RECEIVED
CLERK'S
OFFICE
MAY 3 0 2006
STATE OP ILLINOIS
Pollution Control Board
OFFICE OF THE SECRETARY OF STATE
JESSE WHITE • Secretary of State
05/25/2006
POLLUTION CONTROL BOARD
James R. Thompson Center 100 W . Randolph St ., Ste 11-500
Dorothy Gunn
CHICAGO, IL 60601
Dear Dorothy Gunn
Your rules Listed below met our codification standards and have been published in
Volume 30, Issue 22 of the Illinois Register, dated 06/02/2006 .
NOTICE OF CORRECTIONS
Control of Emissions from Large Combustion Sources (Correction to Proposed Rule)
35 III . Adm . Code 225
Page 10193
Point Of Contact:Erin Conley
If you have any questions, you may contact the Administrative Code Division at
(217) 782 - 7017 .
Index Department - Administrative Code Division -
111 East Monroe Springfield, IL 62756
ILLINOIS REGISTER
POLLUTION CONTROL BOARD
NOTICE OF CORRECTION TO PROPOSED RULE
1)
Heading of the Part :
Control of Emissions from Large Combustion Sources
2)
Code Citation : 35 Ill . Adm. Code Part 225
3)
Illinois Register Citation to Notice of Proposed Rule :
30 Ill . Reg. 9281 (May 19, 2006)
4)
Section being corrected
:
Main authority note to the proposed Part.
5)
Correction being made:
The main authority note to the proposed Part 225 inadvertently contained a reference to
Sections 9.10 and 28.5
of the Illinois Environmental Protection Act (415 ILCS 5) . The
main authority note should read as follows : Implementing and authorized by Section 27
of the Environmental Protection Act [415 ILCS 5/27] .
RECEIVED
m m 1 7 2006
SOS-CODE DIV.
ILLINOIS REGISTER
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NOTICE OF CORECTION TO PROPOSED RULE
b)
The EGUs at each source covered by a Demonstration must also comply with one
of the following emission standards on a source-wide basis for the period covered
by the Demonstration :
1)
An emission standard of 0
.020 lb mercury/GWh gross electrical output
; or
2)
A minimum 75-percent reduction of input mercury
.
c)
For the purpose of this Section, compliance shall be determined using the
equations in Section 225
.230(a)(2), (a)(3), or
(d)(2) of this Subpart, as applicable,
addressing all EGUs at the sources covered by the Demonstration, rather than
only EGUs at one source .
d)
Limitations on Demonstrations
1)
The owners or operators of more than one existing source with EGUs can
only participate in Demonstrations that include other existing sources that
they own or operate
.
2)
Single Existing Source Demonstrations
A)
The owner or operator of only a single existing source with EGUs
(i.e.,
City, Water, Light & Power, City of Springfield, ID
167120AAO
; Electric Energy, Inc ., ID 127855AAC
; Kincaid
Generating Station, ID 021814AAB
; and Southern Illinois Power
Cooperative/Marion Generating Station, ID 199856AAC) can only
participate in Demonstrations with other such owners or operators
of a single existing source of EGUs
.
B)
Participation in Demonstrations under this Section by the owner or
operator of only a single existing source with EGUs must be
authorized through federally enforceable permit conditions for
each such source participating in the Demonstration
.
e)
A source may be included in only one Demonstration during each rolling 12-
month period.
f)
The owner or operator of EGUs using Demonstrations to show compliance with
this Subpart must complete the determination of compliance for each 12-month
rolling period no later than 60 days following the end of the period
.
g)
h)
For purposes of this Section, if the owner or operator of any source that
participates in a Demonstration with an owner or operator of a source that does
not maintain the required records, data, and reports for the EGUs at the source, or
does not submit copies of such records, data, or reports to the Agency upon
request, then the effect of this failure will be deemed to be a failure to
demonstrate compliance and the compliance status of each source shall be
determined under Section 225
.230 of this Subpart as if the sources were not
covered by a Demonstration
.
Section 225
.235
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If averaging is used to demonstrate compliance with this Subpart, the effect of a
failure to demonstrate compliance shall be that the compliance status of each
source shall be determined under Section 225 .230 of this Subpart as if the sources
were not covered by a Demonstration .
Units Scheduled for Permanent Shut Down
a)
The emission standards of Section 225 .230(a) of this Subpart are not applicable to
an EGU that will be permanently shut down as follows
:
1)
The owner or operator of an EGU for which this Section is being relied
upon shall by no later than June 30, 2009 :
A)
Have notified the Illinois EPA that it is planning to permanently
shut down the EGU by the applicable date specified in subsection
(a)(3) or (4) of this Section
. This notification shall be
accompanied by a description of the actions that have already been
taken to allow the shut down of the EGU and a description of the
future actions that must be accomplished to complete the shut
down of the EGU, with the anticipated schedule for those actions
and the anticipated date of permanent shut down of the unit
.
B)
Have applied for a construction permit or be actively pursuing a
federally enforceable agreement that requires the EGU to be
permanently shut down in accordance with this Section
.
C)
Have applied for revisions to the operating permit(s) for the EGU
to include provisions that terminate the authorization to operate the
unit in accordance with this Section .
2)
The owner or operator of an EGU for which this Section is being relied
upon shall by no later than June 30, 2010
:
ILLINOIS REGISTER
POLLUTION CONTROL BOARD
NOTICE OF CORECTION TO PROPOSED RULE
A)
Have obtained a construction permit or entered into a federally
enforceable agreement as addressed by subsection (a)(1)(B) of this
Section; or
B)
Have obtained revised operating permit(s) in accordance with
subsection (a)(1)(C) of this Section .
3) The plan for permanent shut down of the EGU must provide for the EGU
to be permanently shut down by no later than the applicable date specified
below:
A)
If the owner or operator of the EGU is not constructing a new EGU
or other generating units to specifically replace the existing EGU,
by December 31, 2010 .
B) If the owner or operator of the EGU is constructing a new EGU or
other generating units to specifically replace the existing EGU, by
December 31, 2011 .
4)
The owner or operator of the EGU must permanently shut down the EGU
by the date specified in subsection (a)(3)
of this Section, unless the owner
or operator submits a demonstration to the Illinois EPA before such date
showing that circumstances beyond its reasonable control (such as
protracted delays in construction activity, unanticipated outage of another
EGU, or protracted shakedown of a replacement unit) have occurred that
interfere with the plan for permanent shut down of the EGU, in which case
the date for shut down of the EGU may be extended as follows :
A)
If the owner or operator of the EGU is not constructing a new EGU
or other generating units to specifically replace the existing EGU,
for up to one year, i .e., permanent shut down of the EGU to occur
by no later than December 31, 2011
.
B)
If the owner or operator of the EGU is constructing a new EGU or
other generating units to specifically replace the existing EGU, for
up to 18 months, i .e.,
permanent shutdown of the EGU to occur by
no later than June 30, 2013
; provided, however, that after
December 31, 2012, the existing EGU shall only operate as a back-
up unit to address periods when the new generating units are not in
service.
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b)
Notwithstanding Sections 225
.230 and 225 .232 of this Subpart, any EGU that is
not required to comply with Section 225
.230 of this Subpart pursuant to this
Section shall not be included when determining whether any other EGUs at the
source or other sources are in compliance with Section 225
.230 of this Subpart
.
c)
If an EGU, for which the owner or operator of the source has relied upon this
Section in lieu of complying with Section 225
.230(a) of this Subpart, is not
permanently shut down as required by this Section, the EGU shall be considered
to be a new EGU subject to the emission standards in Section 225
.237(a) of this
Subpart beginning in the month after the EGU was required to be permanently
shut down, in addition to any other penalties that may be imposed for failure to
permanently shut down the EGU in accordance with this Section
.
Section 225 .237
Emission Standards for New Sources with EGUs
a)
Standards
1)
The owner or operator of a source with one or more EGUs, but that
previously had not had any EGUs that commenced commercial operation
before January 1, 2009, shall comply with one of the following emission
standards for each EGU on a rolling 12-month basis
:
A)
An emission standard of 0
.0080 lb mercury/GWh gross electrical
output
; or
B)
A minimum 90 percent reduction of input mercury
.
2)
For this purpose, compliance may be demonstrated using the equations in
Section 225 .230(a)(2),
(a)(3), or (b)(2)
of this Subpart .
b)
The initial 12-month rolling period for which compliance with the emission
standards of subsection (a)(1)
of this Section must be demonstrated for a new
EGU shall commence on the date that the initial performance test for the mercury
emission standard under 40 CFR 60
.45a also commences
. The continuous
emission monitoring systems required by this Subpart for mercury emissions from
the EGU must be certified prior to this date
. Thereafter, compliance shall be
demonstrated on a rolling 12-month basis in terms of calendar months
.
Section 225 .240
General Monitoring and Reporting Requirements
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The owner or operator of an EGU shall comply with the monitoring, recordkeeping, and
reporting requirements as provided in this Section, Sections 225
.250 through 225
.290 of this
Subpart, and Subpart I of 40 CFR 75
. If the EGU utilizes a common stack with units that are not
EGUs and the owner or operator of the EGU does not conduct emissions monitoring in the duct
to the common stack from each EGU, the owner or operator of the EGU shall conduct emissions
monitoring in accordance with 40 CFR 75
.82(b)(2) and this Section, including monitoring in the
duct to the common stack from each unit that is not an EGU, unless the owner or operator of the
EGU counts the combined emissions measured at the common stack as the mass emissions of
mercury for the EGUs for recordkeeping and compliance purposes
.
a)
Requirements for installation, certification, and data accounting
. The owner or
operator of each EGU shall :
1)
Install all monitoring systems required under this Section and Sections
225.250 through 225
.290 of this Subpart for monitoring mercury mass
emissions (including all systems required to monitor mercury
concentration, stack gas moisture content, stack gas flow rate, and CO2 or
02 concentration, as applicable, in accordance with 40 CFR 75
.81 and
75 .82).
2)
Successfully complete all certification tests required under Section
225
.250 and meet all other requirements of this Section, Sections 225
.250
through 225.290
of this Subpart, and Subpart I of 40 CFR 75 applicable to
the monitoring systems required under subsection
(a)(1)
of this Section.
3)
Record, report, and quality-assure the data from the monitoring systems
required under subsection (a)(1)
of this Section .
4)
If the owner or operator elects to use the low mass emissions excepted
monitoring methodology for an EGU that emits no more than 464 ounces
(29 pounds) of mercury per year pursuant to 40 CFR 75
.81(b), also
perform emissions testing in accordance with 40 CFR 75
.81(c) to
demonstrate that the EGU is eligible to use this excepted emissions
monitoring methodology, as well as comply with all other applicable
requirements of 40 CFR 75
.81(b) through
(f), and submit a copy of any
information required to be submitted to the USEPA under these provisions
to the Illinois EPA
. The initial emissions testing to demonstrate eligibility
of an EGU for the low mass emissions excepted methodology shall be
conducted by the following dates
:
ILLINOIS REGISTER
POLLUTION CONTROL BOARD
NOTICE OF CORECTION TO PROPOSED RULE
A)
If the EGU has commenced commercial operation before July 1,
2008, at least by January 1, 2009, or 45 days prior to relying on the
low mass emissions excepted methodology, whichever date is
later.
B)
If the EGU has commenced commercial operation on or after July
1, 2008, at least 45 days prior to the applicable date specified under
subsection (b)(2)
of this Section or 45 days prior to relying on the
low mass emissions excepted methodology, whichever date is
later.
b)
Emissions Monitoring Deadlines
. The owner or operator shall meet the emissions
monitoring system certification and other emissions monitoring requirements of
subsections (a)(1)
and (a)(2)
of this Section on or before the following dates . The
owner or operator shall record, report, and quality-assure the data from the
emissions monitoring systems required under subsection
(a)(1) of this Section on
and after the following dates :
1)
For the owner or operator of an EGU that commences commercial
operation before July 1, 2008, by January 1, 2009
.
2)
For the owner or operator of an EGU that commences commercial
operation on or after July 1, 2008, by 90 unit operating days or 180
calendar days, whichever occurs first, after the date on which the EGU
commences commercial operation
.
3)
For the owner or operator of an EGU for which construction of a new
stack or flue or installation of add-on mercury emission controls, a flue
gas desulfurization system, a selective catalytic reduction system, a fabric
filter, or a compact hybrid particulate collector system is completed after
the applicable deadline under subsection
(b)(1)
or (2) of this Section, by
90 unit operating days or 180 calendar days, whichever occurs first, after
the date on which emissions first exit to the atmosphere through the new
stack or flue, add-on mercury emissions controls, flue gas desulfurization
system, selective catalytic reduction system, fabric filter, or compact
hybrid particulate collector system .
c)
Reporting Data
1)
Except as provided in subsection
(c)(2) of this Section, the owner or
operator of an EGU that does not meet the applicable emissions
d)
Prohibitions
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monitoring date set forth in subsection (b) of this Section for any
emissions monitoring system required under subsection (a)(1) of this
Section shall, for each such monitoring system, determine, record, and
report maximum potential (or, as appropriate, minimum potential) values
for mercury concentration, stack gas flow rate, stack gas moisture content,
and any other parameters required to determine mercury mass emissions in
accordance with 40 CFR 75 .80(g).
2)
The owner or operator of an EGU that does not meet the applicable
emissions monitoring date set forth in subsection (b)(3)
of this Section for
any emissions monitoring system required under subsection
(a)(1) of this
Section shall, for each such monitoring system, determine, record, and
report substitute data using the applicable missing data procedures in 40
CFR 75
.80(f), in lieu of the maximum potential (or, as appropriate,
minimum potential) values, for a parameter if the owner or operator
demonstrates that there is continuity between the data streams for that
parameter, before and after the construction or installation under
subsection (b)(3)
of this Section .
1)
No owner or operator of an EGU shall use any alternative emissions
monitoring system, alternative reference method for measuring emissions,
or any other alternative to the emissions monitoring and measurement
requirements of this Section and Sections 225
.250 through 225 .290 of this
Subpart, unless such alternative is promulgated by the USEPA and
approved in writing by the Agency or the use of such alternative is
approved in writing by the Agency and USEPA
.
2)
No owner or operator of an EGU shall operate the EGU so as to discharge,
or allow to be discharged, mercury emissions to the atmosphere without
accounting for all such emissions in accordance with the applicable
provisions of this Section, Sections 225
.250 through 225
.290 of this
Subpart, and Subpart I of 40 CFR 75
.
3)
No owner or operator of an EGU shall disrupt the continuous emission
monitoring system, any portion thereof, or any other approved emission
monitoring method, and thereby avoid monitoring and recording mercury
mass emissions discharged into the atmosphere, except for periods of
recertification or periods when calibration, quality assurance testing, or
maintenance is performed in accordance with the applicable provisions of
e)
Long-term Cold Storage
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this Section, Sections 225 .250 through 225
.290 of this Subpart, and
Subpart I of 40 CFR 75 .
4)
No owner or operator of an EGU shall retire or permanently discontinue
use of the continuous emission monitoring system or any component
thereof, or any other approved monitoring system under this Subpart,
except under any one of the following circumstances
:
A)
The owner or operator is monitoring emissions from the EGU with
another certified monitoring system that has been approved, in
accordance with the applicable provisions of this Section, Sections
225.250 through 225
.290 of this Subpart, and Subpart I of 40 CFR
75, by the Agency for use at that EGU and that provides emission
data for the same pollutant or parameter as the retired or
discontinued monitoring system
; or
B)
The owner or operator or designated representative submits
notification of the date of certification testing of a replacement
monitoring system for the retired or discontinued monitoring
system in accordance with Section 225.250(a)(3)(A)
of this
Subpart.
The owner or operator of an EGU that is in long-term cold storage is subject to
the applicable provisions of 40 CFR 75 for monitoring, recordkeeping, and
reporting for units in long-term cold storage .
Section 225
.250
Initial Certification and Recertification Procedures for Emissions
Monitoring
a)
The owner or operator of an EGU shall comply with the following initial
certification and recertification procedures for a continuous emissions monitoring
system (i
.e.,
a continuous emission monitoring system or an excepted monitoring
system (sorbent trap monitoring system) under 40 CFR 75
.15) required by Section
225.240(a)(1)
. The owner or operator of an EGU that qualifies for, and for which
the owner or operator elects to use, the low mass emissions excepted
methodology under 40 CFR 75
.81(b) shall comply with the procedures in
subsection (c) of this Section .
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1)
Requirements for Initial Certification
. The owner or operator of an EGU
shall ensure that, for each continuous emissions monitoring system
required by Section 225
.240(a)(1) of this Subpart (including the automated
data acquisition and handling system), the owner or operator successfully
completes all of the initial certification testing required under 40 CFR
75.80(d) by the applicable deadline in Section 225
.240(b) of this Subpart.
In addition, whenever the owner or operator of an EGU installs a
monitoring system to meet the requirements of this Subpart in a location
where no such monitoring system was previously installed, the owner or
operator must successfully complete the initial certification requirements
of 40 CFR 75 .80(d).
2)
Requirements for Recertification . Whenever the owner or operator of an
EGU makes a replacement, modification, or change in any certified
continuous emission monitoring system, or an excepted monitoring system
(sorbent trap monitoring system) under 40 CFR 75
.15, and required by
Section 225
.240(a)(1) of this Subpart, that may significantly affect the
ability of the system to accurately measure or record mercury mass
emissions or heat input rate or to meet the quality-assurance and quality-
control requirements of 40 CFR 75
.21 or Appendix B to 40 CFR 75, the
owner or operator of an EGU shall recertify the monitoring system in
accordance with 40 CFR 75 .20(b)
. Furthermore, whenever the owner or
operator of
an EGU makes a replacement, modification, or change to the
flue gas handling system or the EGU's operation that may significantly
change the stack flow or concentration profile, the owner or operator shall
recertify each continuous emission monitoring system, and each excepted
monitoring system (sorbent trap monitoring system) under 40 CFR 75
.15,
whose accuracy is potentially affected by the change, all in accordance
with 40 CFR 75
.20(b)
. Examples of
changes to a continuous emission
monitoring system that require recertification include replacement of the
analyzer, complete replacement of an existing continuous emission
monitoring system, or change in location or orientation of the sampling
probe or site .
3)
Approval process for Initial Certification and Recertification
. Subsections
(a)(3)(A)
through (D) of this Section apply to both initial certification and
recertification of a continuous monitoring system required by Section
225 .240(a)(1) of this Subpart
. For recertifications, replace the words
"certification" and "initial certification" with the word "recertification",
replace the word "certified" with the word "recertified", and follow the
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NOTICE OF CORECTION TO PROPOSED RULE
procedures in 40 CFR 75 .20(b)(5) in lieu of the procedures in subsection
(a)(3)(E) of this Section.
A)
Notification of Certification . The owner or operator shall submit
to the Agency, USEPA Region 5, and the Administrator of the
USEPA written notice of the dates of certification testing, in
accordance with Section 225
.270 of this Subpart
.
B)
Certification Application . The owner or operator shall submit to
the Agency a certification application for each monitoring system .
A complete certification application shall include the information
specified in 40 CFR 75 .63 .
C)
Provisional Certification Date . The provisional certification date
for a monitoring system shall be determined in accordance with 40
CFR 75.20(a)(3). A provisionally certified monitoring system may
be used under this Subpart for a period not to exceed 120 days
after receipt by the Agency of the complete certification
application for the monitoring system under subsection (a)(3)(B) of
this Section
. Data measured and recorded by the provisionally
certified monitoring system, in accordance with the requirements
of 40 CFR 75, will be considered valid quality-assured data
(retroactive to the date and time of provisional certification),
provided that the Agency does not invalidate the provisional
certification by issuing a notice of disapproval within 120 days
after the date of receipt by the Agency of the complete certification
application.
D)
Certification Application Approval Process . The Agency will
issue a written notice of approval or disapproval of the certification
application to the owner or operator within 120 days of receipt
after the complete certification application required by subsection
(a)(3)(B) of this Section
. In the event the Agency does not issue
such a notice within the 120-day period, each monitoring system
that meets the applicable performance requirements of 40 CFR 75
and is included in the certification application will be deemed
certified for use under this Subpart .
i)
Approval Notice
. If the certification application is
complete and shows that each monitoring system meets the
applicable performance requirements of 40 CFR 75, then
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the Agency will issue a written notice of approval of the
certification application within 120 days after receipt .
ii)
Incomplete Application Notice
. If the certification
application is not complete, then the Agency will issue a
written notice of incompleteness that sets a reasonable date
by which the owner or operator must submit the additional
information required to complete the certification
application . If the owner or operator does not comply with
the notice of incompleteness by the specified date, then the
Agency may issue a notice of disapproval under subsection
(a)(3)(D)(iii) of this Section . The 120-day review period
shall not begin before receipt of a complete certification
application .
iii)
Disapproval Notice . If the certification application shows
that any monitoring system does not meet the performance
requirements of 40 CFR 75 or if the certification
application is incomplete and the requirement for
disapproval under subsection (a)(3)(D)(ii)
of this Section is
met, then the Agency will issue a written notice of
disapproval of the certification application. Upon issuance
of such notice of disapproval, the provisional certification
is invalidated by the Agency and the data measured and
recorded by each uncertified monitoring system shall not be
considered valid quality-assured data beginning with the
date and hour of provisional certification (as defined under
40 CFR 75 .20(a)(3)).
The owner or operator shall follow
the procedures for loss of certification in subsection
(a)(3)(E)
of this Section for each monitoring system that is
disapproved for initial certification .
iv)
Audit Decertification
. The Agency may issue a notice of
disapproval of the certification status of a monitor in
accordance with Section 225
.260(b) of this Subpart .
E)
Procedures for Loss of Certification
. If the Agency issues a notice
of disapproval of a certification application under subsection
(a)(3)(D)(iii)
of this Section or a notice of disapproval of
certification status under subsection (a)(3)(D)(iv)
of this Section,
then
:
b)
Exemption
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i)
The owner or operator shall substitute the following values,
for each disapproved monitoring system, for each hour of
EGU operation during the period of invalid data specified
under 40 CFR 75 .20(a)(4)(iii) or 75 .21(e) and continuing
until the applicable date and hour specified under 40 CFR
75 .20(a)(5)(i) .
For a disapproved mercury pollutant
concentration monitor and disapproved flow monitor,
respectively, the maximum potential concentration of
mercury and the maximum potential flow rate, as defined in
Sections 2.1
.7.1 and 2.1 .4.1 of Appendix A to 40 CFR 75 .
For a disapproved moisture monitoring system and
disapproved diluent gas monitoring system, respectively,
the minimum potential moisture percentage and either the
maximum potential CO2 concentration or the minimum
potential 02 concentration (as applicable), as defined in
Sections 2.1.5, 2.1 .3.1, and 2.1 .3.2 of Appendix A to 40
CFR 75. For a disapproved excepted monitoring system
(sorbent trap monitoring system) under 40 CFR 75 .15 and
disapproved flow monitor, respectively, the maximum
potential concentration of mercury and maximum potential
flow rate, as defined in Sections 2 .1 .7.1 and 2.1
.4.1 of
Appendix A to 40 CFR 75 .
ii)
The owner or operator shall submit a notification of
certification retest dates and a new certification application
in accordance with subsections (a)(3)(A)
and (B) of this
Section.
iii)
The owner or operator shall repeat all certification tests or
other requirements that were failed by the monitoring
system, as indicated in the Agency's notice of disapproval,
no later than 30 unit operating days after the date of
issuance of the notice of disapproval
.
1)
If an emissions monitoring system has been previously certified in
accordance with 40 CFR 75 and the applicable quality assurance and
quality control requirements of 40 CFR 75
.21 and Appendix B to 40 CFR
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75 are fully met, the monitoring system shall be exempt from the initial
certification requirements of this Section
.
2)
The recertification provisions of this Section shall apply to an emissions
monitoring system required by Section 225
.240(a)(1) of this Subpart
exempt from initial certification requirements under subsection (a)(1) of
this Section
.
c)
Initial certification and recertification procedures for EGUs using the mercury low
mass emissions excepted methodology under 40 CFR 75
.81(b) . The owner or
operator of an EGU qualified to use the mercury low mass emissions excepted
methodology under 40 CFR 75
.81(b) shall meet the applicable certification and
recertification requirements in 40 CFR 75.81(c)
through (f).
d)
Certification Applications
. The owner or operator of an EGU shall submit an
application to the Agency within 45 days after completing all initial certification
or recertification tests required under this Section, including the information
required under 40 CFR 75 .63
.
Section 225
.260
Out of Control Periods for Emission Monitors
a)
Whenever any emissions monitoring system fails to meet the quality-assurance
and quality-control requirements or data validation requirements of 40 CFR 75,
data shall be substituted using the applicable missing data procedures in Subparts
D and I of 40 CFR 75 .
b)
Audit Decertification
. Whenever both an audit of an emissions monitoring
system and a review of the initial certification or recertification application reveal
that any emissions monitoring system should not have been certified or recertified
because it did not meet a particular performance specification or other
requirement under Section 225
.250 of this Subpart or the applicable provisions of
40 CFR 75, both at the time of the initial certification or recertification application
submission and at the time of the audit, the Agency will issue a notice of
disapproval of the certification status of such monitoring system
. For the
purposes of this subsection, an audit shall be either a field audit or an audit of any
information submitted to the Agency
. By issuing the notice of disapproval, the
Agency revokes prospectively the certification status of the emissions monitoring
system
. The data measured and recorded by the monitoring system shall not be
considered valid quality-assured data from the date of issuance of the notification
of the revoked certification status until the date and time that the owner or
operator completes subsequently approved initial certification or recertification
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tests for the monitoring system
. The owner or operator shall follow the applicable
initial certification or recertification procedures in Section 225
.250 of this Subpart
for each disapproved monitoring system .
Section 225 .261
Additional Requirements to Provide Heat Input Data
The owner or operator of an EGU that monitors and reports mercury mass emissions using a
mercury concentration monitoring system and a flow monitoring system shall also monitor and
report heat input rate at the EGU level using the procedures set forth in 40 CFR 75
.
Section 225
.263
Monitoring of Gross Electrical Output
The owner or operator of an EGU complying with this Subpart by means of Section
225.230(a)(1)
or using electrical output (O;)
and complying by means of Section 225
.230(b) or
(d) or Section 225
.232 of this Subpart shall monitor gross electrical output of the associated
generator(s) in MWh on an hourly basis
.
Section 225
.265
Coal Analysis for Input Mercury Levels
a)
The owner or operator of an EGU complying with this Subpart by means of
Section 225
.230(a)(2) or using input mercury levels
(I,)
and complying by means
of Section 225
.230(b) or (d) or Section 225
.232 of this Subpart shall :
1)
Perform daily sampling of the coal combusted in the EGU for mercury
content
. The owner or operator of such EGU shall collect a minimum of
one 2-lb grab sample per day of operation from the belt feeders anywhere
between the crusher house or breaker building and the boiler
. The sample
shall be taken in such a manner so as to provide a representative mercury
content for the coal burned on that day .
2)
Analyze the grab coal sample for the following
:
A)
Determine the heat content using ASTM D5865-04 or equivalent
approved in writing by the Agency .
B)
Determine the moisture content using ASTM D3173-03 or
equivalent approved in writing by the Agency
.
C)
Measure the mercury content using ASTM D6414-01, ASTM
D3684-01, or equivalent approved in writing by the Agency
.
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3)
The owner or operator of multiple EGUs at the same source using the
same crusher house or breaker building may take one sample per crusher
house or breaker building, rather than one per EGU
.
4)
The owner or operator of an EGU shall use the data analyzed under
subsection (b) of this Section to determine the mercury content in terms of
lbs/trillion Btu .
b)
The owner or operator of an EGU that must conduct sampling and analysis of coal
pursuant to subsection (a) of this Section shall begin such activity by the
following date :
1)
If the EGU is in daily service, at least 30 days before the start of the month
for which such activity will be required .
2)
If the EGU is not in daily service, on the day that the EGU resumes
operation.
a)
Section 225 .270
Notifications
The owner or operator of a source with one or more EGUs shall submit written notice to the
Agency according to the provisions in 40 CFR 75
.61 for each EGU or group of EGUs monitored
at a common stack and each non-EGU monitored under 40 CFR 75
.82(b)(2)(ii) .
Section 225 .290
Recordkeeping and Reporting
General Provisions .
1)
The owner or operator of an EGU and its designated representative shall
comply with all applicable recordkeeping and reporting requirements in
this Section and with all applicable recordkeeping and reporting
requirements of 40 CFR 75
.84.
2)
The owner or operator of an EGU shall maintain records for each month
identifying the emission standard in Section 225
.230(a) or 225
.237(a) of
this Section with which it is complying or that is applicable for the EGU
and the following records related to the emissions of mercury that the
EGU is allowed to emit
:
A)
For an EGU for which the owner or operator is complying with
this Subpart by means of Section 225
.230(a)(2) or
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225 .237(a)(1)(B) or using input mercury levels to determine the
allowable emissions of the EGU, records of the daily mercury
content of coal used (lbs/trillion Btu) and the daily and monthly
input mercury (lbs), which shall be kept in the file required under
40 CFR 75 .84(a) .
B)
For an EGU for which the owner or operator of an EGU complying
with this Subpart by means of Section 225.230(a)(1) or
225.237(a)(1 )(A) or using electrical output to determine the
allowable emissions of the EGU, records of the daily and monthly
gross electrical output (GWh), which shall be kept in the file
required under 40 CFR 75 .84(a).
3)
The owner or operator of an EGU shall maintain records of the following
for each EGU:
A)
Monthly emissions of mercury from the EGU
.
B)
For an EGU for which the owner or operator is complying by
means of Section 225 .230(b) or (d) of this Subpart, records of the
monthly allowable emissions of mercury from the EGU .
4)
The owner or operator of an EGU that is participating in an Averaging
Demonstration pursuant to Section 225 .232 of this Subpart shall maintain
records identifying all sources and EGUs covered by the Demonstration
for each month and, within 60 days after the end of each calendar month,
calculate and record the actual and allowable mercury emissions of the
EGU for the month and the applicable 12-month rolling period .
5)
The owner or operator of an EGU shall maintain the following records
related to quality assurance activities conducted for emissions monitoring
systems :
A)
The results of quarterly assessments conducted under Section 2
.2
of Appendix B of 40 CFR 75
; and
B)
Daily/weekly system integrity checks under Section 2 .6 of
Appendix B of 40 CFR 75.
6)
The owner or operator of an EGU shall maintain an electronic copy of all
electronic submittals to the USEPA under 40 CFR 75 .84(f).
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7)
The owner or operator of an EGU shall retain all records required by this
Section at the source unless otherwise provided in the CAAPP permit
issued for the source and shall make a copy of any record available to the
Agency upon request.
b)
Quarterly Reports
. The owner or operator of a source with one or more EGUs
shall submit quarterly reports to the Agency as follows
:
1)
These reports shall include the following information for operation of the
EGUs during the quarter:
A)
The total operating hours of each EGU and the mercury CEMS, as
also reported in accordance with 40 CFR 75
.
B)
A discussion of any significant changes in the measures used to
control emissions of mercury from the EGUs or the coal supply to
the EGUs, including changes in the source of coal
.
C)
Summary information on the performance of the mercury CEMS
.
When the mercury CEMS was not inoperative, repaired, or
adjusted, except for routine zero and span checks, this shall be
stated in the report.
D)
If the CEMS downtime was more than 5
.0 percent of the total
operating time for the EGU
: the date and time identifying each
period during which the CEMS was inoperative, except for routine
zero and span checks
; the nature of CEMS repairs or adjustments
and a summary of quality assurance data consistent with 40 CFR
75, i.e.,
the dates and results of the Linearity Test(s) and any
Relative Accuracy Test Audit(s) during the quarter
; a listing of any
days when a required daily calibration was not performed
; and the
date and duration of any periods when the CEMS was out-of-
control as addressed by Section 225
.260 of this Subpart .
2)
The owner or operator shall submit each quarterly report to the Agency
within 45 days following the end of the calendar quarter covered by the
report
.
c)
Compliance Certification
. The owner or operator of a source with one or more
EGUs shall submit to the Agency a compliance certification in support of each
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quarterly report based on reasonable inquiry of those persons with primary
responsibility for ensuring that all of the EGUs' emissions are correctly and fully
monitored. The certification shall state
:
1)
That the monitoring data submitted were recorded in accordance with the
applicable requirements of this Section, Sections 225
.240 through
225 .270, and Section 225
.290 of this Subpart, and 40 CFR 75, including
the quality assurance procedures and specifications
; and
2)
For an EGU with add-on mercury emission controls, a flue gas
desulfurization system, a selective catalytic reduction system, or a
compact hybrid particulate collector system and for all hours where
mercury data are substituted in accordance with 40 CFR 75
.34(a)(1) :
A)
That :
i)
The mercury add-on emission controls, flue gas
desulfurization system, selective catalytic reduction system,
or compact hybrid particulate collector system was
operating within the range of parameters listed in the
quality assurance/quality control program under Appendix
B to 40 CFR 75 ; or
ii)
With regard to a flue gas desulfurization system or a
selective catalytic reduction system, quality-assured SO2
emission data recorded in accordance with 40 CFR 75
document that the flue gas desulfurization system was
operating properly, or quality-assured NO
x emission data
recorded in accordance with 40 CFR 75 document that the
selective catalytic reduction system, was operating
properly, as applicable
; and
B)
The substitute data values do not systematically underestimate
mercury emissions .
d)
Annual Certification of Compliance
1)
The owner or operator of a source with one or more EGUs subject to this
Subpart shall submit to the Agency an Annual Certification of Compliance
with this Subpart no later than May I of each year and shall address
compliance for the previous calendar year
. Such certification shall be
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submitted to the Agency, Air Compliance and Enforcement Section, and
the Air Regional Field Office .
2)
Annual Certifications of Compliance shall indicate whether compliance
existed for each EGU for each month in the year covered by the
Certification and certification to that effect
. In addition, for each EGU,
the owner or operator shall provide the following :
A)
If complying with this Subpart by means of Section
225 .230(a)(1)(A) or 225
.237(a)(1)(A):
i)
Actual emissions rate, in lb/GWh, for each 12-month
rolling period ending in the year covered by the
Certification;
ii)
Actual emissions, in Ibs, and gross electrical output, in
GWh, for each 12-month rolling period ending in the year
covered by the Certification
; and
iii)
Actual emissions, in lbs, and gross electrical output, in
GWh, for each month in the year covered by the
Certification and in the previous year
.
B)
If complying with this Subpart by means of Section
225 .230(a)(1)(B) or 225 .237(a)(1)(B):
i)
Actual control efficiency for emissions for each 12-month
rolling period ending in the year covered by the
Certification, expressed as a percent ;
ii)
Actual emissions, in lbs, and mercury content in the fuel
fired in such EGU, in lbs, for each 12-month rolling period
ending in the year covered by the Certification
; and
iii)
Actual emissions, in lbs, and mercury content in the fuel
fired in such EGU, in Ibs, for each month in the year
covered by the Certification and in the previous year
.
C)
If complying with this Subpart by means of Section 225
.230(b):
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i) Actual emissions and allowable emissions for each 12-
month rolling period ending in the year covered by the
Certification; and
ii)
Actual emissions and allowable emissions, and which
standard of compliance the owner or operator was utilizing
for each month in the year covered by the Certification and
in the previous year .
D)
If complying with this Subpart by means of Section 225
.230(d):
i) Actual emissions and allowable emissions for all EGUs at
the source for each 12-month rolling period ending in the
year covered by the Certification
; and
ii)
Actual emissions and allowable emissions, and which
standard of compliance the owner or operator was utilizing
for each month in the year covered by the Certification and
in the previous year .
E)
If complying with this Subpart by means of Section 225
.232 :
i)
Actual emissions and allowable emissions for all EGUs at
the source in an Averaging Demonstration for each 12-
month rolling period ending in the year covered by the
Certification; and
ii)
Actual emissions and allowable emissions, with the
standard of compliance the owner or operator was utilizing
for each EGU at the source in an Averaging Demonstration
for each month for all EGUs at the source in an Averaging
Demonstration in the year covered by the Certification and
in the previous year
.
F)
Any deviations, data substitutions, or exceptions each month and
discussion of the reasons for such deviations, data substitutions, or
exceptions
.
3)
All Annual Certifications of Compliance required to be submitted shall
include the following certification by a responsible official
:
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b)
The Agency shall hold all allowances allocated by the USEPA to the State
. At the
end of each calendar year, the Agency shall instruct the USEPA to retire
permanently all such allowances .
Section
225 .100
Severability
225
.120
Abbreviations and Acronyms
225 .130
Definitions
225
.140
Incorporations by Reference
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TITLE 35
: ENVIRONMENTAL PROTECTION
SUBTITLE B : AIR POLLUTION
CHAPTER I : POLLUTION CONTROL BOARD
SUBCHAPTER c
: EMISSION STANDARDS AND LIMITATIONS FOR STATIONARY
SOURCES
PART 225
CONTROL OF EMISSIONS FROM LARGE COMBUSTION SOURCES
SUBPART A
: GENERAL PROVISIONS
SUBPART B
: CONTROL OF MERCURY EMISSIONS FROM COAL-FIRED ELECTRIC
GENERATING UNITS
Section
225 .200
Purpose
225 .202
Measurement Methods
225 .205
Applicability
225 .210
Compliance Requirements
225
.220
Clean Air Act Permit Program (CAAPP) Permit Requirements
225 .230
Emission Standards for EGUs at Existing Sources
225 .232
Averaging Demonstrations for Existing Sources
225 .235
Units Scheduled for Permanent Shut Down
225 .237
Emission Standards for New Sources with EGUs
225 .240
General Monitoring and Reporting Requirements
225
.250
Initial Certification and Recertification Procedures for Emissions Monitoring
225 .260
Out of Control Periods for Emission Monitors
225 .261
Additional Requirements to Provide Heat Input Data
225 .263
Monitoring of Gross Electrical Output
225 .265
Coal Analysis for Input Mercury Levels
225 .270
Notifications
225 .290
Recordkeeping and Reporting
225 .295
Treatment of Mercury Allowances
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AUTHORITY
: Implementing and authorized by Section 27 of the Environmental Protection Act
[415 ILCS 5/27] .
SOURCE
: Adopted at 30 IllSUBPART
. Reg. A,
:
effectiveGENERAL PROVISIONS
Section 225 .100
Severability
If any Section, subsection or clause of this Part is found invalid, such finding shall not affect the
validity of this Part as a whole or any Section, subsection or clause not found invalid
.
Section 225 .120
Abbreviations and Acronyms
Unless otherwise specified within this Part, the abbreviations used in this Part shall be the same
as those found in 35 111 . Adm. Code 211
. The following abbreviations and acronyms are used in
this Part :
Act
Environmental Protection Act [415 ILCS 5/1]
Btu
British thermal unit
CAA
Clean Air Act [42 USC 7401 et seq.]
CAAPP
Clean Air Act Permit Program
CO2
carbon dioxide
EGU
electric generating unit
GWh
gigawatt hour
hr
hour
lb
pound
MW
megawatt
MWe
megawatt electrical
MWh
megawatt hour
NOx
nitrogen oxides
02
oxygen
RATA
relative accuracy test audit
SO2
sulfur dioxide
USEPA
United States Environmental Protection Agency
Section 225
.130
Definitions
The definitions contained in this Section apply only to the provisions of this Part
. Unless
otherwise defined in this Section and unless a different meaning of a term is clear from its
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context, the definitions of terms used in this Part shall have the meanings specified for those
terms in 35111
. Adm. Code 211 .
"Averaging demonstration" means, with regard to Subpart B of this Part, a demonstration
of compliance that is based on the combined performance of EGUs at two or more
sources.
"Boiler" means an enclosed fossil or other fuel-fired combustion device used to produce
heat and to transfer heat to recirculating water, steam, or other medium
.
"Bottoming-cycle cogeneration unit" means a cogeneration unit in which the energy input
to the unit is first used to produce useful thermal energy and at least some of the reject
heat from the useful thermal energy application or process is then used for electricity
production
.
"Coal" means any solid fuel classified as anthracite, bituminous, subbituminous, or
lignite by the American Society for Testing and Materials (ASTM) Standard
Specification for Classification of Coals by Rank D388-77, 90, 91, 95, 98a, or 99
(Reapproved 2004)
.
"Coal-derived fuel" means any fuel (whether in a solid, liquid or gaseous state) produced
by the mechanical, thermal, or chemical process .
"Coal-fired" means combusting any amount of coal or coal-derived fuel, alone or in
combination with any amount of any other fuel, during a specified year
.
"Cogeneration unit" means a stationary, fossil fuel-fired boiler or stationary, fossil fuel-
fired combustion turbine :
Having equipment used to produce electricity and useful thermal energy for
industrial, commercial, heating, or cooling purposes through the sequential use of
energy ; and
Producing during the 12-month period starting on the date the unit first produces
electricity and during any calendar year after the calendar year in which the unit
first produces electricity :
For a topping-cycle cogeneration unit,
"Combustion turbine" means
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Useful thermal energy not less than 5 percent of total energy
output; and
Useful power that, when added to one-half of useful thermal
energy produced, is not less than 42
.5 percent of total energy input,
if useful thermal energy produced is 15 percent or more of total
energy output, or not less than 45 percent of total energy input, if
useful thermal energy produced is less than 15 percent of total
energy output .
For a bottoming-cycle cogeneration unit, useful power not less than 45
percent of total energy input
.
An enclosed device comprising a compressor, a combustor, and a turbine and in
which the flue gas resulting from the combustion of fuel in the combustor passes
through the turbine, rotating the turbine
; and
If the enclosed device under the above paragraph of this definition is combined
cycle, any associated heat recovery steam generator and steam turbine
.
"Commence commercial operation" means, with regard to Subpart B of this Part, with
regard to an Electric Generating Unit that serves a generator, to have begun to produce
steam, gas, or other heated medium used to generate electricity for sale or use, including
test generation
. Such date shall remain the unit's date of commencement of operation
even if the Electric Generating Unit is subsequently modified, reconstructed or
repowered.
"Designated representative" means, with regard to Subpart B of this Part, the same as
defined in 40 CFR 60 .4102.
"Flue" means a conduit or duct through which gases or other matter is exhausted to the
atmosphere .
"Gross electrical output" means the total electrical output from an Electric Generating
Unit before making any deductions for energy output used in any way related to the
production of energy
. For an Electric Generating Unit generating only electricity, the
gross electrical output is the output from the turbine/generator set
.
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"Input mercury" means the mass of mercury that is contained in the coal combusted
within an Electric Generating Unit .
"Nameplate capacity" means, starting from the initial installation of a generator, the
maximum electrical generating output (in MWe) that the generator is capable of
producing on a steady-state basis and during continuous operation (when not restricted by
seasonal or other deratings) as specified by the manufacturer of the generator or, starting
from the completion of any subsequent physical change in the generator resulting in an
increase in the maximum electrical generating output (in MWe) that the generator is
capable of producing on a steady-state basis and during continuous operation (when not
restricted by seasonal or other deratings), such increased maximum amount as specified
by the person conducting the physical change .
"Output-based emission standard" means, with regard to Subpart B of this Part, a
maximum allowable rate of emissions of mercury per unit of gross electrical output from
an Electric Generating Unit .
"Repowered" means, with regard to an EGU, replacement of a coal-fired boiler with one
of the following coal-fired technologies at the same source as the coal-fired boiler :
Atmospheric or pressurized fluidized bed combustion
;
Integrated gasification combined cycle ;
Magnetohydrodynamics ;
Direct and indirect coal-fired turbines ;
Integrated gasification fuel cells
; or
As determined by the USEPA in consultation with the United States Department
of Energy, a derivative of one or more of the technologies under this definition
and any other coal-fired technology capable of controlling multiple combustion
emissions simultaneously with improved boiler or generation efficiency and with
significantly greater waste reduction relative to the performance of technology in
widespread commercial use as of January 1, 2005 .
"Rolling 12-month basis" means, with regard to Subpart B of this Part, a determination
made on a monthly basis from the relevant data for a particular calendar month and the
preceding 11 calendar months (total of 12 months of data), with two exceptions . For
determinations involving one EGU, calendar months in which the EGU does not operate
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(zero EGU operating hours) shall not be included in the determination, and shall be
replaced by a preceding month or months in which the EGU does operate, so that the
determination is still based on 12 months of data
. For determinations involving two or
more EGUs, calendar months in which none of the EGUs covered by the determination
operates (zero EGU operating hours) shall not be included in the determination, and shall
be replaced by preceding months in which at least one of the EGU covered by the
determination does operate, so that the determination is still based on 12 months of data
.
Section 225 .140
Incorporations by Reference
The following materials are incorporated by reference . These incorporations do not include any
later amendments or editions .
a)
40 CFR 60, § 60
.17, § 60 .45a, § 60 .49a(k)(1), § 60 .49a(p), § 60.50a(h),
and §§
60.4170
through 60 .4176 (2005) .
b)
40 CFR 75 (2005) .
c)
ASTM
. American Society for Testing and Materials, 100 Barr Harbor Drive, P
.O .
Box C700, West Conshohocken PA 19428-2959, (610) 832-9585
:
1)
ASTM D388-77, 90, 91, 95, 98a, or 99, Classification of Coals by Rank
(Reapproved 2004).
2)
ASTM D3173-03, Standard Test Method for Moisture in the Analysis
Sample of Coal and Coke (Approved April 10, 2003) .
3)
ASTM D3684-01, Standard Test Method for Total Mercury in Coal by the
Oxygen Bomb Combustion/Atomic Absorption Method (Approved
October 10, 2001) .
4)
ASTM D5865-04, Standard Test Method for Gross Calorific Value of
Coal and Coke (Approved April 1, 2004)
.
5)
ASTM D6414-01, Standard Test Method for Total Mercury in Coal and
Coal Combustion Residues by Acid Extraction or Wet Oxidation/Cold
Vapor Atomic Absorption (Approved October 10, 2001)
.
6)
ASTM D6784-02, Standard Test Method for Elemental, Oxidized,
Particle-Bound and Total Mercury in Flue Gas Generated from Coal-Fired
Stationary Sources (Ontario Hydro Method) (Approved April 10, 2002)
.
f)
Section 225 .205
Applicability
The following stationary coal-fired boilers and stationary coal-fired combustion turbines are
EGUs and are subject to this Subpart
:
a)
Except as provided in subsection (b) of this Section, a unit serving at any time
since the start-up of the unit's combustion chamber, a generator with nameplate
capacity of more than 25 MWe producing electricity for sale .
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SUBPART B
: CONTROL OF MERCURY EMISSIONS FROM COAL-FIRED ELECTRIC
GENERATING UNITS
Section 225 .200
Purpose
The purpose of this Subpart is to control the emissions of mercury from coal-fired electrical
generating units in Illinois.
Section 225
.202
Measurement Methods
Measurement of mercury shall be according to the following :
a)
Continuous emission monitoring pursuant to 40 CFR 75 (2005) .
b)
ASTM D3173-03, Standard Test Method for Moisture in the Analysis Sample of
Coal and Coke (Approved April 10, 2003) .
c)
ASTM D3684-01, Standard Test Method for Total Mercury in Coal by the
Oxygen Bomb Combustion/Atomic Absorption Method (Approved October 10,
2001) .
d)
ASTM D5865-04, Standard Test Method for Gross Calorific Value of Coal and
Coke (Approved April 1, 2004) .
e)
ASTM D6414-01, Standard Test Method for Total Mercury in Coal and Coal
Combustion Residues by Acid Extraction or Wet Oxidation/Cold Vapor Atomic
Absorption (Approved October 10, 2001)
.
ASTM D6784-02, Standard Test Method for Elemental, Oxidized, Particle-Bound
and Total Mercury in Flue Gas Generated from Coal-Fired Stationary Sources
(Ontario Hydro Method) (Approved April 10, 2002)
.
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b)
For a unit that qualifies as a cogeneration unit during the 12-month period starting
on the date the unit first produces electricity and continues to qualify as a
cogeneration unit, a cogeneration unit serving at any time a generator with
nameplate capacity of more than 25 MWe and supplying in any calendar year
more than one-third of the unit's potential electric output capacity or 219,000
MWh, whichever is greater, to any utility power distribution system for sale
. If a
unit qualifies as a cogeneration unit during the 12-month period starting on the
date the unit first produces electricity but subsequently no longer qualifies as a
cogeneration unit, the unit shall be subject to subsection (a) of this Section
starting on the day on which the unit first no longer qualifies as a cogeneration
unit.
Section 225
.210
Compliance Requirements
a)
Permit Requirements
The owner or operator of each source with one or more EGUs subject to this
Subpart at the source must apply for a CAAPP permit that addresses the
applicable requirements of this Subpart .
b)
Monitoring Requirements
1)
The owner or operator of each source and each EGU at the source must
comply with the monitoring requirements of Sections 225
.240 through
225.290 of this Subpart .
2)
The compliance of each EGU with the mercury requirements under
Sections 225 .230 and 225
.237 of this Subpart shall be determined by the
emissions measurements recorded and reported in accordance with
Sections 225 .240 through 225
.290 of this Subpart .
c)
Mercury Emission Reduction Requirements
The owner or operator of any EGU subject to this Subpart shall comply with
applicable requirements for control of mercury emissions under Section 225
.230
or Section 225
.237 of this Subpart .
d)
Recordkeeping and Reporting Requirements
Unless otherwise provided, the owner or operator of a source with one or more
EGUs at the source shall keep on site at the source each of the documents listed in
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subsections (d)(1) through (d)(3)
of this Section for a period of five years from the
date the document is created . This period may be extended for cause, at any time
prior to the end of five years, in writing by the Agency
.
I)
All emissions monitoring information, in accordance with Sections
225.240 through 225 .290 of this Subpart
.
2)
Copies of all reports, compliance certifications, and other
submissions and all records made or required or documents
necessary to demonstrate compliance with the requirements of this
Subpart.
3)
Copies of all documents used to complete a permit application and
any other submission under this Subpart .
e)
Liability
1)
The owner or operator of each source with one or more EGUs shall meet
the requirements of this Subpart
.
2)
Any provision of this Subpart that applies to a source shall also apply to
the owner and operator of such source and to the owner and operator of
each EGU at the source.
3)
Any provision of this Subpart that applies to an EGU shall also apply to
the owner and operator of such EGU .
f)
Effect on Other Authorities
. No provision of this Subpart shall be construed as
exempting or excluding the owner and operator of a source or EGU from
compliance with any other provision of an approved State Implementation Plan, a
permit, the Act, or the CAA
.
Section 225
.220
Clean Air Act Permit Program (CAAPP) Permit Requirements
a)
Application Requirements
1)
Each source with one or more EGUs subject to the requirements of this
Subpart is required to submit a CAAPP permit application that addresses
all applicable requirements of this Subpart, applicable to each EGU at the
source
.
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2)
For any EGU that commenced commercial operation :
A) on or before December 31, 2008, the owner or operator of such
EGUs must submit an initial permit application or application for
CAAPP permit modification that meets the requirements of this
Section by December 31, 2008 .
B)
after December 31, 2008, the owner or operator of any such EGU
must submit an initial CAAPP permit application or application for
CAAPP modification that meets the requirements of this Section
not later than 180 days before initial startup of the EGU unless the
construction permit issued for the EGU addresses the requirements
of this Subpart.
b)
Contents of Permit Applications
In addition to other information required for a complete application for CAAPP
permit or CAAPP permit modification, the application shall include the following
information :
1)
The ORIS (Office of Regulatory Information Systems) or facility
code assigned to the source by the Energy Information
Administration, if applicable
.
2)
Identification of each EGU at the source
.
3)
The intended approach to the monitoring requirements of Sections
225 .240 through 225
.290 of this Subpart .
4)
The intended approach to the mercury emission reduction
requirements of Section 225
.230 or 225 .237 of this Subpart, as
applicable .
c)
Permit Contents
1)
Each CAAPP permit issued by the Agency for a source with one or more
EGUs subject to the requirements of this Subpart shall contain federally
enforceable conditions addressing all applicable requirements of this
Subpart, which conditions shall be a complete and segregable portion of
the source's entire CAAPP permit.
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2)
In addition to conditions related to the applicable requirements of this
Subpart, each such CAAPP permit shall also contain the information
specified under subsection (b) of this Section
.
Section 225 .230
Emission Standards for EGUs at Existing Sources
a)
Emission Standards
1)
Beginning July 1, 2009, the owner or operator of a source with one
or more EGUs subject to this Subpart that commenced commercial
operation on or before December 31, 2008, shall comply with one of the
following standards for each EGU on a rolling 12-month basis
:
A)
An emission standard of 0
.0080 lb mercury/GWh gross electrical
output
; or
B)
A minimum 90-percent reduction of input mercury
.
2)
For an EGU complying with subsection
(a)(1)(A)
of this Section, the
actual mercury emission rate of the EGU for each 12-month rolling period,
as monitored in accordance with this Subpart and calculated as follows,
shall not exceed the applicable emission standard
:
12
u
ER =ZE,+ O,
Where
:
ER =
Actual mercury emissions rate of the EGU for the particular 12-
month rolling period, expressed in lb/GWh
.
E; =
Actual mercury emissions of the EGU, in lbs, in an individual
month in the 12-month rolling period, as determined in accordance
with the emissions monitoring provisions of this Subpart
.
O; =
Gross electrical output of the EGU, in GWh, in an individual
month in the 12-month rolling period, as determined in accordance
with Section 225
.263 of this Subpart
.
3)
For an EGU complying with subsection
(a)(1)(B)
of this Section, the
actual control efficiency for mercury emissions achieved by the EGU for
each 12-month rolling period, as monitored in accordance with this
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Subpart and calculated as follows, shall meet or exceed the applicable
efficiency requirement :
12
12
CE =100x{1-(ZE,=I1;)}
i= 1
`I
Where:
CE
= Actual control efficiency for mercury emissions of the EGU for the
particular 12-month rolling period, expressed as a percent .
E; - Actual mercury emissions of the EGU, in lbs, in an individual
month in the 12-month rolling period, as determined in accordance
with the emissions monitoring provisions of this Subpart .
1; = Amount of mercury in the fuel fired in the EGU, in pounds, in an
individual month in the 12-month rolling period, as determined in
accordance with Section 225 .265 of this Subpart
.
b)
Alternative Emission Standards for Single EGUs
1)
As an alternative to compliance with one of the above emission standards
in subsection (a) of this Section, the owner or operator of the EGU may
comply with the emission standards of this Subpart by demonstrating that
the actual emissions of mercury from the EGU are less than the allowable
emissions of mercury from the EGU on a rolling 12-month basis
.
2)
For this purpose, for each rolling 12-month period, the actual emissions of
mercury from the EGU, as monitored in accordance with this Subpart,
must not exceed the allowable emissions of mercury from the EGU, as
further provided by the following formulas :
E12 5 A12
12
E12 = LE,
12
A12 = LA,
i=1
Where:
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E12 =
Actual mercury emissions of the EGU for the particular 12-month
rolling period
.
A12= Allowable mercury emissions of the EGU for the particular 12-
month rolling period.
E;
= Actual mercury emissions of the EGU in an individual month in the
12-month rolling period .
A ;
= Allowable mercury emissions of the EGU in an individual month in
the 12-month rolling period, based on either the input mercury to the unit
(A,,, P„, ;) or the electrical output from the EGU (Aou,P,,,
;),
as selected by the
owner or operator of the EGU for that given month .
A,„p,,, ; = Allowable mercury emissions of the EGU in an individual month
based on the input mercury to the EGU, calculated as 10 .0 percent (or
0
.100) of the input mercury to the EGU .
Ao,,,P,,,, = Allowable mercury emissions of the EGU in a particular month
based on the electrical output from the EGU, calculated as the product of
the output based mercury limit, i.e., 0.0080 lb/GWh, and the electrical
output from the EGU, in GWh .
3)
If the owner or operator of an EGU does not conduct the necessary
sampling, analysis, and recordkeeping, in accordance with Section
225
.265 of this Subpart, to determine the mercury input to the EGU, the
allowable emissions of the EGU must be calculated based on the electrical
output of the EGU .
c)
If two or more EGUs are served by common stack(s) and the owner or operator
conducts monitoring for mercury emissions in the common stack(s), as provided
for by 40 CFR 75, Subpart I, such that the mercury emissions of each EGU are
not determined separately, compliance of the EGUs with the applicable emission
standards of this Subpart shall be determined as if the EGUs were a single EGU
.
d)
Alternative Emission Standards for Multiple EGUs
1)
As an alternative to compliance with the emission standards of subsection
(a) of this Section, the owner or operator of a source with an EGU may
comply with the emission standards of this Subpart by demonstrating that
the actual emissions of mercury from all EGUs at the source are less than
the allowable emissions of mercury from all EGUs at the source on a
rolling 12-month basis.
2)
For this purpose, for each rolling 12-month period, the actual emissions of
mercury from all the EGUs at the source, as monitored in accordance with
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this Subpart, must not exceed the sum of the allowable emissions of
mercury from all the EGUs at the source, as further provided by the
following formulas:
E s
<_
As
h
Es
=YE,
=I
As
=
JA,
Where :
Es= Sum of the actual mercury emissions of the EGUs at the source .
As
=
Sum of the allowable mercury emissions of the EGUs at the source.
E; = Actual mercury emissions of an individual EGU at the source, as
determined in accordance with subsection (b)(2)
of this Section .
A ; = Allowable mercury emissions of an individual EGU at the source, as
determined in accordance with subsection (b)(2) of this Section .
n = Number of EGUs covered by the demonstration .
3)
If an owner or operator of a source with two or more EGUs that is relying
on this subsection (d) to demonstrate compliance fails to meet the
requirements of this subsection (d) in a given 12-month rolling period, all
EGUs at such source covered by the compliance demonstration are
considered out of compliance with the applicable emission standards of
this Subpart for the entire last month of that period .
Section 225 .232
Averaging Demonstrations for Existing Sources
a)
Through December 31, 2013, as an alternative to compliance with the emission
standards of Section 225 .230(a) of this Subpart, the owner or operator of an EGU
may comply with the emission standards of this Subpart by means of an
Averaging Demonstration (Demonstration) that shows that the actual emissions of
mercury from the EGU and other EGUs at the source and other EGUs at other
sources covered by the Demonstration are less than the allowable emissions of
mercury from all EGUs covered by the Demonstration on a rolling 12-month
basis.
