ILLINOIS REGISTER
1
KEC EIVED
MAY 1 7 2006
1)
PollutionSTATE
OF ILLINOIS
Heading of the Part : Control of Emissions from Large Combustion Sources
Control Board
2)
Code Citation : 35 Ill. Adm. Code Part 225
3)
4)
5)
Section Numbers :
225 .100
225 .120
225 .130
225 .140
225 .200
225 .202
225.205
225 .210
225 .220
225 .230
225 .232
225 .235
225 .237
225 .240
225 .250
225.260
225.261
225.263
225.265
225 .270
225 .290
225 .295
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED RULES
Proposed Action
:
New
New
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Statutory Authority : 415 ILCS 5/27 (2005)
A Complete Description of the Subjects and Issues Involved :
This rulemaking is
proposed to meet certain obligations of the State of Illinois under the Clean Air Act, 42
USC Section 7401 et seq .
; specifically, to satisfy Illinois' obligation to submit a State
Implementation Plan to address the requirements of the Clean Air Mercury Rule, 70 Fed
.
Reg. 28606
. This proposal will require Illinois coal-fired EGUs that serve a generator
greater than 25 megawatts producing electricity for sale to begin to utilize control
technology for mercury as necessary to achieve the numerical standards set by the
proposed rule beginning July 1, 2009
. To achieve this goal while preserving flexibility,
the regulations provide new and existing sources with two alternative mercury emission
standards to demonstrate compliance
. The first alternative allows a source to comply
ILLINOIS REGISTER
2
06
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED RULES
with a mercury emission standard of 0
.0080 lb mercury/GWh gross electrical output for
each EGU
. In the alternative, sources may control emissions by a minimum of 90% from
input mercury levels
. In addition, through December 31, 2013, companies with several
sources with EGUs may utilize averaging demonstrations between the sources
. Those
sources that have no sister plants are grouped into a co-op so that they may also average
amongst the listed facilities
. However, every source in the averaging demonstration must
attain at least a 75% reduction of input mercury or 0
.020 lb mercury/GWh gross electrical
output
. This proposal also sets forth permitting, monitoring, recordkeeping, and
reporting requirements for affected sources .
As is explained in the Notice of Withdrawal published in this issue of the
Illinois
Register,
this is the second first-notice publication of this proposed rule
. The Board
withdrew its original first notice publication in response to a preliminary injunction
entered by the Sangamon County Circuit Court on May 1, 2006 in "Dynegy Midwest
Generation, Inc
., Kincaid Generation, L .L .C .,
and Midwest Generation, L .L.C. v. PCB
and IEPA", No 2006-CH-213
. The Sangamon County Circuit Court enjoined the Board
from proceeding pursuant to the hearing and rulemaking schedule required by Section
28.5
(fast track Clean Air Act rulemaking procedures) of the Act [415 ILCS 5/28
.5
(2004)]
. Because the Circuit Court's action concerns the statutory authority that the
Board used to propose this rulemaking, the Board is, on its own motion, proposing a new
rule in this same issue of the
Illinois Register
that is in substance identical to the proposal
that is being withdrawn with this notice
. The only change being made in the new
proposal is that the Board is citing only its general rulemaking authority under Section 27
of the Environmental Protection Act (Act) [415 ILCS 5/27 (2004)]
.
6)
Published studies or Reports and Sources of Underlying Data Used to Compose this
Rulemaking
:
The regulatory proposal included the Illinois EPA's "Technical Support
Document for Reducing Mercury Emissions from Coal-Fired Electric Generating Units
(TSD)" that relied on several published studies and reports
. Copies of the documents the
Illinois EPA relied upon are available for review with the Pollution Control Board and
are listed below
. The TSD
includes an executive summary of the results from the
Integrated Planning Model that was performed by ICE Resources, Inc
. contracted by the
Illinois EPA
. The underlying data used to perform the modeling and the results are also
available for review at the Pollution Control Board
.
Anderson,
H.A., J .F. Amrhein, P . Shubat, and J
. Hesse
. Protocol for a uniform Great
7)
Will this proposed rule replace any emergency rule currently in effect?
No
8)
Does this rule contain an automatic repeal date?
No
ILLINOIS REGISTER
3
06
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED RULES
9)
Does this proposed rule contain incorporations by reference?
Yes
10)
Are there any other proposed rules pending on this Part?
No
11)
Statement of Statewide Policy Objectives :
This proposed rule does not create or enlarge
a State mandate, as defined in Section 3(b) of the State Mandates Act
. [30 ILCS 805/3(b)
(2004)]
.
12)
Time, Place, and Manner in which interested persons may comment on this proposed
rulemaking :
The Board will accept written public comment on this proposal for 45 days
after the date of publication in the Illinois Register
. Comments should reference Docket
R06-25 and be addressed to :
Clerk's Office
Illinois Pollution Control Board
100 W. Randolph St
., Suite 11-500
Chicago, IL 60601
Interested persons may request copies of the Board's opinion and order by calling
Dorothy Gunn at 312-814-3620, or download from the Board's Web site at
www.ipcb.state.il.us
.
For more information contact Marie Tipsord at 312/814-4925 or email at
tipsordm@ipcb
.state.il.us .
13)
Initial Regulatory Flexibility Analysis
:
A)
Types of small businesses, small municipalities and not for profit corporations
affected : None
B)
Reporting, bookkeeping or other procedures required for compliance
: The
proposed rulemaking requires the owner or operator of an affected source to
install required emissions monitoring systems, complete required certification
tests, and record, report, and quality-assure the data from such systems
. The
owner or operator of an affected source must also maintain emissions monitoring
information, submit quarterly reports, compliance certifications, and annual
certifications of compliance .
C)
Types of Professional skills necessary for compliance
: No professional skills
ILLINOIS REGISTER 4
06
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED RULES
beyond those currently required by the existing State and federal air pollution
control regulations applicable to affected sources will be required
.
14)
Regulatory Agenda on which this rulemaking was summarized
:
January 2006
The full text of the Proposed Rule begins on the next page
:
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JCAR350225-06092811
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FOR STATIONARY SOURCES
PART 225
4rd
1
2
3
4
5
6
7
8
CONTROL OF EMISSIONS FROM LARGE COMBUSTION SOURCES
9
10
SUBPART A: GENERAL PROVISIONS
11
12
Section
13
225 .100
Severability
14 225.120
Abbreviations and Acronyms
15
225.130
Definitions
16 225.140
Incorporations by Reference
17
18
SUBPART B : CONTROL OF MERCURY EMISSIONS
19
FROM COAL-FIRED ELECTRIC GENERATING UNITS
20
21
Section
22 225.200
Purpose
23 225 .202
Measurement Methods
24
225 .205
Applicability
25 225 .210
Compliance Requirements
26 225 .220
Clean Air Act Permit Program (CAAPP) Permit Requirements
27 225 .230
Emission Standards for EGUs at Existing Sources
28 225 .232
Averaging Demonstrations for Existing Sources
29 225.235
Units Scheduled for Permanent Shut Down
30 225.237
Emission Standards for New Sources with EGUs
31 225 .240
General Monitoring and Reporting Requirements
32
225 .250
Initial Certification and Recertification Procedures for Emissions Monitoring
33 225 .260
Out of Control Periods for Emission Monitors
34 225 .261
Additional Requirements to Provide Heat Input Data
35 225 .263
Monitoring of Gross Electrical Output
36 225 .265
Coal Analysis for Input Mercury Levels
37
225 .270
Notifications
38 225 .290
Recordkeeping and Reporting
39
225 .295
Treatment of Mercury Allowances
40
41 AUTHORITY : Implementing Section 9 .10 and authorized by Sections 27 and 28
.5 of the
42
Environmental Protection Act [415 ILCS 5/9 .10, 27 and 28
.5] .
43
JCAR350225-0609281 r01
4544
SOURCE: Adopted at 30 Ill . Reg. , effective
46
SUBPART A : GENERAL PROVISIONS
47
48 Section 225.100 Severability
49
50
If any Section, subsection or clause of this Part is found invalid, such finding shall not affect the
51
validity of this Part as a whole or any Section, subsection or clause not found invalid
.
52
53 Section 225.120
Abbreviations and Acronyms
54
55
Unless otherwise specified within this Part, the abbreviations used in this Part shall be the same
56
as those found in 35 Ill . Adm. Code 211
. The following abbreviations and acronyms are used in
57
this Part:
58
Act
Environmental Protection Act [415 ILCS 5]
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
59
60
Section 225.130 Definitions
61
62
The definitions contained in this Section apply only to the provisions of this Part
. Unless
63
otherwise defined in this Section and unless a different meaning of a term is clear from its
64
context, the definitions of terms used in this Part shall have the meanings specified for those
65
terms in 35 Ill . Adm. Code 211
.
66
67
"Averaging demonstration" means, with regard to Subpart B of this Part, a
68
demonstration of compliance that is based on the combined performance of EGUs
69
at two or more sources .
JCAR350225-0609281r01
"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
:
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 .
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155
JCAR350225-0609281r01
For a bottoming-cycle cogeneration unit, useful power not less
than 45 percent of total energy input .
"Combustion turbine" means :
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.
"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),
156
157
158
159
160
161
162
163
164
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188
189
190
191
192
193
194
195
196
197
198
JCAR350225-060928Ir01
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 (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 EGUs covered by the
determination does operate, so that the determination is still based on 12 months
of data .
JCAR350225-060928Ir01
199 Section 225.140 Incorporations by Reference
200
201 The following materials are incorporated by reference
. These incorporations do not include any
202 later amendments or editions .
203
204
a)
40 CFR 60, 60 .17, 60 .45a, 60.49a(k)(1), 60
.49a(p), 60.50a(h), and 60.4170
205
through 60
.4176 (2005)
.
206
207
b)
40 CFR 75 (2005) .
208
209
c)
ASTM. American Society for Testing and Materials, 100 Barr Harbor Drive, P .O.
210
Box C700, West Conshohocken PA 19428-2959, (610) 832-9585 :
211
212
1)
ASTM D388-77, 90, 91, 95, 98a, or 99, Classification of Coals by Rank
213
(Reapproved 2004).
214
215
2)
ASTM D3173-03, Standard Test Method for Moisture in the Analysis
216
Sample of Coal and Coke (Approved April 10, 2003) .
217
218
3)
ASTM D3684-01, Standard Test Method for Total Mercury in Coal by the
219
Oxygen Bomb Combustion/Atomic Absorption Method (Approved
220
October 10, 2001) .
221
222
4)
ASTM D5865-04, Standard Test Method for Gross Calorific Value of
223
Coal and Coke (Approved April 1, 2004) .
224
225
5)
ASTM D6414-01, Standard Test Method for Total Mercury in Coal and
226
Coal Combustion Residues by Acid Extraction or Wet Oxidation/Cold
227
Vapor Atomic Absorption (Approved October 10, 2001) .
228
229
6)
ASTM D6784-02, Standard Test Method for Elemental, Oxidized,
230
Particle-Bound and Total Mercury in Flue Gas Generated from Coal-Fired
231
Stationary Sources (Ontario Hydro Method) (Approved April 10, 2002)
.
232
233
SUBPART B : CONTROL OF MERCURY EMISSIONS
234
FROM COAL-FIRED ELECTRIC GENERATING UNITS
235
236
Section 225.200 Purpose
237
238
The purpose of this Subpart is to control the emissions of mercury from coal-fired electrical
239 generating units in Illinois
.
240
241 Section 225.202
Measurement Methods
JCAR350225-0609281r01
242
243 Measurement of mercury shall be according to the following
:
244
245
a)
Continuous emission monitoring pursuant to 40 CFR 75 (2005)
.
246
247
b)
ASTM D3173-03, Standard Test Method for Moisture in the Analysis Sample of
248
Coal and Coke (Approved April 10, 2003).
249
250
c)
ASTM D3684-01, Standard Test Method for Total Mercury in Coal by the
251
Oxygen Bomb Combustion/Atomic Absorption Method (Approved October 10,
252
2001) .
253
254
d)
ASTM D5865-04, Standard Test Method for Gross Calorific Value of Coal and
255
Coke (Approved April 1, 2004) .
256
257
e)
ASTM D6414-01, Standard Test Method for Total Mercury in Coal and Coal
258
Combustion Residues by Acid Extraction or Wet Oxidation/Cold Vapor Atomic
259
Absorption (Approved October 10, 2001)
.
260
261
f)
ASTM D6784-02, Standard Test Method for Elemental, Oxidized, Particle-Bound
262
and Total Mercury in Flue Gas Generated from Coal-Fired Stationary Sources
263
(Ontario Hydro Method) (Approved April 10, 2002)
.
264
265
Section 225.205
Applicability
266
267
The following stationary coal-fired boilers and stationary coal-fired combustion turbines are
268
EGUs and are subject to this Subpart :
269
270
a)
Except as provided in subsection (b) of this Section, a unit serving, at any time
271
since the start-up of the unit's combustion chamber, a generator with nameplate
272
capacity of more than 25 MWe producing electricity for sale .
273
274
b)
For a unit that qualifies as a cogeneration unit during the 12-month period starting
275
on the date the unit first produces electricity and continues to qualify as a
276
cogeneration unit, a cogeneration unit serving at any time a generator with
277
nameplate capacity of more than 25 MWe and supplying in any calendar year
278
more than one-third of the unit's potential electric output capacity or 219,000
279
MWh, whichever is greater, to any utility power distribution system for sale
. If a
280
unit qualifies as a cogeneration unit during the 12-month period starting on the
281
date the unit first produces electricity but subsequently no longer qualifies as a
282
cogeneration unit, the unit shall be subject to subsection (a) of this Section
283
starting on the day on which the unit first no longer qualifies as a cogeneration
284
unit.
JCAR350225-0609281r01
285
286 Section 225.210
Compliance Requirements
287
288
a)
Permit Requirements
289
The owner or operator of each source with one or more EGUs subject to this
290
Subpart at the source must apply for a CAAPP permit that addresses the
291
applicable requirements of this Subpart
.
292
293
b)
Monitoring Requirements
294
295
1)
The owner or operator of each source and each EGU at the source must
296
comply with the monitoring requirements of Sections 225
.240 through
297
225 .290 of this Subpart .
298
299
2)
The compliance of each EGU with the mercury requirements under
300
Sections 225
.230 and 225 .237 of this Subpart shall be determined by the
301
emissions measurements recorded and reported in accordance with
302
Sections 225 .240 through 225 .290 of this Subpart
.
303
304
c)
Mercury Emission Reduction Requirements
305
The owner or operator of any EGU subject to this Subpart shall comply with
306
applicable requirements for control of mercury emissions under Section 225 .230
307
or Section 225
.237 of this Subpart .
308
309
d)
Recordkeeping and Reporting Requirements
310
Unless otherwise provided, the owner or operator of a source with one or more
311
EGUs at the source shall keep on site at the source each of the documents listed in
312
subsections (d)(1)
through (d)(3)
of this Section for a period of five years from the
313
date the document is created
. This period may be extended for cause, at any time
314
prior to the end of five years, in writing by the Agency
.
315
316
1)
All emissions monitoring information, in accordance with Sections
317
225 .240 through 225 .290 of this Subpart
.
318
319
2)
Copies of all reports, compliance certifications, and other submissions and
320
all records made or required or documents necessary to demonstrate
321
compliance with the requirements of this Subpart
.
322
323
3)
Copies of all documents used to complete a permit application and any
324
other submission under this Subpart .
325
326
e)
Liability
327
JCAR350225-060928Ir01
328
1)
The owner or operator of each source with one or more EGUs shall meet
329
the requirements of this Subpart
.
330
331
2)
Any provision of this Subpart that applies to a source shall also apply to
332
the owner and operator of such source and to the owner and operator of
333
each EGU at the source .
334
335
3)
Any provision of this Subpart that applies to an EGU shall also apply to
336
the owner and operator of such EGU .
337
338
f)
Effect on Other Authorities . No provision of this Subpart shall be construed as
339
exempting or excluding the owner and operator of a source or EGU from
340
compliance with any other provision of an approved State Implementation Plan, a
341
permit, the Act, or the CAA .
342
343 Section 225.220
Clean Air Act Permit Program (CAAPP) Permit Requirements
344
345
a)
Application Requirements
346
347
1)
Each source with one or more EGUs subject to the requirements of this
348
Subpart is required to submit a CAAPP permit application that addresses
349
all applicable requirements of this Subpart, applicable to each EGU at the
350
source.
351
352
2)
For any EGU that commenced commercial operation
:
353
354
A)
on or before December 31, 2008, the owner or operator of that
355
EGU must submit an initial permit application or application for
356
CAAPP permit modification that meets the requirements of this
357
Section by December 31, 2008
.
358
359
B)
after December 31, 2008, the owner or operator of any such EGU
360
must submit an initial CAAPP permit application or application for
361
CAAPP modification that meets the requirements of this Section
362
not later than 180 days before initial startup of the EGU, unless the
363
construction permit issued for the EGU addresses the requirements
364
of this Subpart.
365
366
b)
Contents of Permit Applications
367
In addition to other information required for a complete application for CAAPP
368
permit or CAAPP permit modification, the application shall include the following
369
information :
370
JCAR3 50225-060928 1 rOl
371
1)
The ORIS (Office of Regulatory Information Systems) or facility code
372
assigned to the source by the Energy Information Administration, if
373
applicable .
374
375
2)
Identification of each EGU at the source .
376
377
3)
The intended approach to the monitoring requirements of Sections
378
225 .240 through 225 .290 of this Subpart .
379
380
4)
The intended approach to the mercury emission reduction requirements of
381
Section 225 .230 or 225 .237 of this Subpart, as applicable
.
382
383
c)
Permit Contents
384
385
1)
Each CAAPP permit issued by the Agency for a source with one or more
386
EGUs subject to the requirements of this Subpart shall contain federally
387
enforceable conditions addressing all applicable requirements of this
388
Subpart, which conditions shall be a complete and segregable portion of
389
the source's entire CAAPP permit
.
390
391
2)
In addition to conditions related to the applicable requirements of this
392
Subpart, each such CAAPP permit shall also contain the information
393
specified under subsection (b) of this Section .
394
395 Section 225 .230 Emission Standards for EGUs at Existing Sources
396
397
a)
Emission Standards
398
399
1)
Beginning July 1, 2009, the owner or operator of a source with one
400
or more EGUs subject to this Subpart that commenced commercial
401
operation on or before December 31, 2008 shall comply with one of the
402
following standards for each EGU on a rolling 12-month basis :
403
404
A)
An emission standard of 0.0080
lb mercury/GWh gross electrical
405
output; or
406
407
B)
A minimum 90-percent reduction of input mercury
.
408
409
2)
For an EGU complying with subsection (a)(1)(A)
of this Section, the
410
actual mercury emission rate of the EGU for each 12-month rolling period,
411
as monitored in accordance with this Subpart and calculated as follows,
412
shall not exceed the applicable emission standard :
413
JCAR350225-0609281r01
12
12
ER =>.E;=~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 .
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
Subpart and calculated as follows, shall meet or exceed the applicable
efficiency requirement :
12
12
CE=100x{1-(IE,=XI,)}
i=1
iA
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.
I;
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 .
429
430
b)
Alternative Emission Standards for Single EGUs
431
432
1)
As an alternative to compliance with one of the above emission standards
433
in subsection (a) of this Section, the owner or operator of the EGU may
434
comply with the emission standards of this Subpart by demonstrating that
435
the actual emissions of mercury from the EGU are less than the allowable
436
emissions of mercury from the EGU on a rolling 12-month basis
.
414
415
416
417
418
419
3)
420
421
422
423
424
425
426
427
428
Where:
JCAR350225-0609281r01
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
<_ A
12
12
E]2=
Y E;
12
A12 = X A1
E12
Actual mercury emissions of the EGU for the particular 12-
month rolling period .
A 12
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,Pu, ;),
as selected by the owner or operator
of the EGU for that given month .
Aj„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 .
Aou,pu, ; =
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.
451
452
3)
If the owner or operator of an EGU does not conduct the necessary
453
sampling, analysis, and recordkeeping, in accordance with Section
454
225.265 of this Subpart, to determine the mercury input to the EGU, the
455
allowable emissions of the EGU must be calculated based on the electrical
456
output of the EGU .
457
437
438
2)
439
440
441
442
443
444
445
446
447
448
449
450
JCAR350225-060928 I rOl
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
.
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
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 :
ES < AS
A
487
488
489
490
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
458
c)
459
460
461
462
463
464
d)
465
466
467
468
469
470
471
472
473
474
475
476
477
478
479
480
481
482
483
484
485
486
JCAR350225-0609281r01
491
EGUs at such source covered by the compliance demonstration are
492
considered out of compliance with the applicable emission standards of
493
this Subpart for the entire last month of that period
.
494
495
Section 225.232
Averaging Demonstrations for Existing Sources
496
497
a)
Through December 31, 2013, as an alternative to compliance with the emission
498
standards of Section 225
.230(a) of this Subpart, the owner or operator of an EGU
499
may comply with the emission standards of this Subpart by means of an
500
Averaging Demonstration (Demonstration) that shows that the actual emissions of
501
mercury from the EGU and other EGUs at the source and other EGUs at other
502
sources covered by the Demonstration are less than the allowable emissions of
503
mercury from all EGUs covered by the Demonstration on a rolling 12-month
504
basis .
505
506
b)
The EGUs at each source covered by a Demonstration must also comply with one
507
of the following emission standards on a source-wide basis for the period covered
508
by the Demonstration
:
509
510
1)
An emission standard of 0
.020 lb mercury/GWh gross electrical output
; or
511
512
2)
A minimum 75 percent reduction of input mercury
.
513
514
c)
For the purpose of this Section, compliance shall be determined using the
515
equations in Section 225
.230(a)(2), (a)(3), or (d)(2)
of this Subpart, as applicable,
516
addressing all EGUs at the sources covered by the Demonstration, rather than
517
only EGUs at one source .
518
519
d)
Limitations on Demonstrations
520
521
1)
The owners or operators of more than one existing source with EGUs can
522
only participate in Demonstrations that include other existing sources that
523
they own or operate
.
524
525
2)
Single Existing Source Demonstrations
526
527
A)
The owner or operator of only a single existing source with EGUs
528
(i.e.,
City, Water, Light & Power, City of Springfield, ID
529
167120AAO; Electric Energy, Inc.,
ID 127855AAC
; Kincaid
530
Generating Station, ID 021814AAB
; and Southern Illinois Power
531
Cooperative/Marion Generating Station, ID 199856AAC) can only
532
participate in Demonstrations with other such owners or operators
533
of a single existing source of EGUs
.
JCAR350225-060928 I rOl
534
535
B)
Participation in Demonstrations under this Section by the owner or
536
operator of only a single existing source with EGUs must be
537
authorized through federally enforceable permit conditions for
538
each such source participating in the Demonstration
.
539
540
e)
A source may be included in only one Demonstration during each rolling 12-
541
month period.
542
543
f)
The owner or operator of EGUs using Demonstrations to show compliance with
544
this Subpart must complete the determination of compliance for each 12-month
545
rolling period no later than 60 days following the end of the period
.
546
547
g)
If averaging is used to demonstrate compliance with this Subpart, the effect of a
548
failure to demonstrate compliance shall be that the compliance status of each
549
source shall be determined under Section 225
.230 of this Subpart as if the sources
550
were not covered by a Demonstration .
551
552
h)
For purposes of this Section, if the owner or operator of any source that
553
participates in a Demonstration with an owner or operator of a source that does
554
not maintain the required records, data, and reports for the EGUs at the source, or
555
does not submit copies of such records, data, or reports to the Agency upon
556
request, then the effect of this failure will be deemed to be a failure to
557
demonstrate compliance and the compliance status of each source shall be
558
determined under Section 225
.230 of this Subpart as if the sources were not
559
covered by a Demonstration .
560
561 Section 225.235 Units Scheduled for Permanent Shut Down
562
563
a)
The emission standards of Section 225
.230(a) of this Subpart are not applicable to
564
an EGU that will be permanently shut down as follows :
565
566
1)
The owner or operator of an EGU for which this Section is being relied
567
upon shall by no later than June 30, 2009 :
568
569
A)
Have notified the Illinois EPA that it is planning to permanently
570
shut down the EGU by the applicable date specified in subsection
571
(a)(3)
or (4) of this Section
. This notification shall be
572
accompanied by a description of the actions that have already been
573
taken to allow the shut down of the EGU and a description of the
574
future actions that must be accomplished to complete the shut
575
down of the EGU, with the anticipated schedule for those actions
576
and the anticipated date of permanent shut down of the unit
.
JCAR350225-0609281r01
577
578
B)
Have applied for a construction permit or be actively pursuing a
579
federally enforceable agreement that requires the EGU to be
580
permanently shut down in accordance with this Section
.
581
582
C)
Have applied for revisions to the operating permit(s) for the EGU
583
to include provisions that terminate the authorization to operate the
584
unit in accordance with this Section .
585
586
2)
The owner or operator of an EGU for which this Section is being relied
587
upon shall by no later than June 30, 2010 :
588
589
A)
Have obtained a construction permit or entered into a federally
590
enforceable agreement as addressed by subsection (a)(1)(B) of this
591
Section; or
592
593
B)
Have obtained revised operating permit(s) in accordance with
594
subsection (a)(1)(C)
of this Section .
595
596
3)
The plan for permanent shut down of the EGU must provide for the EGU
597
to be permanently shut down by no later than the applicable date specified
598
below:
599
600
A)
If the owner or operator of the EGU is not constructing a new EGU
601
or other generating units to specifically replace the existing EGU,
602
by December 31, 2010 .
603
604
B)
If the owner or operator of the EGU is constructing a new EGU or
605
other generating units to specifically replace the existing EGU, by
606
December 31, 2011
.
607
608
4)
The owner or operator of the EGU must permanently shut down the EGU
609
by the date specified in subsection
(a)(3) of this Section, unless the owner
610
or operator submits a demonstration to the Illinois EPA before such date
611
showing that circumstances beyond its reasonable control (such as
612
protracted delays in construction activity, unanticipated outage of another
613
EGU, or protracted shakedown of a replacement unit) have occurred that
614
interfere with the plan for permanent shut down of the EGU, in which case
615
the date for shut down of the EGU may be extended as follows
:
616
617
A)
If the owner or operator of the EGU is not constructing a new EGU
618
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)
619
620
621
622
623
624
625
626
627
628
629
630
631
632
633
634
635
636
637
638
639
640
641
642
643 Section 225.237 Emission Standards for New Sources with EGUs
644
645
646
647
648
649
650
651
652
653
654
655
656
657
658
659
660
661
a)
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)
JCAR350225-0609281rOl
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.
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
.
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
JCAR350225-0609281 r01
662
EGU shall commence on the date that the initial performance test for the mercury
663
emission standard under 40 CFR 60
.45a also commences. The continuous
664
emission monitoring systems required by this Subpart for mercury emissions from
665
the EGU must be certified prior to this date . Thereafter, compliance shall be
666
demonstrated on a rolling 12-month basis in terms of calendar months .
667
668 Section 225
.240 General Monitoring and Reporting Requirements
669
670
The owner or operator of an EGU shall comply with the monitoring, recordkeeping, and
671
reporting requirements as provided in this Section, Sections 225 .250 through 225 .290 of this
672 Subpart, and subpart I of 40 CFR 75 . If the EGU utilizes a common stack with units that are not
673 EGUs and the owner or operator of the EGU does not conduct emissions monitoring in the duct
674
to the common stack from each EGU, the owner or operator of the EGU shall conduct emissions
675 monitoring in accordance with 40 CFR 75 .82(b)(2) and this Section, including monitoring in the
676
duct to the common stack from each unit that is not an EGU, unless the owner or operator of the
677 EGU counts the combined emissions measured at the common stack as the mass emissions of
678 mercury for the EGUs for recordkeeping and compliance purposes
.
679
680
a)
Requirements for installation, certification, and data accounting
. The owner or
681
operator of each EGU shall :
682
683
1)
Install all monitoring systems required under this Section and Sections
684
225 .250 through 225 .290 of this Subpart for monitoring mercury mass
685
emissions (including all systems required to monitor mercury
686
concentration, stack gas moisture content, stack gas flow rate, and CO2 or
687
02
concentration, as applicable, in accordance with 40 CFR 75 .81 and
688
75 .82)
.
689
690
2)
Successfully complete all certification tests required under Section
691
225 .250 and meet all other requirements of this Section, Sections 225
.250
692
through 225.290
of this Subpart, and subpart I of 40 CFR 75 applicable to
693
the monitoring systems required under subsection (a)(1) of this Section
.
694
695
3)
Record, report, and quality-assure the data from the monitoring systems
696
required under subsection (a)(1)
of this Section .
697
698
4)
If the owner or operator elects to use the low mass emissions excepted
699
monitoring methodology for an EGU that emits no more than 464 ounces
700
(29 pounds) of mercury per year pursuant to 40 CFR 75
.81(b), also
701
perform emissions testing in accordance with 40 CFR 75
.81(c) to
702
demonstrate that the EGU is eligible to use this excepted emissions
703
monitoring methodology, as well as comply with all other applicable
704
requirements of 40 CFR 75 .81(b) through (f), and submit a copy of any
JCAR350225-060928Ir01
705
information required to be submitted to the USEPA under these provisions
706
to the Illinois EPA
. The initial emissions testing to demonstrate eligibility
707
of an EGU for the low mass emissions excepted methodology shall be
708
conducted by the following dates :
709
710
A)
If the EGU has commenced commercial operation before July 1,
711
2008, at least by January 1, 2009, or 45 days prior to relying on the
712
low mass emissions excepted methodology, whichever date is
713
later .
714
715
B)
If the EGU has commenced commercial operation on or after July
716
1, 2008, at least 45 days prior to the applicable date specified under
717
subsection (b)(2) of this Section or 45 days prior to relying on the
718
low mass emissions excepted methodology, whichever date is
719
later .
720
721
b)
Emissions Monitoring Deadlines
. The owner or operator shall meet the emissions
722
monitoring system certification and other emissions monitoring requirements of
723
subsections (a)(1)
and (a)(2) of this Section on or before the following dates
. The
724
owner or operator shall record, report, and quality-assure the data from the
725
emissions monitoring systems required under subsection
(a)(1) of this Section on
726
and after the following dates :
727
728
1)
For the owner or operator of an EGU that commences commercial
729
operation before July 1, 2008, by January 1, 2009 .
730
731
2)
For the owner or operator of an EGU that commences commercial
732
operation on or after July 1, 2008, by 90 unit operating days or 180
733
calendar days, whichever occurs first, after the date on which the EGU
734
commences commercial operation .
735
736
3)
For the owner or operator of an EGU for which construction of a new
737
stack or flue or installation of add-on mercury emission controls, a flue
738
gas desulfurization system, a selective catalytic reduction system, a fabric
739
filter, or a compact hybrid particulate collector system is completed after
740
the applicable deadline under subsection (b)(1)
or (2) of this Section, by
741
90 unit operating days or 180 calendar days, whichever occurs first, after
742
the date on which emissions first exit to the atmosphere through the new
743
stack or flue, add-on mercury emissions controls, flue gas desulfurization
744
system, selective catalytic reduction system, fabric filter, or compact
745
hybrid particulate collector system
.
746
747
c)
Reporting Data
748
749
1)
750
751
752
753
754
755
756
757
758
759
2)
760
761
762
763
764
765
766
767
768
769
770
d)
Prohibitions
771
772
773
774
775
776
777
778
779
780
781
782
783
784
785
786
787
788
789
790
1)
2)
3)
JCAR350225-0609281 rOl
Except as provided in subsection (c)(2)
of this Section, the owner or
operator of an EGU that does not meet the applicable emissions
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) .
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 .
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
.
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
.
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
JCAR350225-060928 I rOl
791
maintenance is performed in accordance with the applicable provisions of
792
this Section, Sections 225.250
through 225 .290 of this Subpart, and
793
subpart I of 40 CFR 75.
794
795
4)
No owner or operator of an EGU shall retire or permanently discontinue
796
use of the continuous emission monitoring system or any component
797
thereof, or any other approved monitoring system under this Subpart,
798
except under any one of the following circumstances
:
799
800
A)
The owner or operator is monitoring emissions from the EGU with
801
another certified monitoring system that has been approved, in
802
accordance with the applicable provisions of this Section, Sections
803
225 .250 through 225
.290 of this Subpart, and subpart I of 40 CFR
804
75, by the Agency for use at that EGU and that provides emission
805
data for the same pollutant or parameter as the retired or
806
discontinued monitoring system
; or
807
808
B)
The owner or operator or designated representative submits
809
notification of the date of certification testing of a replacement
810
monitoring system for the retired or discontinued monitoring
811
system in accordance with Section 225
.250(a)(3)(A) of this
812
Subpart.
813
814
e)
Long-term Cold Storage
815
The owner or operator of an EGU that is in long-term cold storage is subject to
816
the applicable provisions of 40 CFR 75 for monitoring, recordkeeping, and
817
reporting for units in long-term cold storage .
818
819
Section 225.250
Initial Certification and Recertification Procedures for Emissions
820 Monitoring
821
822
a)
The owner or operator of an EGU shall comply with the following initial
823
certification and recertifrcation procedures for a continuous emissions monitoring
824
system (i.e.,
a continuous emission monitoring system or an excepted monitoring
825
system (sorbent trap monitoring system) under 40 CFR 75
.15) required by Section
826
225 .240(a)(1)
. The owner or operator of an EGU that qualifies for, and for which
827
the owner or operator elects to use, the low mass emissions excepted
828
methodology under 40 CFR 75
.81(b) shall comply with the procedures in
829
subsection (c) of this Section .
830
831
1)
Requirements for Initial Certification
. The owner or operator of an EGU
832
shall ensure that, for each continuous emissions monitoring system
833
required by Section 225.240(a)(1)
of this Subpart (including the automated
JCAR350225-0609281r01
834
data acquisition and handling system), the owner or operator successfully
835
completes all of the initial certification testing required under 40 CFR
836
75
.80(d) by the applicable deadline in Section 225
.240(b) of this Subpart
.
837
In addition, whenever the owner or operator of an EGU installs a
838
monitoring system to meet the requirements of this Subpart in a location
839
where no such monitoring system was previously installed, the owner or
840
operator must successfully complete the initial certification requirements
841
of 40 CFR 75
.80(d).
842
843
2)
Requirements for Recertification
. Whenever the owner or operator of an
844
EGU makes a replacement, modification, or change in any certified
845
continuous emission monitoring system, or an excepted monitoring system
846
(sorbent trap monitoring system) under 40 CFR 75
.15, and required by
847
Section 225
.240(a)(1) of this Subpart, that may significantly affect the
848
ability of the system to accurately measure or record mercury mass
849
emissions or heat input rate or to meet the quality-assurance and quality-
850
control requirements of 40 CFR 75
.21 or appendix B to 40 CFR 75, the
851
owner or operator of an EGU shall recertify the monitoring system in
852
accordance with 40 CFR 75 .20(b)
. Furthermore, whenever the owner or
853
operator of an EGU makes a replacement, modification, or change to the
854
flue gas handling system or the EGU's operation that may significantly
855
change the stack flow or concentration profile, the owner or operator shall
856
recertify each continuous emission monitoring system, and each excepted
857
monitoring system (sorbent trap monitoring system) under 40 CFR 75
.15,
858
whose accuracy is potentially affected by the change, all in accordance
859
with 40 CFR 75
.20(b)
. Examples of changes to a continuous emission
860
monitoring system that require recertification include replacement of the
861
analyzer, complete replacement of an existing continuous emission
862
monitoring system, or change in location or orientation of the sampling
863
probe or site .
864
865
3)
Approval Process for Initial Certification and Recertification
. Subsections
866
(a)(3)(A)
through (D) of this Section apply to both initial certification and
867
recertification of a continuous monitoring system required by Section
868
225
.240(a)(1) of this Subpart
. For recertifications, replace the words
869
"certification" and "initial certification" with the word "recertification",
870
replace the word "certified" with the word "recertified", and follow the
871
procedures in 40 CFR 75
.20(b)(5) in lieu of the procedures in subsection
872
(a)(3)(E)
of this Section .
873
874
A)
Notification of Certification
. The owner or operator shall submit
875
to the Agency, USEPA Region 5, and the Administrator of the
JCAR350225-060928 I rOl
876
USEPA written notice of the dates of certification testing, in
877
accordance with Section 225
.270 of this Subpart .
878
879
B)
Certification Application
. The owner or operator shall submit to
880
the Agency a certification application for each monitoring system
.
881
A complete certification application shall include the information
882
specified in 40 CFR 75.63
.
883
884
C)
Provisional Certification Date
. The provisional certification date
885
for a monitoring system shall be determined in accordance with 40
886
CFR 75 .20(a)(3)
. A provisionally certified monitoring system may
887
be used under this Subpart for a period not to exceed 120 days
888
after receipt by the Agency of the complete certification
889
application for the monitoring system under subsection
(a)(3)(B) of
890
this Section
. Data measured and recorded by the provisionally
891
certified monitoring system, in accordance with the requirements
892
of 40 CFR 75, will be considered valid quality-assured data
893
(retroactive to the date and time of provisional certification),
894
provided that the Agency does not invalidate the provisional
895
certification by issuing a notice of disapproval within 120 days
896
after the date of receipt by the Agency of the complete certification
897
application.
898
899
D)
Certification Application Approval Process
. The Agency will
900
issue a written notice of approval or disapproval of the certification
901
application to the owner or operator within 120 days after receipt
902
of the complete certification application required by subsection
903
(a)(3)(B) of this Section
. In the event the Agency does not issue
904
such a notice within the 120-day period, each monitoring system
905
that meets the applicable performance requirements of 40 CFR 75
906
and is included in the certification application will be deemed
907
certified for use under this Subpart
.
908
909
i)
Approval Notice
. If the certification application is
910
complete and shows that each monitoring system meets the
911
applicable performance requirements of 40 CFR 75, then
912
the Agency will issue a written notice of approval of the
913
certification application within 120 days after receipt
.
914
915
ii)
Incomplete Application Notice
. If the certification
916
application is not complete, then the Agency will issue a
917
written notice of incompleteness that sets a reasonable date
918
by which the owner or operator must submit the additional
JCAR350225-0609281 r01
919
information required to complete the certification
920
application
. If the owner or operator does not comply with
921
the notice of incompleteness by the specified date, then the
922
Agency may issue a notice of disapproval under subsection
923
(a)(3)(D)(iii)
of this Section
. The 120-day review period
924
shall not begin before receipt of a complete certification
925
application.
926
927
iii)
Disapproval Notice
. If the certification application shows
928
that any monitoring system does not meet the performance
929
requirements of 40 CFR 75 or if the certification
930
application is incomplete and the requirement for
931
disapproval under subsection
(a)(3)(D)(ii)
of this Section is
932
met, then the Agency will issue a written notice of
933
disapproval of the certification application
. Upon issuance
934
of such notice of disapproval, the provisional certification
935
is invalidated by the Agency and the data measured and
936
recorded by each uncertified monitoring system shall not be
937
considered valid quality-assured data beginning with the
938
date and hour of provisional certification (as defined under
939
40 CFR 75 .20(a)(3))
. The owner or operator shall follow
940
the procedures for loss of certification in subsection
941
(a)(3)(E)
of this Section for each monitoring system that is
942
disapproved for initial certification .
943
944
iv)
Audit Decertification
. The Agency may issue a notice of
945
disapproval of the certification status of a monitor in
946
accordance with Section 225
.260(b) of this Subpart
.
947
948
E)
Procedures for Loss of Certification
. If the Agency issues a notice
949
of disapproval of a certification application under subsection
950
(a)(3)(D)(iii) of this Section or a notice of disapproval of
951
certification status under subsection
(a)(3)(D)(iv)
of this Section,
952
then:
953
954
i)
The owner or operator shall substitute the following values,
955
for each disapproved monitoring system, for each hour of
956
EGU operation during the period of invalid data specified
957
under 40 CFR 75
.20(a)(4)(iii) or 75
.21(e) and continuing
958
until the applicable date and hour specified under 40 CFR
959
75 .20(a)(5)(i)
. For a disapproved mercury pollutant
960
concentration monitor and disapproved flow monitor,
961
respectively, the maximum potential concentration of
JCAR350225-0609281r01
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 .
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
75 are fully met, the monitoring system shall be exempt from the initial
certification requirements of this Section
.
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
.
962
963
964
965
966
967
968
969
970
971
972
973
974
975
976
977
978
979
980
981
982
983
984
985
986
987
988
b)
Exemption
989
990
1)
991
992
993
994
995
996
2)
997
998
999
1000
1001
c)
Initial certification and recertification procedures for EGUs using the mercury low
1002
mass emissions excepted methodology under 40 CFR 75
.81(b)
. The owner or
1003
operator of an EGU qualified to use the mercury low mass emissions excepted
JCAR350225-0609281 rOl
1004
methodology under 40 CFR 75
.81(b) shall meet the applicable certification and
1005
recertification requirements in 40 CFR 75
.81(c) through (f) .
1006
1007
d)
Certification Applications
. The owner or operator of an EGU shall submit an
1008
application to the Agency within 45 days after completing all initial certification
1009
or recertification tests required under this Section, including the information
1010
required under 40 CFR 75
.63
.
1011
1012
Section 225.260
Out of Control Periods for Emission Monitors
1013
1014
a)
Whenever any emissions monitoring system fails to meet the quality-assurance
1015
and quality-control requirements or data validation requirements of 40 CFR 75,
1016 data shall be substituted using the applicable missing data procedures in subparts
1017
D and I of 40 CFR 75 .
1018
1019
b)
Audit Decertification
. Whenever both an audit of an emissions monitoring
1020
system and a review of the initial certification or recertification application reveal
1021
that any emissions monitoring system should not have been certified or recertified
1022
because it did not meet a particular performance specification or other
1023
requirement under Section 225
.250 of this Subpart or the applicable provisions of
1024
40 CFR 75, both at the time of the initial certification or recertification application
1025
submission and at the time of the audit, the Agency will issue a notice of
1026
disapproval of the certification status of such monitoring system
. For the
1027
purposes of this subsection, an audit shall be either a field audit or an audit of any
1028
information submitted to the Agency
. By issuing the notice of disapproval, the
1029
Agency revokes prospectively the certification status of the emissions monitoring
1030
system
. The data measured and recorded by the monitoring system shall not be
1031
considered valid quality-assured data from the date of issuance of the notification
1032
of the revoked certification status until the date and time that the owner or
1033
operator completes subsequently approved initial certification or recertification
1034
tests for the monitoring system
. The owner or operator shall follow the applicable
1035
initial certification or recertification procedures in Section 225
.250 of this Subpart
1036
for each disapproved monitoring system
.
1037
1038 Section 225
.261 Additional Requirements to Provide Heat Input Data
1039
1040
The owner or operator of an EGU that monitors and reports mercury mass emissions using a
1041 mercury concentration monitoring system and a flow monitoring system shall also monitor and
1042
report heat input rate at the EGU level using the procedures set forth in 40 CFR 75
.
1043
1044
Section 225.263
Monitoring of Gross Electrical Output
1045
JCAR350225-0609281r01
1046
The owner or operator of an EGU complying with this Subpart by means of Section
1047
225.230(a)(1)
or using electrical output (O) and complying by means of Section 225
.230(b) or
1048
(d) or Section 225
.232 of this Subpart shall monitor gross electrical output of the associated
1049
generator(s) in MWh on an hourly basis .
1050
1051
Section 225.265
Coal Analysis for Input Mercury Levels
1052
1053
a)
The owner or operator of an EGU complying with this Subpart by means of
1054
Section 225
.230(a)(2) or using input mercury levels (I) and complying by means
1055
of Section 225
.230(b) or (d) or Section 225
.232 of this Subpart shall
:
1056
1057
1)
Perform daily sampling of the coal combusted in the EGU for mercury
1058
content
. The owner or operator of such EGU shall collect a minimum of
1059
one 2-lb grab sample per day of operation from the belt feeders anywhere
1060
between the crusher house or breaker building and the boiler
. The sample
1061
shall be taken in such a manner so as to provide a representative mercury
1062
content for the coal burned on that day .
1063
1064
2)
Analyze the grab coal sample for the following
:
1065
1066
A)
Determine the heat content using ASTM D5865-04 or equivalent
1067
approved in writing by the Agency
.
1068
1069
B)
Determine the moisture content using ASTM D3173-03 or
1070
equivalent approved in writing by the Agency
.
1071
1072
C)
Measure the mercury content using ASTM D6414-01, ASTM
1073
D3684-01, or equivalent approved in writing by the Agency
.
1074
1075
3)
The owner or operator of multiple EGUs at the same source using the
1076
same crusher house or breaker building may take one sample per crusher
1077
house or breaker building, rather than one per EGU
.
1078
1079
4)
The owner or operator of an EGU shall use the data analyzed under
1080
subsection (b) of this Section to determine the mercury content in terms of
1081
lbs/trillion Btu .
1082
1083
b)
The owner or operator of an EGU that must conduct sampling and analysis of coal
1084
pursuant to subsection (a) of this Section shall begin such activity by the
1085
following date :
1086
1087
1)
If the EGU is in daily service, at least 30 days before the start of the month
1088
for which such activity will be required
.
JCAR350225-0609281r01
1089
1090
2)
If the EGU is not in daily service, on the day that the EGU resumes
1091
operation .
1092
1093
Section 225.270
Notifications
1094
1095
The owner or operator of a source with one or more EGUs shall submit written notice to the
1096
Agency according to the provisions in 40 CFR 75
.61 for each EGU or group of EGUs monitored
1097 at a common stack and each non-EGU monitored under 40 CFR 75
.82(b)(2)(ii) .
1098
1099 Section 225.290
Recordkeeping and Reporting
1100
1101
a)
General Provisions
1102
1103
1)
The owner or operator of an EGU and its designated representative shall
1104
comply with all applicable recordkeeping and reporting requirements in
1105
this Section and with all applicable recordkeeping and reporting
1106
requirements of 40 CFR 75 .84.
1107
1108
2)
The owner or operator of an EGU shall maintain records for each month
1109
identifying the emission standard in Section 225
.230(a) or 225 .237(a) of
1110
this Section with which it is complying or that is applicable for the EGU
l ill
and the following records related to the emissions of mercury that the
1112
EGU is allowed to emit :
1113
1114
A)
For an EGU for which the owner or operator is complying with
1115
this Subpart by means of Section 225 .230(a)(2) or
1116
225 .237(a)(1)(B) or using input mercury levels to determine the
1117
allowable emissions of the EGU, records of the daily mercury
1118
content of coal used (lbs/trillion Btu) and the daily and monthly
1119
input mercury (lbs), which shall be kept in the file required under
1120
40 CFR 75 .84(a).
1121
1122
B)
For an EGU for which the owner or operator of an EGU complying
1123
with this Subpart by means of Section 225 .230(a)(1) or
1124
225.237(a)(1)(A)
or using electrical output to determine the
1125
allowable emissions of the EGU, records of the daily and monthly
1126
gross electrical output (GWh), which shall be kept in the file
1127
required under 40 CFR 75
.84(a).
1128
1129
3)
The owner or operator of an EGU shall maintain records of the following
1130
for each EGU :
1131
JCAR350225-0609281rOl
1132
A)
Monthly emissions of mercury from the EGU .
1133
1134
B)
For an EGU for which the owner or operator is complying by
1135
means of Section 225 .230(b) or (d) of this Subpart, records of the
1136
monthly allowable emissions of mercury from the EGU
.
1137
1138
4)
The owner or operator of an EGU that is participating in an Averaging
1139
Demonstration pursuant to Section 225.232 of this Subpart shall maintain
1140
records identifying all sources and EGUs covered by the Demonstration
1141
for each month and, within 60 days after the end of each calendar month,
1142
calculate and record the actual and allowable mercury emissions of the
1143
EGU for the month and the applicable 12-month rolling period .
1144
1145
5)
The owner or operator of an EGU shall maintain the following records
1146
related to quality assurance activities conducted for emissions monitoring
1147
systems:
1148
1149
A)
The results of quarterly assessments conducted under Section 2
.2
1150
of appendix B of 40 CFR 75
; and
1151
1152
B)
Daily/weekly system integrity checks under Section 2
.6 of
1153
appendix B of 40 CFR 75
.
1154
1155
6)
The owner or operator of an EGU shall maintain an electronic copy of all
1156
electronic submittals to the USEPA under 40 CFR 75
.84(f).
1157
1158
7)
The owner or operator of an EGU shall retain all records required by this
1159
Section at the source unless otherwise provided in the CAAPP permit
1160
issued for the source and shall make a copy of any record available to the
1161
Agency upon request.
1162
1163
b)
Quarterly Reports
. The owner or operator of a source with one or more EGUs
1164
shall submit quarterly reports to the Agency as follows :
1165
1166
1)
These reports shall include the following information for operation of the
1167
EGUs during the quarter :
1168
1169
A)
The total operating hours of each EGU and the mercury CEMS, as
1170
also reported in accordance with 40 CFR 75
.
1171
1172
B)
A discussion of any significant changes in the measures used to
1173
control emissions of mercury from the EGUs or the coal supply to
1174
the EGUs, including changes in the source of coal
.
JCAR350225-0609281r01
1175
1176
C)
Summary information on the performance of the mercury CEMS .
1177
When the mercury CEMS was not inoperative, repaired, or
1178
adjusted, except for routine zero and span checks, this shall be
1179
stated in the report .
1180
1181
D)
If the CEMS downtime was more than 5 .0 percent of the total
1182
operating time for the EGU
: the date and time identifying each
1183
period during which the CEMS was inoperative, except for routine
1184
zero and span checks ; the nature of CEMS repairs or adjustments
1185
and a summary of quality assurance data consistent with 40 CFR
1186
75, i .e., the dates and results of the Linearity Test(s) and any
1187
Relative Accuracy Test Audit(s) during the quarter ; a listing of any
1188
days when a required daily calibration was not performed ; and the
1189
date and duration of any periods when the CEMS was out-of-
1190
control as addressed by Section 225 .260 of this Subpart .
1191
1192
2)
The owner or operator shall submit each quarterly report to the Agency
1193
within 45 days following the end of the calendar quarter covered by the
1194
report.
1195
1196
c)
Compliance Certification . The owner or operator of a source with one or more
1197
EGUs shall submit to the Agency a compliance certification in support of each
1198
quarterly report based on reasonable inquiry of those persons with primary
1199
responsibility for ensuring that all of the EGUs' emissions are correctly and fully
1200
monitored
. The certification shall state :
1201
1202
1)
That the monitoring data submitted were recorded in accordance with the
1203
applicable requirements of this Section 225 .290 and Sections 225
.240
1204
through 225
.270 of this Subpart, and 40 CFR 75, including the quality
1205
assurance procedures and specifications ; and
1206
1207
2)
For an EGU with add-on mercury emission controls, a flue gas
1208
desulfurization system, a selective catalytic reduction system, or a
1209
compact hybrid particulate collector system and for all hours where
1210
mercury data are substituted in accordance with 40 CFR 75
.34(a)(1) :
1211
1212
A)
That:
1213
1214
i)
The mercury add-on emission controls, flue gas
1215
desulfurization system, selective catalytic reduction system,
1216
or compact hybrid particulate collector system was
1217
operating within the range of parameters listed in the
1218
1219
1220
1221
1222
1223
1224
1225
1226
1227
1228
1229
1230
1231
1232
1233
d)
Annual Certification of Compliance
1234
1235
1236
1237
1238
1239
1240
1241
1242
1243
1244
1245
1246
1247
1248
1249
1250
1251
1252
1253
1254
1255
1256
1257
1258
1259
1260
1)
JCAR350225-0609281r01
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 S0 2
emission data recorded in accordance with 40 CFR 75
document that the flue gas desulfurization system was
operating properly, or quality-assured NOx 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 .
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 1 of each year and shall address
compliance for the previous calendar year
. Such certification shall be
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 lbs, 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
.
JCAR350225-060928 I rOl
1261
1262
B)
If complying with this Subpart by means of Section
1263
225.230(a)(1)(B) or 225 .237(a)(1)(B) :
1264
1265
i)
Actual control efficiency for emissions for each 12-month
1266
rolling period ending in the year covered by the
1267
Certification, expressed as a percent
;
1268
1269
ii)
Actual emissions, in lbs, and mercury content in the fuel
1270
fired in such EGU, in lbs, for each 12-month rolling period
1271
ending in the year covered by the Certification ; and
1272
1273
iii)
Actual emissions, in lbs, and mercury content in the fuel
1274
fired in such EGU, in lbs, for each month in the year
1275
covered by the Certification and in the previous year .
1276
1277
C)
If complying with this Subpart by means of Section 225 .230(b):
1278
1279
i)
Actual emissions and allowable emissions for each 12-
1280
month rolling period ending in the year covered by the
1281
Certification; and
1282
1283
ii)
Actual emissions and allowable emissions, and which
1284
standard of compliance the owner or operator was utilizing
1285
for each month in the year covered by the Certification and
1286
in the previous year .
1287
1288
D)
If complying with this Subpart by means of Section 225
.230(d):
1289
1290
i)
Actual emissions and allowable emissions for all EGUs at
1291
the source for each 12-month rolling period ending in the
1292
year covered by the Certification; and
1293
1294
ii)
Actual emissions and allowable emissions, and which
1295
standard of compliance the owner or operator was utilizing
1296
for each month in the year covered by the Certification and
1297
in the previous year.
1298
1299
E)
If complying with this Subpart by means of Section 225 .232 :
1300
1301
i)
Actual emissions and allowable emissions for all EGUs at
1302
the source in an Averaging Demonstration for each 12-
JCAR350225-0609281rOl
1345
f)
Quality Assurance RATA Reports
. The owner or operator of an EGU shall
1346
submit to the Agency, Air Compliance and Enforcement Section, the quality
1347
assurance RATA report for each EGU or group of EGUs monitored at a common
1348
stack and each non-EGU under 40 CFR 75
.82(b)(2)(ii) within 45 days after
1349
completing a quality assurance RATA .
1350
1351
Section 225.295 Treatment of Mercury Allowances
1352
1353
Any mercury allowances allocated to the Agency by the USEPA shall be treated as follows
:
1354
1355
a)
No such allowances shall be allocated to any owner or operator of an EGU or
1356
other sources of mercury emissions into the atmosphere or discharges into the
1357
waters of the State .
1358
1359
b)
The Agency shall hold all allowances allocated by the USEPA to the State
. At the
1360
end of each calendar year, the Agency shall instruct the USEPA to retire
1361
permanently all such allowances .
