once every 5 years, set the oxygen level no lower
than the oxygen concentration measured during the most recent tune-up.
* * * * *
    (14) * * *
    (i) Operate the mercury CEMS in accordance with performance
specification 12A of 40 CFR part 60, appendix B or operate a sorbent
trap based integrated monitor in accordance with performance
specification 12B of 40 CFR part 60, appendix B. The duration of the
performance test must be 30 operating days if you specified a 30
operating day basis in Sec.  63.7545(e)(2)(iii) for mercury CEMS or it
must be 720 hours if you specified a 720 hour basis in Sec.
63.7545(e)(2)(iii) for mercury CEMS. For each day in which the unit
operates, you must obtain hourly mercury concentration data, and stack
gas volumetric flow rate data.
* * * * *
    (15) * * *
    (i) Operate the continuous emissions monitoring system in
accordance with the applicable performance specification in 40 CFR part
60, appendix B. The duration of the performance test must be 30
operating

days if you specified a 30 operating day basis in Sec.
63.7545(e)(2)(iii) for HCl CEMS or it must be 720 hours if you
specified a 720 hour basis in Sec.  63.7545(e)(2)(iii) for HCl CEMS.
For each day in which the unit operates, you must obtain hourly HCl
concentration data, and stack gas volumetric flow rate data.
* * * * *
    (17) If you demonstrate compliance with an applicable TSM emission
limit through fuel analysis for solid or liquid fuels, and you plan to
burn a new type of fuel, you must recalculate the TSM emission rate
using Equation 18 of Sec.  63.7530 according to the procedures
specified in paragraphs (a)(5)(i) through (iii) of this section. You
are not required to conduct fuel analyses for the fuels described in
Sec.  63.7510(a)(2)(i) through (iii). You may exclude the fuels
described in Sec.  63.7510(a)(2)(i) through (iii) when recalculating
the TSM emission rate.
* * * * *
    (iii) Recalculate the TSM emission rate from your boiler or process
heater under these new conditions using Equation 18 of Sec.  63.7530.
The recalculated TSM emission rate must be less than the applicable
emission limit.
* * * * *
    (18) * * *
    (i) To determine continuous compliance, you must record the PM CPMS
output data for all periods when the process is operating and the PM
CPMS is not out-of-control. You must demonstrate continuous compliance
by using all quality-assured hourly average data collected by the PM
CPMS for all operating hours to calculate the arithmetic average
operating parameter in units of the operating limit (milliamps) on a
30-day rolling average basis.
* * * * *
    (19) * * *
    (iii) Collect PM CEMS hourly average output data for all boiler
operating hours except as indicated in paragraph (v) of this section.
* * * * *
    (d) For startup and shutdown, you must meet the work practice
standards according to items 5 and 6 of Table 3 of this subpart.

0
16. Section 63.7545 is amended by revising paragraphs (e) introductory
text, (e)(8)(i), adding paragraph (e)(2)(iii), and revising paragraph
(h) introductory text to read as follows:

Sec.  63.7545  What notifications must I submit and when?

* * * * *
    (e) If you are required to conduct an initial compliance
demonstration as specified in Sec.  63.7530, you must submit a
Notification of Compliance Status according to Sec.  63.9(h)(2)(ii).
For the initial compliance demonstration for each boiler or process
heater, you must submit the Notification of Compliance Status,
including all performance test results and fuel analyses, before the
close of business on the 60th day following the completion of all
performance test and/or other initial compliance demonstrations for all
boiler or process heaters at the facility according to Sec.
63.10(d)(2). The Notification of Compliance Status report must contain
all the information specified in paragraphs (e)(1) through (8) of this
section, as applicable. If you are not required to conduct an initial
compliance demonstration as specified in Sec.  63.7530(a), the
Notification of Compliance Status must only contain the information
specified in paragraphs (e)(1) and (8) of this section and must be
submitted within 60 days of the compliance date specified at Sec.
63.7495(b).
* * * * *
    (2) * * *
    (iii) Identification of whether you are complying the arithmetic
mean of all valid hours of data from the previous 30 operating days or
of the previous 720 hours. This identification shall be specified
separately for each operating parameter.
* * * * *
    (8) * * *
    (i) ``This facility completed the required initial tune-up for all
of the boilers and process heaters covered by 40 CFR part 63 subpart
DDDDD at this site according to the procedures in Sec.
63.7540(a)(10)(i) through (vi).''
* * * * *
    (h) If you have switched fuels or made a physical change to the
boiler or process heater and the fuel switch or physical change
resulted in the applicability of a different subcategory, you must
provide notice of the date upon which you switched fuels or made the
physical change within 30 days of the switch/change. The notification
must identify:
* * * * *

0
17. Section 63.7550 is amended by revising paragraphs (b), (c)(1)
through (4), (c)(5)(viii) and (xvi), adding paragraph (c)(5)(xviii),
and revising paragraph (d) introductory text, (d)(1), and (h) to read
as follows:

Sec.  63.7550  What reports must I submit and when?

* * * * *
    (b) Unless the EPA Administrator has approved a different schedule
for submission of reports under Sec.  63.10(a), you must submit each
report, according to paragraph (h) of this section, by the date in
Table 9 to this subpart and according to the requirements in paragraphs
(b)(1) through (4) of this section. For units that are subject only to
a requirement to conduct subsequent annual, biennial, or 5-year tune-up
according to Sec.  63.7540(a)(10), (11), or (12), respectively, and not
subject to emission limits or Table 4 operating limits, you may submit
only an annual, biennial, or 5-year compliance report, as applicable,
as specified in paragraphs (b)(1) through (4) of this section, instead
of a semi-annual compliance report.
    (1) The first semi-annual compliance report must cover the period
beginning on the compliance date that is specified for each boiler or
process heater in Sec.  63.7495 and ending on June 30 or December 31,
whichever date is the first date that occurs at least 180 days after
the compliance date that is specified for your source in Sec.  63.7495.
If submitting an annual, biennial, or 5-year compliance report, the
first compliance report must cover the period beginning on the
compliance date that is specified for each boiler or process heater in
Sec.  63.7495 and ending on December 31 within 1, 2, or 5 years, as
applicable, after the compliance date that is specified for your source
in Sec.  63.7495.
    (2) The first semi-annual compliance report must be postmarked or
submitted no later than July 31 or January 31, whichever date is the
first date following the end of the first calendar half after the
compliance date that is specified for each boiler or process heater in
Sec.  63.7495. The first annual, biennial, or 5-year compliance report
must be postmarked or submitted no later than January 31.
    (3) Each subsequent semi-annual compliance report must cover the
semiannual reporting period from January 1 through June 30 or the
semiannual reporting period from July 1 through December 31. Annual,
biennial, and 5-year compliance reports must cover the applicable 1-,
2-, or 5-year periods from January 1 to December 31.
    (4) Each subsequent semi-annual compliance report must be
postmarked or submitted no later than July 31 or January 31, whichever
date is the first date following the end of the semiannual reporting
period. Annual, biennial, and 5-year compliance reports must be
postmarked or submitted no later than January 31.
    (5) For each affected source that is subject to permitting
regulations pursuant to part 70 or part 71 of this

chapter, and if the permitting authority has established dates for
submitting semiannual reports pursuant to 70.6(a)(3)(iii)(A) or
71.6(a)(3)(iii)(A), you may submit the first and subsequent compliance
reports according to the dates the permitting authority has established
in the permit instead of according to the dates in paragraphs (b)(1)
through (4) of this section.
    (c) * * *
    (1) If the facility is subject to the requirements of a tune up you
must submit a compliance report with the information in paragraphs
(c)(5)(i) through (iii) of this section, (xiv) and (xvii) of this
section, and paragraph (c)(5)(iv) of this section for limited-use
boiler or process heater.
    (2) If you are complying with the fuel analysis you must submit a
compliance report with the information in paragraphs (c)(5)(i) through
(iii), (vi), (x), (xi), (xiii), (xv), (xvii), (xviii) and paragraph (d)
of this section.
    (3) If you are complying with the applicable emissions limit with
performance testing you must submit a compliance report with the
information in (c)(5)(i) through (iii), (vi), (vii), (viii), (ix),
(xi), (xiii), (xv), (xvii), (xviii) and paragraph (d) of this section.
    (4) If you are complying with an emissions limit using a CMS the
compliance report must contain the information required in paragraphs
(c)(5)(i) through (iii), (v), (vi), (xi) through (xiii), (xv) through
(xviii), and paragraph (e) of this section.
    (5) * * *
    (viii) A statement indicating that you burned no new types of fuel
in an individual boiler or process heater subject to an emission limit.
Or, if you did burn a new type of fuel and are subject to a HCl
emission limit, you must submit the calculation of chlorine input,
using Equation 7 of Sec.  63.7530, that demonstrates that your source
is still within its maximum chlorine input level established during the
previous performance testing (for sources that demonstrate compliance
through performance testing) or you must submit the calculation of HCl
emission rate using Equation 16 of Sec.  63.7530 that demonstrates that
your source is still meeting the emission limit for HCl emissions (for
boilers or process heaters that demonstrate compliance through fuel
analysis). If you burned a new type of fuel and are subject to a
mercury emission limit, you must submit the calculation of mercury
input, using Equation 8 of Sec.  63.7530, that demonstrates that your
source is still within its maximum mercury input level established
during the previous performance testing (for sources that demonstrate
compliance through performance testing), or you must submit the
calculation of mercury emission rate using Equation 17 of Sec.  63.7530
that demonstrates that your source is still meeting the emission limit
for mercury emissions (for boilers or process heaters that demonstrate
compliance through fuel analysis). If you burned a new type of fuel and
are subject to a TSM emission limit, you must submit the calculation of
TSM input, using Equation 9 of Sec.  63.7530, that demonstrates that
your source is still within its maximum TSM input level established
during the previous performance testing (for sources that demonstrate
compliance through performance testing), or you must submit the
calculation of TSM emission rate, using Equation 18 of Sec.  63.7530,
that demonstrates that your source is still meeting the emission limit
for TSM emissions (for boilers or process heaters that demonstrate
compliance through fuel analysis).
* * * * *
    (xvi) For each reporting period, the compliance reports must
include all of the calculated 30 day rolling average values for CEMS
(CO, HCl, SO2, and mercury), 10 day rolling average values
for CO CEMS when the limit is expressed as a 10 day instead of 30 day
rolling average, and the PM CPMS data.
* * * * *
    (xviii) For each instance of startup or shutdown include the
information required to be monitored, collected, or recorded according
to the requirements of Sec.  63.7555(d).
    (d) For each deviation from an emission limit or operating limit in
this subpart that occurs at an individual boiler or process heater
where you are not using a CMS to comply with that emission limit or
operating limit, or from the work practice standards for periods if
startup and shutdown, the compliance report must additionally contain
the information required in paragraphs (d)(1) through (3) of this
section.
    (1) A description of the deviation and which emission limit,
operating limit, or work practice standard from which you deviated.
* * * * *
    (h) You must submit the reports according to the procedures
specified in paragraphs (h)(1) through (3) of this section.
    (1) Within 60 days after the date of completing each performance
test (as defined in Sec.  63.2) required by this subpart, you must
submit the results of the performance tests, including any fuel
analyses, following the procedure specified in either paragraph
(h)(1)(i) or (ii) of this section.
    (i) For data collected using test methods supported by the EPA's
Electronic Reporting Tool (ERT) as listed on the EPA's ERT Web site
(http://www.epa.gov/ttn/chief/ert/index.html), you must submit the
results of the performance test to the EPA via the Compliance and
Emissions Data Reporting Interface (CEDRI). (CEDRI can be accessed
through the EPA's Central Data Exchange (CDX) (https://cdx.epa.gov/).)
Performance test data must be submitted in a file format generated
through use of the EPA's ERT or an electronic file format consistent
with the extensible markup language (XML) schema listed on the EPA's
ERT Web site. If you claim that some of the performance test
information being submitted is confidential business information (CBI),
you must submit a complete file generated through the use of the EPA's
ERT or an alternate electronic file consistent with the XML schema
listed on the EPA's ERT Web site, including information claimed to be
CBI, on a compact disc, flash drive, or other commonly used electronic
storage media to the EPA. The electronic media must be clearly marked
as CBI and mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: Group
Leader, Measurement Policy Group, MD C404-02, 4930 Old Page Rd.,
Durham, NC 27703. The same ERT or alternate file with the CBI omitted
must be submitted to the EPA via the EPA's CDX as described earlier in
this paragraph.
    (ii) For data collected using test methods that are not supported
by the EPA's ERT as listed on the EPA's ERT Web site at the time of the
test, you must submit the results of the performance test to the
Administrator at the appropriate address listed in Sec.  63.13.
    (2) Within 60 days after the date of completing each CEMS
performance evaluation (as defined in 63.2), you must submit the
results of the performance evaluation following the procedure specified
in either paragraph (h)(2)(i) or (ii) of this section.
    (i) For performance evaluations of continuous monitoring systems
measuring relative accuracy test audit (RATA) pollutants that are
supported by the EPA's ERT as listed on the EPA's ERT Web site at the
time of the evaluation, you must submit the results of the performance
evaluation to the EPA via the CEDRI. (CEDRI can be accessed through the
EPA's CDX.) Performance evaluation data must be submitted in a file
format generated through the use of the EPA's ERT or an alternate file
format consistent with the XML schema listed on the EPA's ERT

Web site. If you claim that some of the performance evaluation
information being transmitted is CBI, you must submit a complete file
generated through the use of the EPA's ERT or an alternate electronic
file consistent with the XML schema listed on the EPA's ERT Web site,
including information claimed to be CBI, on a compact disc, flash
drive, or other commonly used electronic storage media to the EPA. The
electronic media must be clearly marked as CBI and mailed to U.S. EPA/
OAPQS/CORE CBI Office, Attention: Group Leader, Measurement Policy
Group, MD C404-02, 4930 Old Page Rd., Durham, NC 27703. The same ERT or
alternate file with the CBI omitted must be submitted to the EPA via
the EPA's CDX as described earlier in this paragraph.
    (ii) For any performance evaluations of continuous monitoring
systems measuring RATA pollutants that are not supported by the EPA's
ERT as listed on the ERT Web site at the time of the evaluation, you
must submit the results of the performance evaluation to the
Administrator at the appropriate address listed in Sec.  63.13.
    (3) You must submit all reports required by Table 9 of this subpart
electronically to the EPA via the CEDRI. (CEDRI can be accessed through
the EPA's CDX.) You must use the appropriate electronic report in CEDRI
for this subpart. Instead of using the electronic report in CEDRI for
this subpart, you may submit an alternate electronic file consistent
with the XML schema listed on the CEDRI Web site (http://www.epa.gov/ttn/chief/cedri/index.html), once the XML schema is available. If the
reporting form specific to this subpart is not available in CEDRI at
the time that the report is due, you must submit the report to the
Administrator at the appropriate address listed in Sec.  63.13. You
must begin submitting reports via CEDRI no later than 90 days after the
form becomes available in CEDRI.

0
18. Section 63.7555 is amended by:
0
a. Adding paragraph (a)(3).
0
b. Removing paragraph (d)(3).
0
c. Redesignating paragraphs (d)(4) through (11) as paragraphs (d)(3)
through (10).
0
d. Revising newly designated paragraphs (d)(3), (d)(4), and (d)(8).
0
e. Adding new paragraph (d)(11) and paragraphs (d)(12) and (d)(13).
0
f. Removing paragraphs (i) and (j).
    The additions and revisions read as follows:

Sec.  63.7555  What records must I keep?

    (a) * * *
    (3) For units in the limited use subcategory, you must keep a copy
of the federally enforceable permit that limits the annual capacity
factor to less than or equal to 10 percent and fuel use records for the
days the boiler or process heater was operating.
* * * * *
    (d) * * *
    (3) A copy of all calculations and supporting documentation of
maximum chlorine fuel input, using Equation 7 of Sec.  63.7530, that
were done to demonstrate continuous compliance with the HCl emission
limit, for sources that demonstrate compliance through performance
testing. For sources that demonstrate compliance through fuel analysis,
a copy of all calculations and supporting documentation of HCl emission
rates, using Equation 16 of Sec.  63.7530, that were done to
demonstrate compliance with the HCl emission limit. Supporting
documentation should include results of any fuel analyses and basis for
the estimates of maximum chlorine fuel input or HCl emission rates. You
can use the results from one fuel analysis for multiple boilers and
process heaters provided they are all burning the same fuel type.
However, you must calculate chlorine fuel input, or HCl emission rate,
for each boiler and process heater.
    (4) A copy of all calculations and supporting documentation of
maximum mercury fuel input, using Equation 8 of Sec.  63.7530, that
were done to demonstrate continuous compliance with the mercury
emission limit for sources that demonstrate compliance through
performance testing. For sources that demonstrate compliance through
fuel analysis, a copy of all calculations and supporting documentation
of mercury emission rates, using Equation 17 of Sec.  63.7530, that
were done to demonstrate compliance with the mercury emission limit.
Supporting documentation should include results of any fuel analyses
and basis for the estimates of maximum mercury fuel input or mercury
emission rates. You can use the results from one fuel analysis for
multiple boilers and process heaters provided they are all burning the
same fuel type. However, you must calculate mercury fuel input, or
mercury emission rates, for each boiler and process heater.
* * * * *
    (8) A copy of all calculations and supporting documentation of
maximum TSM fuel input, using Equation 9 of Sec.  63.7530, that were
done to demonstrate continuous compliance with the TSM emission limit
for sources that demonstrate compliance through performance testing.
For sources that demonstrate compliance through fuel analysis, a copy
of all calculations and supporting documentation of TSM emission rates,
using Equation 18 of Sec.  63.7530, that were done to demonstrate
compliance with the TSM emission limit. Supporting documentation should
include results of any fuel analyses and basis for the estimates of
maximum TSM fuel input or TSM emission rates. You can use the results
from one fuel analysis for multiple boilers and process heaters
provided they are all burning the same fuel type. However, you must
calculate TSM fuel input, or TSM emission rates, for each boiler and
process heater.
* * * * *
    (11) For each startup period, for units selecting paragraph (2) of
the definition of ``startup'' in Sec.  63.7575 you must maintain
records of the time that clean fuel combustion begins; the time when
you start feeding fuels that are not clean fuels; the time when useful
thermal energy is first supplied; and the time when the PM controls are
engaged.
    (12) If you choose to rely on paragraph (2) of the definition of
``startup'' in Sec.  63.7575, for each startup period, you must
maintain records of the hourly steam temperature, hourly steam
pressure, hourly steam flow, hourly flue gas temperature, and all
hourly average CMS data (e.g., CEMS, PM CPMS, COMS, ESP total secondary
electric power input, scrubber pressure drop, scrubber liquid flow
rate) collected during each startup period to confirm that the control
devices are engaged. In addition, if compliance with the PM emission
limit is demonstrated using a PM control device, you must maintain
records as specified in paragraphs (d)(12)(i) through (iii) of this
section.
    (i) For a boiler or process heater with an electrostatic
precipitator, record the number of fields in service, as well as each
field's secondary voltage and secondary current during each hour of
startup.
    (ii) For a boiler or process heater with a fabric filter, record
the number of compartments in service, as well as the differential
pressure across the baghouse during each hour of startup.
    (iii) For a boiler or process heater with a wet scrubber needed for
filterable PM control, record the scrubber's liquid flow rate and the
pressure drop during each hour of startup.
    (13) If you choose to use paragraph (2) of the definition of
``startup'' in Sec.  63.7575 and you find that you are unable to safely
engage and operate your PM control(s) within 1 hour of first firing of
non-clean fuels, you may choose to rely on paragraph (1) of

definition of ``startup'' in Sec.  63.7575 or you may submit to the
delegated permitting authority a request for a variance with the PM
controls requirement, as described below.
    (i) The request shall provide evidence of a documented
manufacturer-identified safety issue.
    (ii) The request shall provide information to document that the PM
control device is adequately designed and sized to meet the applicable
PM emission limit.
    (iii) In addition, the request shall contain documentation that:
    (A) The unit is using clean fuels to the maximum extent possible to
bring the unit and PM control device up to the temperature necessary to
alleviate or prevent the identified safety issues prior to the
combustion of primary fuel;
    (B) The unit has explicitly followed the manufacturer's procedures
to alleviate or prevent the identified safety issue; and
    (C) Identifies with specificity the details of the manufacturer's
statement of concern.
    (iv) You must comply with all other work practice requirements,
including but not limited to data collection, recordkeeping, and
reporting requirements.
* * * * *

0
19. Section 63.7570 is amended by revising paragraph (b) to read as
follows:

Sec.  63.7570  Who implements and enforces this subpart?

* * * * *
    (b) In delegating implementation and enforcement authority of this
subpart to a state, local, or tribal agency under 40 CFR part 63,
subpart E, the authorities listed in paragraphs (b)(1) through (4) of
this section are retained by the EPA Administrator and are not
transferred to the state, local, or tribal agency, however, the EPA
retains oversight of this subpart and can take enforcement actions, as
appropriate.
    (1) Approval of alternatives to the emission limits and work
practice standards in Sec.  63.7500(a) and (b) under Sec.  63.6(g),
except as specified in Sec.  63.7555(d)(13).
    (2) Approval of major change to test methods in Table 5 to this
subpart under Sec.  63.7(e)(2)(ii) and (f) and as defined in Sec.
63.90, and alternative analytical methods requested under Sec.
63.7521(b)(2).
    (3) Approval of major change to monitoring under Sec.  63.8(f) and
as defined in Sec.  63.90, and approval of alternative operating
parameters under Sec. Sec.  63.7500(a)(2) and 63.7522(g)(2).
    (4) Approval of major change to recordkeeping and reporting under
Sec.  63.10(e) and as defined in Sec.  63.90.

0
20. Section 63.7575 is amended by:
0
a. Revising the definition for ``30-day rolling average.''
0
b. Removing the definition for ``Affirmative defense.''
0
c. Adding in alphabetical order a definition for ``Clean dry biomass.''
0
d. Revising the definition for ``Energy assessment.''
0
e. Adding in alphabetical order a definition for ``Fossil fuel.''
0
f. Revising the definitions for ``Hybrid suspension grate boiler,''
``Limited-use boiler or process heater,'' ``Liquid fuel,'' ``Load
fraction,'' ``Minimum sorbent injection rate,'' ``Operating day,'' and
``Oxygen trim system.''
0
g. Adding in alphabetical order a definition for ``Rolling average''.
0
h. Revising the definitions for ``Shutdown,'' ``Startup,'' ``Steam
output,'' and ``Temporary boiler.''
0
i. Adding in alphabetical order a definition for ``Useful thermal
energy.''
    The revisions and additions read as follows:

Sec.  63.7575  What definitions apply to this subpart?

* * * * *
    30-day rolling average means the arithmetic mean of the previous
720 hours of valid CO CEMS data. The 720 hours should be consecutive,
but not necessarily continuous if operations were intermittent. For
parameters other than CO, 30-day rolling average means either the
arithmetic mean of all valid hours of data from 30 successive operating
days or the arithmetic mean of the previous 720 hours of valid
operating data. Valid data excludes hours during startup and shutdown,
data collected during periods when the monitoring system is out of
control as specified in your site-specific monitoring plan, while
conducting repairs associated with periods when the monitoring system
is out of control, or while conducting required monitoring system
quality assurance or quality control activities, and periods when this
unit is not operating.
* * * * *
    Clean dry biomass means any biomass-based solid fuel that have not
been painted, pigment-stained, or pressure treated, does not contain
contaminants at concentrations not normally associated with virgin
biomass materials and has a moisture content of less than 20 percent
and is not a solid waste.
* * * * *
    Energy assessment means the following for the emission units
covered by this subpart:
    (1) The energy assessment for facilities with affected boilers and
process heaters with a combined heat input capacity of less than 0.3
trillion Btu (TBtu) per year will be 8 on-site technical labor hours in
length maximum, but may be longer at the discretion of the owner or
operator of the affected source. The boiler system(s), process
heater(s), and any on-site energy use system(s) accounting for at least
50 percent of the affected boiler(s) energy (e.g., steam, hot water,
process heat, or electricity) production, as applicable, will be
evaluated to identify energy savings opportunities, within the limit of
performing an 8-hour on-site energy assessment.
    (2) The energy assessment for facilities with affected boilers and
process heaters with a combined heat input capacity of 0.3 to 1.0 TBtu/
year will be 24 on-site technical labor hours in length maximum, but
may be longer at the discretion of the owner or operator of the
affected source. The boiler system(s), process heater(s), and any on-
site energy use system(s) accounting for at least 33 percent of the
energy (e.g., steam, hot water, process heat, or electricity)
production, as applicable, will be evaluated to identify energy savings
opportunities, within the limit of performing a 24-hour on-site energy
assessment.
    (3) The energy assessment for facilities with affected boilers and
process heaters with a combined heat input capacity greater than 1.0
TBtu/year will be up to 24 on-site technical labor hours in length for
the first TBtu/yr plus 8 on-site technical labor hours for every
additional 1.0 TBtu/yr not to exceed 160 on-site technical hours, but
may be longer at the discretion of the owner or operator of the
affected source. The boiler system(s), process heater(s), and any on-
site energy use system(s) accounting for at least 20 percent of the
energy (e.g., steam, process heat, hot water, or electricity)
production, as applicable, will be evaluated to identify energy savings
opportunities.
    (4) The on-site energy use systems serving as the basis for the
percent of affected boiler(s) and process heater(s) energy production
in paragraphs (1), (2), and (3) of this definition may be segmented by
production area or energy use area as most logical and applicable to
the specific facility being assessed (e.g., product X manufacturing
area; product Y drying area; Building Z).
* * * * *

    Fossil fuel means natural gas, oil, coal, and any form of solid,
liquid, or gaseous fuel derived from such material.
* * * * *
    Hybrid suspension grate boiler means a boiler designed with air
distributors to spread the fuel material over the entire width and
depth of the boiler combustion zone. The biomass fuel combusted in
these units exceeds a moisture content of 40 percent on an as-fired
annual heat input basis as demonstrated by monthly fuel analysis. The
drying and much of the combustion of the fuel takes place in
suspension, and the combustion is completed on the grate or floor of
the boiler. Fluidized bed, dutch oven, and pile burner designs are not
part of the hybrid suspension grate boiler design category.
* * * * *
    Limited-use boiler or process heater means any boiler or process
heater that burns any amount of solid, liquid, or gaseous fuels and has
a federally enforceable annual capacity factor of no more than 10
percent.
    Liquid fuel includes, but is not limited to, light liquid, heavy
liquid, any form of liquid fuel derived from petroleum, used oil,
liquid biofuels, biodiesel, and vegetable oil.
    Load fraction means the actual heat input of a boiler or process
heater divided by heat input during the performance test that
established the minimum sorbent injection rate or minimum activated
carbon injection rate, expressed as a fraction (e.g., for 50 percent
load the load fraction is 0.5). For boilers and process heaters that
co-fire natural gas or refinery gas with a solid or liquid fuel, the
load fraction is determined by the actual heat input of the solid or
liquid fuel divided by heat input of the solid or liquid fuel fired
during the performance test (e.g., if the performance test was
conducted at 100 percent solid fuel firing, for 100 percent load firing
50 percent solid fuel and 50 percent natural gas the load fraction is
0.5).
* * * * *
    Minimum sorbent injection rate means:
    (1) The load fraction multiplied by the lowest hourly average
sorbent injection rate for each sorbent measured according to Table 7
to this subpart during the most recent performance test demonstrating
compliance with the applicable emission limits; or
    (2) For fluidized bed combustion not using an acid gas wet scrubber
or dry sorbent injection control technology to comply with the HCl
emission limit, the lowest average ratio of sorbent to sulfur measured
during the most recent performance test.
* * * * *
    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 boiler or process heater unit. It is not necessary for fuel to be
combusted for the entire 24-hour period. For calculating rolling
average emissions, an operating day does not include the hours of
operation during startup or shutdown.
* * * * *
    Oxygen trim system means a system of monitors that is used to
maintain excess air at the desired level in a combustion device over
its operating load range. A typical system consists of a flue gas
oxygen and/or CO monitor that automatically provides a feedback signal
to the combustion air controller or draft controller.
* * * * *
    Rolling average means the average of all data collected during the
applicable averaging period. For demonstration of compliance with a CO
CEMS-based emission limit based on CO concentration a 30-day (10-day)
rolling average is comprised of the average of all the hourly average
concentrations over the previous 720 (240) operating hours calculated
each operating day. To demonstrate compliance on a 30-day rolling
average basis for parameters other than CO, you must indicate the basis
of the 30-day rolling average period you are using for compliance, as
discussed in Sec.  63.7545(e)(2)(iii). If you indicate the 30 operating
day basis, you must calculate a new average value each operating day
and shall include the measured hourly values for the preceding 30
operating days. If you select the 720 operating hours basis, you must
average of all the hourly average concentrations over the previous 720
operating hours calculated each operating day.
    Shutdown means the period in which cessation of operation of a
boiler or process heater is initiated for any purpose. Shutdown begins
when the boiler or process heater no longer supplies useful thermal
energy (such as heat or steam) for heating, cooling, or process
purposes and/or generates electricity or when no fuel is being fed to
the boiler or process heater, whichever is earlier. Shutdown ends when
the boiler or process heater no longer supplies useful thermal energy
(such as steam or heat) for heating, cooling, or process purposes and/
or generates electricity, and no fuel is being combusted in the boiler
or process heater.
* * * * *
    Startup means:
    (1) Either the first-ever firing of fuel in a boiler or process
heater for the purpose of supplying useful thermal energy for heating
and/or producing electricity, or for any other purpose, or the firing
of fuel in a boiler after a shutdown event for any purpose. Startup
ends when any of the useful thermal energy from the boiler or process
heater is supplied for heating, and/or producing electricity, or for
any other purpose, or
    (2) The period in which operation of a boiler or process heater is
initiated for any purpose. Startup begins with either the first-ever
firing of fuel in a boiler or process heater for the purpose of
supplying useful thermal energy (such as steam or heat) for heating,
cooling or process purposes, or producing electricity, or the firing of
fuel in a boiler or process heater for any purpose after a shutdown
event. Startup ends four hours after when the boiler or process heater
supplies useful thermal energy (such as heat or steam) for heating,
cooling, or process purposes, or generates electricity, whichever is
earlier.
    Steam output means:
    (1) For a boiler that produces steam for process or heating only
(no power generation), the energy content in terms of MMBtu of the
boiler steam output,
    (2) For a boiler that cogenerates process steam and electricity
(also known as combined heat and power), the total energy output, which
is the sum of the energy content of the steam exiting the turbine and
sent to process in MMBtu and the energy of the electricity generated
converted to MMBtu at a rate of 10,000 Btu per kilowatt-hour generated
(10 MMBtu per megawatt-hour), and
    (3) For a boiler that generates only electricity, the alternate
output-based emission limits would be the appropriate emission limit
from Table 1 or 2 of this subpart in units of pounds per million Btu
heat input (lb per MWh).
    (4) For a boiler that performs multiple functions and produces
steam to be used for any combination of paragraphs (1), (2), and (3) of
this definition that includes electricity generation of paragraph (3)
of this definition, the total energy output, in terms of MMBtu of steam
output, is the sum of the energy content of steam sent directly to the
process and/or used for heating (S1), the energy content of
turbine steam sent to process plus energy in electricity

according to paragraph (2) of this definition (S2), and the
energy content of electricity generated by a electricity only turbine
as paragraph (3) of this definition (MW(3)) and would be
calculated using Equation 21 of this section. In the case of boilers
supplying steam to one or more common heaters, S1,
S2, and MW(3) for each boiler would be calculated
based on the its (steam energy) contribution (fraction of total steam
energy) to the common heater.
[GRAPHIC] [TIFF OMITTED] TR20NO15.000

Where:

SOM = Total steam output for multi-function boiler, MMBtu
S1 = Energy content of steam sent directly to the process
and/or used for heating, MMBtu
S2 = Energy content of turbine steam sent to the process
plus energy in electricity according to (2) above, MMBtu
MW(3) = Electricity generated according to paragraph (3)
of this definition, MWh
CFn = Conversion factor for the appropriate subcategory for
converting electricity generated according to paragraph (3) of this
definition to equivalent steam energy, MMBtu/MWh
CFn for emission limits for boilers in the unit designed to burn
solid fuel subcategory = 10.8
CFn PM and CO emission limits for boilers in one of the
subcategories of units designed to burn coal = 11.7
CFn PM and CO emission limits for boilers in one of the
subcategories of units designed to burn biomass = 12.1
CFn for emission limits for boilers in one of the subcategories of
units designed to burn liquid fuel = 11.2
CFn for emission limits for boilers in the unit designed to burn gas
2 (other) subcategory = 6.2

* * * * *
    Temporary boiler means any gaseous or liquid fuel boiler or process
heater that is designed to, and is capable of, being carried or moved
from one location to another by means of, for example, wheels, skids,
carrying handles, dollies, trailers, or platforms. A boiler or process
heater is not a temporary boiler or process heater if any one of the
following conditions exists:
    (1) The equipment is attached to a foundation.
    (2) The boiler or process heater or a replacement remains at a
location within the facility and performs the same or similar function
for more than 12 consecutive months, unless the regulatory agency
approves an extension. An extension may be granted by the regulating
agency upon petition by the owner or operator of a unit specifying the
basis for such a request. Any temporary boiler or process heater that
replaces a temporary boiler or process heater at a location and
performs the same or similar function will be included in calculating
the consecutive time period.
    (3) The equipment is located at a seasonal facility and operates
during the full annual operating period of the seasonal facility,
remains at the facility for at least 2 years, and operates at that
facility for at least 3 months each year.
    (4) The equipment is moved from one location to another within the
facility but continues to perform the same or similar function and
serve the same electricity, process heat, steam, and/or hot water
system in an attempt to circumvent the residence time requirements of
this definition.
* * * * *
    Useful thermal energy means energy (i.e., steam, hot water, or
process heat) that meets the minimum operating temperature, flow, and/
or pressure required by any energy use system that uses energy provided
by the affected boiler or process heater.
* * * * *

0
21. Table 1 to subpart DDDDD of part 63 is amended by:
0
a. Revising rows ``3.a'', ``4.a'', ``5.a'', ``6.a'', ``7.a'', ``9.a'',
``10.a'', ``11.a'', and ``13.a''.
0
b. Revising footnote ``c''; and
0
c. Adding footnote ``d''.
    The revisions and addition read as follows:
    As stated in Sec.  63.7500, you must comply with the following
applicable emission limits:

    Table 1 to Subpart DDDDD of Part 63--Emission Limits for New or Reconstructed Boilers and Process Heaters
                     [Units with heat input capacity of 10 million Btu per hour or greater]
----------------------------------------------------------------------------------------------------------------
                                                                           Or the emissions
                                                      The emissions must    must not exceed
                                                        not exceed the       the following        Using this
If your boiler or process heater   For the following  following emission  alternative output- specified sampling
  is in this subcategory . . .     pollutants . . .     limits, except       based limits,    volume or test run
                                                      during startup and     except during      duration . . .
                                                        shutdown . . .        startup and
                                                                            shutdown . . .
----------------------------------------------------------------------------------------------------------------

                                                  * * * * * * *
3. Pulverized coal boilers        a. Carbon monoxide  130 ppm by volume   0.11 lb per MMBtu   1 hr minimum
 designed to burn coal/solid       (CO) (or CEMS).     on a dry basis      of steam output     sampling time.
 fossil fuel.                                          corrected to 3      or 1.4 lb per
                                                       percent oxygen, 3-  MWh; 3-run
                                                       run average; or     average.
                                                       (320 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\d\ 30-day
                                                       rolling average).
4. Stokers/others designed to     a. CO (or CEMS)...  130 ppm by volume   0.12 lb per MMBtu   1 hr minimum
 burn coal/solid fossil fuel.                          on a dry basis      of steam output     sampling time.
                                                       corrected to 3      or 1.4 lb per
                                                       percent oxygen, 3-  MWh; 3-run
                                                       run average; or     average.
                                                       (340 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\d\ 30-day
                                                       rolling average).

5. Fluidized bed units designed   a. CO (or CEMS)...  130 ppm by volume   0.11 lb per MMBtu   1 hr minimum
 to burn coal/solid fossil fuel.                       on a dry basis      of steam output     sampling time.
                                                       corrected to 3      or 1.4 lb per
                                                       percent oxygen, 3-  MWh; 3-run
                                                       run average; or     average.
                                                       (230 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\d\ 30-day
                                                       rolling average).
6. Fluidized bed units with an    a. CO (or CEMS)...  140 ppm by volume   1.2E-01 lb per      1 hr minimum
 integrated heat exchanger                             on a dry basis      MMBtu of steam      sampling time.
 designed to burn coal/solid                           corrected to 3      output or 1.5 lb
 fossil fuel.                                          percent oxygen, 3-  per MWh; 3-run
                                                       run average; or     average.
                                                       (150 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\d\ 30-day
                                                       rolling average).
7. Stokers/sloped grate/others    a. CO (or CEMS)...  620 ppm by volume   5.8E-01 lb per      1 hr minimum
 designed to burn wet biomass                          on a dry basis      MMBtu of steam      sampling time.
 fuel.                                                 corrected to 3      output or 6.8 lb
                                                       percent oxygen, 3-  per MWh; 3-run
                                                       run average; or     average.
                                                       (390 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\d\ 30-day
                                                       rolling average).

                                                  * * * * * * *
9. Fluidized bed units designed   a. CO (or CEMS)...  230 ppm by volume   2.2E-01 lb per      1 hr minimum
 to burn biomass/bio-based                             on a dry basis      MMBtu of steam      sampling time.
 solids.                                               corrected to 3      output or 2.6 lb
                                                       percent oxygen, 3-  per MWh; 3-run
                                                       run average; or     average.
                                                       (310 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\d\ 30-day
                                                       rolling average).

                                                  * * * * * * *
10. Suspension burners designed   a. CO (or CEMS)...  2,400 ppm by        1.9 lb per MMBtu    1 hr minimum
 to burn biomass/bio-based                             volume on a dry     of steam output     sampling time.
 solids.                                               basis corrected     or 27 lb per MWh;
                                                       to 3 percent        3-run average.
                                                       oxygen, 3-run
                                                       average; or
                                                       (2,000 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\d\ 10-day
                                                       rolling average).

                                                  * * * * * * *
11. Dutch Ovens/Pile burners      a. CO (or CEMS)...  330 ppm by volume   3.5E-01 lb per      1 hr minimum
 designed to burn biomass/bio-                         on a dry basis      MMBtu of steam      sampling time.
 based solids.                                         corrected to 3      output or 3.6 lb
                                                       percent oxygen, 3-  per MWh; 3-run
                                                       run average; or     average.
                                                       (520 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\d\ 10-day
                                                       rolling average).

                                                  * * * * * * *
13. Hybrid suspension grate       a. CO (or CEMS)...  1,100 ppm by        1.4 lb per MMBtu    1 hr minimum
 boiler designed to burn biomass/                      volume on a dry     of steam output     sampling time.
 bio-based solids.                                     basis corrected     or 12 lb per MWh;
                                                       to 3 percent        3-run average.
                                                       oxygen, 3-run
                                                       average; or (900
                                                       ppm by volume on
                                                       a dry basis
                                                       corrected to 3
                                                       percent
                                                       oxygen,\d\ 30-day
                                                       rolling average).

                                                  * * * * * * *
----------------------------------------------------------------------------------------------------------------
 * * * * * * *
\c\ If your affected source is a new or reconstructed affected source that commenced construction or
  reconstruction after June 4, 2010, and before April 1, 2013, you may comply with the emission limits in Tables
  11, 12 or 13 to this subpart until January 31, 2016. On and after January 31, 2016, you must comply with the
  emission limits in Table 1 to this subpart.
\d\ An owner or operator may request an alternative test method under Sec.   63.7 of this chapter, in order that
  compliance with the carbon monoxide emissions limit be determined using carbon dioxide as a diluent correction
  in place of oxygen at 3%. EPA Method 19 F-factors and EPA Method 19 equations must be used to generate the
  appropriate CO2 correction percentage for the fuel type burned in the unit, and must also take into account
  that the 3% oxygen correction is to be done on a dry basis. The alternative test method request must account
  for any CO2 being added to, or removed from, the emissions gas stream as a result of limestone injection,
  scrubber media, etc.

0
22. Table 2 to subpart DDDDD of part 63 is amended by revising the rows
``3.a'', ``4.a'', ``5.a'', ``6.a'', ``7.a'', ``9.a'', ``10.a'',
``11.a'', ``13.a'', ``14.b'', and ``16.b'' and adding footnote ``c'' to
read as follows:
    As stated in Sec.  63.7500, you must comply with the following
applicable emission limits:

          Table 2 to Subpart DDDDD of Part 63--Emission Limits for Existing Boilers and Process Heaters
                     [Units with heat input capacity of 10 million Btu per hour or greater]
----------------------------------------------------------------------------------------------------------------
                                                                          The emissions must
                                                      The emissions must    not exceed the
                                                        not exceed the         following          Using this
If your boiler or process heater   For the following  following emission  alternative output- specified sampling
  is in this subcategory . . .     pollutants . . .     limits, except       based limits,    volume or test run
                                                      during startup and     except during      duration . . .
                                                        shutdown . . .        startup and
                                                                            shutdown . . .
----------------------------------------------------------------------------------------------------------------

                                                  * * * * * * *
3. Pulverized coal boilers        a. CO (or CEMS)...  130 ppm by volume   0.11 lb per MMBtu   1 hr minimum
 designed to burn coal/solid                           on a dry basis      of steam output     sampling time.
 fossil fuel.                                          corrected to 3      or 1.4 lb per
                                                       percent oxygen, 3-  MWh; 3-run
                                                       run average; or     average.
                                                       (320 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\c\ 30-day
                                                       rolling average).
4. Stokers/others designed to     a. CO (or CEMS)...  160 ppm by volume   0.14 lb per MMBtu   1 hr minimum
 burn coal/solid fossil fuel.                          on a dry basis      of steam output     sampling time.
                                                       corrected to 3      or 1.7 lb per
                                                       percent oxygen, 3-  MWh; 3-run
                                                       run average; or     average.
                                                       (340 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\c\ 30-day
                                                       rolling average).
5. Fluidized bed units designed   a. CO (or CEMS)...  130 ppm by volume   0.12 lb per MMBtu   1 hr minimum
 to burn coal/solid fossil fuel.                       on a dry basis      of steam output     sampling time.
                                                       corrected to 3      or 1.4 lb per
                                                       percent oxygen, 3-  MWh; 3-run
                                                       run average; or     average.
                                                       (230 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\c\ 30-day
                                                       rolling average).
6. Fluidized bed units with an    a. CO (or CEMS)...  140 ppm by volume   1.3E-01 lb per      1 hr minimum
 integrated heat exchanger                             on a dry basis      MMBtu of steam      sampling time.
 designed to burn coal/solid                           corrected to 3      output or 1.5 lb
 fossil fuel.                                          percent oxygen, 3-  per MWh; 3-run
                                                       run average; or     average.
                                                       (150 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\c\ 30-day
                                                       rolling average).

7. Stokers/sloped grate/others    a. CO (or CEMS)...  1,500 ppm by        1.4 lb per MMBtu    1 hr minimum
 designed to burn wet biomass                          volume on a dry     of steam output     sampling time.
 fuel.                                                 basis corrected     or 17 lb per MWh;
                                                       to 3 percent        3-run average.
                                                       oxygen, 3-run
                                                       average; or (720
                                                       ppm by volume on
                                                       a dry basis
                                                       corrected to 3
                                                       percent
                                                       oxygen,\c\ 30-day
                                                       rolling average).

                                                  * * * * * * *
9. Fluidized bed units designed   a. CO (or CEMS)...  470 ppm by volume   4.6E-01 lb per      1 hr minimum
 to burn biomass/bio-based solid.                      on a dry basis      MMBtu of steam      sampling time.
                                                       corrected to 3      output or 5.2 lb
                                                       percent oxygen, 3-  per MWh; 3-run
                                                       run average; or     average.
                                                       (310 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\c\ 30-day
                                                       rolling average).

                                                  * * * * * * *
10. Suspension burners designed   a. CO (or CEMS)...  2,400 ppm by        1.9 lb per MMBtu    1 hr minimum
 to burn biomass/bio-based solid.                      volume on a dry     of steam output     sampling time.
                                                       basis corrected     or 27 lb per MWh;
                                                       to 3 percent        3-run average.
                                                       oxygen, 3-run
                                                       average; or
                                                       (2,000 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\c\ 10-day
                                                       rolling average).

                                                  * * * * * * *
11. Dutch Ovens/Pile burners      a. CO (or CEMS)...  770 ppm by volume   8.4E-01 lb per      1 hr minimum
 designed to burn biomass/bio-                         on a dry basis      MMBtu of steam      sampling time.
 based solid.                                          corrected to 3      output or 8.4 lb
                                                       percent oxygen, 3-  per MWh; 3-run
                                                       run average; or     average.
                                                       (520 ppm by
                                                       volume on a dry
                                                       basis corrected
                                                       to 3 percent
                                                       oxygen,\c\ 10-day
                                                       rolling average).

                                                  * * * * * * *
13. Hybrid suspension grate       a. CO (or CEMS)...  3,500 ppm by        3.5 lb per MMBtu    1 hr minimum
 units designed to burn biomass/                       volume on a dry     of steam output     sampling time.
 bio-based solid.                                      basis corrected     or 39 lb per MWh;
                                                       to 3 percent        3-run average.
                                                       oxygen, 3-run
                                                       average; or (900
                                                       ppm by volume on
                                                       a dry basis
                                                       corrected to 3
                                                       percent
                                                       oxygen,\c\ 30-day
                                                       rolling average).

                                                  * * * * * * *
14. Units designed to burn        b. Mercury........  2.0E-06 \a\ lb per  2.5E-06 \a\ lb per  For M29, collect a
 liquid fuel.                                          MMBtu of heat       MMBtu of steam      minimum of 3 dscm
                                                       input.              output or 2.8E-05   per run; for M30A
                                                                           lb per MWh.         or M30B collect a
                                                                                minimum sample as
                                                                                specified in the
                                                                                method, for ASTM
                                                                                D6784,\b\ collect
                                                                                a minimum of 2
                                                                                dscm.

                                                  * * * * * * *
16. Units designed to burn light  b. Filterable PM    7.9E-03 \a\ lb per  9.6E-03 \a\ lb per  Collect a minimum
 liquid fuel.                      (or TSM).           MMBtu of heat       MMBtu of steam      of 3 dscm per
                                                       input; or (6.2E-    output or 1.1E-01   run.
                                                       05 lb per MMBtu     \a\ lb per MWh;
                                                       of heat input).     or (7.5E-05 lb
                                                                           per MMBtu of
                                                                           steam output or
                                                                           8.6E-04 lb per
                                                                           MWh).

                                                  * * * * * * *
----------------------------------------------------------------------------------------------------------------
* * * * * * *
\c\ An owner or operator may request an alternative test method under Sec.   63.7 of this chapter, in order that
  compliance with the carbon monoxide emissions limit be determined using carbon dioxide as a diluent correction
  in place of oxygen at 3%. EPA Method 19 F-factors and EPA Method 19 equations must be used to generate the
  appropriate CO2 correction percentage for the fuel type burned in the unit, and must also take into account
  that the 3% oxygen correction is to be done on a dry basis. The alternative test method request must account
  for any CO2 being added to, or removed from, the emissions gas stream as a result of limestone injection,
  scrubber media, etc.

0
23. Table 3 to subpart DDDDD of part 63 is amended by revising the
entries for ``4,'' ``5,'' and ``6'' and adding footnote ``a'' to read
as follows:
    As stated in Sec.  63.7500, you must comply with the following
applicable work practice standards:

      Table 3 to Subpart DDDDD of Part 63--Work Practice Standards
------------------------------------------------------------------------
       If your unit is . . .          You must meet the following . . .
------------------------------------------------------------------------

                              * * * * * * *
4. An existing boiler or process    Must have a one-time energy
 heater located at a major source    assessment performed by a qualified
 facility, not including limited     energy assessor. An energy
 use units.                          assessment completed on or after
                                     January 1, 2008, that meets or is
                                     amended to meet the energy
                                     assessment requirements in this
                                     table, satisfies the energy
                                     assessment requirement. A facility
                                     that operated under an energy
                                     management program developed
                                     according to the ENERGY STAR
                                     guidelines for energy management or
                                     compatible with ISO 50001 for at
                                     least one year between January 1,
                                     2008 and the compliance date
                                     specified in Sec.   63.7495 that
                                     includes the affected units also
                                     satisfies the energy assessment
                                     requirement. The energy assessment
                                     must include the following with
                                     extent of the evaluation for items
                                     a. to e. appropriate for the on-
                                     site technical hours listed in Sec.
                                       63.7575:
                                    a. A visual inspection of the boiler
                                     or process heater system.
                                    b. An evaluation of operating
                                     characteristics of the boiler or
                                     process heater systems,
                                     specifications of energy using
                                     systems, operating and maintenance
                                     procedures, and unusual operating
                                     constraints.
                                    c. An inventory of major energy use
                                     systems consuming energy from
                                     affected boilers and process
                                     heaters and which are under the
                                     control of the boiler/process
                                     heater owner/operator.
                                    d. A review of available
                                     architectural and engineering
                                     plans, facility operation and
                                     maintenance procedures and logs,
                                     and fuel usage.
                                    e. A review of the facility's energy
                                     management program and provide
                                     recommendations for improvements
                                     consistent with the definition of
                                     energy management program, if
                                     identified.
                                    f. A list of cost-effective energy
                                     conservation measures that are
                                     within the facility's control.
                                    g. A list of the energy savings
                                     potential of the energy
                                     conservation measures identified.
                                    h. A comprehensive report detailing
                                     the ways to improve efficiency, the
                                     cost of specific improvements,
                                     benefits, and the time frame for
                                     recouping those investments.

5. An existing or new boiler or     a. You must operate all CMS during
 process heater subject to           startup.
 emission limits in Table 1 or 2    b. For startup of a boiler or
 or 11 through 13 to this subpart    process heater, you must use one or
 during startup.                     a combination of the following
                                     clean fuels: Natural gas, synthetic
                                     natural gas, propane, other Gas 1
                                     fuels, distillate oil, syngas,
                                     ultra-low sulfur diesel, fuel oil-
                                     soaked rags, kerosene, hydrogen,
                                     paper, cardboard, refinery gas,
                                     liquefied petroleum gas, clean dry
                                     biomass, and any fuels meeting the
                                     appropriate HCl, mercury and TSM
                                     emission standards by fuel
                                     analysis.
                                    c. You have the option of complying
                                     using either of the following work
                                     practice standards.
                                    (1) If you choose to comply using
                                     definition (1) of ``startup'' in
                                     Sec.   63.7575, once you start
                                     firing fuels that are not clean
                                     fuels, you must vent emissions to
                                     the main stack(s) and engage all of
                                     the applicable control devices
                                     except limestone injection in
                                     fluidized bed combustion (FBC)
                                     boilers, dry scrubber, fabric
                                     filter, and selective catalytic
                                     reduction (SCR). You must start
                                     your limestone injection in FBC
                                     boilers, dry scrubber, fabric
                                     filter, and SCR systems as
                                     expeditiously as possible. Startup
                                     ends when steam or heat is supplied
                                     for any purpose, OR
                                    (2) If you choose to comply using
                                     definition (2) of ``startup'' in
                                     Sec.   63.7575, once you start to
                                     feed fuels that are not clean
                                     fuels, you must vent emissions to
                                     the main stack(s) and engage all of
                                     the applicable control devices so
                                     as to comply with the emission
                                     limits within 4 hours of start of
                                     supplying useful thermal energy.
                                     You must engage and operate PM
                                     control within one hour of first
                                     feeding fuels that are not clean
                                     fuels\a\. You must start all
                                     applicable control devices as
                                     expeditiously as possible, but, in
                                     any case, when necessary to comply
                                     with other standards applicable to
                                     the source by a permit limit or a
                                     rule other than this subpart that
                                     require operation of the control
                                     devices. You must develop and
                                     implement a written startup and
                                     shutdown plan, as specified in Sec.
                                       63.7505(e).
                                    d. You must comply with all
                                     applicable emission limits at all
                                     times except during startup and
                                     shutdown periods at which time you
                                     must meet this work practice. You
                                     must collect monitoring data during
                                     periods of startup, as specified in
                                     Sec.   63.7535(b). You must keep
                                     records during periods of startup.
                                     You must provide reports concerning
                                     activities and periods of startup,
                                     as specified in Sec.   63.7555.
6. An existing or new boiler or     You must operate all CMS during
 process heater subject to           shutdown.
 emission limits in Tables 1 or 2   While firing fuels that are not
 or 11 through 13 to this subpart    clean fuels during shutdown, you
 during shutdown.                    must vent emissions to the main
                                     stack(s) and operate all applicable
                                     control devices, except limestone
                                     injection in FBC boilers, dry
                                     scrubber, fabric filter, and SCR
                                     but, in any case, when necessary to
                                     comply with other standards
                                     applicable to the source that
                                     require operation of the control
                                     device.
                                    If, in addition to the fuel used