Illinois Administrative Code
Title 35 - ENVIRONMENTAL PROTECTION
Part 225 - CONTROL OF EMISSIONS FROM LARGE COMBUSTION SOURCES
Subpart B - CONTROL OF MERCURY EMISSIONS FROM COAL-FIRED ELECTRIC GENERATING UNITS
Section 225.233 - Multi-Pollutant Standards (MPS)
Universal Citation: 35 IL Admin Code ยง 225.233
Current through Register Vol. 48, No. 38, September 20, 2024
a) General
1) As an alternative to compliance
with the emissions standards of Section
225.230(a),
the owner of eligible EGUs may elect for those EGUs to demonstrate compliance
pursuant to this Section, which establishes control requirements and standards
for emissions of NOx and SO2, as
well as for emissions of mercury.
2) For the purpose of this Section, the
following requirements apply:
A) An eligible
EGU is an EGU that is located in Illinois and which commenced commercial
operation on or before December 31, 2004; and
B) Ownership of an eligible EGU is determined
based on direct ownership, by the holding of a majority interest in a company
that owns the EGU or EGUs, or by the common ownership of the company that owns
the EGU, whether through a parent-subsidiary relationship, as a sister
corporation, or as an affiliated corporation with the same parent corporation,
provided that the owner has the right or authority to submit a CAAPP
application on behalf of the EGU.
3) The owner of one or more EGUs electing to
demonstrate compliance with this Subpart B pursuant to this Section must submit
an application for a CAAPP permit modification to the Agency, as provided in
Section
225.220,
that includes the information specified in subsection (b) and which clearly
states the owner's election to demonstrate compliance pursuant to this Section
225.233.
A) If the owner of one or more EGUs
elects to demonstrate compliance with this Subpart pursuant to this Section,
then all EGUs it owns in Illinois as of July 1, 2006, as defined in subsection
(a)(2)(B), must be thereafter subject to the standards and control requirements
of this Section, except as provided in subsection (a)(3)(B). Such EGUs must be
referred to as a Multi-Pollutant Standard (MPS) Group.
B) Notwithstanding the foregoing, the owner
may exclude from an MPS Group any EGU scheduled for permanent shutdown that the
owner so designates in its CAAPP application required to be submitted pursuant
to subsection (a)(3), with compliance for such units to be achieved by means of
Section
225.235.
4) Notwithstanding any contrary provision in
this subsection (a), on and after January 1, 2019:
A) The following EGUs shall be merged into a
new MPS Group: Baldwin Units 1, 2, and 3; Coffeen Units 1 and 2; Duck Creek
Unit 1; E.D. Edwards Units 2 and 3; Havana Unit 9; Hennepin Units 1 and 2;
Joppa Units 1, 2, 3, 4, 5, and 6; and Newton Unit 1. If one or more of the
above EGUs are transferred to a different owner, such EGU or EGUs will become a
separate MPS Group on and after the date of transfer. For purposes of this
Section, "transfer" means sale, conveyance, transfer, or other change in
ownership of an EGU; and
B) No
other EGUs except for those listed in subsection (a)(4)(A) are subject to the
requirements of this Section.
5) When an EGU is subject to the requirements
of this Section, the requirements apply to all owners or operators of the
EGU.
b) Notice of Intent
The owner of one or more EGUs that intends to comply with this Subpart B by means of this Section must notify the Agency of its intention by December 31, 2007. The following information must accompany the notification:
1) The identification of
each EGU that will be complying with this Subpart B by means of the
multi-pollutant standards contained in this Section, with evidence that the
owner has identified all EGUs that it owned in Illinois as of July 1, 2006 and
which commenced commercial operation on or before December 31, 2004;
2) If an EGU identified in subsection (b)(1)
is also owned or operated by a person different than the owner submitting the
notice of intent, a demonstration that the submitter has the right to commit
the EGU or authorization from the responsible official for the EGU accepting
the application;
3) The Base
Emission Rates for the EGUs, with copies of supporting data and
calculations;
4) A summary of the
current control devices installed and operating on each EGU and identification
of the additional control devices that will likely be needed for the each EGU
to comply with emission control requirements of this Section, including
identification of each EGU in the MPS group that will be addressed by
subsection (c)(1)(B), with information showing that the eligibility criteria
for this subsection (b) are satisfied; and
5) Identification of each EGU that is
scheduled for permanent shutdown, as provided by Section 225.235, which will
not be part of the MPS Group and which will not be demonstrating compliance
with this Subpart B pursuant to this Section.
c) Control Technology Requirements for Emissions of Mercury
1) Requirements for EGUs
in an MPS Group
A) For each EGU in an MPS
Group other than an EGU that is addressed by subsection (c)(1)(B) for the
period beginning July 1, 2009 (or December 31, 2009 for an EGU for which an SO2
scrubber or fabric filter is being installed to be in operation by December 31,
2009), and ending on December 31, 2014 (or such earlier date that the EGU is
subject to the mercury emission standard in subsection (d)(1)), the owner or
operator of the EGU must install, to the extent not already installed, and
properly operate and maintain one of the following emission control devices:
i) A Halogenated Activated Carbon Injection
System, complying with the sorbent injection requirements of subsection (c)(2)
of this Section, except as may be otherwise provided by subsection (c)(4), and
followed by a Cold-Side Electrostatic Precipitator or Fabric Filter;
or
ii) If the boiler fires
bituminous coal, a Selective Catalytic Reduction (SCR) System and an
SO2 Scrubber.
B) An owner of an EGU in an MPS Group has two
options under this subsection (c). For an MPS Group that contains EGUs smaller
than 90 gross MW in capacity, the owner may designate any such EGUs to be not
subject to subsection (c)(1)(A). Or, for an MPS Group that contains EGUs with
gross MW capacity of less than 115 MW, the owner may designate any such EGUs to
be not subject to subsection (c)(1)(A), provided that the aggregate gross MW
capacity of the designated EGUs does not exceed 4% of the total gross MW
capacity of the MPS Group. For any EGU subject to one of these two options,
unless the EGU is subject to the emission standards in subsection (d)(2),
beginning on January 1, 2013, and continuing until such date that the owner or
operator of the EGU commits to comply with the mercury emission standard in
subsection (d)(2), the owner or operator of the EGU must install and properly
operate and maintain a Halogenated Activated Carbon Injection System that
complies with the sorbent injection requirements of subsection (c)(2), except
as may be otherwise provided by subsection (c)(4), and followed by either a
Cold-Side Electrostatic Precipitator or Fabric Filter. The use of a properly
installed, operated, and maintained Halogenated Activated Carbon Injection
System that meets the sorbent injection requirements of subsection (c)(2) is
defined as the "principal control technique."
2) For each EGU for which injection of
halogenated activated carbon is required by subsection (c)(1), the owner or
operator of the EGU must inject halogenated activated carbon in an optimum
manner, which, except as provided in subsection (c)(4), is defined as all of
the following:
A) The use of an injection
system designed for effective absorption of mercury, considering the
configuration of the EGU and its ductwork;
B) The injection of halogenated activated
carbon manufactured by Alstom, Norit, or Sorbent Technologies, Calgon Carbon's
FLUEPAC CF Plus, or Calgon Carbon's FLUEPAC MC Plus, or the injection of any
other halogenated activated carbon or sorbent that the owner or operator of the
EGU has demonstrated to have similar or better effectiveness for control of
mercury emissions; and
C) The
injection of sorbent at the following minimum rates, as applicable:
i) For an EGU firing subbituminous coal, 5.0
lbs per million actual cubic feet or, for any cyclone-fired EGU that will
install a scrubber and baghouse by December 31, 2012, and which already meets
an emission rate of 0.020 lbs mercury/GWh gross electrical output or at least
75 percent reduction of input mercury, 2.5 lbs per million actual cubic
feet;
ii) For an EGU firing
bituminous coal, 10.0 lbs per million actual cubic feet for any cyclone-fired
EGU that will install a scrubber and baghouse by December 31, 2012, and which
already meets an emission rate of 0.020 lbs mercury/GWh gross electrical output
or at least 75 percent reduction of input mercury, 5.0 lbs per million actual
cubic feet;
iii) For an EGU firing
a blend of subbituminous and bituminous coal, a rate that is the weighted
average of the above rates, based on the blend of coal being fired;
or
iv) A rate or rates set lower by
the Agency, in writing, than the rate specified in any of subsections
(c)(2)(C)(i), (c)(2)(C)(ii), or (c)(2)(C)(iii) on a unit-specific basis,
provided that the owner or operator of the EGU has demonstrated that such rate
or rates are needed so that carbon injection will not increase particulate
matter emissions or opacity so as to threaten noncompliance with applicable
requirements for particulate matter or opacity.
D) For the purposes of subsection (c)(2)(C),
the flue gas flow rate shall be the gas flow rate in the stack for all units
except for those equipped with activated carbon injection prior to a hot-side
electrostatic precipitator; for units equipped with activated carbon injection
prior to a hot-side electrostatic precipitator, the flue gas flow rate shall be
the gas flow rate at the inlet to the hot-side electrostatic precipitator,
which shall be determined as the stack flow rate adjusted through the use of
Charles' Law for the differences in gas temperatures in the stack and at the
inlet to the electrostatic precipitator (Vesp =
Vstack x
Tesp/Tstack, where V = gas flow
rate in acf and T = gas temperature in Kelvin or Rankine).
3) The owner or operator of an EGU that seeks
to operate an EGU with an activated carbon injection rate or rates that are set
on a unit-specific basis pursuant to subsection (c)(2)(C)(iv) must submit an
application to the Agency proposing such rate or rates, and must meet the
requirements of subsections (c)(3)(A) and (c)(3)(B), subject to the limitations
of subsections (c)(3)(C) and (c)(3)(D):
A)
The application must be submitted as an application for a new or revised
federally enforceable operating permit for the EGU, and it must include a
summary of relevant mercury emission data for the EGU, the unit-specific
injection rate or rates that are proposed, and detailed information to support
the proposed injection rate or rates; and
B) This application must be submitted no
later than the date that activated carbon must first be injected. For example,
the owner or operator of an EGU that must inject activated carbon pursuant to
subsection (c)(1)(A) must apply for unit-specific injection rate or rates by
July 1, 2009. Thereafter, the owner or operator of the EGU may supplement its
application; and
C) Any decision of
the Agency denying a permit or granting a permit with conditions that set a
lower injection rate or rates may be appealed to the Board pursuant to Section
39 of the Act; and
D) The owner or
operator of an EGU may operate at the injection rate or rates proposed in its
application until a final decision is made on the application, including a
final decision on any appeal to the Board.
4) During any evaluation of the effectiveness
of a listed sorbent, an alternative sorbent, or other technique to control
mercury emissions, the owner or operator of an EGU need not comply with the
requirements of subsection (c)(2) for any system needed to carry out the
evaluation, as further provided as follows:
A) The owner or operator of the EGU must
conduct the evaluation in accordance with a formal evaluation program submitted
to the Agency at least 30 days prior to commencement of the
evaluation;
B) The duration and
scope of the evaluation may not exceed the duration and scope reasonably needed
to complete the desired evaluation of the alternative control technique, as
initially addressed by the owner or operator in a support document submitted
with the evaluation program;
C) The
owner or operator of the EGU must submit a report to the Agency no later than
30 days after the conclusion of the evaluation that describes the evaluation
conducted and which provides the results of the evaluation; and
D) If the evaluation of the alternative
control technique shows less effective control of mercury emissions from the
EGU than was achieved with the principal control technique, the owner or
operator of the EGU must resume use of the principal control technique. If the
evaluation of the alternative control technique shows comparable effectiveness
to the principal control technique, the owner or operator of the EGU may either
continue to use the alternative control technique in a manner that is at least
as effective as the principal control technique, or it may resume use of the
principal control technique. If the evaluation of the alternative control
technique shows more effective control of mercury emissions than the control
technique, the owner or operator of the EGU must continue to use the
alternative control technique in a manner that is more effective than the
principal control technique, so long as it continues to be subject to this
subsection (c).
5) In
addition to complying with the applicable recordkeeping and monitoring
requirements in Sections
225.240
through
225.290,
the owner or operator of an EGU that elects to comply with this Subpart B by
means of this Section must also comply with the following additional
requirements:
A) For the first 36 months that
injection of sorbent is required, it must maintain records of the usage of
sorbent, the flue gas flow rate from the EGU (and, if the unit is equipped with
activated carbon injection prior to a hot-side electrostatic precipitator, flue
gas temperature at the inlet of the hot-side electrostatic precipitator and in
the stack), and the sorbent feed rate, in pounds per million actual cubic feet
of flue gas, on a weekly average;
B) After the first 36 months that injection
of sorbent is required, it must monitor activated sorbent feed rate to the EGU,
gas flow rate in the stack, and, if the unit is equipped with activated carbon
injection prior to a hot-side electrostatic precipitator, flue gas temperature
at the inlet of the hot-side electrostatic precipitator and in the stack. It
must automatically record this data and the sorbent carbon feed rate, in pounds
per million actual cubic feet of flue gas, on an hourly average; and
C) If a blend of bituminous and subbituminous
coal is fired in the EGU, it must keep records of the amount of each type of
coal burned and the required injection rate for injection of activated carbon,
on a weekly basis.
6)
Until June 30, 2012, as an alternative to the CEMS or excepted monitoring
system (sorbent trap system) monitoring, recordkeeping, and reporting
requirements in Sections
225.240
through 225.290, the owner or operator of an EGU may elect to comply with the
emissions testing, monitoring, recordkeeping, and reporting requirements in
Section
225.239(c),
(d), (e), (f)(1) and (2), (h)(2), (i)(3) and
(4), and (j)(1).
7) In addition to complying with the
applicable reporting requirements in Sections
225.240
through 225.290, the owner or operator of an EGU that elects to comply with
this Subpart B by means of this Section must also submit quarterly reports for
the recordkeeping and monitoring conducted pursuant to subsection
(c)(5).
d) Emission Standards for Mercury
1) For each EGU in an
MPS Group that is not addressed by subsection (c)(1)(B), beginning January 1,
2015 (or such earlier date when the owner or operator of the EGU notifies the
Agency that it will comply with these standards) and continuing thereafter, the
owner or operator of the EGU must comply with one of the following standards 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 each EGU
in an MPS Group that has been addressed under subsection (c)(1)(B), beginning
on the date when the owner or operator of the EGU notifies the Agency that it
will comply with these standards and continuing thereafter, the owner or
operator of the EGU must comply with one of the following standards 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.
3) Compliance
with the mercury emission standard or reduction requirement of this subsection
(d) must be calculated in accordance with Section
225.230(a)
or (d), or Section
225.232
until December 31, 2013.
4) Until
June 30, 2012, as an alternative to demonstrating compliance with the emissions
standards in this subsection (d), the owner or operator of an EGU may elect to
comply with the emissions testing requirements in Section
225.239(a)(4)
and (b), (c), (d), (e), (f), (g), (h), (i),
and (j).
e) Emission Standards for NOx and SO2
1) NOx Emission
Standards
A) Beginning in calendar year 2012
and continuing through calendar year 2018, for the EGUs in each MPS Group, the
owner and operator of the EGUs must comply with an overall
NOx annual emission rate of no more than 0.11 lb/mmBtu
or an emission rate equivalent to 52 percent of the Base Annual Rate of
NOx emissions, whichever is more stringent.
B) Beginning in the 2012 ozone season and
continuing through the 2018 ozone season, for the EGUs in each MPS Group, the
owner and operator of the EGUs must comply with an overall
NOx seasonal emission rate of no more than 0.11 lb/mmBtu
or an emission rate equivalent to 80 percent of the Base Seasonal Rate of
NOx emissions, whichever is more stringent.
C) Except as otherwise provided in
subsections (f), (g), and (h), beginning in calendar year 2019 and continuing
in each calendar year thereafter, the owner and operator of the EGUs in an MPS
Group must not cause or allow to be discharged into the atmosphere combined
annual NOx emissions in excess of 19,000 tons from all
EGUs.
D) Except as otherwise
provided in subsections (f), (g), and (h), beginning in calendar year 2019 and
continuing in each calendar year thereafter, from May 1 to September 30 the
owner and operator of the EGUs in an MPS Group must not cause or allow to be
discharged into the atmosphere combined NOx emissions in
excess of 11,500 tons from all EGUs.
E) On and after January 1, 2019, the owner
and operator of any of Baldwin Units 1 and 2, Coffeen Units 1 and 2, Duck Creek
Unit 1, E.D. Edwards Unit 3, and Havana Unit 9 must comply with the following:
i) Operate each existing selective catalytic
reduction (SCR) control system on each EGU in accordance with good operating
practices and at all times when the unit it serves is in operation, provided
that such operation of the SCR control system is consistent with the
technological limitations, manufacturers' specifications, and good engineering
and maintenance practices for the SCR control system. During any such period in
which the SCR is not operational, the owner and operator must minimize
emissions to the extent reasonably practicable. All NOx
emissions from each EGU, regardless of whether the SCR is operational or
non-operational, must be included in determining compliance with the emission
standards set forth under subsections (e)(1)(C), (e)(1)(D), (f)(1), (g)(1), and
(h)(1), as applicable.
ii) From May
1 through September 30, comply with a combined NOx
average emission rate of no more than 0.10 lb/mmBtu. Averaging is only allowed
among EGUs in the same MPS Group.
2) SO2 Emission
Standards
A) Beginning in calendar year 2013
and continuing in calendar year 2014, for the EGUs in each MPS Group, the owner
and operator of the EGUs must comply with an overall SO2
annual emission rate of 0.33 lb/mmBtu or a rate equivalent to 44 percent of the
Base Rate of SO2 emissions, whichever is more
stringent.
B) Beginning in calendar
year 2015 and continuing through calendar year 2018, for the EGUs in each MPS
Group, the owner and operator of the EGUs must comply with an overall annual
emission rate for SO2 of 0.25 lbs/mmBtu or a rate
equivalent to 35 percent of the Base Rate of SO2
emissions, whichever is more stringent.
C) Except as otherwise provided in subsection
(f), (g), and (h), beginning in calendar year 2019 and continuing in each
calendar year thereafter, the owner and operator of the EGUs in an MPS Group
must not cause or allow to be discharged into the atmosphere combined annual
SO2 emissions in excess of 34,500 tons from all
EGUs.
D) Beginning in calendar year
2019 and continuing in each calendar year thereafter, the owner and operator of
Joppa Units 1, 2, 3, 4, 5, and 6 must not cause or allow to be discharged into
the atmosphere combined annual SO2 emissions in excess
of 19,860 tons from such EGUs.
f) Transfer of EGUs in an MPS Group
1) If EGUs in an MPS Group are transferred to
a different owner:
A) For the MPS Group from
which EGUs are transferred: The combined emissions limitations for the MPS
Group set forth in this Section, as applicable, must be adjusted by subtracting
from those limitations the applicable allocation amounts set forth in Columns
A, B, and C in subsection (f)(2) that are attributable to the transferred EGUs.
The owner and operator of the MPS Group must comply with the adjusted emissions
limitations beginning with the year in which the transfer occurs.
B) For a new MPS Group consisting of the
acquired EGUs:
i) The owner and operator of
the EGUs in an MPS Group must not cause or allow to be discharged into the
atmosphere combined annual NOx emissions in excess of
the applicable annual NOx limitation from all EGUs. The
applicable annual NOx limitation shall be the sum of the
allocation amounts attributable to all EGUs in the MPS Group set forth in
Column A of subsection (f)(2).
ii)
From May 1 through September 30, the owner and operator of the EGUs in an MPS
Group must not cause or allow to be discharged into the atmosphere combined
NOx emissions in excess of the applicable seasonal
NOx limitation from all EGUs. The applicable seasonal
NOx limitation shall be the sum of the allocation
amounts attributable to all EGUs in the MPS Group set forth in Column B of
subsection (f)(2).
iii) The owner
and operator of the EGUs in an MPS Group must not cause or allow to be
discharged into the atmosphere combined annual SO2
emissions in excess of the applicable annual SO2
limitation from all EGUs. The applicable annual SO2
limitation shall be the sum of the unit allocation amounts attributable to all
EGUs in the MPS Group set forth in Column C of subsection (f)(2).
iv) Notwithstanding subsections (f)(1)(B)(i)
through (iii), if all the EGUs set forth under subsection (a)(4)(A) are
transferred to the same owner on the same date, the owner and operator of the
EGUs in the new MPS Group must comply with the emission limitations under
subsection (e); the allocation amounts in subsection (f)(2) shall not
apply.
C) The owner and
operator of the EGUs as of the last day of the applicable compliance period
must demonstrate compliance with the emission standards of this Section for the
entire applicable compliance period. In determining compliance, such owner and
operator must include in their calculations emissions from the EGUs for the
entire applicable compliance period; the prior owner and operator shall not
include in their calculations emissions from the EGUs for the applicable
compliance period.
D) Nothing in
this subsection (f) relieves owners and operators of EGUs in an MPS Group from
any of the other requirements set forth in this Section, including the mercury
standards in subsection (d).
2) Allocation Amounts in the Event of
Transfer of EGUs
|
Column A. |
Column B. |
Column C. |
||
|
Nox Allocation Amount (TPY in the Event of Transfer |
NOx Allocation Amount (May1 through Sept 30 Tons) in the Event of Transfer |
SO2 Allocation Amount (TPY) in the Event of Transfer |
||
|
A) |
Baldwin |
4,570 |
2,700 |
3,760 |
|
B) |
Havana |
1,370 |
810 |
940 |
|
C) |
Hennepin |
1,140 |
675 |
3,760 |
|
D) |
Coffeen |
1,520 |
900 |
150 |
|
E) |
Duck Creek |
1,070 |
630 |
150 |
|
F) |
Edwards |
2,280 |
1,350 |
6,300 |
|
G) |
Joppa |
3,960 |
2,340 |
11,290 |
|
H) |
Newton |
2,050 |
1,215 |
6,300 |
3) If
EGUs in an MPS Group are transferred to a different owner:
A) The transferring owner must notify the
Agency's Bureau of Air, Compliance Section, in writing within seven days after
the date of transfer. The notification must include the following information:
i) Name and address of the transferring owner
and operator;
ii) List of the EGUs
transferred;
iii) For the remaining
EGUs in the MPS Group, calculations pursuant to subsection (f)(1)(A)
demonstrating the adjusted combined annual NOx emissions
limitation, the adjusted combined NOx emissions
limitation from May 1 through September 30, and the adjusted combined annual
SO2 emissions limitation that are applicable to the MPS
Group;
iv) Name and address of the
new owner and operator; and
v) Date
of transfer.
B) The
acquiring owner must notify the Agency's Bureau of Air, Compliance Section, in
writing within seven days after the date of transfer. The notification must
include the following information:
i) Name
and address of the acquiring owner and operator;
ii) Name and address of the transferring
owner and operator;
iii) List of
the EGUs acquired;
iv) Calculations
pursuant to subsection (f)(1)(B) demonstrating the combined annual
NOx emissions limitation, the combined
NOx emissions limitation from May 1 through September
30, and the combined annual SO2 emissions limitation
that are applicable to the acquiring owner and operator's MPS Group; and
v) Date of
transfer.
g) Permanent Shutdown of EGUs in an MPS Group
1) If one or more EGUs in an MPS Group are
permanently shut down:
A) Such EGU or EGUs
are no longer part of an MPS Group and no longer subject to the requirements of
this Section.
B) The combined
emissions limitations for the MPS Group set forth in this Section, as
applicable, must be adjusted by subtracting from those limitations the
applicable allocation amounts set forth in Columns A, B, and C in subsection
(g)(2) that are attributable to the shut-down EGU or EGUs. The owner and
operator of the MPS Group must comply with the adjusted emissions limitations,
beginning with the compliance period or periods during which the permanent
shutdown occurs. For the purposes of this Section, "permanent shutdown" occurs
on the date the owner or operator of the EGUs submits a written request to the
Agency to modify its operating permit to reflect the shutdown of the EGU or
EGUs, or to withdraw the permit for the source. In determining compliance with
the adjusted emission limitations, the owner and operator must include in their
calculations emissions from the shut-down EGU or EGUs for the entire applicable
compliance period.
C) Nothing in
this subsection (g) relieves owners and operators of EGUs in an MPS Group from
any of the other requirements set forth in this Section, including the mercury
standards in subsection (d).
2) Allocation Amounts in the Event of
Shutdown of EGUs
|
Column A. |
Column B. |
Column C. |
||||
|
Nox Allocation Amount (TPY) for Shutdown |
NOx Allocation (May 1 through Sept 30 Tons) for Shutdown |
SO2 Allocation Amount (TPY) for Shutdown |
||||
|
A) |
Baldwin 1 |
1,560 |
920 |
1,290 |
||
|
B) |
Baldwin 2 |
1,450 |
860 |
1,200 |
||
|
C) |
Baldwin 3 |
1,560 |
920 |
1,270 |
||
|
D) |
Havana 9 |
1,370 |
810 |
940 |
||
|
E) |
Hennepin 1 |
270 |
160 |
910 |
||
|
F) |
Hennepin 2 |
870 |
500 |
2,860 |
||
|
G) |
Coffeen 1 |
570 |
340 |
60 |
||
|
H) |
Coffeen 2 |
960 |
560 |
90 |
||
|
I) |
Duck Creek 1 |
1,070 |
630 |
150 |
||
|
J) |
Edwards 2 |
960 |
560 |
2,640 |
||
|
K) |
Edwards 3 |
1,330 |
780 |
3,660 |
||
|
L) |
Joppa 1 |
660 |
390 |
1,880 |
||
|
M) |
Joppa 2 |
660 |
390 |
1,880 |
||
|
N) |
Joppa 3 |
660 |
390 |
1,880 |
||
|
O) |
Joppa 4 |
660 |
390 |
1,880 |
||
|
P) |
Joppa 5 |
660 |
390 |
1,880 |
||
|
Q) |
Joppa 6 |
660 |
390 |
1,880 |
||
|
R) |
Newton 1 |
2,050 |
1,215 |
6,300 |
||
3) If
one or more EGUs in an MPS Group are permanently shut down, the owner must
notify the Agency's Bureau of Air, Compliance Section, in writing within seven
days after the date of shutdown. Such notification must include the following
information:
A) Name and address of the owner
and operator;
B) List of the EGUs
permanently shut down;
C) For the
remaining EGUs in the MPS Group, calculations pursuant to subsection (g)(1)(B)
demonstrating the adjusted combined annual NOx emissions
limitation, the adjusted combined NOx emissions
limitation from May 1 through September 30, and the adjusted combined annual
SO2 emissions limitation that are applicable to the MPS
Group; and
D) Date of permanent
shutdown, which is the date the owner or operator submitted a written request
to the Agency to modify its operating permit to reflect the shutdown or to
withdraw the permit for the source.
h) Temporary shutdown of EGUs in an MPS Group
1) If one or more EGUs in an MPS Group do not
operate to produce electricity for sale during an entire compliance period or
periods:
A) The combined emissions
limitations for the MPS Group set forth in this Section, as applicable, must be
adjusted by subtracting from those limitations the applicable allocation
amounts set forth in Columns A, B, and C in subsection (h)(2) that are
attributable to the temporarily shut-down EGU or EGUs.
B) The owner and operator of the MPS Group
must comply with the adjusted emissions limitations for that compliance period
or periods.
C) Nothing in this
subsection (h) relieves owners and operators of EGUs in an MPS Group from any
of the other requirements set forth in this Section, including the mercury
standards in subsection (d).
2) Allocation amounts in the event of
temporary shutdown of EGUs:
|
Column A. |
Column B. |
Column C. |
||
|
NOx Allocation Amount (TPY) for Temporary Shutdown |
NOx Allocation Amount (May1 through Sept 30 Tons) for Temporary Shutdown |
SO2 Allocation Amount (TPY) for Temporary Shutdown |
||
|
A) |
Baldwin 1 |
1,560 |
920 |
1,290 |
|
B) |
Baldwin 2 |
1,450 |
860 |
1,200 |
|
C) |
Baldwin 3 |
1,560 |
920 |
1,270 |
|
D) |
Havana 9 |
1,370 |
810 |
940 |
|
E) |
Hennepin 1 |
270 |
160 |
910 |
|
F) |
Hennepin 2 |
870 |
500 |
2,860 |
|
G) |
Coffeen 1 |
570 |
340 |
60 |
|
H) |
Coffeen 2 |
960 |
560 |
90 |
|
I) |
Duck Creek 1 |
1,070 |
630 |
150 |
|
J) |
Edwards 2 |
960 |
560 |
2,640 |
|
K) |
Edwards 3 |
1,330 |
780 |
3,660 |
|
L) |
Joppa 1 |
660 |
390 |
1,880 |
|
M) |
Joppa 2 |
660 |
390 |
1,880 |
|
N) |
Joppa 3 |
660 |
390 |
1,880 |
|
O) |
Joppa 4 |
660 |
390 |
1,880 |
|
P) |
Joppa 5 |
660 |
390 |
1,880 |
|
Q) |
Joppa 6 |
660 |
390 |
1,880 |
|
R) |
Newton 1 |
2,050 |
1,215 |
6,300 |
3) If
one or more EGUs in an MPS Group do not operate to produce electricity for sale
during an entire compliance period, the owner or operator must notify the
Agency's Bureau of Air, Compliance Section, in writing within seven days after
the end of each compliance period. The notification must include the following
information:
A) Name and address of the owner
and operator;
B) List of the EGUs
temporarily shut down;
C) For the
remaining EGUs in the MPS Group, calculations pursuant to subsection (g)(1)(B)
demonstrating the adjusted combined annual NOx emissions
limitation, the adjusted combined NOx emissions
limitation from May 1 through September 30, and the adjusted combined annual
SO2 emissions limitation that are applicable to the MPS
Group for the pertinent compliance period; and
D) Date that the EGU or EGUs stopped
operating.
i) Requirements for NOx and SO2 Allowances.
1) The owner or operator of EGUs
in an MPS Group must not sell or trade to any person or otherwise exchange with
or give to any person NOx allowances allocated to the
EGUs in the MPS Group for vintage years 2012 and beyond that would otherwise be
available for sale, trade, or exchange as a result of actions taken to comply
with the standards in subsection (e). Such allowances that are not retired for
compliance must be surrendered to the Agency on an annual basis, beginning in
calendar year 2013. This provision does not apply to the use, sale, exchange,
gift, or trade of allowances among the EGUs in an MPS Group.
2) The owners or operators of EGUs in an MPS
Group must not sell or trade to any person or otherwise exchange with or give
to any person SO2 allowances allocated to the EGUs in
the MPS Group for vintage years 2013 and beyond that would otherwise be
available for sale or trade as a result of actions taken to comply with the
standards in subsection (e). Such allowances that are not retired for
compliance, or otherwise surrendered pursuant to a consent decree to which the
State of Illinois is a party, must be surrendered to the Agency on an annual
basis, beginning in calendar year 2014. This provision does not apply to the
use, sale, exchange, gift, or trade of allowances among the EGUs in an MPS
Group.
3) The provisions of this
subsection (i) do not restrict or inhibit the sale or trading of allowances
that become available from one or more EGUs in a MPS Group as a result of
holding allowances that represent over-compliance with the
NOx or SO2 standard in subsection
(e), once such a standard becomes effective, whether such over-compliance
results from control equipment, fuel changes, changes in the method of
operation, unit shutdowns, or other reasons.
4) For purposes of this subsection (i),
NOx and SO2 allowances mean
allowances necessary for compliance with Sections
225.310,
225.410,
or
225.510,
40 CFR 72, or Subparts AA and AAAA of 40 CFR 96, or any future federal
NOx or SO2 emissions trading
programs that modify or replace these programs. This Section does not prohibit
the owner or operator of EGUs in an MPS Group from purchasing or otherwise
obtaining allowances from other sources as allowed by law for purposes of
complying with federal or state requirements, except as specifically set forth
in this Section.
5) By March 1,
2010, and continuing each year thereafter, the owner or operator of EGUs in an
MPS Group must submit a report to the Agency that demonstrates compliance with
the requirements of this subsection (i) for the previous calendar year, and
which includes identification of any allowances that have been surrendered to
the USEPA or to the Agency and any allowances that were sold, gifted, used,
exchanged, or traded because they became available due to over-compliance. All
allowances that are required to be surrendered must be surrendered by August
31, unless USEPA has not yet deducted the allowances from the previous year. A
final report will be submitted to the Agency by August 31 of each year,
verifying that the actions described in the initial report have taken place or,
if such actions have not taken place, an explanation of all changes that have
occurred and the reasons for such changes. If USEPA has not deducted the
allowances from the previous year by August 31, the final report will be due,
and all allowances required to be surrendered must be surrendered, within 30
days after such deduction occurs.
j) Recordkeeping
On and after January 1, 2019, and continuing each year thereafter, the owner and operator of the EGUs in an MPS Group must keep and maintain all records necessary to demonstrate compliance with this Section, including but not limited to those listed in subsections (j)(1) and (j)(2). Copies of such records must be kept at the source and maintained for at least five years from the date the document is created and must be submitted by the owner and operator to the Agency within 30 days after receipt of a written request by the Agency.
1) All emissions
monitoring information gathered in accordance with 40 CFR 75.
2) Copies of all reports and compliance
certifications required under subsection (k) of this Section.
k) Reporting
1) Prior to January 1, 2019, compliance with
the NOx and SO2 emission
standards must be demonstrated in accordance with Sections 225.310, 225.410,
and 225.510. The owner or operator of EGUs must complete the demonstration of
compliance before March 1 of the following year for annual standards and before
November 1 for seasonal standards, by which date a compliance report must be
submitted to the Agency.
2) On and
after January 1, 2019, and continuing each year thereafter, the owner and
operator of the EGUs in an MPS Group must demonstrate compliance with the
applicable requirements set forth in this subsection (k)(2).
A) Beginning in 2020, and continuing each
year thereafter, the owner and operator of EGUs in an MPS Group must submit to
the Agency's Bureau of Air, Compliance Section, a report demonstrating
compliance with the annual emissions standards in subsections (e)(1)(C),
(e)(2)(C), (e)(2)(D), (f)(1), (g)(1), and (h)(1), as applicable, and with the
requirements of subsection (e)(1)(E)(i), as applicable, on or before March 1 of
each year. The compliance report must include the following for the preceding
calendar year:
i) Actual emissions of each
pollutant, expressed in tons, for each individual EGU in the MPS
Group.
ii) Combined actual
emissions of each pollutant, expressed in tons, for all EGUs in the MPS
Group.
iii) Combined actual
emissions of SO2, expressed in tons, for all Joppa
EGUs.
iv) A statement indicating
whether each existing SCR control system on Baldwin Units 1 and 2, Coffeen
Units 1 and 2, Duck Creek Unit 1, E.D. Edwards Unit 3, and Havana Unit 9 was
operated in accordance with good operating practices and at all times when the
unit it serves was in operation, consistent with the technological limitations,
manufacturers' specifications, and good engineering and maintenance practices
for the SCR control system.
v) A
statement indicating whether the EGUs in an MPS Group were operated in
compliance with the requirements of this Section.
vi) A certification by a responsible official
that states the following:
I certify under penalty of law that this document and all attachments were prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the information submitted. Based on my inquiry of the person or persons directly responsible for gathering the information, the information submitted is, to the best of my knowledge and belief, true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment for knowing violations.
B) By
November 1 of each year, the owner and operator of EGUs in an MPS Group must
submit to the Agency's Bureau of Air, Compliance Section, a report
demonstrating compliance with the seasonal emissions standards under
subsections (e)(1)(D), (e)(1)(E)(ii), (f)(1), (g)(1), and (h)(1), as
applicable. The compliance report must include the following for the preceding
May 1 through September 30:
i) Actual
emissions of NOx, expressed in tons, for each individual
EGU in the MPS Group.
ii) Combined
actual emissions of NOx, expressed in tons, of all EGUs
in the MPS Group.
iii)
NOx average emission rate (lbs/mmBtu) for each of
Baldwin Units 1 and 2; Coffeen Units 1 and 2; Duck Creek Unit 1; E.D. Edwards
Unit 3; and Havana Unit 9, as applicable.
iv) Combined NOx
average emission rate (lbs/mmBtu) for Baldwin Units 1 and 2; Coffeen Units 1
and 2; Duck Creek Unit 1; E.D. Edwards Unit 3; and Havana Unit 9, as applicable
under subsection (e)(1)(E)(ii).
v)
A statement indicating whether the EGUs in an MPS Group were operated in
compliance with the requirements of this Section.
vi) A certification by a responsible official
that states the following:
I certify under penalty of law that this document and all attachments were prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the information submitted. Based on my inquiry of the person or persons directly responsible for gathering the information, the information submitted is, to the best of my knowledge and belief, true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment for knowing violations.
3) For each EGU in an MPS Group, the owner or
operator must notify the Agency of deviations from any of the requirements of
this Section within 30 days after discovery of the deviations. At a minimum,
these notifications must include a description of the deviations, a discussion
of the possible cause of the deviations, and a description of any corrective
actions and preventative measures taken.
4) Within 30 days after the beginning of a
period during which the SCR control system on any of Baldwin Unit 1, Baldwin
Unit 2, Coffeen Unit 1, Coffeen Unit 2, Duck Creek Unit 1, E.D. Edwards Unit 3,
or Havana Unit 9 is not operated when the EGU it serves is in operation, the
owner and operator must notify the Agency's Bureau of Air, Compliance Section,
in writing. This notification must include, at a minimum, a description of why
the SCR control system was not operated, the time frames during which the SCR
control system was not operated, and the steps taken to minimize emissions
during those time frames.
l) EGU Shutdowns
1) By September 23, 2019, the owner or
operator of the EGUs in the MPS group specified in subsection (a)(4)(A) must
submit documentation to the regional transmission operator, Midcontinent
Independent System Operator (MISO), that meets all applicable regulatory
requirements necessary to obtain MISO approval to permanently cease operating
one or more EGUs from that MPS Group with an aggregate capacity of at least
2,000 MW (calculated on a nameplate basis) of coal-fired electric
generation.
2) The owner or
operator must permanently cease operating each coal-fired EGU identified in the
documentation within 60 days after receiving notification from MISO that the
owner or operator may cease operating that unit, but in no event later than
December 31, 2019, except as follows:
A) If
MISO determines that operation of a coal-fired EGU is required to continue to
operate to maintain transmission reliability, the owner or operator may
continue operating the EGU but must use its best efforts to resolve the
reliability requirement with MISO and cease operation of the EGU as soon as
practicable.
B) If MISO has not yet
approved the cessation of operation of an EGU by December 31, 2019, the owner
or operator may continue operating the EGU but must continue to seek a
resolution with MISO until such time as MISO approves the cessation of
operation of the unit.
C) The owner
or operator must permanently cease operating an EGU referenced in subsection
(l)(2)(A) or (B) no later than 30 days after receipt of MISO's notification
that the owner or operator may cease operating the unit.
3) The owner or operator of the EGUs in the
MPS Group must submit the following notifications to the Agency's Bureau of
Air, Compliance Section, to demonstrate compliance with this subsection (l):
A) By October 7, 2019, the owner or operator
must submit a notification to the Agency containing the date that the owner or
operator submitted the documentation required by subsection (l)(1) to MISO and
a certification that the owner or operator has designated in that documentation
EGUs from the MPS Group with an aggregate capacity of at least 2,000 MW of
coal-fired electric generation for permanent cessation of operations.
B) Within 30 days after the owner's or
operator's receipt of MISO's response regarding whether an EGU in the MPS Group
may cease operations or is required to continue to operate to maintain
transmission reliability, but for responses received on or before December 31,
2019, in no event later than January 7, 2020, the owner or operator must notify
the Agency of MISO's decision and identify each EGU to which the decision
applies. If an EGU is required to continue operation, the notification to the
Agency must also describe the status of resolving the transmission reliability
requirement. If MISO has not yet responded regarding one or more EGUs by
December 31, 2019, the owner or operator must notify the Agency by January 7,
2020, identifying each EGU still awaiting a response. The owner or operator
must update the Agency on the status of either resolving any transmission
reliability requirement or receipt of MISO's response by the end of each
calendar month until MISO approves the cessation of operation.
C) Within seven days after the permanent
cessation of operations of an EGU under this subsection (l), the owner or
operator must submit a notification to the Agency identifying the EGU in the
MPS Group that has permanently ceased operation, the nameplate capacity of that
EGU, and the date the EGU permanently ceased operations.
Disclaimer: These regulations may not be the most recent version. Illinois may have more current or accurate information. We make no warranties or guarantees about the accuracy, completeness, or adequacy of the information contained on this site or the information linked to on the state site. Please check official sources.
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