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 8 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.

    (d) If you own or operate an existing unit with a heat input
capacity of 10 million Btu per hour or less, 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 submit the energy assessment report, along with a
signed certification that the assessment 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).

Continuous Compliance Requirements

Sec.  63.7535  How do I monitor and collect data to demonstrate
continuous compliance?

    (a) You must monitor and collect data according to this section and
the site-specific monitoring plan required by Sec.  63.7505(d).
    (b) Except for monitor malfunctions, associated repairs, and
required quality assurance or control activities (including, as
applicable, calibration checks and required zero and span adjustments),
you must monitor continuously (or collect data at all required
intervals) at all times that the affected source is operating.
    (c) You may not use data recorded during monitoring malfunctions,
associated repairs, or required quality assurance or control activities
in data averages and calculations used to report emission or operating
levels. You must use all the data collected during all other periods in
assessing the operation of the control device and associated control
system.

Sec.  63.7540  How do I demonstrate continuous compliance with the
emission limits and work practice standards?

    (a) You must demonstrate continuous compliance with each emission
limit, operating limit, and work practice standard in Tables 1 through
3 to this subpart that applies to you according to the methods
specified in Table 8 to this subpart and paragraphs (a)(1) through (10)
of this section.
    (1) Following the date on which the initial performance test is
completed or is required to be completed under Sec. Sec.  63.7 and
63.7510, whichever date comes first, you must not operate above any of
the applicable maximum operating limits or below any of the applicable
minimum operating limits listed in Table 4 to this subpart at any
times. Operation above the established maximum or below the established
minimum operating limits shall constitute a deviation of established
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 either result in lower emissions of HCl
and mercury, than the applicable emission limit for each pollutant (if
you demonstrate compliance through fuel analysis), or result in lower
fuel input of chlorine and mercury than the maximum values calculated
during the last performance tests (if you demonstrate compliance
through performance stack testing).
    (3) If you demonstrate compliance with an applicable HCl emission
limit through fuel analysis and you plan to burn a new type of fuel,
you must recalculate the HCl emission rate using Equation 9 of Sec.
63.7530 according to paragraphs (a)(3)(i) through (iii) of this
section.
    (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 HCl emission rate from your boiler or process
heater under these new conditions using Equation 9 of Sec.  63.7530.
The recalculated HCl emission rate must be less than the applicable
emission limit.
    (4) If you demonstrate compliance with an applicable HCl 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 5 of Sec.  63.7530. If the results of
recalculating the maximum chlorine input using Equation 5 of Sec.
63.7530 are higher 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 HCl 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(c).
    (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
11 of Sec.  63.7530 according to the procedures specified in paragraphs
(a)(7)(i) through (iii) of this section.
    (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 11 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 7 of Sec.  63.7530. If the results
of recalculating the maximum mercury input using Equation 7 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(c).
    (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 are required to install a CEMS according to Sec.
63.7525(a), then you must meet the requirements in paragraphs (a)(8)(i)
through (iii) of this section.
    (i) You must continuously monitor CO according to Sec. Sec.
63.7525(a) and 63.7535.
    (ii) Maintain a CO emission level below or at your applicable CO
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 CEMS
measuring PM emissions to meet requirements of this subpart shall
install, certify, operate, and maintain the CEMS as specified in
paragraphs (a)(9)(i) through (a)(9)(iv) of this section.
    (i) The owner or operator shall conduct a performance evaluation of
the CEMS according to the applicable requirements of Sec.  60.13 of 40
CFR, Performance Specification 11 in appendix B of 40 CFR part 60, and
procedure 2 in appendix F of 40 CFR part 60.
    (ii) During each PM correlation testing run of the CEMS required by
Performance Specification 11 in appendix B of 40 CFR part 60, PM and O2
(or CO2) data shall be collected concurrently (or within a 30- to 60-
minute period) by both the CEMS and conducting performance tests using
Method 5 or 5B of appendix A-3 of 40 CFR part 60 or Method 17 of
appendix A-6 of 40 CFR part 60.
    (iii) Quarterly accuracy determinations and daily calibration drift
tests shall be performed in accordance with procedure 2 in appendix F
of 40 CFR part 60. Relative Response Audits must be performed annually
and Response Correlation Audits must be performed every 3 years.
    (iv) After December 31, 2011, within 60 days after the date of
completing each performance evaluation conducted to demonstrate
compliance with this subpart, the owner or operator of the affected
facility must submit the test data to EPA by successfully entering the
data electronically into EPA's WebFIRE database through EPA's Central
Data Exchange. The owner or operator of an affected facility shall
enter the test data into EPA's data base using the Electronic Reporting
Tool (ERT) or other compatible electronic spreadsheet.
    (10) If your boiler or process heater is in either the Gas 1 (NG/
RG) or Metal Process Furnace subcategories and have 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
(a)(10)(vi) of this section.
    (i) Inspect the burner, and clean or replace any components of the
burner as necessary;
    (ii) Inspect the flame pattern and make any adjustments to the
burner necessary to optimize the flame pattern consistent with the
manufacturer's specifications;
    (iii) Inspect the system controlling the air-to-fuel ratio, and
ensure that it is correctly calibrated and functioning properly;
    (iv) Minimize total emissions of CO consistent with the
manufacturer's specifications;
    (v) Measure the concentration in the effluent stream of CO in parts
per million, by volume, dry basis (ppmvd), 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 CO in the effluent stream in ppmvd, and
oxygen in percent dry basis, 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.
    (11) If your boiler or process heater has a heat input capacity of
less than 10 million Btu per hour, you must conduct a tune-up of the
boiler or process heater biennially to demonstrate continuous
compliance as specified in paragraphs (a)(10)(i) through (a)(10)(vi) of
this section.
    (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 in this subpart. These deviations must be reported
according to the requirements in Sec.  63.7550.

Sec.  63.7541  How do I demonstrate continuous compliance under the
emission 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) through (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 nonaffected 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 3-hour
average parameter values at or below the operating limits established
during the most recent performance test; and
    (4) For each existing unit participating in the emissions averaging
option that has an approved alternative operating plan, maintain the 3-
hour 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 all of the notifications in Sec. Sec.  63.7(b)
and (c), 63.8 (e), (f)(4) and (6), and 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 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 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
30 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 each initial compliance demonstration, 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 the performance test and/or other initial
compliance demonstrations according to Sec.  63.10(d)(2). The
Notification of Compliance Status report must contain all the
information specified in paragraphs (e)(1) through (9) of this section,
as applicable.
    (1) A description of the affected source(s) including
identification of which subcategory the source is in, the design
capacity of the source, a description of the add-on controls used on
the source, 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 40 CFR 241.3, whether the fuel(s) were processed from
discarded non-hazardous secondary materials within the meaning of 40
CFR 241.3, and justification for the selection of fuel(s) burned during
the performance test.
    (2) Summary of the results of all performance tests (stack tests
and fuel analyses) and calculations conducted to demonstrate initial
compliance including all established operating limits.
    (3) A summary of the CO emissions monitoring data and the maximum
CO 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.
    (4) Identification of whether you plan to demonstrate compliance
with each applicable emission limit through performance stack testing
or fuel analysis.
    (5) Identification of whether you plan to demonstrate compliance by
emissions averaging.
    (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.
    (f) If you operate a natural gas-fired boiler or process heater
that is subject to this subpart, and you intend to use a fuel other
than natural gas or equivalent to fire the affected unit, you must
submit a notification of alternative fuel use within 48 hours of the
declaration of a 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.

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.
    (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 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.
    (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.
    (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.

    (5) For each affected source that is subject to permitting
regulations pursuant to 40 CFR part 70 or 40 CFR part 71, and if the
permitting authority has established dates for submitting semiannual
reports pursuant to 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR
71.6(a)(3)(iii)(A), you may submit the first and subsequent compliance
reports according to the dates the permitting authority has established
instead of according to the dates in paragraphs (b)(1) through (4) of
this section.
    (c) The compliance report must contain the information required in
paragraphs (c)(1) through (9) 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 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 and
documentation of any operating limits that were reestablished during
this test, if applicable. If you are conducting stack tests once every
three years consistent with Sec.  63.7515(b) or (c), the date of the
last three stack tests, a comparison of the emission level you achieved
in the last three stack tests to the 90 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 stack
test that could increase emissions.
    (6) A signed statement indicating that you burned no new types of
fuel. Or, if you did burn a new type of fuel, 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 HCl emission rate using Equation 9 of
Sec.  63.7530 that demonstrates that your source is still meeting the
emission limit for HCl emissions (for boilers or process heaters that
demonstrate compliance through fuel analysis). If you burned a new type
of fuel, you must submit the calculation of mercury input, using
Equation 7 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 11 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).
    (7) If you wish to burn a new type of fuel and you cannot
demonstrate compliance with the maximum chlorine input operating limit
using Equation 5 of Sec.  63.7530 or the maximum mercury input
operating limit using Equation 7 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) 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.
    (9) If there were no deviations from the monitoring requirements
including no periods during which the CMSs, including CEMS, COMS, and
CPMS, 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.
    (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, and
whether each deviation occurred during a period of startup, shutdown,
or malfunction or during another period.
    (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 startup, shutdown, control
equipment problems, process problems, other known causes, and other
unknown causes.
    (7) A summary of the total duration of CMSs 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 40 CFR part 70 or 40 CFR part 71 must report all
deviations as defined in this subpart in the semiannual monitoring
report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR
71.6(a)(3)(iii)(A). If an affected source submits a compliance report
pursuant to Table 9 to this subpart along with, or as part of, the
semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or
40 CFR 71.6(a)(3)(iii)(A), and the compliance report 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 permit authority.
    (g) In addition to the information required in Sec.  63.9(h)(2),
your notification must include the following certification(s) of
compliance, as applicable, and signed by a responsible official:
    (1) ``This facility complies with the requirements in Sec.
63.7540(a)(10) to conduct an annual tune-up of the unit''.
    (2) ``This facility has had an energy assessment performed
according to Sec.  63.7530(e).''
    (3) ``No secondary materials that are solid waste were combusted in
any affected unit.''
    (h) After December 31, 2011, within 60 days after the date of
completing each performance evaluation conducted to demonstrate
compliance with this subpart, the owner or operator of the affected
facility must submit the test data to EPA by entering the data
electronically into EPA's WebFIRE data base through EPA's Central Data
Exchange. The owner or operator of an affected facility shall enter the
test data into EPA's data base using the Electronic Reporting Tool or
other compatible electronic spreadsheet. Only performance evaluation
data collected using methods compatible with ERT are subject to this
requirement to be submitted electronically into EPA's WebFIRE database.

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 stack tests, fuel analyses, or other
compliance demonstrations, performance evaluations, and opacity
observations as required in Sec.  63.10(b)(2)(viii).
    (b) For each CEMS, CPMS, and COMS, you must keep records according
to paragraphs (b)(1) through (5) of this section.
    (1) Records described in Sec.  63.10(b)(2)(vi) 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, and whether the deviation occurred during a period of startup,
shutdown, or malfunction or during another period.
    (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, and pH 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,
you must also keep the records in paragraphs (d)(1) through (5) 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 40 CFR 41.3(b)(1), you
must keep a record which 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
40 CFR 241.3(b)(2), you must keep records as to how the operations that
produced the fuel satisfies the definition of processing in 40 CFR
241.2. If the fuel received a non-waste determination pursuant to the
petition process submitted under 40 CFR 241.3(c), you must keep a
record which documents how the fuel satisfies the requirements of the
petition process.
    (3) You must keep records of monthly hours of operation by each
boiler or process heater. This requirement applies only to limited-use
boilers and process heaters.
    (4) A copy of all calculations and supporting documentation of
maximum chlorine fuel input, using Equation 5 of Sec.  63.7530, that
were done to demonstrate continuous compliance with the HCl emission
limit, for sources that demonstrate compliance through performance
testing. For sources that demonstrate compliance through fuel analysis,
a copy of all calculations and supporting documentation of HCl emission
rates, using Equation 9 of Sec.  63.7530, that were done to demonstrate
compliance with the HCl emission limit. Supporting documentation should
include results of any fuel analyses and basis for the estimates of
maximum chlorine fuel input or HCl emission rates. You can use the
results from one fuel analysis for multiple boilers and process heaters
provided they are all burning the same fuel type. However, you must
calculate chlorine fuel input, or HCl emission rate, for each boiler
and process heater.
    (5) A copy of all calculations and supporting documentation of
maximum mercury fuel input, using Equation 7 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 11 of Sec.  63.7530, that
were done to demonstrate compliance with the mercury emission limit.
Supporting documentation should include results of any fuel analyses
and basis for the estimates of maximum mercury fuel input or mercury
emission rates. You can use the results from one fuel analysis for
multiple boilers and process heaters provided they are all burning the
same fuel type. However, you must calculate mercury fuel input, or
mercury emission rates, for each boiler and process heater.
    (6) If consistent with Sec.  63.7555(b) and (c), you choose to
stack test less frequently than annually, you must keep annual records
that document that your emissions in the previous stack test(s) were
less than 90 percent of the applicable emission limit, and document
that there was no change in source operations including fuel
composition and operation of air pollution control equipment that would
cause emissions of the relevant pollutant to increase within the past
year.
    (7) If you operate a gaseous fuel unit that is subject to the
emission limits specified in Table 1 or 2 to this subpart, and you
intend to use a fuel other than natural gas or equivalent to fire the
affected unit, you must keep records of the information required by the
notification under Sec.  63.7550, and records of the total hours per
calendar year that liquid fuel is burned.
    (e) If you elect to average emissions consistent with Sec.
63.7522, you must additionally keep a copy of the emission averaging
implementation plan required in Sec.  63.7522(g), all calculations
required

under Sec.  63.7522, including daily records of heat input or steam
generation, as applicable, and monitoring records consistent with Sec.
63.7541.

Sec.  63.7560  In what form and how long must I keep my records?

    (a) Your records must be in a form suitable and readily available
for expeditious review, according to Sec.  63.10(b)(1).
    (b) As specified in Sec.  63.10(b)(1), you must keep each record
for 5 years following the date of each occurrence, measurement,
maintenance, corrective action, report, or record.
    (c) You must keep each record on site for at least 2 years after
the date of each occurrence, measurement, maintenance, corrective
action, report, or record, according to Sec.  63.10(b)(1). You can keep
the records off site for the remaining 3 years.

Other Requirements and Information

Sec.  63.7565  What parts of the General Provisions apply to me?

    Table 10 to this subpart shows which parts of the General
Provisions in Sec. Sec.  63.1 through 63.15 apply to you.

Sec.  63.7570  Who implements and enforces this subpart?

    (a) This subpart can be implemented and enforced by U.S. EPA, or a
delegated authority such as your State, local, or tribal agency. If the
EPA Administrator has delegated authority to your State, local, or
tribal agency, then that agency (as well as the U.S. EPA) has the
authority to implement and enforce this subpart. You should contact
your EPA Regional Office to find out if this subpart is delegated to
your State, local, or tribal agency.
    (b) In delegating implementation and enforcement authority of this
subpart to a State, local, or tribal agency under 40 CFR part 63,
subpart E, the authorities listed in paragraphs (b)(1) through (5) of
this section are retained by the EPA Administrator and are not
transferred to the State, local, or tribal agency, however, the U.S.
EPA retains oversight of this subpart and can take enforcement actions,
as appropriate.
    (1) Approval of alternatives to the non-opacity emission limits and
work practice standards in Sec.  63.7500(a) and (b) under Sec.
63.6(g).
    (2) Approval of alternative opacity emission limits in Sec.
63.7500(a) under Sec.  63.6(h)(9).
    (3) Approval of major change to test methods in Table 5 to this
subpart under Sec.  63.7(e)(2)(ii) and (f) and as defined in Sec.
63.90, and alternative analytical methods requested under
63.7521(b)(2).
    (4) Approval of major change to monitoring under Sec.  63.8(f) and
as defined in Sec.  63.90, and approval of alternative operating
parameters under 63.7500(a)(2) and 63.7522(g)(2).
    (5) Approval of major change to recordkeeping and reporting under
Sec.  63.10(e) and as defined in Sec.  63.90.

Sec.  63.7575  What definitions apply to this subpart?

    Terms used in this subpart are defined in the Clean Air Act (CAA),
in Sec.  63.2 (the General Provisions), and in this section as follows:
    Bag leak detection system means a group of instruments that are
capable of monitoring particulate matter loadings in the exhaust of a
fabric filter (i.e., baghouse) in order to detect bag failures. A bag
leak detection system includes, but is not limited to, an instrument
that operates on electrodynamic, triboelectric, light scattering, light
transmittance, or other principle to monitor relative particulate
matter loadings.
    Biomass fuel means but is not limited to, wood residue, and wood
products (e.g., trees, tree stumps, tree limbs, bark, lumber, sawdust,
sanderdust, chips, scraps, slabs, millings, and shavings); animal
manure, including litter and other bedding materials; vegetative
agricultural and silvicultural materials, such as logging residues
(slash), nut and grain hulls and chaff (e.g., almond, walnut, peanut,
rice, and wheat), bagasse, orchard prunings, corn stalks, coffee bean
hulls and grounds. This definition of biomass fuel is not intended to
suggest that these materials are or are not solid waste.
    Blast furnace gas fuel-fired boiler or process heater means an
industrial/commercial/institutional boiler or process heater that
receives 90 percent or more of its total heat input (based on an annual
average) from blast furnace gas.
    Boiler means an enclosed device using controlled flame combustion
and having the primary purpose of recovering thermal energy in the form
of steam or hot water. A device combusting solid waste, as defined in
40 CFR 241.3, is not a boiler. Waste heat boilers are excluded from
this definition.
    Boiler system means the boiler and associated components, such as,
the feedwater system, the combustion air system, the fuel system
(including burners), blowdown system, combustion control system, and
energy consuming systems.
    Coal means all solid fuels classifiable as anthracite, bituminous,
sub-bituminous, or lignite by the American Society for Testing and
Materials in ASTM D388-991.\1\, ``Standard Specification for
Classification of Coals by Rank'' \1\ (incorporated by reference, see
Sec.  63.14(b)), coal refuse, and petroleum coke. Synthetic fuels
derived from coal for the purpose of creating useful heat including,
but not limited to, solvent-refined coal, coal-oil mixtures, and coal-
water mixtures, for the purposes of this subpart. Coal derived gases
are excluded from this definition.
    Coal refuse means any by-product of coal mining or coal cleaning
operations with an ash content greater than 50 percent (by weight) and
a heating value less than 13,900 kilojoules per kilogram (6,000 Btu per
pound) on a dry basis.
    Commercial/institutional boiler means a boiler used in commercial
establishments or institutional establishments such as medical centers,
research centers, institutions of higher education, hotels, and
laundries to provide electricity, steam, and/or hot water.
    Common stack means the exhaust of emissions from two or more
affected units through a single flue.
    Cost-effective energy conservation measure means a measure that is
implemented to improve the energy efficiency of the boiler or facility
that has a payback (return of investment) period of two years or less.
    Deviation. (1) Deviation means any instance in which an affected
source subject to this subpart, or an owner or operator of such a
source:
    (i) Fails to meet any requirement or obligation established by this
subpart including, but not limited to, any emission limit, operating
limit, or work practice standard; or
    (ii) Fails to meet any term or condition that is adopted to
implement an applicable requirement in this subpart and that is
included in the operating permit for any affected source required to
obtain such a permit.
    (2) A deviation is not always a violation. The determination of
whether a deviation constitutes a violation of the standard is up to
the discretion of the entity responsible for enforcement of the
standards.
    Distillate oil means fuel oils, including recycled oils, that
comply with the specifications for fuel oil numbers 1 and 2, as defined
by the American Society for Testing and Materials in ASTM D396-02a,
``Standard Specifications for Fuel Oils'' \1\ (incorporated by
reference, see Sec.  63.14(b)).
    Dry scrubber means an add-on air pollution control system that
injects dry alkaline sorbent (dry injection) or sprays an alkaline
sorbent (spray dryer) to react

with and neutralize acid gas in the exhaust stream forming a dry powder
material. Sorbent injection systems in fluidized bed boilers and
process heaters are included in this definition.
    Dutch oven means a unit having a refractory-walled cell connected
to a conventional boiler setting. Fuel materials are introduced through
an opening in the roof of the Dutch oven and burn in a pile on its
floor.
    Electric utility steam generating unit means a fossil fuel-fired
combustion unit of more than 25 megawatts that serves a generator that
produces electricity for sale. A fossil fuel-fired unit that
cogenerates steam and electricity and supplies more than one-third of
its potential electric output capacity and more than 25 megawatts
electrical output to any utility power distribution system for sale is
considered an electric utility steam generating unit.
    Electrostatic precipitator means an add-on air pollution control
device used to capture particulate matter by charging the particles
using an electrostatic field, collecting the particles using a grounded
collecting surface, and transporting the particles into a hopper.
    Energy assessment means an in-depth assessment of a facility to
identify immediate and long-term opportunities to save energy, focusing
on the steam and process heating systems which involves a thorough
examination of potential savings from energy efficiency improvements,
waste minimization and pollution prevention, and productivity
improvement.
    Equivalent means the following only as this term is used in Table 6
to subpart DDDDD:
    (1) An equivalent sample collection procedure means a published
voluntary consensus standard or practice (VCS) or EPA method that
includes collection of a minimum of three composite fuel samples, with
each composite consisting of a minimum of three increments collected at
approximately equal intervals over the test period.
    (2) An equivalent sample compositing procedure means a published
VCS or EPA method to systematically mix and obtain a representative
subsample (part) of the composite sample.
    (3) An equivalent sample preparation procedure means a published
VCS or EPA method that: Clearly states that the standard, practice or
method is appropriate for the pollutant and the fuel matrix; or is
cited as an appropriate sample preparation standard, practice or method
for the pollutant in the chosen VCS or EPA determinative or analytical
method.
    (4) An equivalent procedure for determining heat content means a
published VCS or EPA method to obtain gross calorific (or higher
heating) value.
    (5) An equivalent procedure for determining fuel moisture content
means a published VCS or EPA method to obtain moisture content. If the
sample analysis plan calls for determining metals (especially the
mercury, selenium, or arsenic) using an aliquot of the dried sample,
then the drying temperature must be modified to prevent vaporizing
these metals. On the other hand, if metals analysis is done on an ``as
received'' basis, a separate aliquot can be dried to determine moisture
content and the metals concentration mathematically adjusted to a dry
basis.
    (6) An equivalent pollutant (mercury) determinative or analytical
procedure means a published VCS or EPA method that clearly states that
the standard, practice, or method is appropriate for the pollutant and
the fuel matrix and has a published detection limit equal to or lower
than the methods listed in Table 6 to subpart DDDDD for the same
purpose.
    Fabric filter means an add-on air pollution control device used to
capture particulate matter by filtering gas streams through filter
media, also known as a baghouse.
    Federally enforceable means all limitations and conditions that are
enforceable by the EPA Administrator, including the requirements of 40
CFR parts 60 and 61, requirements within any applicable State
implementation plan, and any permit requirements established under 40
CFR 52.21 or under 40 CFR 51.18 and 40 CFR 51.24.
    Fuel type means each category of fuels that share a common name or
classification. Examples include, but are not limited to, bituminous
coal, subbituminous coal, lignite, anthracite, biomass, residual oil.
Individual fuel types received from different suppliers are not
considered new fuel types.
    Fluidized bed boiler means a boiler utilizing a fluidized bed
combustion process.
    Fluidized bed combustion means a process where a fuel is burned in
a bed of granulated particles which are maintained in a mobile
suspension by the forward flow of air and combustion products.
    Fuel cell means a boiler type in which the fuel is dropped onto
suspended fixed grates and is fired in a pile. The refractory-lined
fuel cell uses combustion air preheating and positioning of secondary
and tertiary air injection ports to improve boiler efficiency.
    Gaseous fuel includes, but is not limited to, natural gas, process
gas, landfill gas, coal derived gas, refinery gas, and biogas. Blast
furnace gas is exempted from this definition.
    Heat input means heat derived from combustion of fuel in a boiler
or process heater and does not include the heat input from preheated
combustion air, recirculated flue gases, or exhaust gases from other
sources such as gas turbines, internal combustion engines, kilns, etc.
    Hot water heater means a closed vessel with a capacity of no more
than 120 U.S. gallons in which water is heated by combustion of gaseous
or liquid fuel and is withdrawn for use external to the vessel at
pressures not exceeding 160 psig, including the apparatus by which the
heat is generated and all controls and devices necessary to prevent
water temperatures from exceeding 210 [deg] F (99 [deg] C).
    Industrial boiler means a boiler used in manufacturing, processing,
mining, and refining or any other industry to provide steam, hot water,
and/or electricity.
    Liquid fuel includes, but is not limited to, distillate oil,
residual oil, on-spec used oil, and biodiesel.
    Liquid fuel subcategory includes any boiler or process heater of
any design that burns more than 10 percent liquid fuel and less than 10
percent solid fuel, on an annual heat input basis.
    Metal process furnaces include natural gas-fired annealing
furnaces, preheat furnaces, reheat furnaces, aging furnaces, and heat
treat furnaces.
    Minimum pressure drop means 90 percent of the test average pressure
drop measured according to Table 7 to this subpart during the most
recent performance test demonstrating compliance with the applicable
emission limit.
    Minimum scrubber effluent pH means 90 percent of the test average
effluent pH measured at the outlet of the wet scrubber according to
Table 7 to this subpart during the most recent performance test
demonstrating compliance with the applicable hydrogen chloride emission
limit.
    Minimum scrubber flow rate means 90 percent of the test average
flow rate measured according to Table 7 to this subpart during the most
recent performance test demonstrating compliance with the applicable
emission limit.
    Minimum sorbent injection rate means 90 percent of the test average
sorbent (or activated carbon) injection rate for each sorbent measured
according to Table 7 to this subpart during the most recent performance
test

demonstrating compliance with the applicable emission limits.
    Minimum voltage or amperage means 90 percent of the test average
voltage or amperage to the electrostatic precipitator measured
according to Table 7 to this subpart during the most recent performance
test demonstrating compliance with the applicable emission limits.
    Natural gas means:
    (1) A naturally occurring mixture of hydrocarbon and nonhydrocarbon
gases found in geologic formations beneath the earth's surface, of
which the principal constituent is methane; or
    (2) Liquid petroleum gas, as defined by the American Society for
Testing and Materials in ASTM D1835-03a, ``Standard Specification for
Liquid Petroleum Gases'' (incorporated by reference, see Sec.
63.14(b)).
    Opacity means the degree to which emissions reduce the transmission
of light and obscure the view of an object in the background.
    Particulate matter means any finely divided solid or liquid
material, other than uncombined water, as measured by the test methods
specified under this subpart, or an alternative method.
    Period of natural gas curtailment or supply interruption means a
period of time during which the supply of natural gas to an affected
facility is halted for reasons beyond the control of the facility. An
increase in the cost or unit price of natural gas does not constitute a
period of natural gas curtailment or supply interruption.
    Process heater means an enclosed device using controlled flame,
that is not a boiler, and the unit's primary purpose is to transfer
heat indirectly to a process material (liquid, gas, or solid) or to a
heat transfer material for use in a process unit, instead of generating
steam. Process heaters are devices in which the combustion gases do not
directly come into contact with process materials. A device combusting
solid waste, as defined in 40 CFR 241.3, is not a process heater.
Process heaters do not include units used for comfort heat or space
heat, food preparation for on-site consumption, or autoclaves.
    Pulverized coal boiler means a boiler in which pulverized coal is
introduced into an air stream that carries the coal to the combustion
chamber of the boiler where it is fired in suspension.
    Qualified personnel means specialists in evaluating energy systems,
such as those who have successfully completed the DOE Qualified
Specialist program for all systems, Certified Energy Manager certified
by the Association of Energy Engineers, or the equivalent.
    Residual oil means crude oil, and all fuel oil numbers 4, 5 and 6,
as defined by the American Society for Testing and Materials in ASTM
D396-02a, ``Standard Specifications for Fuel Oils \1\'' (incorporated
by reference, see Sec.  63.14(b)).
    Responsible official means responsible official as defined in 40
CFR 70.2.
    Stoker means a unit consisting of a mechanically operated fuel
feeding mechanism, a stationary or moving grate to support the burning
of fuel and admit undergrate air to the fuel, an overfire air system to
complete combustion, and an ash discharge system. There are two general
types of stokers: Underfeed and overfeed. Overfeed stokers include mass
feed and spreader stokers.
    Suspension boiler means a unit designed to feed the fuel by means
of fuel distributors. The distributors inject air at the point where
the fuel is introduced into the boiler in order to spread the fuel
material over the boiler width. The drying (and much of the combustion)
occurs while the material is suspended in air. The combustion of the
fuel material is completed on a grate or floor below. Suspension
boilers almost universally are designed to have high heat release rates
to quickly dry the wet fuel as it is blown into the boilers.
    Temporary boiler means any gaseous or liquid fuel boiler that is
designed to, and is capable of, being carried or moved from one
location to another. A temporary boiler that remains at a location for
more than 180 consecutive days is no longer considered to be a
temporary boiler. Any temporary boiler that replaces a temporary boiler
at a location and is intended to perform the same or similar function
will be included in calculating the consecutive time period.
    Tune-up means adjustments made to a boiler in accordance with
procedures supplied by the manufacturer (or an approved specialist) to
optimize the combustion efficiency.
    Unit designed to burn biomass subcategory includes any boiler or
process heater that burns at least 10 percent biomass, but less than 10
percent coal, on a heat input basis on an annual average, either alone
or in combination with liquid fuels or gaseous fuels.
    Unit designed to burn coal subcategory includes any boiler or
process heater that burns any coal alone or at least 10 percent coal on
a heat input basis on an annual average in combination with biomass,
liquid fuels, or gaseous fuels.
    Unit designed to burn gas 1 (NG/RG) subcategory includes any boiler
or process heater that burns at least 90 percent natural gas and/or
refinery gas on a heat input basis on an annual average.
    Unit designed to burn gas 2 (other) subcategory includes any boiler
or process heater that burns gaseous fuels other than natural gas and/
or refinery gas not combined with any solid or liquid fuels.
    Unit designed to burn oil subcategory includes any boiler or
process heater that burns any liquid fuel, but less than 10 percent
solid fuel on a heat input basis on an annual average, either alone or
in combination with gaseous fuels. Gaseous fuel boilers and process
heaters that burn liquid fuel during periods of gas curtailment, gas
supply emergencies or for periodic testing of liquid fuel not to exceed
a combined total of 48 hours during any calendar year are not included
in this definition.
    Voluntary Consensus Standards or VCS mean technical standards
(e.g., materials specifications, test methods, sampling procedures,
business practices) developed or adopted by one or more voluntary
consensus bodies. EPA/OAQPS has by precedent only used VCS that are
written in English. Examples of VCS bodies are: American Society of
Testing and Materials (ASTM), American Society of Mechanical Engineers
(ASME), International Standards Organization (ISO), Standards Australia
(AS), British Standards (BS), Canadian Standards (CSA), European
Standard (EN or CEN) and German Engineering Standards (VDI). The types
of standards that are not considered VCS are standards developed by:
The U.S. states, e.g., California (CARB) and Texas (TCEQ); industry
groups, such as American Petroleum Institute (API), Gas Processors
Association (GPA), and Gas Research Institute (GRI); and other branches
of the U.S. government, e.g., Department of Defense (DOD) and
Department of Transportation (DOT). This does not preclude EPA from
using standards developed by groups that are not VCS bodies within
their rule. When this occurs, EPA has done searches and reviews for VCS
equivalent to these non-EPA methods.
    Waste heat boiler means a device that recovers normally unused
energy and converts it to usable heat. Waste heat recovery boilers
incorporating duct or supplemental burners that are designed to supply
50 percent or more of the total rated heat input capacity of the waste
heat boiler are not considered waste heat boilers, but are considered
boilers. Waste heat boilers are also referred to as heat recovery steam
generators.

    Waste heat process heater means an enclosed device that recovers
normally unused energy and converts it to usable heat. Waste heat
process heaters incorporating duct or supplemental burners that are
designed to supply 50 percent or more of the total rated heat input
capacity of the waste heat process heater are not considered waste heat
process heaters, but are considered process heaters. Waste heat process
heaters are also referred to as recuperative process heaters.
    Wet scrubber means any add-on air pollution control device that
mixes an aqueous stream or slurry with the exhaust gases from a boiler
or process heater to control emissions of particulate matter and/or to
absorb and neutralize acid gases, such as hydrogen chloride.
    Work practice standard means any design, equipment, work practice,
or operational standard, or combination thereof, that is promulgated
pursuant to section 112(h) of the CAA.

Tables to Subpart DDDDD of Part 63

    As stated in Sec.  63.7500, you must comply with the following
applicable emission limits:

     Table 1 to Subpart DDDDD of Part 63--Emission Limits for New or
                Reconstructed Boilers and Process Heaters
------------------------------------------------------------------------
                                                     You must meet the
   If your boiler or process    For the following    following emission
 heater is in this subcategory   pollutants . . .     limits and work
             . . .                                 practice  standards .
                                                            . .
------------------------------------------------------------------------
1. Pulverized coal............  a. Particulate     0.001 lb per MMBtu of
                                 Matter.            heat input.
                                b. Hydrogen        0.00006 lb per MMBtu
                                 Chloride.          of heat input.
                                c. Mercury.......  2.0E-06 lb per MMBtu
                                                    of heat input.
                                d. CO............  90 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.002 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
2. Stokers designed to burn     a. Particulate     0.001 lb per MMBtu of
 coal.                           Matter.            heat input.
                                b. Hydrogen        0.00006 lb per MMBtu
                                 Chloride.          of heat input.
                                c. Mercury.......  2.0E-06 lb per MMBtu
                                                    of heat input.
                                d. CO............  7 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.003 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
3. Fluidized bed units          a. Particulate     0.001 lb per MMBtu of
 designed to burn coal.          Matter.            heat input.
                                b. Hydrogen        0.00006 lb per MMBtu
                                 Chloride.          of heat input.
                                c. Mercury.......  2.0E-06 lb per MMBtu
                                                    of heat input.
                                d. CO............  30 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.00003 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
4. Stokers designed to burn     a. Particulate     0.008 lb per MMBtu of
 biomass.                        Matter.            heat input.
                                b. Hydrogen        0.004 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  2.0E-07 lb per MMBtu
                                d. CO............   of heat input.
                                                   560 ppm by volume on
                                                    a dry basis
                                                    corrected to 3
                                                    percent oxygen (30-
                                                    day rolling average
                                                    for units 100 MMBtu/
                                                    hr or greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.00005 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
5. Fluidized bed units          a. Particulate     0.008 lb per MMBtu of
 designed to burn biomass.       Matter.            heat input.
                                b. Hydrogen        0.004 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  2.0E-07 lb per MMBtu
                                                    of heat input.
                                d. CO............  40 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.007 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
6. Suspension burners/Dutch     a. Particulate     0.008 lb per MMBtu of
 Ovens designed to burn          Matter.            heat input.
 biomass.                       b. Hydrogen        0.004 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  2.0E-07 lb per MMBtu
                                d. CO............   of heat input.
                                                   1,010 ppm by volume
                                                    on a dry basis
                                                    corrected to 3
                                                    percent oxygen (30-
                                                    day rolling average
                                                    for units 100 MMBtu/
                                                    hr or greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.03 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
7. Fuel cells designed to burn  a. Particulate     0.008 lb per MMBtu of
 biomass.                        Matter.            heat input.
                                b. Hydrogen        0.004 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  2.0E-07 lb per MMBtu
                                d. CO............   of heat input.
                                                   270 ppm by volume on
                                                    a dry basis
                                                    corrected to 3
                                                    percent oxygen (30-
                                                    day rolling average
                                                    for units 100 MMBtu/
                                                    hr or greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.0005 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
8. Units designed to burn       a. Particulate     0.002 lb per MMBtu of
 liquid fuel.                    Matter.            heat input.
                                b. Hydrogen        0.0004 lb per MMBtu
                                 Chloride.          of heat input.
                                c. Mercury.......  3.0E-07 lb per MMBtu
                                                    of heat input.
                                d. CO............  1 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.002 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.

9. Units designed to burn       a. Particulate     0.003 lb per MMBtu of
 other gases.                    Matter.            heat input.
                                b. Hydrogen        3.0E-06 lb per MMBtu
                                 Chloride.          of heat input.
                                c. Mercury.......  2.0E-07 lb per MMBtu
                                d. CO............   of heat input.
                                                   1 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.009 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
------------------------------------------------------------------------

    As stated in Sec.  63.7500, you must comply with the following
applicable emission limits:

    Table 2 to Subpart DDDDD of Part 63--Emission Limits for Existing
                       Boilers and Process Heaters
 [Units with heat input capacity of 10 million Btu per hour or greater]
------------------------------------------------------------------------
                                                     You must meet the
   If your boiler or process    For the following    following emission
 heater is in this subcategory   pollutants . . .     limits and work
             . . .                                 practice  standards .
                                                            . .
------------------------------------------------------------------------
1. Pulverized coal............  a. Particulate     0.02 lb per MMBtu of
                                 Matter.            heat input.
                                b. Hydrogen        0.02 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  3.0E-06 lb per MMBtu
                                                    of heat input.
                                d. CO............  90 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.004 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
2. Stokers designed to burn     a. Particulate     0.02 lb per MMBtu of
 coal.                           Matter.            heat input.
                                b. Hydrogen        0.02 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  3.0E-06 lb per MMBtu
                                                    of heat input.
                                d. CO............  50 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.003 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
3. Fluidized bed units          a. Particulate     0.02 lb per MMBtu of
 designed to burn coal.          Matter.            heat input.
                                b. Hydrogen        0.02 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  3.0E-06 lb per MMBtu
                                                    of heat input.
                                d. CO............  30 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.002 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
4. Stokers designed to burn     a. Particulate     0.02 lb per MMBtu of
 biomass.                        Matter.            heat input.
                                b. Hydrogen        0.006 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  9.0E-07 lb per MMBtu
                                d. CO............   of heat input.
                                                   560 ppm by volume on
                                                    a dry basis
                                                    corrected to 3
                                                    percent oxygen (30-
                                                    day rolling average
                                                    for units 100 MMBtu/
                                                    hr or greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.004 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
5. Fluidized bed units          a. Particulate     0.02 lb per MMBtu of
 designed to burn biomass.       Matter.            heat input.
                                b. Hydrogen        0.006 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  9.0E-07 lb per MMBtu
                                                    of heat input.
                                d. CO............  250 ppm by volume on
                                                    a dry basis
                                                    corrected to 3
                                                    percent oxygen (30-
                                                    day rolling average
                                                    for units 100 MMBtu/
                                                    hr or greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.02 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
6. Suspension burners/Dutch     a. Particulate     0.02 lb per MMBtu of
 Ovens designed to burn          Matter.            heat input.
 biomass.                       b. Hydrogen        0.006 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  9.0E-07 lb per MMBtu
                                                    of heat input.
                                d. CO............  1,010 ppm by volume
                                                    on a dry basis
                                                    corrected to 3
                                                    percent oxygen (30-
                                                    day rolling average
                                                    for units 100 MMBtu/
                                                    hr or greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.03 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
7. Fuel cells designed to burn  a. Particulate     0.02 lb per MMBtu of
 biomass.                        Matter.            heat input.
                                b. Hydrogen        0.006 lb per MMBtu of
                                 Chloride.          heat input.
                                c. Mercury.......  9.0E-07 lb per MMBtu
                                d. CO............   of heat input.
                                                   270 ppm by volume on
                                                    a dry basis
                                                    corrected to 3
                                                    percent oxygen (30-
                                                    day rolling average
                                                    for units 100 MMBtu/
                                                    hr or greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.02 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.

8. Units designed to burn       a. Particulate     0.004 lb per MMBtu of
 liquid fuel.                    Matter.            heat input.
                                b. Hydrogen        0.0009 lb per MMBtu
                                 Chloride.          of heat input.
                                c. Mercury.......  4.0E-06 lb per MMBtu
                                                    of heat input.
                                d. CO............  1 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.002 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
9. Units designed to burn       a. Particulate     0.05 lb per MMBtu of
 other gases.                    Matter.            heat input.
                                b. Hydrogen        3.0E-06 lb per MMBtu
                                 Chloride.          of heat input.
                                c. Mercury.......  2.0E-07 lb per MMBtu
                                d. CO............   of heat input.
                                                   1 ppm by volume on a
                                                    dry basis corrected
                                                    to 3 percent oxygen
                                                    (30-day rolling
                                                    average for units
                                                    100 MMBtu/hr or
                                                    greater, 3-run
                                                    average for units
                                                    less than 100 MMBtu/
                                                    hr).
                                e. Dioxin/Furan..  0.009 ng/dscm (TEQ)
                                                    corrected to 7
                                                    percent oxygen.
------------------------------------------------------------------------

    As stated in Sec. Sec.  63.11202 and 63.11203, you must comply with
the following applicable work practice standards:

      Table 3 to Subpart DDDDD of Part 63--Work Practice Standards
------------------------------------------------------------------------
   If your boiler is . . .         You must meet the following . . .
------------------------------------------------------------------------
1. An existing boiler or       Conduct a tune-up of the boiler
 process heater with heat       biennially as specified in Sec.
 input capacity of less than    63.7540.
 10 million Btu per hour.
2. A new or existing boiler    Conduct a tune-up of the boiler annually
 or process heater in either    as specified in Sec.   63.7540.
 the Gas 1 or Metal Process
 Furnace subcategory with
 heat input capacity of 10
 million Btu per hour or
 greater.
3. An existing boiler located  Must have an energy assessment performed
 at a major source facility.    on the major source facility by
                                qualified personnel which includes:
                                  (a) a visual inspection of the boiler
                                   system.
                               (b) establish operating characteristics
                                of the facility, energy system
                                specifications, operating and
                                maintenance procedures, and unusual
                                operating constraints,
                                  (c) identify major energy consuming
                                   systems,
                                  (d) a review of available
                                   architectural and engineering plans,
                                   facility operation and maintenance
                                   procedures and logs, and fuel usage,
                                  (e) a list of major energy
                                   conservation measures,
                                  (f) the energy savings potential of
                                   the energy conservation measures
                                   identified, and
                                  (g) a comprehensive report detailing
                                   the ways to improve efficiency, the
                                   cost of specific improvements,
                                   benefits, and the time frame for
                                   recouping those investments, and
                                  (h) a facility energy management
                                   program developed according to the
                                   ENERGY STAR guideline for energy
                                   management.
------------------------------------------------------------------------

    As stated in Sec.  63.7500, you must comply with the applicable
operating limits:

  Table 4 to Subpart DDDDD of Part 63--Operating Limits for Boilers and
                             Process Heaters
------------------------------------------------------------------------
If you demonstrate compliance   You must meet these operating limits . .
         using . . .                               .
------------------------------------------------------------------------
1. Wet scrubber control......  a. Maintain the minimum pressure drop and
                                liquid flow-rate at or above the
                                operating levels established during the
                                performance test according to Sec.
                                63.7530(c) and Table 7 to this subpart.
2. Fabric filter control.....  a. Install and operate a bag leak
                                detection system according to Sec.
                                63.7525 and operate the fabric filter
                                such that the bag leak detection system
                                alarm does not sound more than 5 percent
                                of the operating time during each 6-
                                month period; or
                               b. This option is for boilers and process
                                heaters that operate dry control
                                systems. Existing and new boilers and
                                process heaters must maintain opacity to
                                less than or equal to 10 percent (daily
                                block average).
3. Electrostatic precipitator  a. This option is for boilers and process
 control.                       heaters that operate dry control
                                systems. Existing and new boilers and
                                process heaters must maintain opacity to
                                less than or equal to 10 percent opacity
                                (daily block average); or

                               b. This option is only for boilers and
                                process heaters that operate additional
                                wet control systems. Maintain the
                                minimum voltage and secondary current or
                                total power input of the electrostatic
                                precipitator at or above the operating
                                limits established during the
                                performance test according to Sec.
                                63.7530(c) and Table 7 to this subpart.
4. Dry scrubber or carbon      Maintain the minimum sorbent or carbon
 injection control.             injection rate at or above the operating
                                levels established during the
                                performance test according to Sec.
                                63.7530(c) and Table 7 to this subpart.
5. Any other control type....  This option is for boilers and process
                                heaters that operate dry control
                                systems. Existing and new boilers and
                                process heaters must maintain opacity to
                                less than or equal to 10 percent opacity
                                (daily block average).
6. Fuel analysis.............  Maintain the fuel type or fuel mixture
                                such that the applicable emission rates
                                calculated according to Sec.
                                63.7530(d)(3), (4) and/or (5) is less
                                than the applicable emission limits.
------------------------------------------------------------------------

    As stated in Sec.  63.7520, you must comply with the following
requirements for performance test for existing, new or reconstructed
affected sources:

  Table 5 to Subpart DDDDD of Part 63--Performance Testing Requirements
------------------------------------------------------------------------
 To conduct a performance test
 for the following pollutant .    You must . . .        Using . . .
              . .
------------------------------------------------------------------------
1. Particulate Matter.........  a. Select          Method 1 in appendix
                                 sampling ports     A to part 60 of this
                                 location and the   chapter.
                                 number of
                                 traverse points.
                                b. Determine       Method 2, 2F, or 2G
                                 velocity and       in appendix A to
                                 volumetric flow-   part 60 of this
                                 rate of the        chapter.
                                 stack gas.
                                c. Determine       Method 3A or 3B in
                                 oxygen and         appendix A to part
                                 carbon dioxide     60 of this chapter,
                                 concentrations     or ASME PTC 19, Part
                                 of the stack gas.  10 (1981) (IBR, see
                                                    Sec.   63.14(i)).
                                d. Measure the     Method 4 in appendix
                                 moisture content   A to part 60 of this
                                 of the stack gas.  chapter.
                                e. Measure the     Method 5 or 17
                                 particulate        (positive pressure
                                 matter emission    fabric filters must
                                 concentration.     use Method 5D) in
                                                    appendix A to part
                                                    60 of this chapter.
                                f. Convert         Method 19 F-factor
                                 emissions          methodology in
                                 concentration to   appendix A to part
                                 lb per MMBtu       60 of this chapter.
                                 emission rates.
2. Hydrogen chloride..........  a. Select          Method 1 in appendix
                                 sampling ports     A to part 60 of this
                                 location and the   chapter.
                                 number of
                                 traverse points.
                                b. Determine       Method 2, 2F, or 2G
                                 velocity and       in appendix A to
                                 volumetric flow-   part 60 of this
                                 rate of the        chapter.
                                 stack gas.
                                c. Determine       Method 3A or 3B in
                                 oxygen and         appendix A to part
                                 carbon dioxide     60 of this chapter,
                                 concentrations     or ASME PTC 19, Part
                                 of the stack gas.  10 (1981) (IBR, see
                                                    Sec.   63.14(i)).
                                d. Measure the     Method 4 in appendix
                                 moisture content   A to part 60 of this
                                 of the stack gas.  chapter.
                                e. Measure the     Method 26 or 26A in
                                 hydrogen           appendix A to part
                                 chloride           60 of this chapter.
                                 emission
                                 concentration.
                                f. Convert         Method 19 F-factor
                                 emissions          methodology in
                                 concentration to   appendix A to part
                                 lb per MMBtu       60 of this chapter.
                                 emission rates.
3. Mercury....................  a. Select          Method 1 in appendix
                                 sampling ports     A to part 60 of this
                                 location and the   chapter.
                                 number of
                                 traverse points.
                                b. Determine       Method 2, 2F, or 2G
                                 velocity and       in appendix A to
                                 volumetric flow-   part 60 of this
                                 rate of the        chapter.
                                 stack gas.
                                c. Determine       Method 3A or 3B in
                                 oxygen and         appendix A to part
                                 carbon dioxide     60 of this chapter,
                                 concentrations     or ASME PTC 19, Part
                                 of the stack gas.  10 (1981) (IBR, see
                                                    Sec.   62.14(i)).
                                d. Measure the     Method 4 in appendix
                                 moisture content   A to part 60 of this
                                 of the stack gas.  chapter.
                                e. Measure the     Method 29 in appendix
                                 mercury emission   A to part 60 of this
                                 concentration.     chapter or Method
                                                    101A in appendix B
                                                    to part 61 of this
                                                    chapter or ASTM
                                                    Method D6784-02
                                                    (IBR, see Sec.
                                                    63.14(b)).
                                f. Convert         Method 19 F-factor
                                 emissions          methodology in
                                 concentration to   appendix A to part
                                 lb per MMBtu       60 of this chapter.
                                 emission rates.
4. CO.........................  a. Select the      Method 1 in appendix
                                 sampling ports     A to part 60 of this
                                 location and the   chapter.
                                 number of
                                 traverse points.
                                b. Determine       Method 3A or 3B in
                                 oxygen and         appendix A to part
                                 carbon dioxide     60 of this chapter,
                                 concentrations     or ASTM D6522-00
                                 of the stack gas.  (IBR, see Sec.
                                                    63.14(b)), or ASME
                                                    PTC 19, Part 10
                                                    (1981) (IBR, see
                                                    Sec.   63.14(i)).
                                c. Measure the     Method 4 in appendix
                                 moisture content   A to part 60 of this
                                 of the stack gas.  chapter.
                                d. Measure the CO  Method 10 in appendix
                                 emission           A to part 60 of this
                                 concentration.     chapter.
5. Dioxin/Furan...............  a. Select the      Method 1 in appendix
                                 sampling ports     A to part 60 of this
                                 location and the   chapter.
                                 number of
                                 traverse points.

                                b. Determine       Method 3A or 3B in
                                 oxygen and         appendix A to part
                                 carbon dioxide     60 of this chapter,
                                 concentrations     or ASTM D6522-00
                                 of the stack gas.  (IBR, see Sec.
                                                    63.14(b)), or ASME
                                                    PTC 19, Part 10
                                                    (1981) (IBR, see
                                                    Sec.   63.14(i)).
                                c. Measure the     Method 4 in appendix
                                 moisture content   A to part 60 of this
                                 of the stack gas.  chapter.
                                d. Measure the     Method -- in appendix
                                 dioxin/furans      A to part 60 of this
                                 emission           chapter.
                                 concentration.
------------------------------------------------------------------------

    As stated in Sec.  63.7521, you must comply with the following
requirements for fuel analysis testing for existing, new or
reconstructed affected sources. However, equivalent methods may be used
in lieu of the prescribed methods at the discretion of the source owner
or operator:

     Table 6 to Subpart DDDDD of Part 63--Fuel Analysis Requirements
------------------------------------------------------------------------
To conduct a fuel analysis for
 the following pollutant . . .    You must . . .        Using . . .

------------------------------------------------------------------------
1. Mercury....................  a. Collect fuel    Procedure in Sec.
                                 samples.           63.7521(c) or ASTM
                                                    D2234-D2234M-03 (for
                                                    coal) (IBR, see Sec.
                                                      63.14(b)) or ASTM
                                                    D6323-98 (2003) (for
                                                    biomass) (IBR, See
                                                    Sec.   63.14(b)) or
                                                    equivalent.
                                b. Composite fuel  Procedure in Sec.
                                 samples.           63.7521(d) or
                                                    equivalent.
                                c. Prepare         SW-846-3050B (for
                                 composited fuel    solid samples) or SW-
                                 samples.           846-3020A (for
                                                    liquid samples) or
                                                    ASTM D2013-04 (for
                                                    coal) (IBR, see Sec.
                                                      63.14(b)) or ASTM
                                                    D5198-92 (2003) (for
                                                    biomass) (IBR, see
                                                    Sec.   63.14(b)) or
                                                    equivalent.
                                d. Determine heat  ASTM D5865-04 (for
                                 content of the     coal) (IBR, see Sec.
                                 fuel type.           63.24(b)) or ASTM
                                                    E711-87 (for
                                                    biomass) (IBR, see
                                                    Sec.   63.14(b)) or
                                                    equivalent.
                                e. Determine       ASTM D3173-03 (IBR,
                                 moisture content   see Sec.   63.14(b))
                                 of the fuel type.  or ASTM E871-82
                                                    (1998) (IBR, see
                                                    Sec.   63.14(b)) or
                                                    equivalent.
                                f. Measure         ASTM D6722-01 (for
                                 mercury            coal) (IBR, see Sec.
                                 concentration in     6314(b)) or SW-846-
                                 fuel sample.       7471A (for solid
                                                    samples) or SW-846-
                                                    7470A (for liquid
                                                    samples or
                                                    equivalent.
                                g. Convert         .....................
                                 concentration
                                 into units of
                                 pounds of
                                 pollutant per
                                 MMBtu of heat
                                 content.
2. Hydrogen Chloride..........  a. Collect fuel    Procedure in Sec.
                                 samples.           63.7521(c) or ASTM
                                                    D2234-D2234M-03 (for
                                                    coal) (IBR, see Sec.
                                                      63.14(b)) or ASTM
                                                    D6323-98 (2003) (for
                                                    biomass) (IBR, see
                                                    Sec.   63.14(b)) or
                                                    equivalent.
                                b. Composite fuel  Procedure in Sec.
                                 samples.           63.7521(d) or
                                                    equivalent.
                                c. Prepare         SW-846-3050B (for
                                 composited fuel    solid samples) or SW-
                                 samples.           846-3020A (for
                                                    liquid samples) or
                                                    ASTM D2013-04 (for
                                                    coal) (IBR, see Sec.
                                                      63.14(b)) or ASTM
                                                    D5198-92 (2003) (for
                                                    biomass) (IBR, see
                                                    Sec.   63.14(b)) or
                                                    equivalent.
                                d. Determine heat  ASTM D5865-04 (for
                                 content of the     coal) (IBR, see Sec.
                                 fuel type * * *.     63.14(b)) or ASTM
                                                    E711-87 (1996) (for
                                                    biomass) (IBR, see
                                                    Sec.   63.14(b)) or
                                                    equivalent.
                                e. Determine       ASTM D3173-03 (IBR,
                                 moisture content   see Sec.   63.14(b))
                                 of the fuel type.  or ASTM E871-82
                                                    (1998) or
                                                    equivalent.
                                f. Measure         SW-846-9250 or ASTM
                                 chlorine           D6721-01 (for coal)
                                 concentration in   or ASTM E776-87
                                 fuel sample.       (1996) (for biomass)
                                                    (IBR, see Sec.
                                                    63.14(b)) or
                                                    equivalent.
                                g. Convert         .....................
                                 concentrations
                                 into units of
                                 pounds of
                                 pollutant per
                                 MMBtu of heat
                                 content.
------------------------------------------------------------------------

    As stated in Sec.  63.7520, you must comply with the following
requirements for establishing operating limits:

                       Table 7 to Subpart DDDDD of Part 63--Establishing Operating Limits
----------------------------------------------------------------------------------------------------------------
                                  And your operating                                           According to the
    If you have an applicable      limits are based     You must . . .        Using . . .          following
    emission limit for . . .           on . . .                                               requirements . . .
----------------------------------------------------------------------------------------------------------------
1. Particulate matter or mercury  a. Wet scrubber     i. Establish a      (1) Data from the   (a) You must
                                   operating           site-specific       pressure drop and   collect pressure
                                   parameters.         minimum pressure    liquid flow rate    drop and liquid
                                                       drop and minimum    monitors and the    flow-rate data
                                                       flow rate           particulate         every 15 minutes
                                                       operating limit     matter or mercury   during the entire
                                                       according to Sec.   performance test.   period of the
                                                         63.7530(c).                           performance
                                                                                tests;
                                                                                (b) Determine the
                                                                                average pressure
                                                                                drop and liquid
                                                                                flow-rate for
                                                                                each individual
                                                                                test run in the
                                                                                three-run
                                                                                performance test
                                                                                by computing the
                                                                                average of all
                                                                                the 15-minute
                                                                                readings taken
                                                                                during each test
                                                                                run.
                                  b. Electrostatic    i. Establish a      (1) Data from the   (a) You must
                                   precipitator        site-specific       pressure drop and   collect voltage
                                   operating           minimum voltage     liquid flow rate    and secondary
                                   parameters          and secondary       monitors and the    current or total
                                   (option only for    current or total    particulate         power input data
                                   units with          power input         matter or mercury   every 15 minutes
                                   additional wet      according to Sec.   performance test.   during the entire
                                   scrubber control).    63.7530(c).                           period of the
                                                                                performance
                                                                                tests;
                                                                                (b) Determine the
                                                                                average voltage
                                                                                and secondary
                                                                                current or total
                                                                                power input for
                                                                                each individual
                                                                                test run in the
                                                                                three-run
                                                                                performance test
                                                                                by computing the
                                                                                average of all
                                                                                the 15-minute
                                                                                readings taken
                                                                                during each test
                                                                                run.
2. Hydrogen Chloride............  a. Wet scrubber     i. Establish a      (1) Data from the   (a) You must
                                   operating           site-specific       pH, pressure        collect pH,
                                   parameters.         minimum pressure    drop, and liquid    pressure drop,
                                                       drop and minimum    flow-rate           and liquid flow-
                                                       flow rate           monitors and the    rate data every
                                                       operating limit     hydrogen chloride   15 minutes during
                                                       according to Sec.   performance test.   the entire period
                                                         63.7530(c).                           of the
                                                                                performance
                                                                                tests;
                                                                                (b) Determine the
                                                                                average pH,
                                                                                pressure drop,
                                                                                and liquid flow-
                                                                                rate for each
                                                                                individual test
                                                                                run in the three-
                                                                                run performance
                                                                                test by computing
                                                                                the average of
                                                                                all the 15-minute
                                                                                readings taken
                                                                                during each test
                                                                                run.
                                  b. Dry scrubber     i. Establish a      (1) Data from the   (a) You must
                                   operating           site-specific       sorbent injection   collect sorbent
                                   parameters.         minimum sorbent     rate monitors and   injection rate
                                                       injection rate      hydrogen chloride   data every 15
                                                       operating limit     performance test.   minutes during
                                                       according to Sec.                       the entire period
                                                         63.7530(c).                           of the
                                                                                performance
                                                                                tests;
                                                                                (b) Determine the
                                                                                average sorbent
                                                                                injection rate
                                                                                for each
                                                                                individual test
                                                                                run in the three-
                                                                                run performance
                                                                                test by computing
                                                                                the average of
                                                                                all the 15-minute
                                                                                readings taken
                                                                                during each test
                                                                                run.
----------------------------------------------------------------------------------------------------------------

    As stated in Sec.  63.7540, you must show continuous compliance
with the emission limitations for affected sources according to the
following:

Table 8 to Subpart DDDDD of Part 63--Demonstrating Continuous Compliance
------------------------------------------------------------------------
  If you must meet the following
 operating limits or work practice     You must demonstrate continuous
          standards . . .                    compliance by . . .
------------------------------------------------------------------------
1. Opacity........................  a. Collecting the opacity monitoring
                                     system data according to Sec.  Sec.
                                       63.7525(b) and 63.7535; and
                                    b. Reducing the opacity monitoring
                                     data to 6-minute averages; and
                                    c. Maintaining opacity to less than
                                     or equal to 10 percent (daily block
                                     average).
2. Fabric Filter Bag Leak           Installing and operating a bag leak
 Detection Operation.                detection system according to Sec.
                                      63.7525 and operating the fabric
                                     filter such that the requirements
                                     in Sec.   63.7540(a)(9) are met.
3. Wet Scrubber Pressure Drop and   a. Collecting the pressure drop and
 Liquid Flow-rate.                   liquid flow rate monitoring system
                                     data according to Sec.  Sec.
                                     63.7525 and 63.7535; and
                                    b. Reducing the data to 12-hour
                                     block averages; and
                                    c. Maintaining the 12-hour average
                                     pressure drop and liquid flow-rate
                                     at or above the operating limits
                                     established during the performance
                                     test according to Sec.
                                     63.7530(c).
4. Wet Scrubber pH................  a. Collecting the pH monitoring
                                     system data according to Sec.  Sec.
                                       63.7525 and 63.7535; and
                                    b. Reducing the data to 12-hour
                                     block averages; and
                                    c. Maintaining the 12-hour average
                                     pH at or above the operating limit
                                     established during the performance
                                     test according to Sec.
                                     63.7530(c).
5. Dry Scrubber Sorbent or Carbon   a. Collecting the sorbent or carbon
 Injection Rate.                     injection rate monitoring system
                                     data for the dry scrubber according
                                     to Sec.  Sec.   63.7525 and
                                     63.7535; and
                                    b. Reducing the data to 12-hour
                                     block averages; and
                                    c. Maintaining the 12-hour average
                                     sorbent or carbon injection rate at
                                     or above the operating limit
                                     established during the performance
                                     test according to Sec.  Sec.
                                     63.7530(c).
6. Electrostatic Precipitator       a. Collecting the secondary current
 Secondary Current and Voltage or    and voltage or total power input
 Total Power Input.                  monitoring system data for the
                                     electrostatic precipitator
                                     according to Sec.  Sec.   63.7525
                                     and 63.7535; and
                                    b. Reducing the data to 12-hour
                                     block averages; and
                                    c. Maintaining the 12-hour average
                                     secondary current and voltage or
                                     total power input at or above the
                                     operating limits established during
                                     the performance test according to
                                     Sec.  Sec.   63.7530(c).
7. Fuel Pollutant Content.........  a. Only burning the fuel types and
                                     fuel mixtures used to demonstrate
                                     compliance with the applicable
                                     emission limit according to Sec.
                                     63.7530(c) or (d) as applicable;
                                     and
                                    b. Keeping monthly records of fuel
                                     use according to Sec.   63.7540(a).
------------------------------------------------------------------------

    As stated in Sec.  63.7550, you must comply with the following
requirements for reports:

       Table 9 to Subpart DDDDD of Part 63--Reporting Requirements
------------------------------------------------------------------------
                                    The report must     You must submit
   You must submit a(n) . . .        contain . . .     the report . . .
------------------------------------------------------------------------
1. Compliance report............  a. Information      Semiannually
                                   required in Sec.    according to the
                                    63.7550(c)(1)      requirements in
                                   through (11); and   Sec.
                                                       63.7550(b).
                                  b. If there are no  ..................
                                   deviations from
                                   any emission
                                   limitation
                                   (emission limit
                                   and operating
                                   limit) that
                                   applies to you
                                   and there are no
                                   deviations from
                                   the requirements
                                   for work practice
                                   standards in
                                   Table 8 to this
                                   subpart that
                                   apply to you, a
                                   statement that
                                   there were no
                                   deviations from
                                   the emission
                                   limitations and
                                   work practice
                                   standards during
                                   the reporting
                                   period. If there
                                   were no periods
                                   during which the
                                   CMSs, including
                                   continuous
                                   emissions
                                   monitoring
                                   system,
                                   continuous
                                   opacity
                                   monitoring
                                   system, and
                                   operating
                                   parameter
                                   monitoring
                                   systems, were out-
                                   of-control as
                                   specified in Sec.
                                     63.8(c)(7), a
                                   statement that
                                   there were no
                                   periods during
                                   which the CMSs
                                   were out-of-
                                   control during
                                   the reporting
                                   period; and

                                  c. If you have a    ..................
                                   deviation from
                                   any emission
                                   limitation
                                   (emission limit
                                   and operating
                                   limit) or work
                                   practice standard
                                   during the