date of the waste-to-fuel switch. If you have not conducted your
compliance demonstration for this subpart within the previous 12
months, you must complete all compliance demonstrations for this
subpart before you commence or recommence combustion of solid waste.

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

    (a) You must conduct all applicable performance tests according to
Sec.  63.7520 on an annual basis, except as specified in paragraphs (b)
through (e) of this section. Annual performance tests must be completed
no more than 13 months after the previous performance test, except as
specified in paragraphs (b) through (e) of this section.
    (b) You can conduct performance tests less often for a given
pollutant if your performance tests for the pollutant for at least 2
consecutive years show that your emissions are at or below 75 percent
of the emission limit (or, in limited instances as specified in Tables
1 and 2 to this subpart, at or below the emission limit) and if there
are no changes in the operation of the affected source or air pollution
control equipment that could increase emissions. In this case, you do
not have to conduct a performance test for that pollutant for the next
2 years. You must conduct a performance test during the third year and
no more than 37 months after the previous performance test. If you
elect to demonstrate compliance using emission averaging under Sec.
63.7522, you must continue to conduct performance tests annually.
    (c) If your boiler or process heater continues to meet the emission
limit for the pollutant, you may choose to conduct performance tests
for the pollutant every third year if your emissions are at or below 75
percent of the emission limit (or, in limited instances as specified in
Tables 1 and 2 to this subpart, at or below the emission limit) and if
there are no changes in the operation of the affected source or air
pollution control equipment that could increase emissions, but each
such performance test must be conducted no more than 37 months after
the previous performance test. If you elect to demonstrate compliance
using emission averaging under Sec.  63.7522, you must continue to
conduct performance tests annually. The requirement to test at maximum
chloride input level is waived unless the stack test is conducted for
hydrogen chloride. The requirement to test at maximum mercury input
level is waived unless the stack test is conducted for mercury. The
requirement to test at maximum total selected metals input level is
waived unless the stack test is conducted for total selected metals.
    (d) If a performance test shows emissions exceeded the emission
limit or 75 percent of the emission limit (as specified in Tables 1 and
2) for a pollutant, you must conduct annual performance tests for that
pollutant until all performance tests over a consecutive 2-year period
meet the required level (either 75 percent of the emission or the
emission limit, as specified in Tables 1 and 2).
    (e) 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, the first
annual, biennial, or 5-year tune-up must be no later than 13 months, 25
months, or 61 months, respectively, after the initial startup of the
new or reconstructed affected source.
    (f) If you demonstrate compliance with the mercury, hydrogen
chloride, or total selected metals 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 Table 1 or
2 to this subpart. 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 12 consecutive monthly
fuel analyses demonstrate compliance, you may request decreased fuel
analysis frequency by applying to the EPA Administrator for approval of
alternative monitoring under Sec.  63.8(f).
    (g) You must report the results of performance tests and the
associated initial fuel analyses within 90 days after the completion of
the performance tests. This report must also verify that the operating
limits for your affected source have not changed or provide
documentation of revised operating limits established according to
Sec.  63.7530 and Table 7 to this subpart, as applicable. The reports
for all subsequent performance tests must include all applicable
information required in Sec.  63.7550.

Sec.  63.7520  What stack tests and procedures must I use?

    (a) You must conduct all performance tests according to Sec.
63.7(c), (d), (f), and (h). You must also develop a site-specific stack
test plan according to the requirements in Sec.  63.7(c). You shall
conduct all performance tests under such conditions as the
Administrator specifies to you based on representative performance of
the affected source for the period being tested. Upon request, you
shall make available to the Administrator such records as may be
necessary to determine the conditions of the performance tests.

    (b) You must conduct each performance test according to the
requirements in Table 5 to this subpart.
    (c) You must conduct each performance test under the specific
conditions listed in Tables 5 and 7 to this subpart. You must conduct
performance tests at representative operating load conditions while
burning the type of fuel or mixture of fuels that has the highest
content of chlorine and mercury, and total selected metals if you are
opting to comply with the total selected metals alternative standard,
and you must demonstrate initial compliance and establish your
operating limits based on these performance tests. These requirements
could result in the need to conduct more than one performance test.
Following each performance test and until the next performance test,
you must comply with the operating limit for operating load conditions
specified in Table 4 to this subpart.
    (d) You must conduct three separate test runs for each performance
test required in this section, as specified in Sec.  63.7(e)(3). Each
test run must comply with the minimum applicable sampling times or
volumes specified in Tables 1 and 2 to this subpart.
    (e) To determine compliance with the emission limits, you must use
the F-Factor methodology and equations in sections 12.2 and 12.3 of EPA
Method 19 at 40 CFR part 60, appendix A-7 of this chapter to convert
the measured particulate matter concentrations, the measured hydrogen
chloride concentrations, the measured mercury concentrations, and the
measured total selected metals concentrations that result from the
initial performance test to pounds per million Btu heat input emission
rates using F-factors.

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, you must also conduct fuel analyses for total selected
metals if you are opting to comply with the total selected metals
alternative standard. For gas 2 (other) fuels, you must conduct fuel
analysis 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
total selected metals alternative standard or the hydrogen chloride
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, hydrogen chloride, or total selected
metals in Tables 1 and 2 to this subpart. Gaseous and liquid fuels are
exempt from the sampling requirements in paragraphs (c) and (d) of this
section and Table 6 of this subpart.
    (b) You must develop and submit a site-specific fuel monitoring
plan to the EPA Administrator for review and approval according to the
following procedures and requirements in paragraphs (b)(1) and (2) of
this section, if you are required to conduct fuel analyses as specified
in Sec.  63.7510.
    (1) You must submit the fuel analysis plan no later than 60 days
before the date that you intend to conduct the initial compliance
demonstration described in Sec.  63.7510.
    (2) You must include the information contained in paragraphs
(b)(2)(i) through (vi) of this section in your fuel analysis plan.
    (i) The identification of all fuel types anticipated to be burned
in each boiler or process heater.
    (ii) For each anticipated fuel type, the notification of whether
you or a fuel supplier will be conducting the fuel analysis.
    (iii) For each anticipated fuel type, a detailed description of the
sample location and specific procedures to be used for collecting and
preparing the composite samples if your procedures are different from
paragraph (c) or (d) of this section. Samples should be collected at a
location that most accurately represents the fuel type, where possible,
at a point prior to mixing with other dissimilar fuel types.
    (iv) For each anticipated fuel type, the analytical methods from
Table 6, with the expected minimum detection levels, to be used for the
measurement of chlorine or mercury.
    (v) If you request to use an alternative analytical method other
than those required by Table 6 to this subpart, you must also include a
detailed description of the methods and procedures that you are
proposing to use. Methods in Table 6 shall be used until the requested
alternative is approved.
    (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.
    (c) At a minimum, you must obtain three composite fuel samples for
each fuel type according to the procedures in paragraph (c)(1) or (2)
of this section, or use an automated sampling mechanism that provides
representative composite fuel samples for each fuel type that includes
both coarse and fine material.
    (1) If sampling from a belt (or screw) feeder, collect fuel samples
according to paragraphs (c)(1)(i) and (ii) of this section.
    (i) Stop the belt and withdraw a 6-inch wide sample from the full
cross-section of the stopped belt to obtain a minimum two pounds of
sample. You must collect all the material (fines and coarse) in the
full cross-section. You must transfer the sample to a clean plastic
bag.
    (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. For
monthly sampling, each composite sample shall be collected at
approximately equal 10-day intervals during the month.
    (2) If sampling from a fuel pile or truck, you must collect fuel
samples according to paragraphs (c)(2)(i) through (iii) of this
section.
    (i) For each composite sample, you must select a minimum of five
sampling locations uniformly spaced over the surface of the pile.
    (ii) At each sampling site, you must dig into the pile to a uniform
depth of approximately 18 inches. You must insert a clean shovel into
the hole and withdraw a sample, making sure that large pieces do not
fall off during sampling; use the same shovel to collect all samples.
    (iii) You must transfer all samples to a clean plastic bag for
further processing.
    (d) You must prepare each composite sample according to the
procedures in paragraphs (d)(1) through (7) of this section.
    (1) You must thoroughly mix and pour the entire composite sample
over a clean plastic sheet.
    (2) You must break large sample pieces (e.g., larger than 3 inches)
into smaller sizes.
    (3) You must make a pie shape with the entire composite sample and
subdivide it into four equal parts.
    (4) You must separate one of the quarter samples as the first
subset.

    (5) If this subset is too large for grinding, you must repeat the
procedure in paragraph (d)(3) of this section with the quarter sample
and obtain a one-quarter subset from this sample.
    (6) You must grind the sample in a mill.
    (7) You must use the procedure in paragraph (d)(3) of this section
to obtain a one-quarter subsample for analysis. If the quarter sample
is too large, subdivide it further using the same procedure.
    (e) You must determine the concentration of pollutants in the fuel
(mercury and/or chlorine and/or total selected metals) in units of
pounds per million Btu of each composite sample for each fuel type
according to the procedures in Table 6 to this subpart, for use in
Equations 7, 8, and 9 of this subpart.
    (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 (3) of this section.
    (1) You are not required to conduct the fuel specification analyses
in paragraphs (g) through (i) of this section for natural gas or
refinery gas.
    (2) You are not required to conduct the fuel specification analyses
in paragraphs (g) through (i) of this section for gaseous fuels that
are subject to another subpart of this part.
    (3) You are not required to conduct the fuel specification analyses
in paragraphs (g) through (i) of this section on gaseous fuels for
units that are complying with the limits for units designed to burn gas
2 (other) fuels.
    (g) You must develop and submit a site-specific fuel analysis plan
for other gas 1 fuels to the EPA Administrator for review and approval
according to the following procedures and requirements in paragraphs
(g)(1) and (2) of this section.
    (1) You must submit the fuel analysis plan no later than 60 days
before the date that you intend to conduct the initial compliance
demonstration described in Sec.  63.7510.
    (2) You must include the information contained in paragraphs
(g)(2)(i) through (vi) of this section in your fuel analysis plan.
    (i) The identification of all gaseous fuel types other than those
exempted from fuel specification analysis under (f)(1) through (3) of
this section anticipated to be burned in each boiler or process heater.
    (ii) For each anticipated fuel type, the notification of whether
you or a fuel supplier will be conducting the fuel specification
analysis.
    (iii) For each anticipated fuel type, a detailed description of the
sample location and specific procedures to be used for collecting and
preparing the samples if your procedures are different from the
sampling methods contained in Table 6 to this subpart. Samples should
be collected at a location that most accurately represents the fuel
type, where possible, at a point prior to mixing with other dissimilar
fuel types. If multiple boilers or process heaters are fueled by a
common fuel stream it is permissible to conduct a single gas
specification at the common point of gas distribution.
    (iv) For each anticipated fuel type, the analytical methods from
Table 6 to this subpart, with the expected minimum detection levels, to
be used for the measurement of mercury.
    (v) If you request to use an alternative analytical method other
than those required by Table 6 to this subpart, you must also include a
detailed description of the methods and procedures that you are
proposing to use. Methods in Table 6 to this subpart shall be used
until the requested alternative is approved.
    (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.
    (h) You must obtain a single fuel sample for each fuel type
according to the sampling procedures listed in Table 6 for fuel
specification of gaseous fuels.
    (i) You must determine the concentration in the fuel of mercury, in
units of microgram per cubic meter, dry basis, of each sample for each
gas 1 fuel type according to the procedures in Table 6 to this subpart.

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

    (a) As an alternative to meeting the requirements of Sec.  63.7500
for particulate matter, hydrogen chloride, or mercury on a boiler or
process heater-specific basis, if you have more than one existing
boiler or process heater in any subcategory located at your facility,
you may demonstrate compliance by emissions averaging, if your averaged
emissions are not more than 90 percent of the applicable emission
limit, according to the procedures in this section. You may not include
new boilers or process heaters in an emissions average.
    (b) For a group of two or more existing boilers or process heaters
in the same subcategory that each vent to a separate stack, you may
average particulate matter, hydrogen chloride, or mercury emissions
among existing units to demonstrate compliance with the limits in Table
2 to this subpart as specified in paragraph (b)(1) through (3) of this
section, if you satisfy the requirements in paragraphs (c) through (g)
of this section.
    (1) You may not include in an average units using a CEMS or PM CPMS
for demonstrating compliance, even if the use of a CEMS or PM CPMS is
optional.
    (2) For Hg and HCl, averaging is allowed as follows:
    (i) You may average among units in any of the solid fuel
subcategories.
    (ii) You may average among units in any of the liquid fuel
subcategories.
    (iii) You may average among units in a subcategory of units
designed to burn gas 2 (other) fuels.
    (iv) You may not average across the liquid, solid fuel, and gas 2
(other) subcategories.
    (3) For particulate matter, averaging is only allowed between units
within each of the following combustor level subcategories and you may
not average across subcategories:
    (i) Pulverized coal/solid fossil fuel units.
    (ii) Stokers designed to burn coal/solid fossil fuel.
    (iii) Fluidized bed units designed to burn coal/solid fossil fuel.
    (iv) Stokers/sloped grate/other units designed to burn kiln dried
biomass/bio-based solids.
    (v) Stokers/sloped grate/other units designed to burn wet biomass/
bio-based solids.
    (vi) Fluidized bed units designed to burn biomass/bio-based solid.
    (vii) Suspension burners designed to burn biomass/bio-based solid.
    (viii) Dutch ovens/pile burners designed to burn biomass/bio-based
solid.
    (ix) Fuel Cells designed to burn biomass/bio-based solid.
    (x) Hybrid suspension/grate burners designed to burn wet biomass/
bio-based solid.
    (xi) Units designed to burn heavy liquid fuel.
    (xii) Units designed to burn light liquid fuel.
    (xiii) Units designed to burn liquid fuel in non-continental states
or territories.
    (xiv) Units designed to burn gas 2 (other) gases.
    (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 [DATE 60 DAYS AFTER PUBLICATION OF THE
FINAL RULE IN THE Federal Register] 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 [DATE 60
DAYS AFTER PUBLICATION OF THE FINAL RULE IN THE Federal Register].
    (d) The averaged emissions rate from the existing boilers and
process heaters participating in the emissions averaging option must be
in compliance with the limits in Table 2 to this subpart at all times
following the compliance date specified in Sec.  63.7495.
    (e) You must demonstrate initial compliance according to paragraph
(e)(1) or (2) of this section using the maximum rated heat input
capacity or maximum steam generation capacity of each unit and the
results of the initial performance tests or fuel analysis.
    (1) You must use Equation 1a or 1b of this section to demonstrate
that the particulate matter, hydrogen chloride, or mercury emissions
from all existing units participating in the emissions averaging option
for that pollutant do not exceed the emission limits in Table 2 to this
subpart. Use Equation 1a if you are complying with the emission limits
on a heat input basis and use Equation 1b if you are complying with the
emission limits on a steam generation (output) basis.
[GRAPHIC] [TIFF OMITTED] TP23DE11.029

Where:

AveWeightedEmissions = Average weighted emissions for particulate
matter, hydrogen chloride, or mercury, in units of pounds per
million Btu of heat input.

Er = Emission rate (as determined during the initial compliance
demonstration) of particulate matter, hydrogen chloride, or mercury
from unit, i, in units of pounds per million Btu of heat input.
Determine the emission rate for particulate matter, hydrogen
chloride, or mercury by performance testing according to Table 5 to
this subpart, or by fuel analysis for hydrogen chloride or mercury
using the applicable equation in Sec.  63.7530(c).
Hm = Maximum rated heat input capacity of unit, i, in units of
million Btu per hour.
n = Number of units participating in the emissions averaging option.
1.1 = Required discount factor.

[GRAPHIC] [TIFF OMITTED] TP23DE11.030

Where:

AveWeightedEmissions = Average weighted emissions for particulate
matter, hydrogen chloride, or mercury, in units of pounds per
million Btu of steam output.

Er = Emission rate (as determined during the initial compliance
demonstration) of particulate matter, hydrogen chloride, or mercury
from unit, i, in units of pounds per million Btu of steam output.
Determine the emission rate for particulate matter, hydrogen
chloride, or mercury by performance testing according to Table 5 to
this subpart, or by fuel analysis for hydrogen chloride or mercury
using the applicable equation in Sec.  63.7530(c). If you are taking
credit for energy conservation measures from a unit according to
Sec.  63.7533, use the adjusted emission level for that unit,
Eadj, determined according to Sec.  63.7533 for that
unit.
So = Maximum steam output capacity of unit, i, in units of million
Btu per hour, as defined in Sec.  63.7575.
n = Number of units participating in the emissions averaging option.
1.1 = Required discount factor.

    (2) If you are not capable of determining the maximum rated heat
input capacity of one or more boilers that generate steam, you may use
Equation 2 of this section as an alternative to using Equation 1a of
this section to demonstrate that the particulate matter, hydrogen
chloride, or mercury emissions from all existing units participating in
the emissions averaging option do not exceed the emission limits for
that pollutant in Table 2 to this subpart that are in pounds per
million Btu of heat input.

[GRAPHIC] [TIFF OMITTED] TP23DE11.031

Where:

AveWeightedEmissions = Average weighted emission level for PM,
hydrogen chloride, or mercury, in units of pounds per million Btu of
heat input.

Er = Emission rate (as determined during the most recent compliance
demonstration) of particulate matter, hydrogen chloride, or mercury
from unit, i, in units of pounds per million Btu of heat input.
Determine the emission rate for particulate matter, hydrogen
chloride, or mercury by performance testing according to Table 5 to
this subpart, or by fuel analysis for hydrogen chloride or mercury
using the applicable equation in Sec.  63.7530(c).
Sm = Maximum steam generation capacity by unit, i, in units of
pounds per hour.
Cfi = Conversion factor, calculated from the most recent compliance
test, in units of million Btu of heat input per pounds of steam
generated for unit, i.
1.1 = Required discount factor.

    (f) After the initial compliance demonstration described in
paragraph (e) of this section, you must demonstrate compliance on a
monthly basis determined at the end of every month (12 times per year)
according to paragraphs (f)(1) through (3) of this section. The first
monthly period begins on the compliance date specified in Sec.
63.7495.
    (1) For each calendar month, you must use Equation 3a or 3b 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.

[GRAPHIC] [TIFF OMITTED] TP23DE11.032

Where:

AveWeightedEmissions = Average weighted emission level for
particulate matter, hydrogen chloride, or mercury, in units of
pounds per million Btu of heat input, for that calendar month.

Er = Emission rate (as determined during the most recent compliance
demonstration) of particulate matter, hydrogen chloride, or mercury
from unit, i, in units of pounds per million Btu of heat input.
Determine the emission rate for particulate matter, hydrogen
chloride, or mercury by performance testing according to Table 5 to
this subpart, or by fuel analysis for hydrogen chloride or mercury
using the applicable equation in Sec.  63.7530(c).
Hb = The heat input for that calendar month to unit, i, in units of
million Btu.
n = Number of units participating in the emissions averaging option.
1.1 = Required discount factor.

[GRAPHIC] [TIFF OMITTED] TP23DE11.033

Where:

AveWeightedEmissions = Average weighted emission level for
particulate matter, hydrogen chloride, or mercury, in units of
pounds per million Btu of steam output, for that calendar month.
Er = Emission rate (as determined during the most recent compliance
demonstration) of particulate matter, hydrogen chloride, or mercury
from unit, i, in units of pounds per million Btu of steam output.
Determine the emission rate for particulate matter, hydrogen
chloride, or mercury by performance testing according to Table 5 to
this subpart, or by fuel analysis for hydrogen chloride or mercury
using the applicable equation in Sec.  63.7530(c). If you are taking
credit for energy conservation measures from a unit according to
Sec.  63.7533, use the adjusted emission level for that unit,
Eadj, determined according to Sec.  63.7533 for that
unit.
So = The steam output for that calendar month from unit, i, in units
of million Btu, as defined in Sec.  63.7575.
n = Number of units participating in the emissions averaging option.
1.1 = Required discount factor.

    (2) If you are not capable of monitoring heat input, you may use
Equation 4 of this section as an alternative to using Equation 3a of
this section to calculate the average weighted emission rate using the
actual steam generation from the boilers participating in the emissions
averaging option.
[GRAPHIC] [TIFF OMITTED] TP23DE11.034

Where:

AveWeightedEmissions = average weighted emission level for PM,
hydrogen chloride, or mercury, in units of pounds per million Btu of
heat input for that calendar month.

Er = Emission rate (as determined during the most recent compliance
demonstration of particulate matter, hydrogen chloride, or mercury
from unit, i, in units of pounds per million Btu of heat input.
Determine the emission rate for particulate matter, hydrogen
chloride, or mercury by performance testing according to Table 5 to
this subpart, or by fuel analysis for hydrogen chloride or mercury
using the applicable equation in Sec.  63.7530(c).
Sa = Actual steam generation for that calendar month by boiler, i,
in units of pounds.
Cfi = Conversion factor, as calculated during the most recent
compliance test, in units of million Btu of heat input per pounds of
steam generated for boiler, i.
1.1 = Required discount factor.

    (3) Until 12 monthly weighted average emission rates have been
accumulated, calculate and report only the average weighted emission
rate determined under paragraph (f)(1) or (2) of this section for each
calendar month. After 12 monthly weighted average emission rates have
been accumulated, for each subsequent calendar month, use Equation 5 of
this section to calculate the 12-month rolling average of the monthly
weighted average emission rates for the current calendar month and the
previous 11 calendar months.
[GRAPHIC] [TIFF OMITTED] TP23DE11.035

Where:

Eavg = 12-month rolling average emission rate, (pounds per million
Btu heat input)
ERi = Monthly weighted average, for calendar month ``i'' (pounds per
million Btu heat input), as calculated by paragraph (f)(1) or (2) of
this section.

    (g) You must develop, and submit to the applicable delegated
authority for review and approval, an implementation plan for emission
averaging according to the following procedures and requirements in
paragraphs (g)(1) through (4) of this section.
    (1) 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.
    (2) You must include the information contained in paragraphs
(g)(2)(i) through (vii) of this section in your implementation plan for
all emission sources included in an emissions average:
    (i) The identification of all existing boilers and process heaters
in the averaging group, including for each either the applicable HAP
emission level or the control technology installed as of [DATE 60 DAYS
AFTER PUBLICATION OF THE FINAL RULE IN THE Federal Register] and the
date on which you are requesting emission averaging to commence;
    (ii) The process parameter (heat input or steam generated) that
will be monitored for each averaging group;

    (iii) The specific control technology or pollution prevention
measure to be used for each emission boiler or process heater in the
averaging group and the date of its installation or application. If the
pollution prevention measure reduces or eliminates emissions from
multiple boilers or process heaters, the owner or operator must
identify each boiler or process heater;
    (iv) The test plan for the measurement of particulate matter,
hydrogen chloride, or mercury emissions in accordance with the
requirements in Sec.  63.7520;
    (v) The operating parameters to be monitored for each control
system or device consistent with Sec.  63.7500 and Table 4, and a
description of how the operating limits will be determined;
    (vi) If you request to monitor an alternative operating parameter
pursuant to Sec.  63.7525, you must also include:
    (A) A description of the parameter(s) to be monitored and an
explanation of the criteria used to select the parameter(s); and
    (B) A description of the methods and procedures that will be used
to demonstrate that the parameter indicates proper operation of the
control device; the frequency and content of monitoring, reporting, and
recordkeeping requirements; and a demonstration, to the satisfaction of
the applicable delegated authority, that the proposed monitoring
frequency is sufficient to represent control device operating
conditions; and
    (vii) A demonstration that compliance with each of the applicable
emission limit(s) will be achieved under representative operating load
conditions. Following each compliance demonstration and until the next
compliance demonstration, you must comply with the operating limit for
operating load conditions specified in Table 4 to this subpart.
    (3) The delegated authority shall review and approve or disapprove
the plan according to the following criteria:
    (i) Whether the content of the plan includes all of the information
specified in paragraph (g)(2) of this section; and
    (ii) Whether the plan presents sufficient information to determine
that compliance will be achieved and maintained.
    (4) The applicable delegated authority shall not approve an
emission averaging implementation plan containing any of the following
provisions:
    (i) Any averaging between emissions of differing pollutants or
between differing sources; or
    (ii) The inclusion of any emission source other than an existing
unit in the same subcategory.
    (h) For a group of two or more existing affected units, each of
which vents through a single common stack, you may average particulate
matter, hydrogen chloride, or mercury emissions to demonstrate
compliance with the limits for that pollutant in Table 2 to this
subpart if you satisfy the requirements in paragraph (i) or (j) of this
section.
    (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) For all other groups of units subject to the common stack
requirements of paragraph (h) of this section, including situations
where the exhaust of affected units are each individually controlled
and then sent to a common stack, the owner or operator may elect to:
    (1) Conduct performance tests according to procedures specified in
Sec.  63.7520 in the common stack if affected units from other
subcategories vent to the common stack. The emission limits that the
group must comply with are determined by the use of Equation 6 of this
section.
[GRAPHIC] [TIFF OMITTED] TP23DE11.036

Where:

En = HAP emission limit, pounds per million British thermal units
(lb/MMBtu), parts per million (ppm), or nanograms per dry standard
cubic meter (ng/dscm).
ELi = Appropriate emission limit from Table 2 to this subpart for
unit i, in units of lb/MMBtu, ppm or ng/dscm.
Hi = Heat input from unit i, MMBtu.

    (2) Conduct performance tests according to procedures specified in
Sec.  63.7520 in the common stack. If affected units and non-affected
units vent to the common stack, the non-affected units must be shut
down or vented to a different stack during the performance test unless
the facility determines to demonstrate compliance with the non-affected
units venting to the stack; and
    (3) Meet the applicable operating limit specified in Sec.  63.7540
and Table 8 to this subpart for each emissions control system (except
that, if each unit venting to the common stack has an applicable
opacity operating limit, then a single continuous opacity monitoring
system may be located in the common stack instead of in each duct to
the common stack).
    (k) The common stack of a group of two or more existing boilers or
process heaters in the same subcategory subject to paragraph (h) of
this section may be treated as a separate stack for purposes of
paragraph (b) of this section and included in an emissions averaging
group subject to paragraph (b) of this section.

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

    (a) If your boiler or process heater is subject to a carbon
monoxide emission limit in Table 1 or 2 to this subpart, you must
install, operate, and maintain an oxygen analyzer system as defined in
Sec.  63.7575, or a carbon monoxide continuous emission monitoring
system (CO CEMS) according to the procedures in paragraphs (a)(1)
through (10) of this section.
    (1) The oxygen analyzer system or the CO CEMS must be installed by
the compliance date specified in Sec.  63.7495. If a CO CEMS is used,
the carbon monoxide level shall be monitored at the outlet of the
boiler or process heater.
    (2) You must operate the oxygen trim system with the oxygen level
set at the minimum percent oxygen by volume that is established as the
operating limit for oxygen according to Table 4 to this subpart.
    (3) Each CO CEMS must be installed, operated, and maintained
according to the applicable procedures under Performance Specification
4, 4A, or 4B at 40 CFR part 60, appendix B, and according to the site-
specific monitoring plan developed according to Sec.  63.7505(d).
    (4) For a new unit, the initial performance evaluation shall be
completed no later than [DATE 240 DAYS AFTER PUBLICATION OF THE FINAL
RULE IN THE Federal Register] or 180 days after the date of initial
startup, whichever is later. For an

existing unit, the initial performance evaluation shall be completed no
later than [DATE 3 YEARS AND 180 DAYS AFTER PUBLICATION OF THE FINAL
RULE IN THE Federal Register].
    (5) You must conduct a performance evaluation of each CO CEMS
according to the requirements in Sec.  63.8(e) and according to
Performance Specification 4, 4A, or 4B at 40 CFR part 60, appendix B.
During each relative accuracy test run of the CO CEMS, emission data
for carbon monoxide must be collected concurrently (or within a 30- to
60-minute period) by both the CO CEMS and by Method 10, 10A, or 10B at
40 CFR part 60, appendix A-4. The relative accuracy testing must be at
representative operating conditions.
    (6) For each CO CEMS, you must follow the quality assurance
procedures (e.g., quarterly accuracy determinations and daily
calibration drift tests) of Procedure 1 of appendix F to part 60. The
span value of the CO CEMS must be two times the applicable CO emission
limit, expressed as a concentration.
    (7) Each CO CEMS must complete a minimum of one cycle of operation
(sampling, analyzing, and data recording) for each successive 15-minute
period. Collect at least four CO 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.
    (8) The CO CEMS data must be reduced as specified in Sec.
63.8(g)(2).
    (9) You must calculate one-hour arithmetic averages, corrected to 3
percent oxygen from each hour of CO CEMS data in parts per million
carbon monoxide concentration. For all subcategories except for units
designed to burn liquid fuels in non-continental states and
territories, the one-hour arithmetic averages required shall be used to
calculate the boiler operating day daily arithmetic average emissions.
Calculate a 10-day rolling average from the daily averages. For units
designed to burn liquid fuels in non-continental states and
territories, the one-hour arithmetic averages required shall be used to
calculate the 3-hour arithmetic 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 carbon monoxide concentration from the hourly
values.
    (10) For purposes of collecting CO data, you must operate the CO
CEMS as specified in Sec.  63.7535(b). You must use all the data
collected during all periods in calculating data averages and assessing
compliance, except that you must exclude certain data as specified in
Sec.  63.7535(c). Periods when CO data are unavailable may constitute
monitoring deviations as specified in Sec.  63.7535(d).
    (b) If your boiler or process heater has an average annual heat
input rate greater than 250 MMBtu per hour from solid fossil fuel and/
or residual oil, and you demonstrate compliance with the PM limit
instead of the alternative total selected metals limit, you must
install, certify, 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. For other
boilers or process heaters, you may elect to use a PM CPMS operated in
accordance with this section in lieu of using other CMS for monitoring
PM compliance (e.g., bag leak detectors, ESP secondary power, PM
scrubber pressure).
    (1) Install, certify, 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 (b)(1)(i) through (iii) of this section.
    (i) The operating principle of the PM CPMS must be based on in-
stack or extractive light scatter, light scintillation, beta
attenuation, or mass accumulation detection of PM in the exhaust gas or
representative exhaust gas sample. The reportable measurement output
from the PM CPMS may be expressed as milliamps, stack concentration, or
other raw data signal.
    (ii) The PM CPMS must have a cycle time (i.e., period required to
complete sampling, measurement, and reporting for each measurement) no
longer than 60 minutes.
    (iii) The PM CPMS must be capable of detecting and responding to
particulate matter concentrations of no greater than 0.5 milligram per
actual cubic meter.
    (2) For a new unit, complete the initial performance evaluation no
later than [DATE 240 DAYS AFTER PUBLICATION OF THE FINAL RULE IN THE
Federal Register] or 180 days after the date of initial startup,
whichever is later. For an existing unit, complete the initial
performance evaluation no later than [DATE 3 YEARS AND 180 DAYS AFTER
PUBLICATION OF THE FINAL RULE IN THE Federal Register].
    (3) Collect PM CPMS hourly average output data for all boiler
operating hours except as indicated in Sec.  63.7535(a) through (d).
Express the PM CPMS output as millamps, PM concentration, or other raw
data signal value.
    (4) Calculate the arithmetic 30-day rolling average of all of the
hourly average PM CPMS output data collected during all boiler
operating hours (e.g., milliamps, PM concentration, raw data signal).
    (c) If you have an applicable opacity operating limit in this rule,
and are not otherwise required or elect to install and operate a PM
CPMS or a bag leak detection system, you must install, operate, certify
and maintain each COMS according to the procedures in paragraphs (c)(1)
through (7) of this section by the compliance date specified in Sec.
63.7495.
    (1) Each COMS must be installed, operated, and maintained according
to Performance Specification 1 at appendix B to part 60 of this
chapter.
    (2) You must conduct a performance evaluation of each COMS
according to the requirements in Sec.  63.8(e) and according to
Performance Specification 1 at appendix B to part 60 of this chapter.
    (3) As specified in Sec.  63.8(c)(4)(i), each COMS must complete a
minimum of one cycle of sampling and analyzing for each successive 10-
second period and one cycle of data recording for each successive 6-
minute period.
    (4) The COMS data must be reduced as specified in Sec.  63.8(g)(2).
    (5) You must include in your site-specific monitoring plan
procedures and acceptance criteria for operating and maintaining each
COMS according to the requirements in Sec.  63.8(d). At a minimum, the
monitoring plan must include a daily calibration drift assessment, a
quarterly performance audit, and an annual zero alignment audit of each
COMS.
    (6) You must operate and maintain each COMS according to the
requirements in the monitoring plan and the requirements of Sec.
63.8(e). You must identify periods the COMS is out of control including
any periods that the COMS fails to pass a daily calibration drift
assessment, a quarterly performance audit, or an annual zero alignment
audit. Any 6-minute period for which the monitoring system is out of
control and data are not available for a required calculation
constitutes a deviation from the monitoring requirements.
    (7) You must determine and record all the 6-minute averages (and
daily block averages as applicable) collected for periods during which
the COMS is not out of control.
    (d) If you have an operating limit that requires the use of a CMS
other than a PM CPMS or COMS, you must install, operate, and maintain
each CMS according to the procedures in

paragraphs (d)(1) through (5) of this section by the compliance date
specified in Sec.  63.7495.
    (1) The continuous parameter monitoring system must complete a
minimum of one cycle of operation for each successive 15-minute period.
You must have a minimum of four successive cycles of operation to have
a valid hour of data.
    (2) You must operate the monitoring system as specified in Sec.
63.7535(b), and comply with the data calculation requirements specified
in Sec.  63.7535(c).
    (3) Any 15-minute period for which the monitoring system is out-of-
control and data are not available for a required calculation
constitutes a deviation from the monitoring requirements. Other
situations that constitute a monitoring deviation are specified in
Sec.  63.7535(d).
    (4) You must determine the 30-day rolling average of all recorded
readings, except as provided in paragraph (d)(3) of this section.
    (5) You must record the results of each inspection, calibration,
and validation check.
    (e) If you have an operating limit that requires the use of a flow
monitoring system, you must meet the requirements in paragraphs (d) and
(e)(1) through (4) of this section.
    (1) You must install the flow sensor and other necessary equipment
in a position that provides a representative flow.
    (2) You must use a flow sensor with a measurement sensitivity of no
greater than 2 percent of the expected flow rate.
    (3) You must minimize the effects of swirling flow or abnormal
velocity distributions due to upstream and downstream disturbances.
    (4) You must conduct a flow monitoring system performance
evaluation in accordance with your monitoring plan at the time of each
performance test but no less frequently than annually.
    (f) If you have an operating limit that requires the use of a
pressure monitoring system, you must meet the requirements in
paragraphs (d) and (f)(1) through (6) of this section.
    (1) Install the pressure sensor(s) in a position that provides a
representative measurement of the pressure (e.g., PM scrubber pressure
drop).
    (2) Minimize or eliminate pulsating pressure, vibration, and
internal and external corrosion.
    (3) Use a pressure sensor with a minimum tolerance of 1.27
centimeters of water or a minimum tolerance of 1 percent of the
pressure monitoring system operating range, whichever is less.
    (4) Perform checks at least once each process operating day to
ensure pressure measurements are not obstructed (e.g., check for
pressure tap pluggage daily).
    (5) Conduct a performance evaluation of the pressure monitoring
system in accordance with your monitoring plan at the time of each
performance test but no less frequently than annually.
    (6) If at any time the measured pressure exceeds the manufacturer's
specified maximum operating pressure range, conduct a performance
evaluation of the pressure monitoring system in accordance with your
monitoring plan and confirm that the pressure monitoring system
continues to meet the performance requirements in you monitoring plan.
Alternatively, install and verify the operation of a new pressure
sensor.
    (g) If you have an operating limit that requires a pH monitoring
system, you must meet the requirements in paragraphs (d) and (g)(1)
through (4) of this section.
    (1) Install the pH sensor in a position that provides a
representative measurement of scrubber effluent pH.
    (2) Ensure the sample is properly mixed and representative of the
fluid to be measured.
    (3) Conduct a performance evaluation of the pH monitoring system in
accordance with your monitoring plan at least once each process
operating day.
    (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 quarterly.
    (h) If you have an operating limit that requires a secondary
electric power monitoring system for an electrostatic precipitator
(ESP) operated with a wet scrubber, you must meet the requirements in
paragraphs (h)(1) and (2) of this section.
    (1) Install sensors to measure (secondary) voltage and current to
the precipitator collection plates.
    (2) Conduct a performance evaluation of the electric power
monitoring system in accordance with your monitoring plan at the time
of each performance test but no less frequently than annually.
    (i) If you have an operating limit that requires the use of a
monitoring system to measure sorbent injection rate (e.g., weigh belt,
weigh hopper, or hopper flow measurement device), you must meet the
requirements in paragraphs (d) and (i)(1) and (2) of this section.
    (1) Install the system in a position(s) that provides a
representative measurement of the total sorbent injection rate.
    (2) Conduct a performance evaluation of the sorbent injection rate
monitoring system in accordance with your monitoring plan at the time
of each performance test but no less frequently than annually.
    (j) If you are not required to use a PM CPMS and elect to use a
fabric filter bag leak detection system to comply with the requirements
of this subpart, you must install, calibrate, maintain, and
continuously operate the bag leak detection system as specified in
paragraphs (j)(1) through (6) of this section.
    (1) You must install a bag leak detection sensor(s) in a
position(s) that will be representative of the relative or absolute
particulate matter loadings for each exhaust stack, roof vent, or
compartment (e.g., for a positive pressure fabric filter) of the fabric
filter.
    (2) Conduct a performance evaluation of the bag leak detection
system in accordance with your monitoring plan and consistent with the
guidance provided in EPA-454/R-98-015 (incorporated by reference, see
Sec.  63.14).
    (3) Use a bag leak detection system certified by the manufacturer
to be capable of detecting particulate matter emissions at
concentrations of 10 milligrams per actual cubic meter or less.
    (4) Use a bag leak detection system equipped with a device to
record continuously the output signal from the sensor.
    (5) Use a bag leak detection system equipped with a system that
will alert when an increase in relative particulate matter emissions
over a preset level is detected. The alarm must be located where it can
be easily heard or seen by plant operating personnel.
    (6) Where multiple bag leak detectors are required, the system's
instrumentation and alarm may be shared among detectors.
    (k) For each unit that meets the definition of limited-use boiler
or process heater, you must monitor and record the operating hours per
year for that unit.
    (l) For each unit for which you decide to demonstrate compliance
with the mercury or hydrogen chloride emissions limits in Tables 1 or 2
of this subpart by use of a CEMS for mercury or hydrogen chloride, you
must install, certify, maintain, and operate a CEMS measuring emissions
discharged to the atmosphere and record the output of the system as
specified in paragraphs (l)(1) through (8) of this section. For
hydrogen chloride, this option for an affected unit takes effect on the
date a final

performance specification for a hydrogen chloride CEMS is published in
the Federal Register or the date of approval of a site-specific
monitoring plan.
    (1) Notify the Administrator one month before starting use of the
CEMS, and notify the Administrator one month before stopping use of the
CEMS.
    (2) Each CEMS shall be installed, certified, operated, and
maintained according to the requirements in Sec.  63.7540(a)(14) for a
mercury CEMS and Sec.  63.7540(a)(15) for a hydrogen chloride CEMS.
    (3) For a new unit, you must complete the initial performance
evaluation of the CEMS by the latest of the dates specified in
paragraph (l)(3)(i) through (iii) of this section.
    (i) No later than [DATE 240 DAYS AFTER PUBLICATION OF THE FINAL
RULE IN THE Federal Register].
    (ii) No later 180 days after the date of initial startup.
    (iii) No later 180 days after notifying the Administrator before
starting to use the CEMS in place of performance testing or fuel
analysis to demonstrate compliance.
    (4) For an existing unit, you must complete the initial performance
evaluation by the latter of the two dates specified in paragraph
(l)(4)(i) and (ii) of this section.
    (i) No later than [DATE 3 YEARS AND 180 DAYS AFTER PUBLICATION OF
THE FINAL RULE IN THE Federal Register].
    (ii) No later 180 days after notifying the Administrator before
starting to use the CEMS in place of performance testing or fuel
analysis to demonstrate compliance.
    (5) Compliance with the applicable emissions limit shall be
determined based on the 30-day rolling average of the hourly arithmetic
average emissions rates using the continuous monitoring system outlet
data. The 30-day rolling arithmetic average emission rate (lb/MMBtu)
shall be calculated using the equations in EPA Reference Method 19 at
40 CFR part 60, appendix A-7, but substituting the mercury or hydrogen
chloride concentration for the pollutant concentrations normally used
in Method 19.
    (6) Collect CEMS hourly averages for all operating hours on a 30-
day rolling average basis. Collect at least four CMS data values
representing the four 15-minute periods in an hour, or at least two 15-
minute data values during an hour when CMS calibration, quality
assurance, or maintenance activities are being performed.
    (7) The one-hour arithmetic averages required shall be expressed in
lb/MMBtu and shall be used to calculate the boiler operating day daily
arithmetic average emissions.
    (8) If you are using an add-on control to comply with the mercury
or hydrogen chloride emission limit, you are allowed to substitute the
use of the mercury or hydrogen chloride CEMS for the applicable fuel
analysis, annual performance test, and operating limits specified in
Table 4 to this subpart to demonstrate compliance with the mercury or
hydrogen chloride emissions limit.

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. If applicable, you must also install,
operate, and maintain all applicable CMS (including CEMS, COMS, and
continuous parameter monitoring systems) according to Sec.  63.7525.
    (b) If you demonstrate compliance through performance 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 total selected metals 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) You must establish the maximum chlorine fuel input (Clinput)
during the initial fuel analysis according to the procedures in
paragraphs (b)(1)(i) through (iii) of this section.
    (i) You must determine the fuel type or fuel mixture that you could
burn in your boiler or process heater that has the highest content of
chlorine.
    (ii) During the fuel analysis for hydrogen chloride, you must
determine the fraction of the total heat input for each fuel type
burned (Qi) based on the fuel mixture that has the highest content of
chlorine, and the average chlorine concentration of each fuel type
burned (Ci).
    (iii) You must establish a maximum chlorine input level using
Equation 7 of this section.

[GRAPHIC] [TIFF OMITTED] TP23DE11.037

Where:

Clinput = Maximum amount of chlorine entering the boiler or process
heater through fuels burned in units of pounds per million Btu.
Ci = Arithmetic average concentration of chlorine in fuel type, i,
analyzed according to Sec.  63.7521, in units of pounds per million
Btu.
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 during the performance testing, it is not
necessary to determine the value of this term. Insert a value of
``1'' for Qi.
n = Number of different fuel types burned in your boiler or process
heater for the mixture that has the highest content of chlorine.

    (2) You must establish the maximum mercury fuel input level
(Mercuryinput) during the initial fuel analysis using the procedures in
paragraphs (b)(2)(i) through (iii) of this section.
    (i) You must determine the fuel type or fuel mixture that you could
burn in your boiler or process heater that has the highest content of
mercury.
    (ii) During the compliance demonstration for mercury, you must
determine the fraction of total heat input for each fuel burned (Qi)
based on the fuel mixture that has the highest content of mercury, and
the average mercury concentration of each fuel type burned (HGi).
    (iii) You must establish a maximum mercury input level using
Equation 8 of this section.

[GRAPHIC] [TIFF OMITTED] TP23DE11.038

Where:

Mercuryinput = Maximum amount of mercury entering the boiler or
process heater through fuels burned in units of pounds per million
Btu.
HGi = Arithmetic average concentration of mercury in fuel type, i,
analyzed according to Sec.  63.7521, in units of pounds per million
Btu.
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 during the performance test, it is not
necessary to determine the value of this term. Insert a value of
``1'' for Qi.
n = Number of different fuel types burned in your boiler or process
heater for the mixture that has the highest content of mercury.

    (3) If you opt to comply with the alternative total selected metals
limit, you must establish the maximum total selected metals fuel input
(TSMinput) for solid fuels during the initial fuel analysis according
to the procedures in paragraphs (b)(3)(i) through (iii) of this
section.
    (i) You must determine the fuel type or fuel mixture that you could
burn in your boiler or process heater that has the highest content of
total selected metals.
    (ii) During the fuel analysis for total selected metals, you must
determine the fraction of the total heat input for each fuel type
burned (Qi) based on the fuel mixture that has the highest content of
total selected metals, and the average total selected metals
concentration of each fuel type burned (TSMi).
    (iii) You must establish a maximum total selected metals input
level using Equation 9 of this section.

[GRAPHIC] [TIFF OMITTED] TP23DE11.039

Where:

TSMinput = Maximum amount of total selected metals entering the
boiler or process heater through fuels burned in units of pounds per
million Btu.
TSMi = Arithmetic average concentration of total selected metals in
fuel type, i, analyzed according to Sec.  63.7521, in units of
pounds per million Btu.
Qi = Fraction of total heat input from fuel type, i, based on the
fuel mixture that has the highest content of total selected metals.
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.
n = Number of different fuel types burned in your boiler or process
heater for the mixture that has the highest content of total
selected metals.

    (4) You must establish parameter operating limits according to
paragraphs (b)(4)(i) through (vii) of this section. As indicated in
Table 4 to this subpart, you are not required to establish and comply
with the operating parameter limits when you are using a CEMS to
monitor and demonstrate compliance with the applicable emission limit
for that control device parameter.
    (i) For a wet acid gas scrubber, you must establish the minimum
scrubber effluent pH 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 hydrogen
chloride and mercury emissions, you must establish one set of minimum
scrubber effluent pH, liquid flow rate, and pressure drop operating
limits. The minimum scrubber effluent pH operating limit must be
established during the hydrogen chloride performance test. If you
conduct multiple performance tests, you must set the minimum liquid
flow rate operating limit at the higher of the minimum values
established during the performance tests.
    (ii) For any particulate control device (e.g., ESP, particulate wet
scrubber, fabric filter) for which you use a PM CPMS, you must
establish your operating limit during the three-run performance during
which you demonstrate compliance with your applicable limit. The PM
CPMS operating limit is the 1-hour average PM CPMS output value
recorded during the performance test. If you conduct separate
performance tests for PM and total selected metals, you must set the
maximum PM CPMS operating limits at the lower of maximum PM CPMS values
established during the performance tests.
    (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
particulate matter and total selected metals 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 hydrogen chloride 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 operated with a wet
scrubber, you must establish the minimum voltage and secondary amperage
(or total power input), 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. (These operating
limits do not apply to electrostatic precipitators 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 alarm
does not sound more than 5 percent of the operating time during a 6-
month period.
    (c) If you elect to demonstrate compliance with an applicable
emission limit through fuel analysis, you must conduct fuel analyses
according to Sec.  63.7521 and follow the procedures in paragraphs
(c)(1) through (5) of this section.
    (1) If you burn more than one fuel type, you must determine the
fuel mixture you could burn in your boiler or process heater that would
result in the maximum emission rates of the pollutants that you elect
to demonstrate compliance through fuel analysis.
    (2) You must determine the 90th percentile confidence level fuel

pollutant concentration of the composite samples analyzed for each fuel
type using the one-sided z-statistic test described in Equation 10 of
this section.

[GRAPHIC] [TIFF OMITTED] TP23DE11.040

Where:

P90 = 90th percentile confidence level pollutant concentration, in
pounds per million Btu.
Mean = Arithmetic average of the fuel pollutant concentration in the
fuel samples analyzed according to Sec.  63.7521, in units of pounds
per million Btu.
SD = Standard deviation of the pollutant concentration in the fuel
samples analyzed according to Sec.  63.7521, in units of pounds per
million Btu.
T = t distribution critical value for 90th percentile (0.1)
probability for the appropriate degrees of freedom (number of
samples minus one) as obtained from a Distribution Critical Value
Table.

    (3) To demonstrate compliance with the applicable emission limit
for hydrogen chloride, the hydrogen chloride emission rate that you
calculate for your boiler or process heater using Equation 11 of this
section must not exceed the applicable emission limit for hydrogen
chloride.

[GRAPHIC] [TIFF OMITTED] TP23DE11.041

Where:

HCl = Hydrogen chloride emission rate from the boiler or process
heater in units of pounds per million Btu.
Ci90 = 90th percentile confidence level concentration of chlorine in
fuel type, i, in units of pounds per million Btu as calculated
according to Equation 10 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.
n = Number of different fuel types burned in your boiler or process
heater for the mixture that has the highest content of chlorine.
1.028 = Molecular weight ratio of hydrogen chloride to chlorine.

    (4) To demonstrate compliance with the applicable emission limit
for mercury, the mercury emission rate that you calculate for your
boiler or process heater using Equation 12 of this section must not
exceed the applicable emission limit for mercury.

[GRAPHIC] [TIFF OMITTED] TP23DE11.042

Where:

Mercury = Mercury emission rate from the boiler or process heater in
units of pounds per million Btu.
Hgi90 = 90th percentile confidence level concentration of mercury in
fuel, i, in units of pounds per million Btu as calculated according
to Equation 10 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.
n = Number of different fuel types burned in your boiler or process
heater for the mixture that has the highest mercury content.

    (5) To demonstrate compliance with the applicable emission limit
for total selected metals for solid fuels, the total selected metals
emission rate that you calculate for your boiler or process heater from
solid fuels using Equation 13 of this section must not exceed the
applicable emission limit for total selected metals.

[GRAPHIC] [TIFF OMITTED] TP23DE11.043

Where:

Metals = Total selected metals emission rate from the boiler or
process heater in units of pounds per million Btu.
TSMi90 = 90th percentile confidence level concentration of total
selected metals in fuel, i, in units of pounds per million Btu as
calculated according to Equation 10 of this section.
Qi = Fraction of total heat input from fuel type, i, based on the
fuel mixture that has the highest total selected metals 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.
n = Number of different fuel types burned in your boiler or process
heater for the mixture that has the highest total selected metals
content.

    (d) If you own or operate an existing unit with a heat input
capacity of less than 10 million Btu per hour, you must submit a signed
statement in the Notification of Compliance Status report that
indicates that you conducted a tune-up of the unit.
    (e) You must include with the Notification of Compliance Status a
signed certification that the energy assessment was completed according
to Table 3 to this subpart and is an accurate depiction of your
facility.
    (f) You must submit the Notification of Compliance Status
containing the results of the initial compliance demonstration
according to the requirements in Sec.  63.7545(e).
    (g) If you elect to demonstrate that a gaseous fuel meets the
specifications of an other gas 1 fuel as defined in Sec.  63.7575, you
must conduct an initial fuel specification analyses according to Sec.
63.7521(f) through (i). If the mercury constituents in the gaseous
fuels will never exceed the specification included in the definition,
you will include a signed certification with the Notification of
Compliance Status that the initial fuel specification test meets the
gas specification outlined in the definition of other gas 1 fuels. If
your gas constituents could vary above the specification, you will
conduct monthly testing according to the procedures in Sec.  63.7521(f)
through (i) and Sec.  63.7540(c)

and maintain records of the results of the testing as outlined in Sec.
63.7555(g).
    (h) If you own or operate a unit subject to emission limits in
Tables 1 or 2 to this subpart, you must meet the work practice standard
according to Table 3 of this subpart. You must submit a signed
statement in the Notification of Compliance Status report that
indicates that you employed good combustion practices and you
maintained oxygen concentrations as specified by the boiler
manufacturer for each startup and shutdown event.

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

    (a) If you elect to comply with the alternative equivalent steam
output-based emission limits, instead of the heat input-based limits
listed in Table 2 to this subpart, and you want to take credit for
implementing energy conservation measures identified in an energy
assessment, you may demonstrate compliance using emission reduction
credits according to the procedures in this section. You may use this
compliance approach for an existing affected boiler for demonstrating
initial compliance according to Sec.  63.7522(e) and for demonstrating
monthly compliance according to Sec.  63.7522(f). Owners or operators
using this compliance approach must establish an emissions benchmark,
calculate and document the emission credits, develop an Implementation
Plan, comply with the general reporting requirements, and apply the
emission credit according to the procedures in paragraphs (b) through
(f) of this section. You cannot use this compliance approach for a new
or reconstructed affected boiler.
    (b) For each existing affected boiler for which you intend to apply
emissions credits, establish a benchmark from which emission reduction
credits may be generated by determining the actual annual fuel heat
input to the affected boiler before initiation of an energy
conservation activity to reduce energy demand (i.e., fuel usage)
according to paragraphs (b)(1) through (4) of this section. The
benchmark shall be expressed in trillion Btu per year heat input.
    (1) The benchmark from which emission credits may be generated
shall be determined by using the most representative, accurate, and
reliable process available for the source. The benchmark shall be
established for a one-year period before the date that an energy demand
reduction occurs, unless it can be demonstrated that a different time
period is more representative of historical operations.
    (2) Determine the starting point from which to measure progress.
Inventory all fuel purchased and generated on-site (off-gases,
residues) in physical units (MMBtu, million cubic feet, etc.).
    (3) Document all uses of energy from the affected boiler. Use the
most recent data available.
    (4) Collect non-energy related facility and operational data to
normalize, if necessary, the benchmark to current operations, such as
building size, operating hours, etc. If possible, use actual data that
are current and timely rather than estimated data.
    (c) Emissions credits can be generated if the energy conservation
measures were implemented after January 1, 2008 and if sufficient
information is available to determine the appropriate value of credits.
    (1) The following emission points cannot be used to generate
emissions averaging credits:
    (i) Energy conservation measures implemented on or before January
1, 2008, unless the level of energy demand reduction is increased after
January 1, 2008, in which case credit will be allowed only for change
in demand reduction achieved after January 1, 2008.
    (ii) Emission credits on shut-down boilers. Boilers that are shut
down cannot be used to generate credits.
    (2) For all points included in calculating emissions credits, the
owner or operator shall:
    (i) Calculate annual credits for all energy demand points. Use
Equation 14 to calculate credits. Energy conservation measures that
meet the criteria of paragraph (c)(1) of this section shall not be
included, except as specified in paragraph (c)(1)(i) of this section.
    (3) Credits are generated by the difference between the benchmark
that is established for each affected boiler, and the actual energy
demand reductions from energy conservation measures implemented after
January 1, 2008. Credits shall be calculated using Equation 14 of this
section as follows:
    (i) The overall equation for calculating credits is:

    [GRAPHIC] [TIFF OMITTED] TP23DE11.044

Where:

ECredits = Energy Input Savings for all energy conservation measures
implemented for an affected boiler, expressed as a decimal fraction
of the baseline energy input.
EISiactual = Energy Input Savings for each energy
conservation measure, i, implemented for an affected boiler, million
Btu per year.
EIbaseline = Energy Input baseline for the affected
boiler, million Btu per year.
n = Number of energy conservation measures included in the emissions
credit for the affected boiler.

    (d) The owner or operator shall develop and submit for approval an
Implementation Plan containing all of the information required in this
paragraph for all boilers to be included in an emissions credit
approach. The Implementation Plan shall identify all existing affected
boilers to be included in applying the emissions credits. The
Implementation Plan shall include a description of the energy
conservation measures implemented and the energy savings generated from
each measure and an explanation of the criteria used for determining
that savings. You must submit the implementation plan for emission
credits to the applicable delegated authority for review and approval
no later than 180 days before the date on which the facility intends to
demonstrate compliance using the emission credit approach.
    (e) The emissions rate as calculated using Equation 15 of this
section from each existing boiler participating in the emissions credit
option must be in compliance with the limits in Table 2 to this subpart
at all times following the compliance date specified in Sec.  63.7495.
    (f) You must use Equation 15 of this section to demonstrate initial
compliance by demonstrating that the emissions from the affected boiler
participating in the emissions credit compliance approach do not exceed
the emission limits in Table 2 to this subpart.

[GRAPHIC] [TIFF OMITTED] TP23DE11.045

Where:

Eadj = Emission level adjusted by applying the emission
credits earned, lb per million Btu steam output for the affected
boiler.
Em = Emissions measured during the performance test, lb
per million Btu steam output for the affected boiler.
ECredits = Emission credits from Equation 14 for the affected
boiler.

Continuous Compliance Requirements

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

    (a) You must monitor and collect data according to this section and
the site-specific monitoring plan required by Sec.  63.7505(d).
    (b) You must operate the monitoring system and collect data at all
required intervals at all times that the affected source is operating
and compliance is required, except for periods of monitoring system
malfunctions or out of control periods (see Sec.  63.8(c)(7) of this
part), and required monitoring system quality assurance or control
activities, including, as applicable, calibration checks, required zero
and span adjustments, and scheduled CMS maintenance as defined in your
site-specific monitoring plan. A monitoring system malfunction is any
sudden, infrequent, not reasonably preventable failure of the
monitoring system to provide valid data. Monitoring system failures
that are caused in part by poor maintenance or careless operation are
not malfunctions. You are required to complete monitoring system
repairs in response to monitoring system malfunctions or out-of-control
periods and to return the monitoring system to operation as
expeditiously as practicable.
    (c) You may not use data recorded during 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.

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

    (a) You must demonstrate continuous compliance with each emission
limit in Tables 1 and 2 to this subpart, the work practice standards in
Table 3 to this subpart, and the operating limits in Table 4 to this
subpart that applies to you according to the methods specified in Table
8 to this subpart and paragraphs (a)(1) through (17) of this section.
    (1) Following the date on which the initial compliance
demonstration is completed or is required to be completed under
Sec. Sec.  63.7 and 63.7510, whichever date comes first, operation
above the established maximum or below the established minimum
operating limits shall constitute a deviation of established operating
limits listed in Table 4 of this subpart except during performance
tests conducted to determine compliance with the emission limits or to
establish new operating limits. Operating limits must be confirmed or
reestablished during performance tests.
    (2) As specified in Sec.  63.7550(c), 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) Lower emissions of hydrogen chloride, mercury, and total
selected metals than the applicable emission limit for each pollutant,
if you demonstrate compliance through fuel analysis.
    (ii) Lower fuel input of chlorine, mercury, and total selected
metals 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 hydrogen
chloride 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 hydrogen chloride emission rate using Equation 11 of
Sec.  63.7530 according to paragraphs (a)(3)(i) through (iii) of this
section. You are not required to complete 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 hydrogen chloride emission rate.
    (i) You must determine the chlorine concentration for any new fuel
type in units of pounds per million Btu, based on supplier data or your
own fuel analysis, according to the provisions in your site-specific
fuel analysis plan developed according to Sec.  63.7521(b).
    (ii) You must determine the new mixture of fuels that will have the
highest content of chlorine.
    (iii) Recalculate the hydrogen chloride emission rate from your
boiler or process heater under these new conditions using Equation 11
of Sec.  63.7530. The recalculated hydrogen chloride emission rate must
be less than the applicable emission limit.
    (4) If you demonstrate compliance with an applicable hydrogen
chloride emission limit through performance testing and you plan to
burn a new type of fuel or a new mixture of fuels, you must recalculate
the maximum chlorine input using Equation 7 of Sec.  63.7530. If the
results of recalculating the maximum chlorine input using Equation 7 of
Sec.  63.7530 are greater than the maximum chlorine input level
established during the previous performance test, then you must conduct
a new performance test within 60 days of burning the new fuel type or
fuel mixture according to the procedures in Sec.  63.7520 to
demonstrate that the hydrogen chloride emissions do not exceed the
emission limit. You must also establish new operating limits based on
this performance test according to the procedures in Sec.  63.7530(b).
In recalculating the maximum chlorine input and establishing the new
operating limits, you are not required to complete fuel analyses for
and include the fuels described in Sec.  63.7510(a)(2)(i) through
(iii).
    (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
12 of Sec.  63.7530 according to the procedures specified in paragraphs
(a)(5)(i) through (iii) of this

section. You are not required to complete 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.
    (i) You must determine the mercury concentration for any new fuel
type in units of pounds per million Btu, based on supplier data or your
own fuel analysis, according to the provisions in your site-specific
fuel analysis plan developed according to Sec.  63.7521(b).
    (ii) You must determine the new mixture of fuels that will have the
highest content of mercury.
    (iii) Recalculate the mercury emission rate from your boiler or
process heater under these new conditions using Equation 12 of Sec.
63.7530. The recalculated mercury emission rate must be less than the
applicable emission limit.
    (6) If you demonstrate compliance with an applicable mercury
emission limit through performance testing, and you plan to burn a new
type of fuel or a new mixture of fuels, you must recalculate the
maximum mercury input using Equation 8 of Sec.  63.7530. If the results
of recalculating the maximum mercury input using Equation 8 of Sec.
63.7530 are higher than the maximum mercury input level established
during the previous performance test, then you must conduct a new
performance test within 60 days of burning the new fuel type or fuel
mixture according to the procedures in Sec.  63.7520 to demonstrate
that the mercury emissions do not exceed the emission limit. You must
also establish new operating limits based on this performance test
according to the procedures in Sec.  63.7530(b). You are not required
to complete 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.
    (7) If your unit is controlled with a fabric filter, and you
demonstrate continuous compliance using a bag leak detection system,
you must initiate corrective action within 1 hour of a bag leak
detection system alarm and complete corrective actions as soon as
practical, and operate and maintain the fabric filter system such that
the alarm does not sound more than 5 percent of the operating time
during a 6-month period. You must also keep records of the date, time,
and duration of each alarm, the time corrective action was initiated
and completed, and a brief description of the cause of the alarm and
the corrective action taken. You must also record the percent of the
operating time during each 6-month period that the alarm sounds. In
calculating this operating time percentage, if inspection of the fabric
filter demonstrates that no corrective action is required, no alarm
time is counted. If corrective action is required, each alarm shall be
counted as a minimum of 1 hour. If you take longer than 1 hour to
initiate corrective action, the alarm time shall be counted as the
actual amount of time taken to initiate corrective action.
    (8) If you install a CO CEMS according to Sec.  63.7525(a), then
you must meet the requirements in paragraphs (a)(8)(i) through (iii) of
this section.
    (i) Continuously monitor CO according to Sec. Sec.  63.7525(a) and
63.7535.
    (ii) Maintain a CO emission level below or at your applicable
alternative CO CEMS-based standard in Tables 1 or 2 to this subpart at
all times.
    (iii) Keep records of CO levels according to Sec.  63.7555(b).
    (9) The owner or operator of an affected source using a PM CPMS to
meet requirements of this subpart shall install, certify, operate, and
maintain the PM CPMS in accordance with your site-specific monitoring
plan as required in Sec.  63.7505(d).
    (10) If your boiler or process heater is in either the natural gas,
refinery gas, other gas 1, or Metal Process Furnace subcategories and
has a heat input capacity of 10 million Btu per hour or greater, you
must conduct a tune-up of the boiler or process heater annually to
demonstrate continuous compliance as specified in paragraphs (a)(10)(i)
through (vi) of this section. This requirement does not apply to
limited-use boilers and process heaters, as defined in Sec.  63.7575.
    (i) As applicable, inspect the burner, and clean or replace any
components of the burner as necessary (you may delay the burner
inspection until the next scheduled or unscheduled unit shutdown);
    (ii) Inspect the flame pattern, as applicable, and adjust the
burner as necessary to optimize the flame pattern. The adjustment
should be consistent with the manufacturer's specifications, if
available;
    (iii) Inspect the system controlling the air-to-fuel ratio, as
applicable, and ensure that it is correctly calibrated and functioning
properly;
    (iv) Optimize total emissions of carbon monoxide. This optimization
should be consistent with the manufacturer's specifications, if
available;
    (v) Measure the concentrations in the effluent stream of carbon
monoxide in parts per million, by volume, and oxygen in volume percent,
before and after the adjustments are made (measurements may be either
on a dry or wet basis, as long as it is the same basis before and after
the adjustments are made); and
    (vi) Maintain on-site and submit, if requested by the
Administrator, an annual report containing the information in
paragraphs (a)(10)(vi)(A) through (C) of this section,
    (A) The concentrations of carbon monoxide in the effluent stream in
parts per million by volume, and oxygen in volume percent, measured
before and after the adjustments of the boiler;
    (B) A description of any corrective actions taken as a part of the
combustion adjustment; and
    (C) The type and amount of fuel used over the 12 months prior to
the annual adjustment, but only if the unit was physically and legally
capable of using more than one type of fuel during that period. Units
sharing a fuel meter may estimate the fuel used by each unit.
    (11) If your boiler or process heater has a heat input capacity of
less than 10 million Btu per hour (except as specified in paragraph
(a)(12) of this section), or meets the definition of limited-use boiler
or process heater in Sec.  63.7575, you must conduct a biennial tune-up
of the boiler or process heater as specified in paragraphs (a)(10)(i)
through (a)(10)(vi) of this section to demonstrate continuous
compliance.
    (12) If your boiler or process heater has a heat input capacity of
less than 5 million Btu per hour, and the unit is in the units designed
to burn natural gas, refinery gas or other gas 1 fuels, units designed
to burn gas 2 (other), or units designed to burn light liquid
subcategories, 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.
    (13) If the unit is not operating on the required date for a tune-
up, the tune-up must be conducted within one week of startup.
    (14) If you are using a CEMS measuring mercury emissions to meet
requirements of this subpart you must install, certify, operate, and
maintain the mercury CEMS as specified in paragraphs (a)(14)(i) and
(ii) of this section.
    (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 a calendar month. For each calendar month in
which the unit operates, you must obtain hourly mercury concentration
data, and stack gas volumetric flow rate data.
    (ii) If you are using a mercury CEMS, you must install, operate,
calibrate, and maintain an instrument for continuously measuring and
recording the mercury mass emissions rate to the atmosphere according
to the requirements of performance specifications 6 and 12A of 40 CFR
part 60, appendix B, and quality assurance procedure 6 of 40 CFR part
60, appendix F.
    (15) If you are using a CEMS to measure hydrogen chloride emissions
to meet requirements of this subpart, you must install, certify,
operate, and maintain the hydrogen chloride CEMS as specified in
paragraphs (a)(15)(i) and (ii) of this section. This option for an
affected unit takes effect on the date a final performance
specification for a hydrogen chloride CEMS is published in the Federal
Register or the date of approval of a site-specific monitoring plan.
    (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 a calendar
month. For each calendar month in which the unit operates, you must
obtain hourly hydrogen chloride concentration data, and stack gas
volumetric flow rate data.
    (ii) If you are using a hydrogen chloride continuous emissions
monitoring system, you must install, operate, calibrate, and maintain
an instrument for continuously measuring and recording the hydrogen
chloride mass emissions rate to the atmosphere according to the
requirements of the applicable performance specification of 40 CFR part
60, appendix B, and the quality assurance procedures of 40 CFR part 60,
appendix F.
    (16) If you demonstrate compliance with an applicable total
selected metals emission limit through performance testing, and you
plan to burn a new type of fuel or a new mixture of fuels, you must
recalculate the maximum total selected metals input using Equation 9 of
Sec.  63.7530. If the results of recalculating the maximum total
selected metals input using Equation 9 of Sec.  63.7530 are higher than
the maximum total selected input level established during the previous
performance test, then you must conduct a new performance test within
60 days of burning the new fuel type or fuel mixture according to the
procedures in Sec.  63.7520 to demonstrate that the total selected
metals emissions do not exceed the emission limit. You must also
establish new operating limits based on this performance test according
to the procedures in Sec.  63.7530(b). You are not required to complete
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 total selected metals emission
rate.
    (17) If you demonstrate compliance with an applicable total
selected metals emission limit through fuel analysis for solid fuels,
and you plan to burn a new type of fuel, you must recalculate the total
selected metals emission rate using Equation 13 of Sec.  63.7530
according to the procedures specified in paragraphs (a)(5)(i) through
(iii) of this section. You are not required to complete 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 total selected metals emission rate.
    (i) You must determine the total selected metals concentration for
any new fuel type in units of pounds per million Btu, based on supplier
data or your own fuel analysis, according to the provisions in your
site-specific fuel analysis plan developed according to Sec.
63.7521(b).
    (ii) You must determine the new mixture of fuels that will have the
highest content of total selected metals.
    (iii) Recalculate the total selected metals emission rate from your
boiler or process heater under these new conditions using Equation 13
of Sec.  63.7530. The recalculated total selected metals emission rate
must be less than the applicable emission limit.
    (b) You must report each instance in which you did not meet each
emission limit and operating limit in Tables 1 through 4 to this
subpart that apply to you. These instances are deviations from the
emission limits or operating limits, respectively, in this subpart.
These deviations must be reported according to the requirements in
Sec.  63.7550.
    (c) If you elected to demonstrate that the unit meets the
specification for mercury for the other gas 1 subcategory and you
cannot submit a signed certification under Sec.  63.7545(g) because the
constituents could exceed the specification, you must conduct monthly
fuel specification testing of the gaseous fuels, according to the
procedures in Sec.  63.7521(f) through (i).
    (d) For periods of startup and shutdown, you must meet the work
practice standards according to Table 3 of this subpart.

Sec.  63.7541  How do I demonstrate continuous compliance under the
emissions averaging provision?

    (a) Following the compliance date, the owner or operator must
demonstrate compliance with this subpart on a continuous basis by
meeting the requirements of paragraphs (a)(1) through (5) of this
section.
    (1) For each calendar month, demonstrate compliance with the
average weighted emissions limit for the existing units participating
in the emissions averaging option as determined in Sec.  63.7522(f) and
(g).
    (2) You must maintain the applicable opacity limit according to
paragraphs (a)(2)(i) and (ii) of this section.
    (i) For each existing unit participating in the emissions averaging
option that is equipped with a dry control system and not vented to a
common stack, maintain opacity at or below the applicable limit.
    (ii) For each group of units participating in the emissions
averaging option where each unit in the group is equipped with a dry
control system and vented to a common stack that does not receive
emissions from non-affected units, maintain opacity at or below the
applicable limit at the common stack.
    (3) For each existing unit participating in the emissions averaging
option that is equipped with a wet scrubber, maintain the 30-day
rolling average parameter values at or below the operating limits
established during the most recent performance test.
    (4) For each existing unit participating in the emissions averaging
option that has an approved alternative operating plan, maintain the
30-day rolling average parameter values at or below the operating
limits established in the most recent performance test.
    (5) For each existing unit participating in the emissions averaging
option venting to a common stack configuration containing affected
units from other subcategories, maintain the appropriate operating
limit for each unit as specified in Table 4 to this subpart that
applies.
    (b) Any instance where the owner or operator fails to comply with
the continuous monitoring requirements in paragraphs (a)(1) through (5)
of this section is a deviation.

Notification, Reports, and Records

Sec.  63.7545  What notifications must I submit and when?

    (a) You must submit to the delegated authority all of the
notifications in Sec.  63.7(b) and (c), Sec.  63.8(e), (f)(4) and (6),
and Sec.  63.9(b) through (h) that apply to you by the dates specified.
    (b) As specified in Sec.  63.9(b)(2), if you startup your affected
source before [DATE 60 DAYS AFTER THE DATE OF PUBLICATION OF THE FINAL
RULE IN THE Federal Register], you must submit an Initial Notification
not later than 120 days after [DATE 60 DAYS AFTER THE DATE OF
PUBLICATION OF THE FINAL RULE IN THE Federal Register].
    (c) As specified in Sec.  63.9(b)(4) and (b)(5), if you startup
your new or reconstructed affected source on or after [DATE 60 DAYS
AFTER PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], you must
submit an Initial Notification not later than 15 days after the actual
date of startup of the affected source.
    (d) If you are required to conduct a performance test you must
submit a Notification of Intent to conduct a performance test at least
60 days before the performance test is scheduled to begin.
    (e) If you are required to conduct an initial compliance
demonstration as specified in Sec.  63.7530(a), you must submit a
Notification of Compliance Status according to Sec.  63.9(h)(2)(ii).
For the initial compliance demonstration for each affected source, 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 the affected
source 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), as applicable.
    (1) A description of the affected unit(s) including identification
of which subcategory the unit is in, the design heat input capacity of
the unit, a description of the add-on controls used on the unit,
description of the fuel(s) burned, including whether the fuel(s) were
determined by you or EPA through a petition process to be a non-waste
under Sec.  241.3, whether the fuel(s) were processed from discarded
non-hazardous secondary materials within the meaning of Sec.  241.3,
and justification for the selection of fuel(s) burned during the
compliance demonstration.
    (2) Summary of the results of all performance tests and fuel
analyses, and calculations conducted to demonstrate initial compliance
including all established operating limits.
    (3) A summary of the maximum carbon monoxide emission levels
recorded during the performance test to show that you have met any
applicable emission standard in Table 1 or 2 to this subpart, if you
are not using a CO CEMS to demonstrate compliance.
    (4) Identification of whether you plan to demonstrate compliance
with each applicable emission limit through performance testing, a
CEMS, or fuel analysis.
    (5) Identification of whether you plan to demonstrate compliance by
emissions averaging and identification of whether you plan to
demonstrate compliance by using emission credits through energy
conservation:
    (i) If you plan to demonstrate compliance by emission averaging,
report the emission level that was being achieved or the control
technology employed on [DATE 60 DAYS AFTER PUBLICATION OF THE FINAL
RULE IN THE Federal Register].
    (6) A signed certification that you have met all applicable
emission limits and work practice standards.
    (7) If you had a deviation from any emission limit, work practice
standard, or operating limit, you must also submit a description of the
deviation, the duration of the deviation, and the corrective action
taken in the Notification of Compliance Status report.
    (8) In addition to the information required in Sec.  63.9(h)(2),
your notification of compliance status must include the following
certification(s) of compliance, as applicable, and signed by a
responsible official:
    (i) ``This facility complies with the requirements in Sec.
63.7540(a)(10), (11), or (12) to conduct an annual, biennial, or 5-year
tune-up, as applicable, of each unit.''
    (ii) ``This facility has had an energy assessment performed
according to Sec.  63.7530(e).''
    (iii) Except for units that qualify for a statutory exemption as
provided in section 129(g)(1) of the Clean Air Act, include the
following: ``No secondary materials that are solid waste were combusted
in any affected unit.''
    (f) If you operate a unit designed to burn natural gas, refinery
gas, or other gas 1 fuels that is subject to this subpart, and you
intend to use a fuel other than natural gas, refinery gas, gaseous fuel
subject to another subpart of this part, or other gas 1 fuel to fire
the affected unit during a period of natural gas curtailment or supply
interruption, as defined in Sec.  63.7575, you must submit a
notification of alternative fuel use within 48 hours of the declaration
of each period of natural gas curtailment or supply interruption, as
defined in Sec.  63.7575. The notification must include the information
specified in paragraphs (f)(1) through (5) of this section.
    (1) Company name and address.
    (2) Identification of the affected unit.
    (3) Reason you are unable to use natural gas or equivalent fuel,
including the date when the natural gas curtailment was declared or the
natural gas supply interruption began.
    (4) Type of alternative fuel that you intend to use.
    (5) Dates when the alternative fuel use is expected to begin and
end.
    (g) If you intend to commence or recommence combustion of solid
waste, you must provide 30 days prior notice of the date upon which you
will commence or recommence combustion of solid waste. The notification
must identify:
    (1) The name of the owner or operator of the affected source, the
location of the source, the boiler(s) or process heater(s) that will
commence burning solid waste, and the date of the notice.
    (2) The currently applicable subcategory under this subpart.
    (3) The date on which you became subject to the currently
applicable emission limits.
    (4) The date upon which you will commence combusting solid waste.
    (h) If you intend to switch fuels, and this fuel switch may result
in the applicability of a different subcategory, you must provide 30
days prior notice of the date upon which you will switch fuels. The
notification must identify:
    (1) The name of the owner or operator of the affected source, the
location of the source, the boiler(s) that will switch fuels, and the
date of the notice.
    (2) The currently applicable subcategory under this subpart.
    (3) The date on which you became subject to the currently
applicable standards.
    (4) The date upon which you will commence the fuel switch.

Sec.  63.7550  What reports must I submit and when?

    (a) You must submit each report in Table 9 to this subpart that
applies to you.
    (b) Unless the EPA Administrator has approved a different schedule
for submission of reports under Sec.  63.10(a), you must submit each
report by the date in Table 9 to this subpart and according to the
requirements in paragraphs (b)(1) through (5) of this section. For
units that are subject only to a requirement to conduct an 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 operating limits, you may submit
only an annual, biennial, or 5-year compliance report, as applicable,
as specified in paragraphs (b)(1) through (5) of this section, instead
of a semi-annual compliance report.
    (1) The first compliance report must cover the period beginning on
the compliance date that is specified for your affected source in Sec.
63.7495 and ending on June 30 or December 31, whichever date is the
first date that occurs at least 180 days (or 1, 2, or 5 years, as
applicable, if submitting an annual, biennial, or 5-year compliance
report) after the compliance date that is specified for your source in
Sec.  63.7495.
    (2) The first compliance report must be postmarked or delivered no
later than July 31 or January 31, whichever date is the first date
following the end of the first calendar half after the compliance date
that is specified for your source in Sec.  63.7495. The first annual,
biennial, or 5-year compliance report must be postmarked no later than
January 31.
    (3) Each subsequent 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 compliance report must be postmarked or
delivered 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 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
delegated authority has established dates for submitting semiannual
reports pursuant to Sec.  70.6(a)(3)(iii)(A) or Sec.
71.6(a)(3)(iii)(A), you may submit the first and subsequent compliance
reports according to the dates the delegated authority has established
instead of according to the dates in paragraphs (b)(1) through (4) of
this section.
    (c) The compliance report must contain the information required in
paragraphs (c)(1) through (13) of this section.
    (1) Company name and address.
    (2) Statement by a responsible official with that official's name,
title, and signature, certifying the truth, accuracy, and completeness
of the content of the report.
    (3) Date of report and beginning and ending dates of the reporting
period.
    (4) The total fuel use by each affected source subject to an
emission limit, for each calendar month within the semiannual (or
annual, biennial, or 5-year) reporting period, including, but not
limited to, a description of the fuel, whether the fuel has received a
non-waste determination by EPA or your basis for concluding that the
fuel is not a waste, and the total fuel usage amount with units of
measure.
    (5) A summary of the results of the annual performance tests for
affected sources subject to an emission limit, a summary of any fuel
analyses associated with performance tests, and documentation of any
operating limits that were reestablished during this test, if
applicable. If you are conducting performance tests once every 3 years
consistent with Sec.  63.7515(b) or (c), the date of the last 2
performance tests, a comparison of the emission level you achieved in
the last 2 performance tests to the 75 percent emission limit threshold
required in Sec.  63.7515(b) or (c), and a statement as to whether
there have been any operational changes since the last performance test
that could increase emissions.
    (6) A signed statement indicating that you burned no new types of
fuel in an affected source subject to an emission limit. Or, if you did
burn a new type of fuel and are subject to a hydrogen chloride emission
limit, you must submit the calculation of chlorine input, using
Equation 5 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
hydrogen chloride emission rate using Equation 11 of Sec.  63.7530 that
demonstrates that your source is still meeting the emission limit for
hydrogen chloride 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
12 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 total selected metals
emission limit, you must submit the calculation of total selected
metals input, using Equation 9 of Sec.  63.7530, that demonstrates that
your source is still within its maximum total selected metals input
level established during the previous performance testing (for sources
that demonstrate compliance through performance testing), or you must
submit the calculation of total selected metals emission rate, using
Equation 13 of Sec.  63.7530, that demonstrates that your source is
still meeting the emission limit for total selected metals emissions
(for boilers or process heaters that demonstrate compliance through
fuel analysis).
    (7) If you wish to burn a new type of fuel in an affected source
subject to an emission limit and you cannot demonstrate compliance with
the maximum chlorine input operating limit using Equation 7 of Sec.
63.7530 or the maximum mercury input operating limit using Equation 8
of Sec.  63.7530, or the maximum total selected metals input operating
limit using Equation 9 of Sec.  63.7530 you must include in the
compliance report a statement indicating the intent to conduct a new
performance test within 60 days of starting to burn the new fuel.
    (8) A summary of any monthly fuel analyses conducted to demonstrate
compliance according to Sec. Sec.  63.7521 and 63.7530 for affected
sources subject to emission limits, and any fuel specification analyses
conducted according to Sec.  63.7521(f) and Sec.  63.7530(g).
    (9) If there are no deviations from any emission limits or
operating limits in this subpart that apply to you, a statement that
there were no deviations from the emission limits or operating limits
during the reporting period.
    (10) If there were no deviations from the monitoring requirements
including no periods during which the CMSs, including CEMS, COMS, and
continuous parameter monitoring systems, were out of control as
specified in Sec.  63.8(c)(7), a statement that there were no
deviations and no periods during which the CMS were out of control
during the reporting period.
    (11) If a malfunction occurred during the reporting period, the
report must include the number, duration, and a brief description for
each type of malfunction which occurred during the reporting period and
which caused or may have caused any applicable emission limitation to
be exceeded. The report must also include a description of

actions taken by you during a malfunction of a boiler, process heater,
or associated air pollution control device or CMS to minimize emissions
in accordance with Sec.  63.7500(a)(3), including actions taken to
correct the malfunction.
    (12) Include the date of the most recent tune-up for each unit
subject to only the requirement to conduct an annual, biennial, or 5-
year tune-up according to Sec.  63.7540(a)(10), (11), or (12)
respectively. Include the date of the most recent burner inspection if
it was not done annually, biennially, or on a 5-year period and was
delayed until the next scheduled or unscheduled unit shutdown.
    (13) If you plan to demonstrate compliance by emission averaging,
certify the emission level achieved or the control technology employed
is no less stringent than the level or control technology contained in
the notification of compliance status in Sec.  63.7545(e)(5)(i).
    (14) For units subject to emission limits in Tables 1 or 2 of this
subpart, for each startup or shutdown event during the reporting
period, report the percentage concentration of oxygen in the firebox on
an hourly basis throughout the event, the calendar date and length of
each event, and the reason for each event.
    (d) For each deviation from an emission limit or operating limit in
this subpart that occurs at an affected source where you are not using
a CMS to comply with that emission limit or operating limit, the
compliance report must additionally contain the information required in
paragraphs (d)(1) through (4) of this section.
    (1) The total operating time of each affected source during the
reporting period.
    (2) A description of the deviation and which emission limit or
operating limit from which you deviated.
    (3) Information on the number, duration, and cause of deviations
(including unknown cause), as applicable, and the corrective action
taken.
    (4) A copy of the test report if the annual performance test showed
a deviation from the emission limits.
    (e) For each deviation from an emission limit, operating limit, and
monitoring requirement in this subpart occurring at an affected source
where you are using a CMS to comply with that emission limit or
operating limit, you must include the information required in
paragraphs (e)(1) through (12) of this section. This includes any
deviations from your site-specific monitoring plan as required in Sec.
63.7505(d).
    (1) The date and time that each deviation started and stopped and
description of the nature of the deviation (i.e., what you deviated
from).
    (2) The date and time that each CMS was inoperative, except for
zero (low-level) and high-level checks.
    (3) The date, time, and duration that each CMS was out of control,
including the information in Sec.  63.8(c)(8).
    (4) The date and time that each deviation started and stopped.
    (5) A summary of the total duration of the deviation during the
reporting period and the total duration as a percent of the total
source operating time during that reporting period.
    (6) An analysis of the total duration of the deviations during the
reporting period into those that are due to control equipment problems,
process problems, other known causes, and other unknown causes.
    (7) A summary of the total duration of CMS's downtime during the
reporting period and the total duration of CMS downtime as a percent of
the total source operating time during that reporting period.
    (8) An identification of each parameter that was monitored at the
affected source for which there was a deviation.
    (9) A brief description of the source for which there was a
deviation.
    (10) A brief description of each CMS for which there was a
deviation.
    (11) The date of the latest CMS certification or audit for the
system for which there was a deviation.
    (12) A description of any changes in CMSs, processes, or controls
since the last reporting period for the source for which there was a
deviation.
    (f) Each affected source that has obtained a Title V operating
permit pursuant to part 70 or part 71 of this chapter must report all
deviations as defined in this subpart in the semiannual monitoring
report required by Sec.  70.6(a)(3)(iii)(A) or Sec.
71.6(a)(3)(iii)(A). If an affected source submits a compliance report
pursuant to Table 9 to this subpart along with, or as part of, the
semiannual monitoring report required by Sec.  70.6(a)(3)(iii)(A) or
Sec.  71.6(a)(3)(iii)(A), and the compliance report includes all
required information concerning deviations from any emission limit,
operating limit, or work practice requirement in this subpart,
submission of the compliance report satisfies any obligation to report
the same deviations in the semiannual monitoring report. However,
submission of a compliance report does not otherwise affect any
obligation the affected source may have to report deviations from
permit requirements to the delegated authority.
    (g) (Reserved)
    (h) Within 60 days after the date of completing each performance
test, you must transmit the results of the performance tests required
by this subpart to EPA's WebFIRE database by using the Compliance and
Emissions Data Reporting Interface (CEDRI) that is accessed through
EPA's Central Data Exchange (CDX) (http://www.epa.gov/cdx). Performance
test data must be submitted in the file format generated through use of
EPA's Electronic Reporting Tool (ERT) (see http://www.epa.gov/ttn/chief/ert/index.html). Only data collected using test methods on the
ERT Web site are subject to this requirement for submitting reports
electronically to WebFIRE. Owners or operators who claim that some of
the information being submitted for performance tests is confidential
business information (CBI) must submit a complete ERT file including
information claimed to be CBI on a compact disk or other commonly used
electronic storage media (including, but not limited to, flash drives)
to the EPA. The electronic media must be clearly marked as CBI and
mailed to U.S. EPA/OAPQS/CORE CBI Office, Attention: WebFIRE
Administrator, MD C404-02, 4930 Old Page Rd., Durham, NC 27703. The
same ERT file with the CBI omitted must be submitted to EPA via CDX as
described earlier in this paragraph. At the discretion of the delegated
authority, you must also submit these reports, including the
confidential business information, to the delegated authority in the
format specified by the delegated authority.
    (i) Within 60 days after the date of completing each CEMS (CO and
Hg) performance evaluation test, as defined in Sec.  63.2 and required
by this subpart, you must submit the relative accuracy test audit data
electronically into EPA's Central Data Exchange by using the Electronic
Reporting Tool as described in paragraph (h) of this section. Only data
collected using test methods compatible with ERT are subject to this
requirement to be submitted electronically to EPA's CDX.
    (j) Within 60 days after the reporting periods ending on March 31,
June 30, September 30, and December 31, you must transmit quarterly
reports to EPA's WebFIRE database by using the Compliance and Emissions
Data Reporting Interface (CEDRI) that is accessed through EPA's Central
Data Exchange (CDX) (www.epa.gov/cdx). For each reporting period, the
quarterly reports must include all of the

calculated 30 day rolling average values based on the daily CEMS (CO
and Hg) and CPMS (PM CPMS output, scrubber pH, scrubber liquid flow
rate, scrubber pressure drop) data.

Sec.  63.7555  What records must I keep?

    (a) You must keep records according to paragraphs (a)(1) and (2) of
this section.
    (1) A copy of each notification and report that you submitted to
comply with this subpart, including all documentation supporting any
Initial Notification or Notification of Compliance Status or semiannual
compliance report that you submitted, according to the requirements in
Sec.  63.10(b)(2)(xiv).
    (2) Records of performance tests, fuel analyses, or other
compliance demonstrations and performance evaluations as required in
Sec.  63.10(b)(2)(viii).
    (b) For each CEMS, COMS, and continuous monitoring system you must
keep records according to paragraphs (b)(1) through (5) of this
section.
    (1) Records described in Sec.  63.10(b)(2)(vii) through (xi).
    (2) Monitoring data for continuous opacity monitoring system during
a performance evaluation as required in Sec.  63.6(h)(7)(i) and (ii).
    (3) Previous (i.e., superseded) versions of the performance
evaluation plan as required in Sec.  63.8(d)(3).
    (4) Request for alternatives to relative accuracy test for CEMS as
required in Sec.  63.8(f)(6)(i).
    (5) Records of the date and time that each deviation started and
stopped.
    (c) You must keep the records required in Table 8 to this subpart
including records of all monitoring data and calculated averages for
applicable operating limits, such as opacity, pressure drop, pH, and
operating load, to show continuous compliance with each emission limit
and operating limit that applies to you.
    (d) For each boiler or process heater subject to an emission limit
in Table 1 or 2 to this subpart, you must also keep the applicable
records in paragraphs (d)(1) through (9) of this section.
    (1) You must keep records of monthly fuel use by each boiler or
process heater, including the type(s) of fuel and amount(s) used.
    (2) If you combust non-hazardous secondary materials that have been
determined not to be solid waste pursuant to Sec.  241.3(b)(1) and (2),
you must keep a record that documents how the secondary material meets
each of the legitimacy criteria. If you combust a fuel that has been
processed from a discarded non-hazardous secondary material pursuant to
Sec.  241.3(b)(4), you must keep records as to how the operations that
produced the fuel satisfy the definition of processing in Sec.  241.2.
If the fuel received a non-waste determination pursuant to the petition
process submitted under Sec.  241.3(c), you must keep a record that
documents how the fuel satisfies the requirements of the petition
process. Units exempt from the incinerator standards under section
129(g)(1) of the Clean Air Act because they are qualifying facilities
burning a homogeneous waste stream do not need to maintain the records
described in this paragraph (d)(2).
    (3) You must keep records of monthly hours of operation by each
boiler or process heater that meets the definition of limited-use
boiler or process heater.
    (4) 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 hydrogen
chloride 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 hydrogen chloride emission rates, using Equation 11 of
Sec.  63.7530, that were done to demonstrate compliance with the
hydrogen chloride emission limit. Supporting documentation should
include results of any fuel analyses and basis for the estimates of
maximum chlorine fuel input or hydrogen chloride 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 hydrogen chloride
emission rate, for each boiler and process heater.
    (5) 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 12 of Sec.  63.7530, that
were done to demonstrate compliance with the mercury emission limit.
Supporting documentation should include results of any fuel analyses