POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

ILLINOIS REGISTER

1

06

4)

Statutory Authority : 415 ILCS 5/9 .10,27 and 28 .5 (2005)

5)

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 § 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, and to address the applicable requirements of Section 9 .10 of the

Environmental Protection Act, 415 ILCS 5/9.10. 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

1)

Heading of the Part : Control of Emissions from Large Combustion Sources

2)

Code Citation : 35 111 . Adm . Code Part 225

3)

Section Numbers :

Proposed Action:

225 .100

New

221120

New

221130

New

221140

New

225 .200

New

225.202

New

225.205

New

225.210

New

225.220

New

225.230

New

225 .232

New

225 .235

New

225

.237

New

225

.240

New

225 .250

New

225.260

New

225 .261

New

225 .263

New

225

.265

New

225 .270

New

225 .290

New

225.295

New

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ILLINOIS REGISTER 2

06

POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

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 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 peiiiiitting,

monitoring, recordkeeping, and reporting requirements for affected sources .

6) ished 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

odel that was perfoinied by ICY Resources, Inc . contracted by the

Illi s The underlying data used to perform the modeling and the results are also

available or review at the Pollution Control Board .

Anderson, H.A.,

J.F. Amrhein, P . Shubat, and J . Hesse. Protocol for a uniform Great

Lakes sport fish consumption advisory . Great Lakes Fish Advisory Task Force Protocol

Drafting Committee . 1993 .

Berry, M ., Irvin, N., Monroe, L ., Bustard, J ., Lindsey, C ., Brignac, P ., Taylor, T

.,

Schlager, R., Sjostrom, S

., Starns, T., Chang, R ., O'Palko, A., 2004. "Field Test Program

for Long-Term Operation of a COHPACO System for Removing Mercury from Coal-

Fired Flue Gas", Presented at the Joint EPRI DOE EPA Combined Utility Air Pollution

Control Symposium, The Mega Symposium, August 31-September 2, 2004, Washington,

D.C.

Bier iann, J ., Higgins, B., Wendt, J.O., Senior, C ., Wang, D . "Mercury Reduction at a

Coal Fired Power Plant at over 2000 °F Using MinPlus Sorbent Through Furnace Sorbent

Injection", 2006 Electric Utilities Environmental Conference, Tucson, AZ, January 22-

25, 2006; Available online at http ://www.mobotecusa .com

Bustard, J . ; Durham, M. ; Lindsey, C.; Stares, T .; Baldrey, K.; Martin, C .

; Schlager, R

.;

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ILLINOIS REGISTER

3

06

POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

Sjostrom, S .; Slye, R . ; Renninger, S . ; Monroe, L . ; Miller, R. ; Chang, R ., "Full-Scale

Evaluation of Mercury Control with Sorbent Injection and COHPAC at Alabama Power

E.C ., Gaston," DOE-EPRI-U .S

. EPA-A&WMA Power Plant Air Pollutant Control Mega

Symposium, Chicago, IL, August 20-23, 2001 .

Cain, Alex, U .S . Environmental Protection Agency Presentation, LADCO Mercury

Workshop, O'Hare International Center -Auditorium, Rosemont, Illinois, February 22,

2006.

Dombrowski, K., Richardson, C ., "Sorbent Injection for Small ESP Mercury Control in

Bituminous Coal Flue Gas", DOE/NETL's Mercury Control Technology R&D Program

Review, Pittsburgh, PA, July 12-13, 2005 .

Dombrowski, K., Richardson, C ., Machalek, T., Chapman, D ., Chang, R ., Monroe, L.,

Berry, M ., Irvin, N ., McBee, K ., Sjostrom, S ., "Sorbent Injection for Mercury Control

Upstream of Small-SCA ESPs", Presented at the Joint EPRI DOE EPA Combined Utility

Air Pollution Control Symposium, The Mega Symposium, August 31-September 2, 2004,

Washington, D .C.

n, "Advances in Mercury Control Technology", Pennsylvania Mercury Rule

oup Meeting, November 18, 2005 .

"Field Test Program for Long-Term Operation of a COHPAC® System for Removing

Mercury", DOE/NETL's Mercury Control Technology R&D Program Review,

, July 12-13, 2005 .

, N., "Brominated Sorbents : Effects on Emissions of Halogenated Air Toxics",

DOE/NETL's Mercury Control Technology R&D Program Review, Pittsburgh, PA, July

12-13, 2005 .

Illinois Department of Public Health . Environmental Health Fact Sheet - Fish Advisories

in Illinois . Illinois Department of Public Health, Division of Environmental Health,

Springfield, IL. 2006 .

Illinois Environmental Protection Agency . Illinois 2004 Section 303(d) List .

g

erg, E ., Yu-Ming, Mehta, A ., "The Passivation of Carbon for Improvement

rainment in Fly Ash Concrete",

e.gov/publications/proceedings/00/ubcOO/HURT .PD F

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ILLINOIS REGISTER 4

06

POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

IEPAIBOW/04-005 . Bureau of Water, Watershed Management Section : Springfield, IL.

November 2004

.

Illinois Environmental Protection Agency . DRAFT

- Illinois Integrated Water Quality

Report and Section 303(d) list - 2006. Clean Water Act Sections 303(d), 305(b) and 314 .

Water Resource Assessment Infounation and Listing of Impaired Waters . Bureau of

Water, Watershed Management Section, Surface Water Section : Springfield, IL.

Institute of Clean Air Companies, "Status and Capabilities of Mercury Control

Technologies," Presentation to EPA Administrator Leavitt, Washington, D.C., July 20,

2004.

Jenkins, R.E., Burkhead, N.M., 1993. Freshwater Fishes of Virginia . American Fisheries

Society . Bethesda, Maryland . Pages 732-736.

Johnson, D ., Cummings, J ., "TOXECONTM Retrofitfor Mercury and Multi-Pollutant

Control", presentation on Clean Coal Power Initiative, downloaded from

www.netl

.doe.gov

Khan, S. and Srinivasachar, S ., "Field Demonstration of Enhanced Sorbent Injection for

Mercury Control", DOE-NETL, Mercury Control Program, Review Meeting, July 12,

2005.

Michigan Electric Utility Workgroup, "Final Report on Mercury Emissions from Coal-

Fired Power Plants", June 20, 2005 .

Migler, Paul, VanAten, Chris . "North American Power Plant Air Emissions . Commission

for Environmental Cooperation of North America, 2004 .

MinPlus Sorbent : Non Carbon Sorbent for Mercury Control in Coal Fired Boilers,

August 2005.

National Wildlife Federation, Getting the Job Done : Affordable Mercury Control at Coal-

Burning Power Plants, October 2004 .

Nelson, S., "Sorbent Technology for Mercury Control", Pennsylvania Mercury Rule

Workgroup Meeting, November 18, 2005 .

Nolan, P ., Downs, W., Bailey, R ., Vecci, S ., "Use of Sulfide Containing Liquors for

Removing Mercury from Flue Gases", U .S. Patent # 6,503,470, January 7, 2003 .

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ILLINOIS REGISTER

5

06

POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

Northeast States for Coordinated Air Use Management (NESCAUM), "Economic

Valuation of Human Health Benefits for Controlling Mercury Emissions from U

.S . Coal-

Fired Power Plants", February 2005 .

Northeast States for Coordinated Air Use Management (NESCAUM), "Mercury

Emissions from Coal-Fired Power Plants . The Case for Regulatory Action," October

2003 .

Renninger, S., Farthing, G ., Ghorishi, S .B ., Teets, C ., Neureuter, J ., "Effects of SCR

Catalyst, Ammonia Injection and Sodium Hydrosulfide on the Speciation and Removal of

Mercury within a Forced-Oxidized Limestone Scrubber", Presented at the Joint EPRI

DOE EPA Combined Utility Air Pollution Control Symposium, The Mega Symposium,

August 31-September 2, 2004, Washington, D .C.

Richardson, C

., Machalek, T.,

Marsh, B., Miller, S ., Richardson, M ., Chang, R ., Strohfus

M

., Smokey, S.,

Hagley, T ., Juip G

., Rosvold, R ., "Chemical Addition for Mercury

Control in Flue Gas Derived from Western Coals" Presented at the Joint EPRI DOE EPA

Combined Utility Air Pollution Control Symposium, The Mega Symposium, May 19-22,

2003, Washington, D .C.

Rostam-Abadi, M., "Illinois Coal Properties In Regard to Mercury", ICCI Mercury

Meeting, Chicago, IL, November 9, 2005 .

U.S . Environmental Protection Agency. Regulatory Impact Analysis of the Clean Air

Mercury Rule . Final Report . EPA-452/R-05-003 . March 2005 .

Smith, Philip W . The Fishes of Illinois . University of Illinois Press . Pages 232-233 .

1979.

Srinivasachar, S ., Kang, S ., "Field Demonstration of Enhanced Sorbent Injection for

Mercury Control : Quarterly Technical Progress Report", Report Period : July 1 -

September 30, 2005, Prepared for U .S. Department of Energy National Energy

Technology Laboratory, Pittsburgh, Pennsylvania (Under Contract DE-FC26-

04NT42306), November 8, 2005

.

Srivastava, R.K. ; Sedman, C.B.; Kilgroe, J.D., "Performance and cost of Mercury

Emission Control Technology Applications on Electric Utility Boilers," EPA-600/R-00-

083, September 2000 .

---

NOTICE OF PROPOSED RULES

Starns, T ., Amrhein, J., Martin, C ., Sjostrom, S ., Bullinger, C., Stockdill, D

., Strohfus,

TM

M ., Chang, R ., "Full-Scale Evaluation of TOXECON II on a Lignite-Fired Boiler",

Presented at the Joint EPRI DOE EPA Combined Utility Air Pollution Control

Symposium, The Mega Symposium, "August 31-September 2, 2004, Washington, D .C .

Staudt, J., "Mercury Allowances and Strategies : Peering Through the Mist", EUCI's

Navigating the Mercury Issue, October 19-20, 2005, Arlington, VA .

Staudt, J.,

Jozewicz, W ., "Performance and Cost of Mercury and Multipollutant Emission

Control Technology Applications on Electric Utility Boilers", EPA/600/R-03/110

; U.S

.

Environmental Protection Agency, Office of Research and Development, National Risk

Management Research Laboratory, Research Triangle Park, NC, October 2003 .

Tran, P., Shore, L., Yang, X ., Hizny, W., Butz, J., "Mercury Control : Novel Non-Carbon

Sorbents", Power-Gen International, Las Vegas, NV, December 6-8, 2005 .

Trasande, L ., Landrigan, P ., Schechter, C

., "Public Health and Economic Consequences

of Mehtylmercury Toxicity to the Developing Brain," Environmental Health Perspective,

February 28, 2005

. Available online at http ://dx.doi.org

"Use of High-Carbon Illinois Fly Ash in Cement Manufacturing Demonstration Phase,"

ICCI Project Number : 99-1/2.1A-1 http ://www.icci.org/00final/bhatty99 .htm

U.S

. Department of Health and Human Services, Agency for Toxic Substances and

Disease Registry (ATSDR)

. 1999 . Toxicological Profile of Mercury . Public Health

Service, Atlanta, GA .

U.S. Environmental Protection Agency

. Mercury Study Report to Congress. An

Inventory of Anthropogenic Mercury Emissions in the United States . Volume II (EPA-

452/R-97-004) ; December 1997 .

U.S

. Environmental Protection Agency Mercury Study Report to Congress, Execute

Summary. Volume I (EPA-US 2/R-97-003) ; December 1997 .

U.S. Environmental Protection Agency

. Mercury Study Report to Congress. Health

Effects of Mercury and Mercury Compounds

. Volume V . (EPA-452/R-97-007) . 1997.

U.S

. Environmental Protection Agency. Mercury Study Report to Congress .

ILLINOIS REGISTER

6

POLLUTION CONTROL BOARD

06

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ILLINOIS REGISTER 7

06

POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

Characterization of Human Health and Wildlife Risks from Mercury Exposure in the

United States. Vol . VII (EPA-452/R-97-009) . December 1997 .

U.S . Environmental Protection Agency, "Control of Mercury Emissions from Coal-Fired

Electric Utility Boilers : Interim Report", EPA-600/R-01-109, April 2002 .

U.S . Environmental Protection Agency, "Engineering and Economic Factors Affecting

the Installation of Control Technologies for Multipollutant Strategies", EPA-600/R-

02/073, October 2002 .

U.S . Environmental Protection Agency, "Study of Hazardous Air Pollutant Emissions

from Electric Utility Steam Generating Units

-

Final Report to Congress," EPA-453/R-

98-004, February 1998 .

U.S . Environmental Protection Agency, 2005, Air Pollution Prevention and Control

Division, National Risk Management Research Laboratory, Office of Research and

Develoment, "Control of Mercury Emissions from Coal Fired Electric Utility Boilers : An

Update", Research Triangle Park, NC, February 18, 2005 .

U.S . Environmental Protection Agency, Emission Generation Resource Grid (eGrid),

User's Manual, Prepared by E .H. Pechan & Associates Inc

., April 2003

; Available Online

at: ( http ://www.epa.gov/cleanenergy/egrid/index .htm

U.S. Environmental Protection Agency

. Guidance for 2006 Assessment, Listing and

Reporting Requirements Pursuant to Sections 303(d), 305(b) and 314 of the Clean Water

Act. Watershed Branch Assessment and Watershed Protection Division, Office of

Wetlands, Oceans, and Watersheds, Office of Water . July 29, 2005 .

U.S . Environmental Protection Agency . Office of Inspector General

. Evaluation Report .

Additional Analyses of Mercury Emissions Needed Before EPA Finalizes Rules for

Coal-Fired Electric Utilities . Report No . 2005-P-00003 . February 3, 2005 .

World Health Organization .

Methyl Mercury, Volume 101 . Distribution and Sales

Service, International Programme on Chemical Safety, Geneva, Switzerland

. 1990 .

California Environmental Protection Agency

. "Chemicals in Fish : Consumption of Fish

and Shellfish in California and the United States ." October 2001 .

Crelling, J . Dr ., Carty, R . Dr . "Prediction of Mercury Removal Efficiencies with Current

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ILLINOIS REGISTER 8

06

POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

Coal Washing Practices ." Interim Final Technical Report

. September 1, 2004 through

August 31, 2005 .

Foerter, David C

. Institute of Clean Air Companies . Testimony Before the USEPA on

CAIR and CAMR. February 26, 2004 .

Illinois Department of Natural Resources . "2006 Illinois Fishing Information

." 2006.

Illinois Department of Public Health

. 2006. Environmental Health Fact Sheet - Fish

Advisories in Illinois

. Illinois Department of Public Health, Division of Environmental

Health, Springfield, IL

Nelson, Sid, Brickett, Lynn

. Large Scale Mercury Control Field Testing- Phase II .

"Advanced Utility Mercury-Sorbent Field Testing Program

." Progress Report . July 2005.

O'Palko, A ., Sjostrom, S ., Starns, T . "Evaluation of Sorbent Injection for Mercury

Control . NETL Meeting. July 12, 2005 .

Pellettieri . M.B., Hallenbeck, W.H.,

Brenniman, G .R., Cailas, M., Clark, M . "PCB Intake

from Sport Fishing Along the Northern Illinois Shore of Lake Michigan

." Environmental

Contamination and Toxicology. 1996 .

Princiotta, F.T., Technical Memorandum, Control of Mercury Emissions from Coal-Fired

Utility Boilers

. October 25, 2000 .

Srivastava, R.K., Staudt, James E ., Jozewicz, W

. "Preliminary Estimates of Performance

and Cost of Mercury Emission Control Technology Applications on Electric Utility

Boilers : An Update ."

U.S . Environmental Protection Agency

. Appendix B Background Material of

Methodology Used to Estimate 1999 National Mercury Emissions from Coal-Fired

Electric Utility Boilers

. Electricity Utility Steam Generating Unit Mercury Emissions

Information Collection Effort . September 15, 2000 .

U.S. Geological Survey. "Coal Quality Information-Key to the Efficient and

Environmentally Sound Use of Coal

." February 9, 2006 .

7)

Will this rulemaking replace any emergency rule currently in effect?

No

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POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

8)

Does this rulemaking contain an automatic repeal date? No

9)

Does this rulemaking contain incorporations by reference? Yes

10)

Are there any other proposed rules pending on this Part? No

11) Statement of Statewide Policy Objective : This rulemaking 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 Flexib lity 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 .

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ILLINOIS REGISTER 10

06

POLLUTION CONTROL BOARD

NOTICE OF PROPOSED RULES

C)

Types of Professional skills necessary for compliance

: No professional skills

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 Rules begins on the next page :

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AUTHORITY :

Implementing Section 9 .10 and authorized by

Sections 27 and 28 .5 of

the Environmental

Protection Act [415 ILCS 5/9 .10, 27 and 28 .5] .

SOURCE : Adopted at 30 Ill

. Reg effective

SUBPART A

: GENERAL PROVISIONS

Section 225 .100

Severability

If any Section, subsection or clause of this Part is found invalid, such finding

shall not affect the validity of this Part as a whole or any Section, subsection

or clause not found invalid .

Section 225 .120

Abbreviations and Acronyms

TITLE 35

: ENVIRONMENTAL PROTECTION

SUBTITLE B :

CHAPTER I :

AIR POLLUTION

POLLUTION CONTROL BOARD

SUBCHAPTER c

: EMISSION STANDARDS AND LIMITATIONS

FOR STATIONARY SOURCES

PART 225

CONTROL OF EMISSIONS FROM LARGE COMBUSTION SOURCES

SUBPART A :

Section

GENERAL PROVISIONS

225 .100

225 .120

225 .130

225 .140

Severability

Abbreviations and Acronyms

Definitions

Incorporations by Reference

SUBPART B :

CONTROL OF MERCURY EMISSIONS

FROM COAL-FIRED ELECTRIC GENERATING UNITS

Section

225 .200

Purpose

225 .202

Measurement Methods

225 .205

Applicability

225 .210

Compliance Requirements

I

225 .220

(CAAPP)

Clean Air Act Permit Program

Requirements

gPermit

225 .230

Emission Standards for EGUs at Existing Sources

225

.232

Averaging Demonstrations for Existing Sources

225 .235

Units Scheduled for Permanent Shut Down

225 .237

Emission Standards for New Sources with EGUs

225 .240

General Monitoring and Reporting Requirements

225 .250

Initial Certification and Recertification Procedures for Emissions

Monitoring

225 .260

Out of Control Periods for Emission Monitors

225 .261

Additional Requirements to Provide Heat Input Data

225 .263

Monitoring of Gross Electrical Output

225 .265

Coal Analysis for Input Mercury Levels

225 .270

Notifications

225 .290

Recordkeeping and Reporting

225 .295

Treatment of Mercury Allowances

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Section 225 .130

Definitions

The definitions contained in this Section

apply only to the provisions of this

Part

. Unless otherwise defined hereiQD_this9__SectionQ

and unless a different

meaning of a term is clear from its context, the definitions of terms used in

this Part shall have the meanings specified for those terms in 35 Ill . Adm . Code

Pant-211 .

"Averaging demonstration" means, with regard to Subpart B of this Part, a

demonstration of compliance that is based on the combined performance of EGUs at

two or more sources .

"Boiler" means an enclosed fossil or other fuel-fired combustion device used to

produce heat and to transfer heat to recirculating water, steam, or other

medium .

"Bottoming-cycle cogeneration unit" means a cogeneration unit in which the

energy input to the unit is first used to produce useful thermal energy and at

least some of the reject heat from the useful thermal energy application or

process is then used for electricity production .

"Coal" means any solid fuel classified as anthracite, bituminous, subbituminous,

or lignite by the American Society for Testing and Materials (ASTM) Standard

Specification for Classification of Coals by Rank D388-77, 90, 91, 95, 98a, or

99 (Reapproved 2004) .

"Coal-derived fuel" means any fuel (whether in a solid, liquid or gaseous state)

produced by the mechanical, thermal, or chemical process .

"Coal-fired" means combusting any amount of coal or coal-derived fuel, alone or

in combination with any amount of any other fuel, during a specified year

.

Unless otherwise specified within this Part,

shall be the same as those found in 35 Ill .

abbreviations and acronyms are used in this

the abbreviations used in this Part

Adm . Code 211

. The following

Part :

I

I

Act

Btu

CAA

CAAPP Clean

C02

Environmental Protection Act [415 ILCS 57AL-7:

British thermal unit

Clean Air Act [42 TwF~Q-USC 7401 et seq .]

Air Act Permit Program

carbon dioxide

EGU

GWh

hr

lb

MW

MWe

MWh

box

02

electric

gigawatt

hour

pound

megawatt

megawatt

megawatt

nitrogen

oxygen

generating unit

hour

electrical

hour

oxides

RATA

S02

relative

accuracy test audit

sulfur dioxide

USEPA United States Environmental Protection Agency

---

"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 y_=

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

theRthan

42 .5 percent of total energy input, if useful thermal energy

produced is 15 percent or more of total energy output, or not less than 45

percent of total energy input, if useful thermal energy produced is less than 15

percent of total energy output .

For a bottoming-cycle cogeneration unit, useful power not less than 45 percent

of total energy input .

"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), 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

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

.

nth basis" means, with regard to Subpart B of this Part, a

ade on a monthly basis from the relevant data for a particular

nd the preceding 11 calendar months (total of 12 months of

:a), 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 EGU covered by the

determination does operate, so that the determination is still based on 12

months of data .

Section 225 .140

Incorporations by Reference

The following materials are incorporated by reference . These incorporations do

not include any later amendments or editions

.

a)

40 CFR Pa-r4-60, § 60 .17, § 60 .45a, § 60 .49a(k)(1), § 60 .49a(p), §

60 .50a(h), and §§ 60

.4170 through 60 .4176 (2005) .

---

b)

40 CFR Pan,-75 (2005) .

c)

ASTM

. American Society for Testing and Materials, 100 Barr Harbor Drive,

P .O

. Box C700, West Conshohocken r PA. 19428-2454P

(610) 832-9585 :

1)

ASTM D388-77, 90, 91, 95, 98a, or 99, Classification of Coals by Rank

(Reapproved 2004) .

2)

ASTM D3173-03, Standard Test Method for Moisture in the Analysis Sample of

Coal and Coke (Approved April 10, 2003) .

3)

ASTM D3684-01, Standard Test Method for Total Mercury in Coal by the

Oxygen Bomb Combustion/Atomic Absorption Method (Approved October 10, 2001)

.

4)

ASTM D5865-04, Standard Test Method for Gross Calorific Value of Coal and

Coke (Approved April 1, 2004) .

5)

ASTM D6414-01, Standard Test Method for Total Mercury in Coal and Coal

Combustion Residues by Acid Extraction or Wet Oxidation/Cold Vapor Atomic

Absorption (Approved October 10, 2001) .

6)

ASTM D6784-02, Standard Test Method for Elemental, Oxidized,

tide-Bound and Total Mercury in Flue Gas Generated from Coal-Fired

Stationary Sources (Ontario Hydro Method) (Approved April 10, 2002) .

SUBPART B

: CONTROL OF MERCURY EMISSIONS

FROM COAL-FIRED ELECTRIC GENERATING UNITS

Section 225 .200

Purpose

e purpose of this Subpart is to control the emissions of mercury from coal-

fired electrical generating units in Illinois .

Section 225 .202

Measurement Methods

Measureme

a)

of mercury shall be according to the following

:

mission monitoring pursuant to 40 CFR Part-75 (2005) .

b)

ASTM D3173-03, Standard Test Method for Moisture in the Analysis Sample of

Coal and Coke (Approved April 10, 2003) .

c)

ASTM D3684-01, Standard Test Method for Total Mercury in Coal by the

Oxygen Bomb Combustion/Atomic Absorption Method (Approved October 10, 2001)

.

d)

ASTM D5865-04, Standard Test Method for Gross Calorific Value of Coal and

Coke (Approved April 1, 2004) .

e)

ASTM D6414-01, Standard Test Method for Total Mercury in Coal and Coal

Combustion Residues by Acid Extraction or Wet Oxidation/Cold Vapor Atomic

Absorption (Approved October 10, 2001) .

f)

ASTM D6784-02, Standard Test Method for Elemental, Oxidized,

Particle-Bound and Total Mercury in Flue Gas Generated from Coal-Fired

Stationary Sources (Ontario Hydro Method) (Approved April 10, 2002)

.

---

Section 225 .205 Applicability

The

following stationary coal-fired boilers and stationary coal-fired combustion

turbines are EGUs and are subject to this Subpart

:

a)

Except as provided in subsection (b) of this Section, a unit servingg at

any time since the start-up of the unit's combustion chamber, a generator with

nameplate capacity of more than 25 MWe producing electricity for sale

.

b)

For a unit that qualifies as a cogeneration unit during the 12-month

period starting on the date the unit first produces electricity and continues to

qualify as a cogeneration unit, a cogeneration unit serving at any time a

generator with nameplate capacity of more than 25 MWe and supplying in any

calendar year more than one-third of the unit's potential electric output

capacity or 219,000 MWh, whichever is greater, to any utility power distribution

system for sale

. If a unit qualifies as a cogeneration unit during the 12-month

period starting on the date the unit first produces electricity but subsequently

no longer qualifies as a cogeneration unit, the unit shall be subject to

subsection (a) of this Section starting on the day on which the unit first no

longer qualifies as a cogeneration unit

.

Section 225 .210

a)

Permit Requirements

The owner or operator of each source with one or more EGUs subject to this

Subpart at the source must apply for a CAAPP permit that addresses the

applicable requirements of this Subpart

.

b)

Monitoring Requirements

1)

The owner or operator of each source and each EGU at the source must

comply with the monitoring requirements of Sections 225

.240 through 225 .290 of

this S

2)

The compliance of each EGU with the mercury requirements under Sections

225 .230 and 225

.237 of this Subpart shall be determined by the emissions

measurements recorded and reported in accordance with Sections 225

.240 through

225

.290 of this Subpart .

c)

The

app

or

Compliance Requirements

-cury

Emission Reduction Requirements

or operator of any EGU subject to this Subpart shall comply with

requirements for control of mercury emissions under Section 225

.230

on 225

.237 of this Subpart .

d)

Recordkeeping and Reporting Requirements

Unless otherwise provided, the owner or operator of a source with one or more

EGUs at the source shall keep on site at the source each of the documents listed

in subsections (d) (1) through (d) (3) of this Section for a period of five years

from the date the document is created . This period may be extended for cause,

at any time prior to the end of five years, in writing by the Agency .

1)

All emissions monitoring information, in accordance with Sections 225 .240

through 225 .290 of this Subpart .

2)

Copies of all reports, compliance certifications, and other submissions

and all records made or required or documents necessary to demonstrate

compliance with the requirements of this Subpart .

---

3)

Copies of all documents used

to complete a permit application and any

other submission under this Subpart .

e)

Liability

1)

The owner or operator of each source with one or more EGUs shall meet the

requirements of this Subpart .

2)

Any provision of this Subpart that applies to a source shall also apply to

the owner and operator of such source and to the owner and operator of each EGU

at the source

.

3)

Any provision of this Subpart that applies to an EGU shall also

apply to the owner and operator of such EGU

.

f)

Effect on Other Authorities . No provision of this Subpart shall be

construed as exempting or excluding the owner and operator of a source or EGU

from compliance with any other provision of an approved State Implementation

Plan, a permit, the Act, or the CAA .

Section 225 .220

Clean Air Act Permit Program (CAAPP) Permit Requirements

a)

Application Requirements

1)

Each source with one or more EGUs subject to the requirements of this

Subpart is required to submit a CAAPP permit application that addresses all

applicable requirements of this Subpart, applicable to each EGU at the source

.

2)

A4-

For EAK*Any.a2j

that commenced commercial operation

on or before December 31, 2008, the owner or operator of

EGU

must submit an initial permit application or application for CAAPP permit

modification that meets the requirements of this Section by December 31, 2008

.

B)

Fer any B

after December 31, 2008,

the owner or operator of any such EGU must submit an initial CAAPP permit

application or application for CAAPP modification that meets the requirements of

this Section not later than 180 days before initial startup of the

EGUU unless

the construction permit issued for the EGU addresses the requirements of this

Subpart .

b)

Contents of Permit Applications

In addition to other information required for a complete application for CAAPP

permit or CAAPP permit modification, the application shall include the following

information :

1)

The ORIS (Office of Regulatory Information Systems) or facility code

assigned to the source by the Energy Information Administration, if applicable

.

2)

Identification of each EGU at the source

.

3)

The intended approach to the monitoring requirements of Sections 225

.240

through 225

.290 of this Subpart .

4)

The intended approach to the mercury emission reduction requirements of

Section 225

.230 or 225 .237 of this Subpart, as applicable

.

---

c)

Permit Contents

1)

Each CAAPP permit issued by the Agency for a source with one or more EGUs

subject to the requirements of this Subpart shall contain federally enforceable

conditions addressing all applicable requirements of this Subpart, which

conditions shall be a complete and segregable portion of the source's entire

CAAPP permit .

2)

In addition to conditions related to the applicable requirements of this

Subpart, each such CAAPP permit shall also contain the information specified

under subsection (b) of this Section .

Section 225 .230

a)

Emission Standards for EGUs at Existing Sources

1)

Beginning July

1,

2009, the owner or operator of a source with one

or more EGUs subject to this Subpart that commenced commercial operation on or

before December 31, 2254.Z008 shall comply with one of the following standards

for each EGU on a rolling 12-month basis :

A)

An emission standard of 0 .0080 A mercury/GWh gross electrical output ; or

B)

A minimum 90-percent reduction of input mercury .

2) For an EGU complying with subsection (a) (1) (A) of this Section, the actual

mercury emission rate of the EGU for each 12-month rolling period, as monitored

in accordance with this Subpart and calculated as follows, shall not exceed the

applicable emission standard :

Where :

ER

Actual mercury emissions rate of the EGU for the particular 12-month

rolling period, expressed in lb/GWh .

Ei

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 .

Oi

Gross electrical output of the EGU, in GWh, in an individual month

in the 12-month rolling period, as determined in accordance with Section 225 .263

of this Subpart .

3)

For an EGU complying with subsection (a) (1) (B) of this Section, the actual

control efficiency for mercury emissions achieved by the EGU for each 12-month

rolling period, as monitored in accordance with this Subpart and calculated as

follows, shall meet or exceed the applicable efficiency requirement :

Where :

---

CE

Actual control efficiency for mercury emissions of the EGU for the

particular 12-month rolling

period, expressed as a percent .

Ei

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 .

Ii

Amount of mercury in the fuel fired in the EGU, in pounds, in an

individual month in the 12-month rolling period, as determined in accordance

with Section 225

.265 of this Subpart .

b)

fr.jM-qkT&z

0 MCOMMON~Mtw*M- NHN~FMMMMMI

rw* EMOYM~=RPHMOR

1)

As an alternative to compliance with one of the above emission standards

in subsection (a) of this Section, the owner or operator of the EGU may comply

with the emission standards of this Subpart by demonstrating that the actual

emissions of mercury from the EGU are less than the allowable emissions of

mercury from the EGU on a rolling 12-month basis

.

2)

For this purpose, for each rolling 12-month period, the actual emissions

of mercury from the EGU, as monitored in accordance with this Subpart, must not

exceed the allowable emissions of mercury from the EGU, as further provided by

the following formulas

:

Q2-n=AA1Z

E12=120SWOU

A12

Where=

12

:

Ai

al-a-1

E12

Actual mercury emissions of the EGU for the particular 12-

month rolling period .

A12

Allowable mercury emissions of the EGU for the particular 12-month

rolling period-

Ei

Actual mercury emissions of the EGU in an individual month in the

12-month rolling period .

Ai

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 (Alnput

i) or the electrical output from the EGU (AOutput i), as selected by the owner

or operator of the EGU for that given month

.

Alnput 1-1-=

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

.

AOutput -i--T-=

Allowable mercury emissions of the EGU in a particular month

based on the electrical output from the EGU, calculated as the product of the

output based mercury limit, i .e ., 0

.0080 lb/GWh, and the electrical output from

the EGU, in GWh .

3)

If the owner or operator of an EGU does not conduct the necessary

sampling, analysis, and recordkeeping, in accordance with Section 225

.265 of

this Subpart, to determine the mercury input to the EGU, the allowable emissions

of the EGU must be calculated based on the electrical output of the EGU .

---

C)

If two

or more EGUs are served by common stack(s) and the owner or

operator conducts monitoring for mercury emissions in the common stack(s), as

provided for by 40 CFR Pant-75, Subpart I, such that the mercury emissions of

each EGU are not determined separately, compliance of the EGUs with the

applicable emission standards of this Subpart shall be determined as if the EGUs

were a single EGU .

d) Alternative Emission Standards for Multiple ECUs

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

ES=nEiSi

aS=nAiSi :-U

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 .

Ei

Actual mercury emissions of an individual EGU at the source, as

determined in accordance with subsection (b) (2) of this Section .

Ai

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

Idl.in a given 12-month rolling period, all EGUs at such

source covered by the compliance demonstration are considered out of compliance

with the applicable emission standards of this Subpart for the entire last month

of that period .

Section 225 .232

Averaging Demonstrations for Existing Sources

a)

Through December 31, 2013, as an alternative to compliance with the

emission standards of Section 225

.230(a) of this Subpart, the owner or operator

of an EGU may comply with the emission standards of this Subpart by means of an

Averaging Demonstration (Demonstration) that shows that the actual emissions of

mercury from the EGU and other EGUs at the source and other EGUs at other

sources covered by the Demonstration are less than the allowable emissions of

mercury from all EGUs covered by the Demonstration on a rolling 12-month basis .

---

b)

The EGUs at each source covered by a Demonstration must also comply with

one of the following emission standards on a source-wide basis for the period

covered by the Demonstration

:

Illinois Power Cooperative/Marion Generating Station, ID 199856AAC) can only

participate in Demonstrations with other such owners or operators of a single

existing source of EGUs .

Va) Participation in Demonstrations under this Section by the owner or

operator of only a single existing source with EGUs must be authorized through

federally enforceable permit conditions for each such source participating in

the Demonstration .

e)

A source may be included in only one Demonstration during each rolling 12-

month period .

f)

The owner or operator of EGUs using Demonstrations to show compliance with

this Subpart must complete the determination of compliance for each 12-month

rolling period no later than 60 days following the end of the period .

g)

If averaging is used to demonstrate compliance with this Subpart, the

effect of a failure to demonstrate compliance shall be that the compliance

status of each source shall be determined under Section 225

.230 of this Subpart

as if the sources were not covered by a Demonstration

.

h)

For purposes of this Section, if the owner or operator of any source that

participates in a Demonstration with an owner or operator of a source that does

not maintain the required records, data, and reports for the EGUs at the source,

or does not submit copies of such records, data, or reports to the Agency upon

request, then the effect of this failure will be deemed to be a failure to

demonstrate compliance and the compliance status of each source shall be

determined under Section 225

.230 of this Subpart as if the sources were not

covered by a Demonstration .

Section 225 .235

Units Scheduled for Permanent Shut Down

I

1)

2)

An emission standard of 0 .020 lb mercury/GWh gross electrical output

; or

A minimum 75- percent reduction of input mercury .

c)

For the purpose of this Section, compliance shall be determined using the

equations in Section 225

.230(a)(2), (a)(3), or (d) (2) of this Subpart, as

applicable, addressing all EGUs at the sources covered by the Demonstration,

rather than only EGUs at one source .

I

d)

Limitations on Demonstrations

I

The owners or operators of more than one existing source with

EGUs can only participate in Demonstrations that include other existing sources

that they own or operate

.

I

2)

Sinale Existina Source Demonstrations

I

a)

The owner or operator of only a single existing source with EGUs (i .e .,

City,

Water, Light & Power, City of Springfield, ID 167120AAD ; Electric Energy,

Inc ., ID 127855AAC

; Kincaid Generating Station, ID 021814AAB ; and Southern

---

a)

The emission standards of Section 225

.230(a) of this Subpart are not

applicable to an EGU that will be permanently shut down as

b-e4-e-w

1)

The owner or operator

of an EGU for which this Section is being relied

upon shall by no later than June 30, 2009

:

A)

Have notified the Illinois EPA that it is planning to permanently shut

down the EGU by the applicable date

specified in subsection (a) (3) or (4) of

this Section . This notification shall be accompanied by a description of the

actions that have already been taken to allow the shut down of the

EGU and a

description of the future actions that must be accomplished to complete the shut

down of the EGU,

with the anticipated schedule for those actions and the

anticipated date of permanent whoodewFahul-down

of the unit .

B)

Have applied for a construction permit or be actively pursuing a federally

enforceable agreement that requires the

EGU to be permanently shut down in

accordance with this Section .

C)

Have applied for revisions to the operating permit(s) for the EGU

to

include provisions that terminate the authorization to operate the unit in

accordance with this Section .

2)

The owner or operator of an EGU for which this Section is being relied

upon shall by no later than June 30, 2010

:

A)

Have obtained a construction permit or entered into a federally

enforceable agreement as addressed by subsection (a) (1) (B) of this Section

; or

B)

Have obtained revised operating permit(s) in accordance with subsection

(a) (1) (C) of this Section .

3)

The plan for permanent shut down of the EGU must provide for the EGU to be

permanently shut down by no later than the applicable date specified below

:

A)

If the owner or operator of the EGU is not constructing a new

EGU

or other

generating units to specifically replace the existing EGU, by December 31, 2010 .

B)

If the owner or operator of the EGU

is constructing a new EGU or other

generating units to specifically replace the existing EGU, by December 31, 2011

.

4)

The owner or operator of the EGU

must permanently shut down the EGU by the

date specified in subsection (a) (3) of this Section, unless the owner or

operator submits a demonstration to the Illinois EPA before such date showing

that circumstances beyond its reasonable control (such as protracted delays in

construction activity, unanticipated outage of another EGU, or protracted

shakedown of a replacement unit) have occurred that interfere with the plan for

permanent shut down of the EGU, in which case the date for shut down of the EGU

may be extended as follows

:

A)

If the owner or operator of the EGU

is not constructing a new EGU or other

generating units to specifically replace the existing EGU,

for up to one year,

i .e .,

permanent shut down of the EGU to occur by no later than December 31,

2011 .

B)

If the owner or operator of the EGU is constructing a new EGU or other

generating units to specifically replace the existing EGU, for up to 18 months,

---

i .e ., permanent

shutdown of the EGU to occur by no later than June 30,

12l3, 013 : 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

.

b)

Notwithstanding Sections 225

.230 and 225 .232 of this Subpart, any EGU that

is not required to comply with Section 225

.230 of this Subpart pursuant to this

Section shall not be included when determining whether any other EGUs at the

source or other sources are in compliance with Section 225 .230 of this Subpart .

C)

If an EGUU 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 Subpartt is

not permanently shut down as required by this Section, the EGU shall be

considered to be a new EGU subject to the emission standards in Section

225

.237(a) of this Subpart beginning in the month after the EGU was required to

be permanently shut down, in addition to any other penalties that may be imposed

for failure to permanently shut down the EGU in accordance with this Section .

Section 225 .237

Emission Standards for New Sources with EGUs

a)

Standards

1)

The owner or operator of a source with one or more EGUs, but that

previously had not had any EGUs that commenced commercial operation before

January 1, 2009, shall comply with one of the following emission standards for

each EGU on a rolling 12-month basis

:

A)

An emission standard of 0 .0080 lb mercury/GWh gross electrical output

; or

B)

A minimum 90- percent reduction of input mercury .

2)

Section 225

.230(a)(2), (a)(3), or

b)

purpose, compliance may be demonstrated using the equations in

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

mence on the date that the initial performance test for the mercury

emission standard under 40 CFR 60

.45a also commences . The continuous emission

monitoring systems required by this Subpart for mercury emissions from the EGU

must be certified prior to this date . Thereafter, compliance shall be

demonstrated on a rolling-12 month basis in terms of calendar months .

General Mon

er or operator of an EGU shall comply with the monitoring, recordkeeping,

eporting requirements as provided in this Section, Sections 225 .250 through

0 of this Subpart, and Subpart I of 40

CFR-Part 75 . If the EGU utilizes a

ommon stack with units that are not EGUs and the owner or operator of the EGU

does not conduct emissions monitoring in the duct to the common stack from each

,

the owner or operator of the EGU shall conduct emissions monitoring in

accordance with 40 CFR 75

.82(b)(2) and this Section, including monitoring in the

duct to the common stack from each unit that is not an EGU, unless the owner or

operator of the EGU counts the combined emissions measured at the common stack

as the mass emissions of mercury for the EGUs for recordkeeping and compliance

purposes .

0

(b) (2) of this Subpart .

g and Reporting Requirements

---

a)

Requirements for installation, certification, and data accounting .

The

owner or operator

of each EGU shall :

1)

Install all monitoring systems

required under this Section and Sections

225 .250 through 225 .290 of this Subpart for monitoring mercury mass emissions

(including all systems required to monitor mercury concentration, stack gas

moisture content, stack gas flow rate, and C02 or 02 concentration, as

applicable, in accordance with 40 CFR 75

.81 and 75 .82) ;-

2)

Successfully complete all certification tests required under Section

225

.250 and meet all other requirements of this Section, Sections 225 .250

through 225

.290 of this Subpart, and Subpart I of 40 CFR Part-75 applicable to

the monitoring systems required under subsection (a) (1) of this Section-T,---a-an

d.

3)

Record, report, and quality-assure the data from the monitoring systems

required under subsection (a) (1) of this Section

.

4)

If the owner or operator elects to use the low mass emissions excepted

monitoring methodology for an EGU that emits no more than 464 ounces (29 pounds)

of mercury per year pursuant to 40 CFR 75

.81(b), also perform emissions testing

in accordance with 40 CFR 75 .81(c) to demonstrate that the EGU is eligible to

use this excepted emissions monitoring methodology. a s

well as comply with all

other applicable requirements of 40 CFR 75 .81(b) through (f), and submit a copy

of any information required to be submitted to the USEPA under these provisions

to the Illinois EPA

. The initial emissions testing to demonstrate eligibility

of an EGU for the low mass emissions excepted methodology shall be conducted by

the following dates :

A)

If the EGU has commenced commercial operation before July 1, 2008, at

least by January 1, 2009, or 45 days prior to relying on the low mass emissions

excepted methodology, whichever date is later .

B)

If the EGU has commenced commercial operation on or after July 1, 2008, at

least 45 days prior to the applicable date specified under subsection (b) (2) of

this Section or 45 days prior to relying on the low mass emissions excepted

methodology, whichever date is later-

b)

Emissions menitering deadlinesMonitoring -Deadlines

. The owner or operator

shall meet the emissions monitoring system certification and other emissions

monitoring requirements of subsections (a) (1) and (a) (2) of this Section on or

before the following dates

. The owner or operator shall record, report, and

quality-assure the data from the emissions monitoring systems required under

subsection (a) (1) of this Section on and after the following dates :

1)

For the owner or operator of an EGU that commences commercial operation

before July 1, 2008, by January 1, 2009 .

2)

For the owner or operator of an EGU that commences commercial operation on

or after July 1, 2008, by 90 unit operating days or 180 calendar days, whichever

occurs first, after the date on which the EGU commences commercial operation .

3)

For the owner or operator of an EGU for which construction of a new stack

or flue or installation of add-on mercury emission controls, a flue gas

desulfurization system, a selective catalytic reduction system, a fabric filter,

or a compact hybrid particulate collector system is completed after the

applicable deadline under subsection (b) (1) or (2) of this Section, by 90 unit

operating days or 180 calendar days, whichever occurs first, after the date on

---

which emissions

first exit to the atmosphere

through

the new stack

or flue, add-

on mercury emissions controls, flue gas desulfurization system, selective

catalytic reduction system,--a fabric filter, or compact hybrid particulate

collector system .

C)

Reporting da0t_Qat"

1)

Except as provided in subsection (c) (2) of this Section, the owner or

operator of an EGU that does not meet the applicable emissions monitoring date

set forth in subsection (b) of this Section for any emissions monitoring system

required under subsection (a) (1) of this Section shall, for each such monitoring

system, determine, record, and report maximum potential (or, as appropriate,

minimum potential) values for mercury concentration, stack gas flow rate, stack

gas moisture content, and any other parameters required to determine mercury

mass emissions in accordance with 40 CFR 75

.80(g) .

2)

The owner or operator of an EGU that does not meet the applicable

emissions monitoring date set forth in subsection (b) (3) of this Section for any

emissions monitoring system required under subsection (a) (1) of this Section

shall, for each such monitoring system, determine, record, and report substitute

data using the applicable missing data procedures in 40 CFR 75

.80(f), in lieu of

the maximum potential (or, as appropriate, minimum potential) values

; for a

eterr

if the owner or operator demonstrates that there is continuity

ween the data streams for that parameter before and after the construction or

stallation under subsection (b) (3) of this Section .

d)

Prohibitions

1)

No owner or operator of an EGU shall use any alternative emissions

monitoring system, alternative reference method for measuring emissions, or any

other alternative to the emissions monitoring and measurement requirements of

this Section and Sections 225

.250 through 225 .290 of this Subpart, unless such

alternative is promulgated by the USEPA and approved in writing by the Agency or

the use of such alternative is approved in writing by the Agency and USEPA

.

2)

No owner or operator of an EGU shall operate the EGU so as to discharge,

or allow to be discharged, mercury emissions to the atmosphere without

accounting for all such emissions in accordance with the applicable provisions

of this Section, Sections 225

.250 through 225

.290 of this Subpart, and Subpart I

of 40 CFR Paro-75 .

3)

No owner or operator of an EGU shall disrupt the continuous emission

monitoring system, any portion thereof, or any other approved emission

monitoring method, and thereby avoid monitoring and recording mercury mass

emissions discharged into the atmosphere, except for periods of recertification

or periods when calibration, quality assurance testing, or maintenance is

performed in accordance with the applicable provisions of this Section, Sections

225 .250 through 225

.290 of this Subpart, and Subpart I of 40 CFR Poo l-75 .

4)

No owner or operator of an EGU shall retire or permanently discontinue use

of the continuous emission monitoring system or any component thereof, or any

other approved monitoring system under this Subpart, except under any one of the

following circumstances :

A)

The owner or operator is monitoring emissions from the EGU with another

certified monitoring system that has been approved, in accordance with the

applicable provisions of this Section, Sections 225

.250 through 225 .290 of this

---

Subpart, and Subpart I of 40 CFR Tont-75, by the Agency for use at that EGU and

that provides emission data for the same pollutant or parameter as the retired

or discontinued monitoring system ; or

B)

The owner or operator or designated representative submits notification of

the date of certification testing of a replacement monitoring system for the

retired or discontinued monitoring system in accordance with Section

225

.250 (a) (3) (A) of this Subpart .

e)

Long-term eeld sterwy4- & -Storage

The owner or operator of an EGU that is in long-term cold storage is subject to

the applicable provisions of 40 CFR P,-t-75

for monitoring, recordkeeping, and

reporting for units in long-term cold storage .

Section 225 .250

Initial Certification and Recertification Procedures for

Emissions Monitoring

a)

The owner or operator of an EGU shall comply with the following initial

certification and recertification procedures for a continuous emissions

monitoring system (i .e .,

a continuous emission monitoring system or an excepted

monitoring system (sorbent trap monitoring system) under 40 CFR 75 .15) required

and

by Section

for which

225the

.240(a)(1)owner

or

. The

operator

owner

elects

or operator

to use,

of

the

an EGU

low

that

mass

qualifies

emissions

for

.

excepted methodology under 40 CFR 75

.81(b) shall comply with the procedures in

subsection (c) of this Section .

1)

Requirements for initial eertifleatle

The owner or

operator of an EGU shall ensure thatt for each continuous emissions monitoring

system required by Section 225 .240 (a) (1) of this Subpart (including the

automated data acquisition and handling system)) the owner or operator

successfully completes all of the initial certification testing required under

40 CFR 75

.80(d) by the applicable deadline in Section 225 .240(b) of this

Subpart . In addition, whenever the owner or operator of an EGU installs a

monitoring system to meet the requirements of this Subpart in a location where

no such monitoring system was previously installed, the owner or operator must

successfully complete the initial certification requirements of 40 CFR 75

.80(d) .

I

2)

Requirements for Whenever the owner or

operator of an EGU makes a replacement, modification, or change in any certified

continuous emission monitoring system, or an excepted monitoring system (sorbent

trap monitoring system) under 40 CFR 75 .15, and required by Section

225 .240 (a) (1) of this Subpart, that may significantly affect the ability of the

system to accurately measure or record mercury mass emissions or heat input rate

or to meet the quality-assurance and quality-control requirements of 40 CFR

75 .21 or Appendix B to 40 CFR-Part 75, the owner or operator of an EGU shall

recertify the monitoring system in accordance with 40 CFR 75 .20(b)

.

Furthermore, whenever the owner or operator of an EGU makes a replacement,

modification, or change to the flue gas handling system or the EGU's operation

that may significantly change the stack flow or concentration profile, the owner

or operator shall recertify each continuous emission monitoring system, and each

excepted monitoring system (sorbent trap monitoring system) under 40 CFR 75

.15,

whose accuracy is potentially affected by the change, all in accordance with 40

CFR 75 .20(b) . Examples of changes to a continuous emission monitoring system

that require recertification include replacement of the analyzer, complete

replacement of an existing continuous emission monitoring system, or change in

location or orientation of the sampling probe or site

.

---

Subsections (a) (3) (A)

through (D) of this Section apply to both initial certification and

recertification of a continuous monitoring system required by Section

225

.240(a)(1) of this Subpart . For recertifications, replace the words

"certification" and "initial certification" with the word "recertification

replace the word "certified" with the word nrecertified~,-", and follow the

procedures in 40 CFR 75

.20(b)(5) in lieu of the procedures in subsection

(a) (3) (E) of this Section

.

A)

Notification of eerVKeat!encertification - watin_c

..

The owner or operator shall

submit to the Agency, USEPA Region 5, and the Administrator of the USEPA written

notice of the dates of certification testing, in accordance with Section 225 .270

of this Subpart .

B)

Certification

The owner or operator shall submit

to the Agency a certification application for each monitoring system . A

complete certification application shall include the information specified in 40

CFR 75 .63 .

C)

Provisional eertifieatien

davaCe rtification Date . The provisional

certification date for a monitoring system shall be determined in accordance

with 40 CFR 75 .20 (a)(3) .

A provisionally certified monitoring system may be

used under this Subpart for a period not to exceed 120 days after receipt by the

Agency of the complete certification application for the monitoring system under

subsection (a) (3) (B) of this Section

. Data measured and recorded by the

provisionally certified monitoring system, in accordance with the requirements

of 40 CFR

Pat 75, will be considered valid quality-assured data (retroactive to

the date and time of provisional certification), provided that the Agency does

not invalidate the provisional certification by issuing a notice of disapproval

within 120 days efgftar

the date of receipt by the Agency of the complete

certification application .

D)

Certification appli

aten appreval preeess afin Aooroval Process .

The Agency will issue a written notice of approval or disapproval of the

certification application to the owner or operator within 120 days

Waftgr

receipt of the complete certification application required by subsection

(a) (3) (B) of this Section

. In the event the Agency does not issue such a notice

within sushthe

120-day period, each monitoring system that meets the applicable

performance requirements of 40 CFR Part-75 and is included in the certification

application will be deemed certified for use under this Subpart .

i)

Approval

If the certification application is complete and

shows that each monitoring system meets the applicable performance requirements

of 40 CFR Part-75, then the Agency will issue a written notice of approval of

the certification application within 120 days

ofAILgI receipt .

ii) Incomplete

1-T

eeAoolicationNo e . If the certification

application is not complete, then the Agency will issue a written notice of

incompleteness that sets a reasonable date by which the owner or operator must

submit the additional information required to complete the certification

application

. If the owner or operator does not comply with the notice of

incompleteness by the specified date, then the Agency may issue a notice of

disapproval under subsection (a) (3) (D) (iii) of this Section . The 120-day review

period shall not begin before receipt of a complete certification application .

---

I

iii)

Disapproval neoleen2till . If the certification application

shows

that any monitoring system does not meet the performance requirements of 40 CFR-

P,*O

75 or if the certification application is incomplete and the requirement

for disapproval under subsection (a) (3) (D)(ii) of this Section is met, then the

Agency will issue a written notice of disapproval of the certification

application . Upon issuance of such notice of disapproval, the provisional

certification is invalidated by the Agency and the data measured and recorded by

each uncertified monitoring system shall not be considered valid quality-assured

data beginning with the date and hour of provisional certification (as defined

under 40 CFR 75 .20(a)(3)) . The owner or operator shall follow the procedures

for loss of certification in subsection (a) (3) (E) of this Section for each

monitoring system that is disapproved for initial certification .

iv) Audit The

Agency may issue a notice of

disapproval of the certification status of a monitor in accordance with Section

225 .260(b) of this Subpart .

E)

b)

1)

If an emissions monitoring system has been previously certified in

accordance with 40 CFR Part-75 and the applicable quality assurance and quality

control requirements of 40 CFR 75 .21 and Appendix B to 40 CFR P*TN-7S are fully

met, the monitoring system shall be exempt from the initial certification

requirements of this Section .

Procedures for len*Lgaa of e-e*t?W-eaV?eRjqrtjfjqajjwn .

If the Agency

issues a notice of disapproval of a certification application under subsection

(a)

(3) (D) (iii) of this Section or a notice of disapproval of certification

tus under subsection (a) (3) (D)(iv) of this Section, then :

The owner or operator shall substitute the following values, for each

disapproved monitoring system, for each hour of EGU operation during the period

of invalid data specified under 40 CFR 75 .20 (a) (4) (iii) or 75 .21(e) and

continuing until the applicable date and hour specified under 40 CFR

75 .20(a)(5)(i) . For a disapproved mercury pollutant concentration monitor and

disapproved flow monitor, respectively, the maximum potential concentration of

mercury and the maximum potential flow rate, as defined in Sections 2 .1 .7 .1 and

sapproved moisture monitoring

ng system, respectively, the minim

he maximum potential C02 concentra

applicable), as defined in

.5, 2

.1 .3

.1, and 2

.1

.3 .2 of Appendix A to 40 CFR Part-

excepted monitoring system (sorbent trap monitoring

d disapproved flow monitor, respectively, the maximum potential

rion of mercury and maximum potential flow rate, as defined in Sections

of Appendix A to 40 CFR Part-75 .

2 .1 .4 .1 of Appendix A to 40 CPR Pant-75 .

system and disapproved diluent gas mor

potential moisture percentage and eithe

or the minimum potential 02 concentratioi

Sections 2 .

disapproved

a

0

m

0

iii)

The owner or operator shall repeat all certification tests or other

led by the monitoring system, as indicated in the

oval, no later than 30 unit operating days after the

tice of disapproval .

---

2) The

recertification provisions of this Section shall apply to an emissions

monitoring system required by Section 225 .240 (a) (1) of this Subpart exempt from

initial certification requirements under subsection (a) (1) of this Section .

c)

Initial certification and recertification procedures for EGUs using the

mercury low mass emissions excepted methodology under 40 CFR 75 .81(b) . The

owner or operator of an EGU qualified to use the mercury low mass emissions

excepted methodology under 40 CFR 75

.81(b) shall meet the applicable

certification and recertification requirements in 40 CFR 75

.81(c) through (f) .

d)

Certification Applications

. The owner or operator of an EGU shall submit

an application to the Agency within 45 days after completing all initial

certification or recertification tests required under this Section, includi

the information required under 40 CFR 75

.63 .

Section 225 .260

Out of Control Periods for Emission Monitors

a)

Whenever any emissions monitoring system fails to meet the quality-

assurance and quality-control requirements or data validation requirements of 40

CFR Part-75, data shall be substituted using the applicable missing data

procedures in Subparts D and I of 40 CFR Part-75 .

ssions monitoring s

recertification application

not have been certified or recertified

performance specification or other requ

Subpart or the applicable provisions of

initial certification or rece

cy wi

oring

ld

the notic

status of t

onitoring system shall not be considered

the date of issuance of the notification

Section 225 .26

Whenever both an audit of an

em and a review of the initial certification or

reveal that any emissions monitoring system should

because it did not meet a particular

irement under Section 225 .250 of this

40 CFR-PanN 75, both at the time of the

tion application submission and at the time

notice of disapproval of the certification

the purposes of this subsection, an audit

ir an audit of any information submitted to the

of disapproval, the Agency revokes prospectively

emissions monitoring system

. The data measured

valid quality-

of the revoked

g

certification status until the date and time that the owner or operator

completes subsequently approved initial certification or recertification tests

for the monitoring system

. The owner or operator shall follow the applicable

initial certification or recertificatio

Subpart for each disapproved monitoring

procedures in Section 225 .250 of this

system .

Additional Requirements to Provide Heat Input Data

The owner or operator of an EGU that monitors and reports mercury mass emissions

using a mercury concentration monitoring system and a flow monitoring system

shall also monitor and report heat input rate at the EGU level using the

procedures set forth in 40 CFR Pant-75 .

Section 225 .263

Monitoring of Gross Electrical Output

The owner or operator of an EGU complying with this Subpart by means of Section

225 .230 (a) (1) or using electrical output (0i) and complying by means of Section

225 .230(b) or (d) or Section 225

.232 of this Subpart shall monitor gross

electrical output of the associated generator(s) in MWh on an hourly basis .

Section 225

.265

Coal Analysis for Input Mercury Levels

---

a)

The owner or operator

of an EGU complying with this Subpart by means

of Section 225 .230 (a) (2) or using input mercury levels (Ii) and complying by

means of Section 225 .230(b) or (d) or Section 225 .232 of this Subpart shall

:

1)

Perform daily sampling of the coal combusted in the EGU for mercury

content

. The owner or operator of such EGU shall collect a minimum of one 2-lb

grab sample per day of operation from the belt feeders anywhere between the

crusher house or breaker building and the boiler . £S The sample shall be taken

in such a manner so as to provide a representative mercury content for the coal

burned on that day .

2)

Analyze the grab coal sample for the following :

A)

Determine the heat content using ASTM D5865-04 or equivalent approved in

writing by the Agency .

B)

Determine the moisture content using ASTM D3173-03 or equivalent approved

in writing by the Agency .

C)

Measure the mercury content using ASTM D6414-01, ASTM D3684-01, or

equivalent approved in writing by the Agency .

3)

The owner or operator of multiple EGUs at the same source using the same

crusher house or breaker building may take one sample per crusher house or

breaker building, rather than one per EGU .

4)

The owner or operator of an EGU shall use the data analyzed under

subsection (b) of this Section to determine the mercury content in terms of

lbs/trillion Bt

e

b)

The owner or operator of an EGU that must conduct sampling and analysis of

coal pursuant to subsection (a) of this Section ; shall begin such activity by

the following date :

1)

If the EGU is in daily service, at least 30 days before the start of the

month for which such activity will be required .

ner

notice to the

up of EGUs m

CFR 75 .82(b)(2)

Section 225 .290

a) General

A not in daily service, on the day that the EGU resumes

or of a source with one or more EGUs shall submit written

cy according to the provisions in 40 CFR 75 .61 for each EGU or

tored at a common stack and each non-EGU monitored under 40

Recordkeeping and Reporting

I

1)

The owner or operator of an EGU and its designated representative shall

comply with all applicable recordkeeping and reporting requirements in this

Section and with all applicable recordkeeping and reporting requirements of 40

CFR 75 .84 .

---

2)

The owner or operator of an EGU shall maintain records for each month

identifying the emission standard in Section 225 .230(a) or 225 .237(a) of this

Section with which it is complying or wh?ehbjL is applicable for the EGU and

the following records related to the emissions of mercury that the EGU is

allowed to emit :

A)

For an EGU for which the owner or operator is complying with this Subpart

by means of Section 225 .230(a)(2) or 225 .237 (a) (1) (B) or using input mercury

levels to determine the allowable emissions of the EGU, records of the daily

mercury content of coal used (lbs/trillion Btu) and the daily and monthly input

mercury (lbs), which shall be kept in the file required under 40 CFR 75 .84(a) .

B)

For an EGU for which the owner or operator of an EGU complying with this

Subpart by means of Section 225 .230 (a) (1) or 225 .237 (a) (1) (A) or using

electrical output to determine the allowable emissions of the EGU, records of

the daily and monthly gross electrical output (GWh), which shall be kept in the

file required under 40 CFR 75

.84(a) .

3)

The owner or operator of an EGU shall maintain records of the following

for each EGU :

A)

Monthly emissions of mercury from the EGU .

B)

For an EGU for which the owner or operator is complying by means of

Section 225 .230(b) or (d) of this Subpart, records of the monthly allowable

emissions of mercury from the EGU .

4)

The owner or operator of an EGU that is participating in an Averaging

Demonstration pursuant to Section 225 .232 of this Subpart shall maintain records

identifying all sources and EGUs covered by the Demonstration for each month

and, within 60 days efaltyL the end of each calendar month, calculate and record

the actual and allowable mercury emissions of the EGU for the month and the

applicable 12-month rolling period .

5) The owner or operator of an EGU shall maintain the following records

related to quality assurance activities conducted for emissions monitoring

systems :

A)

The results of quarterly assessments conducted under Section 2 .2 of

Appendix B of 40 CFR-Parb 75 ; and

B)

Daily/weekly system integrity checks under Section 2 .6 of Appendix B of 40

CFR-Pa*O 75 .

6)

The owner or operator of an EGU shall maintain an electronic copy of all

electronic submittals to the USEPA under 40 CFR 75 .84(f) .

7)

The owner or operator of an EGU shall retain all records required by this

Section at the source unless otherwise provided in the CAAPP permit issued for

the source and shall make a copy of any record available to the Agency upon

request .

b)

Quarterly epe s .

The owner or operator of a source with one or

more EGUs shall submit quarterly reports to the Agency as follows :

I

1)

These reports shall include the following information for operation of the

EGUs during the quarter :

---

A)

The total operating hours of each

EGU and the mercury CEMS, as also

reported in accordance with 40 CM-Pao, 75 .

B) A discussion of any significant changes in the measures used to control

emissions of mercury from the EGUs or the coal supply to the EGUs, including

changes in the source of coal .

C)

Summary information on the performance of the mercury CEMS

. When the

mercury CEMS was not inoperative, repaired, or adjusted, except for routine zero

and span checks, this shall be stated in the report .

EO

If the CEMS downtime was more than 5

.0 percent of the total operating time

for the EGU

: the date and time identifying each period during which the CEMS was

inoperative, except for routine zero and span checks ; the nature of CEMS repairs

or adjustments and a summary of quality assurance data consistent with 40 CFR-

P**O 75, i .e ., the dates and results of the Linearity Test(s) and any Relative

Accuracy Test Audit(s) during the quarter

; a listing of any days when a required

daily calibration was not performed ; and the date and duration of any periods

when the CEMS was out-of-control as addressed by Section 225 .260 of this

Subpart .

2)

The owner or operator shall submit each quarterly report to the Agency

within 45 days following the end of the calendar quarter covered by the report .

c)

Compliance eerQKeaK-onQq1tj1!watjgn . The owner or operator of a source

with one or more EGUs shall submit to the Agency a compliance certification in

support of each quarterly report based on reasonable inquiry of those persons

with primary responsibility for ensuring that all of the EGUs' emissions are

correctly and fully monitored . The certification shall state-that :

1)-m~

That the monitoring data submitted were recorded in accordance with the

applicable requirements of this Section, Sections 225 .240 through 22 S .2?0, and

Seetien 225 .299 of this--& bpa*4,225.21! and 40 CFR Part 75, including the

quality assurance procedures and specifications ; and

2)

For an EGU with add-on mercury emission controls, a flue gas

desulfurization system, a selective catalytic reduction system, or a compact

hybrid particulate collector system and for all hours where mercury data are

substituted in accordance with 40 CFR 75 .34(a)(1) :

IA)

--_-That

i)

The mercury add-on emission controls, flue gas desulfurization system,

selective catalytic reduction system, or compact hybrid particulate collector

system werejag operating within the range of parameters listed in the quality

assurance/quality control program under Appendix B to 40 CFR Par-t-75

; or

ii)

With regard to a flue gas desulfurization system or a selective catalytic

reduction system, quality-assured S02 emission data recorded in accordance with

40 CFR

Part--75

document that the flue gas desulfurization system was operating

properly, or quality-assured NOX emission data recorded in accordance with 40

CFR Part 75 document that the selective catalytic reduction system ; was

operating properly, as applicable ; and

B)

The substitute data values do not systematically underestimate mercury

emissions .

---

d)

Annual Certification of Compliance

1)

Subpart

Theshallownersubmitor

operatorto

the

ofAgency

a sourcean

Annual

with oneCertification

or more EGUsof

Compliance

subject to

withthis

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

.

B)

If complying with this Subpart by means of Section 225 .230 (a) (1) (B) or

225 .237(a)(1)(B)

:

i)

Actual control efficiency for emissions for each 12-month rolling period

ending in the year covered by the Certification, expressed as a percent

;

ii)

Actual emissions, in lbs, and mercury content in the fuel fired in such

EGU, in lbs, for each 12-month rolling period ending in the year covered by the

Certification ; and

al emissions, in lbs, and mercury content in the fuel fired in such

or each month in the year covered by the Certification and in the

ious year .

If complying with this Subpart by means of Section 225

.230(b) :

i)

Actual emissions and allowable emissions for each 12-month rolling period

ending in the year covered by the Certification ; and

ii) Actual emissions and allowable emissions, and which standard of compliance

the owner or operator was utilizing for each month in the year covered by the

Certification and in the previous year

.

D)

If complying with this Subpart by means of Section 225

.230(d) :

i)

Actual emissions and allowable emissions for all EGUs at the source for

each 12-month rolling period ending in the year covered by the Certification

;

and

---

ii)the

ownerActualor

emissionsoperator

wasand utilizingallowable foremissions,each

month

and

in

whichthe

year

standardcovered

of complianceby

the

Certification and in the previous year .

E)

If complying with this Subpart by means of Section 225

.232 :

i)

Actual emissions and allowable emissions for all EGUs at the source in an

Averaging Demonstration for each 12-month rolling period ending in the year

covered by the Certification

; and

ii)

Actual emissions and allowable emissions, with the standard of compliance

the owner or operator was utilizing for each EGU at the source in an Averaging

Demonstration for each month for all EGUs at the source in an Averaging

Demonstration in the year covered by the Certification and in the previous year

.

F) Any deviations, data substitutions, or exceptions each month and

discussion of the reasons for such deviations, data substitutions, or

exceptions .

3)

All Annual Certifications of Compliance required to be submitted shall

include the following certification by a responsible official

:

I certify under penalty of law that this document and all attachments w

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

.

operator is not required

Section 2 95

4) The owner or operato

Certification of Compliance to

in which the EGU commences comme

Notwithstanding subsection (d)

(2)

of Compliance that are required to be

00k~- Za ll to address calendar years

prow :

Deviat

promptly notify the Agency of deviations

a minimum, these notifications shall i

within 30 days

n1allar discovery o

possible cause of such deviation

measures cake

-Fewg

. For each EGU, the o

Treatment of Mercury Allowances

mit its first

calendar year 2009 or the calendar year

operation, whichever is

is Section, in the Annual Certifications

bmitted by may 1,

2545.2jif and May 1,

2010, respectively, the owner or

rolling data for any period that

er o

equirements o

description of

ations, and a discu

corrective actions, and an

. At

ons

e

a

gAnna RATA The

owner or operator of

Compliance and Enforcement Section, the

or group of EGUs monitored at a

Agency,

t for eac

non-EGU under 40 CFR 75

.82(b)(2)(ii) within 45 days after

quality assurance RATA

.

---

Any mercury allowances allocated to the Agency by the USEPA shall be treated as

follows :

a)

No such allowances shall be allocated to any owner or operator of an EGU

or other sources of mercury emissions into the atmosphere or discharges into the

waters of the State .

b) The Agency shall hold all allowances allocated by the USEPA to the State

.

At the end of each calendar year, the Agency shall instruct the USEPA to retire

permanently all such allowances .

POLLUTION CONTROL BOARD

NOTICE OF PROPOSED PULE

---

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9 :29 :07 AM

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file ://I :/Input/35-225-Agency(issuel3) .doc

Document 2

file ://I :/Input/35-225-rOl (issue 13) .doc

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JCAR350225-0605957r01

1

TITLE 35 : ENVIRONMENTAL PROTECTION

2

SUBTITLE B : AIR POLLUTION

3

CHAPTER I : POLLUTION CONTROL BOARD

4

SUBCHAPTER c : EMISSION STANDARDS AND LIMITATIONS

5

FOR STATIONARY SOURCES

6

7

PART 225

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

---

Environmental Protection Act [415 ILCS 5]

British thermal unit

Clean Air Act [42 USC 7401 et seq.]

Clean Air Act Permit Program

carbon dioxide

electric generating unit

gigawatt hour

hour

pound

megawatt

megawatt electrical

megawatt hour

nitrogen oxides

oxygen

JCAR350225-0605957r01

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

59 Act

60 Btu

61 CAA

62 CAAPP

63 CO2

64 EGU

65

GWh

66

hr

67 lb

68 MW

69 MWe

70 MWh

71 NO,

72

02

73

RATA

e ' e accuracy test audit

74 SO2

sulfur dioxide

75 USEPA

United States Environmental Protection Agency

76

77 Section 225.130 Definitions

78

79

The definitions contained in this Section apply only to the provisions of this Part . Unless

80 otherwise defined in this Section and unless a different meaning of a term is clear from its

81

context, the definitions of terms used in this Part shall have the meanings specified for those

82

e

in 35 Ill . Adm . Code 211 .

83

84

"Averaging demonstration" means, with regard to Subpart B of this Part, a

85

demonstration of compliance that is based on the combined performance of EGUs

86

at two or more sources.

---

JCAR350225-0605957r01

"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- oiler 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 .

---

130

131

132

133

134

135

136

137

138

139

140

141

142

143

144

145

146

147

148

149

150

151

152

153

154

155

156

157

158

159

160

161

162

163

164

165

166

167

168

169

170

171

172

JCAR350225-0605957r01

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),

---

JCAR350225-0605957r01

173

such increased maximum amount as specified by the person conducting the

174

physical change .

175

176

"Output-based emission standard" means, with regard to Subpart B of this Part, a

177

maximum allowable rate of emissions of mercury per unit of gross electrical

178

output from an Electric Generating Unit .

179

180

"Repowered" means, with regard to an EGU, replacement of a coal-fired boiler

181

with one of the following coal-fired technologies at the same source as the coal-

182

fired boiler:

183

184

Atmospheric or pressurized fluidized bed combustion ;

185

186

Integrated gasification combined cycle ;

187

188

Magnetohydrodynamics ;

189

190

Direct and indirect coal-fired turbines ;

191

192

Integrated gasification fuel cells ; or

193

194

As determined by the US EPA in consultation with the United States Department

195

of Energy, a derivative of one or more of the technologies under this definition

196

and any other coal-fired technology capable of controlling multiple combustion

197

emissions simultaneously with improved boiler or generation efficiency and with

198

significantly greater waste reduction relative to the performance of technology in

199

widespread commercial use as of January 1, 2005 .

200

201

"Rolling 12-month basis" means, with regard to Subpart B of this Part, a

202

determination made on a monthly basis from the relevant data for a particular

203

calendar month and the preceding 11 calendar months (total of 12 months of

204

data), with two exceptions . For determinations involving one EGU, calendar

205

months in which the EGU does not operate (zero EGU operating hours) shall not

206

be included in the determination, and shall be replaced by a preceding month or

207

months in which the EGU does operate, so that the determination is still based on

208

12 months of data . For determinations involving two or more EGUs, calendar

209

months in which none of the EGUs covered by the determination operates (zero

210

EGU operating hours) shall not be included in the deteiiiiination, and shall be

211

replaced by preceding months in which at least one of the EGU covered by the

212

determination does operate, so that the determination is still based on 12 months

213

of data .

214

215 Section 225.140 Incorporations by Reference

---

JCAR350225-0605957r01

216

217

The following materials are incorporated by reference

. These incorporations do not include any

218

later amendments or editions .

219

220

a)

40 CFR 60, § 60.17,

§ 60.45a, § 60.49a(k)(1), § 60.49a(p), § 60.50a(h), and §§

221

60.4170

through 60 .4176 (2005) .

222

223

b)

40 CFR 75 (2005) .

224

225

c)

ASTM . American Society for Testing and Materials, 100 Barr Harbor Drive, P

.O.

226

Box C700, West Conshohocken PA 19428-2959, (610) 832-9585 :

227

228

1)

ASTM D388-77, 90,

91, 95, 98a, or 99, Classification of Coals by Rank

229

(Reapproved 2004) .

230

231

ASTM D3173-03, Standard Test Method for Moisture in the Analysis

232

Sample of Coal and Coke (Approved April 10, 2003) .

233

234

3)

ASTM D3684-01, Standard Test Method for Total Mercury in Coal by the

235

Oxygen Bomb Combustion/Atomic Absorption Method (Approved

236

October 10, 2001) .

237

238

ASTM D5865-04, Standard Test Method for Gross Calorific Value of

239

Coal and Coke (Approved April 1, 2004) .

240

241

5)

ASTM D6414-01, Standard Test Method for Total Mercury in Coal and

242

Coal Combustion Residues by Acid Extraction or Wet Oxidation/Cold

243

Vapor Atomic Absorption (Approved October 10, 2001) .

244

245

6)

ASTM D6784-02, Standard Test Method for Elemental, Oxidized,

246

Particle-Bound and Total Mercury in Flue Gas Generated from Coal-Fired

247

Stationary Sources (Ontario Hydro Method) (Approved April 10, 2002) .

248

249

SUBPART B : CONTROL OF MERCURY EMISSIONS

250

FROM COAL-FIRED ELECTRIC GENERATING UNITS

251

252 Section 225

.200 Purpose

253

254 The purpose of this Subpart is to control the emissions of mercury from coal-fired electrical

255

generating units in Illinois .

256

257 Section 225 .202 Measurement Methods

258

---

JCAR350225-0605957r0I

259 Measurement of mercury shall be according to the following :

260

261

a)

Conti uous emission monitoring pursuant to 40 CFR 75 (2005) .

262

263

b)

ASTM D3173-03, Standard Test Method for Moisture in the Analysis Sample of

264

Coal and Coke (Approved April 10, 2003) .

265

266

c)

ASTM D3684-01, Standard Test Method for Total Mercury in Coal by the

267

Oxygen Bomb Combustion/Atomic Absorption Method (Approved October 10,

268

2001) .

269

270

d)

ASTM D5865-04, Standard Test Method for Gross Calorific Value of Coal and

271

Coke (Approved April 1, 2004) .

272

273

e)

ASTM D6414-01, Standard Test Method for Total Mercury in Coal and Coal

274

Combustion Residues by Acid Extraction or Wet Oxidation/Cold Vapor Atomic

275

Absorption (Approved October 10, 2001) .

276

277

f)

ASTM D6784-02, Standard Test Method for Elemental, Oxidized, Particle-Bound

278

and Total Mercury in Flue Gas Generated from Coal-Fired Stationary Sources

279

(Ontario Hydro Method) (Approved April 10, 2002).

280

281

Section 225.205 Applicability

282

283 The following stationary coal-fired boilers and stationary coal-fired combustion turbines are

284 EGUs and are subject to this Subpart :

285

286

287

288

289

290

b)

For a unit that qualifies as a cogeneration unit during the 12-month period starting

291

on the date the unit first produces electricity and continues to qualify as a

292

cogeneration unit, a cogeneration unit serving at any time a generator with

293

nameplate capacity of more than 25 MWe and supplying in any calendar year

294

more than one-third of the unit's potential electric output capacity or 219,000

295

MWh, whichever is greater, to any utility power distribution system for sale . If a

296

unit qualifies as a cogeneration unit during the 12-month period starting on the

297

date the unit first produces electricity but subsequently no longer qualifies as a

298

cogeneration unit, the unit shall be subject to subsection (a) of this Section

299

starting on the day on which the unit first no longer qualifies as a cogeneration

300

unit.

301

a)

Except as provided in subsection (b) of this Section, a unit serving, at any time

since the start-up of the unit's combustion chamber, a generator with nameplate

capacity of more than 25 MWe producing electricity for sale .

---

JCAR350225-0605957r01

302

Section 225.210 Compliance Requirements

303

304

a)

Permit Requirements

305

The owner or operator of each source with one or more EGUs subject to this

306

Subpart at the source must apply for a CAAPP permit that addresses the

307

applicable requirements of this Subpart .

308

309

b)

Monitoring Requirements

310

311

1)

The owner or operator of each source and each EGU at the source must

312

comply with the monitoring requirements of Sections 225 .240 through

313

225.290 of this Subpart .

314

315

2)

The compliance of each EGU with the mercury requirements under

316

Sections 225 .230 and 225 .237 of this Subpart shall be determined by the

317

emissions measurements recorded and reported in accordance with

318

Sections 225 .240 through 225 .290 of this Subpart .

319

320

c)

Mercury Emission Reduction Requirements

321

The owner or operator of any EGU subject to this Subpart shall comply with

322

applicable requirements for control of mercury emissions under Section 225 .230

323

or Section 225 .237 of this Subpart .

324

325

Recordkeeping and Reporting Requirements

326

Unless otherwise provided, the owner or operator of a source with one or more

327

EGUs at the source shall keep on site at the source each of the documents listed in

328

subsections (d)(1) through

(d)(3) of this Section for a period of five years from the

329

date the document is created

. This period may be extended for cause, at any time

330

prior to the end of five years, in writing by the Agency

.

331

332

1)

All emissions monitoring information, in accordance with Sections

333

225 .240 through 225 .290 of this Subpart .

334

335

2)

Copies of all reports, compliance certifications, and other submissions and

336

all records made or required or documents necessary to demonstrate

337

compliance with the requirements of this Subpart

.

338

339

3)

Copies of all documents used to complete a permit application and any

340

other submission under this Subpart .

341

342

e)

Liability

343

---

JCAR350225-0605957r01

1)

The owner or operator of each source with one or more EGUs shall meet

the requirements of this Subpart .

2)

Any provision of this Subpart that applies to a source shall also apply to

the owner and operator of such source and to the owner and operator of

each EGU at the source .

3)

Any provision of this Subpart that applies to an EGU shall also apply to

the owner and operator of such EGU.

Effect on Other Authorities . No provision of this Subpart shall be construed as

exempting or excluding the owner and operator of a source or EGU from

compliance with any other provision of an approved State Implementation Plan, a

permit, the Act, or the CAA

.

344

345

346

347

348

349

350

351

352

353

354

f)

355

356

357

358

359 Section 225.220

360

361

a)

362

363

364

365

366

367

368

369

370

371

372

373

374

375

376

377

378

379

380

381

382

b)

Contents of Permit Applications

383

In addition to other information required for a complete application for CAAPP

384

permit or CAAPP

permit

modification, the application shall include the following

385

information :

386

Clean Air Act Permit Program

Application Requirements

1)

Each source with one or more EGUs subject to the requirements of this

Subpart is required to submit a CAAPP permit application that addresses

all applicable requirements of this Subpart, applicable to each EGU at the

source .

2)

For any EGU that commenced commercial operation :

A)

on or before December 31, 2008, the owner or operator of that

EGU must submit an initial permit application or application for

CAAPP permit modification that meets the requirements of this

Section by December 31, 2008 .

B) after December 31, 2008, the owner or operator of any such EGU

must submit an initial CAAPP permit application or application for

CAAPP modification that meets the requirements of this Section

not later than 180 days before initial startup of the EGU, unless the

construction permit issued for the EGU addresses the requirements

of this Subpart.

(CAAPP) Permit Requirements

---

JCAR350225-0605957r01

387

1)

The ORIS (Office of Regulatory Information Systems) or facility code

388

assigned to the source by the Energy Infoiniation Administration, if

389

applicable.

390

391

2)

Identification of each EGU at the source

.

392

393

3)

The intended approach to the monitoring requirements of Sections

394

225 .240 through 225 .290 of this Subpart .

395

396

4)

The intended approach to the mercury emission reduction requirements of

397

Section 225 .230 or 225 .237 of this Subpart, as applicable

.

398

399

c)

Permit Contents

400

401

1)

Each CAAPP permit issued by the Agency for a source with one or more

402

EGUs subject to the requirements of this Subpart shall contain federally

403

enforceable conditions addressing all applicable requirements of this

404

Subpart, which conditions shall be a complete and segregable portion of

405

the source's entire CAAPP peinnit .

406

407

2)

In addition to conditions related to the applicable requirements of this

408

Subpart, each such CAAPP permit shall also contain the information

409

specified under subsection (b) of this Section .

410

411 Section 225 .230 Emission Standards for EGUs at Existing Sources

412

413

a)

Emission Standards

414

415

1)

Beginning July 1, 2009, the owner or operator of a source with one

416

or more EGUs subject to this Subpart that commenced commercial

417

operation on or before December 31, 2008 shall comply with one of the

418

following standards for each EGU on a rolling 12-month basis :

419

420

A)

An emission standard of 0 .0080 lb mercury/GWh gross electrical

421

output; or

422

423

B)

A minimum 90-percent reduction of input mercury .

424

425

2)

For an EGU complying with subsection (a)(1)(A)

of this Section, the

426

actual mercury emission rate of the EGU for each 12-month rolling period,

427

as monitored in accordance with this Subpart and calculated as follows,

428

shall not exceed the applicable emission standard :

429

---

430

431

432

433

434

435

436

437

438

439

440

441

442

443

444

445

446

447

448

449

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 detennined in

accordance with the emissions monitoring provisions of this

Subpart.

O; =

Gross electrical output of the EGU, in GWh, in an individual

month in the 12-month rolling period, as determined in

accordance with Section 225 .263 of this Subpart

.

3)

For an EGU complying with subsection

(a)(1)(B) of this Section, the

actual control efficiency for mercury emissions achieved by the EGU for

each 12-month rolling period, as monitored in accordance with this

Subpart and calculated as follows, shall meet or exceed the applicable

efficiency requirement :

1

1'

450

CE =

100x

{1-

)}

451

452

453

454

455

456

457

458

459

460

461

462

463

464 b) Alternative Emission Standards for Single EGUs

465

466

467

468

469

470

Where:

CE

E,

I

ER

JCAR350225-0605957r01

Actual control efficiency for mercury emissions of the EGU for

the particular 12-month rolling period, expressed as a percent

.

Actual mercury emissions of the EGU, in lbs, in an individual

month in the 12-month rolling period, as deteiinined in

accordance with the emissions monitoring provisions of this

Subpart.

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

.

1)

As an alternative to compliance with one of the above emission standards

in subsection (a) of this Section, the owner or operator of the EGU may

comply with the emission standards of this Subpart by demonstrating that

the actual emissions of mercury from the EGU are less than the allowable

emissions of mercury from the EGU on a rolling 12-month basis .

---

477

478

479

480

481

482

483

484

485

486

487

488

489

490

491

492

493

494

495

496

497

498

499

500501

502

3)

503

504

505

506

507

Where:

E12

A12

IQ

It

Abvw

I

Aonw

j

E12

412

12

E12

E E,

i=1

JCAR350225-0605957r01

471

472

2)

For this purpose, for each rolling 12-month period, the actual emissions of

473

mercury from the EGU, as monitored in accordance with this Subpart,

474

must not exceed the allowable emissions of mercury from the EGU, as

475

further provided by the following formulas :

476

Actual mercury emissions of the EGU for the particular 12-

month rolling period .

Allowable mercury emissions of the EGU for the particular

12-month rolling period

Actual mercury emissions of the EGU in an individual month

in the 12-month rolling period .

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 (Aj p,,, j) or the electrical output from

the EGU (Ao~ow ), as selected by the owner or operator of the

EGU for that given month .

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

.

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 .

If the owner or operator of an JEW does not conduct the necessary

sampling, analysis, and recordkeeping, in accordance with Section

225 .265 of this Subpart, to determine the mercury input to the EGU, the

allowable emissions of the EGU must be calculated based on the electrical

output of the EGU .

---

530

531

532

533

534

535

536

537

538

539

540

541

542

543

Where:

Es

As

E,

A,

n =

n

As =

A,

i=1

Sum of the actual mercury emiss ons of the EGUs at the source .

Sum of the allowable mercury emissions of the EGUs at the

source.

Actual mercury emissions of an individual EGU at the source, as

determined in accordance with subsection (b)(2) of this Section .

Allowable mercury emissions of an individual EGU at the

source, as determined in accordance with subsection (b)(2) of

this Section.

Number of EGUs covered by the demonstratio .

JCAR350225-0605957r01

508

c)

If two or more EGUs are served by common stack(s) and the owner or operator

509

conducts monitoring for mercury emissions in the common stack(s), as provided

510

for by 40 CFR 75, Subpart I, such that the mercury emissions of each EGU are

511

not determined separately, compliance of the EGUs with the applicable emission

512

standards of this Subpart shall be determined as if the EGUs were a single EGU .

513

514

d)

Alternative Emission Standards for Multiple EGUs

515

516

1)

As an alternative to compliance with the emission standards of subsection

517

(a) of this Section, the owner or operator of a source with an EGU may

518

comply with the emission standards of this Subpart by demonstrating that

519

the actual emissions of mercury from all EGUs at the source are less than

520

the allowable emissions of mercury from all EGUs at the source on a

521

rolling 12-month basis .

522

523

2)

For this purpose, for each rolling 12-month period, the actual emissions of

524

mercury from all the EGUs at the source, as monitored in accordance with

525

this Subpart, must not exceed the sum of the allowable emissions of

526

mercury from all the EGUs at the source, as further provided by the

527

following formulas

:

528

Es <_ As

529

n

Es =

E,

i=l

---

JCAR350225-0605957r01

544

3)

If an owner or operator of a source with two or more EGUs that is relying

545

on this subsection (d) to demonstrate compliance fails to meet the

546

requirements of this subsection (d) in a given 12-month rolling period, all

547

EGUs at such source covered by the compliance demonstration are

548

considered out of compliance with the applicable emission standards of

549

this Subpart for the entire last month of that period .

550

551

Section 225 .232 Averaging Demonstrations for Existing Sources

552

553

a)

Through December 31, 2013, as an alternative to compliance with the emission

554

standards of Section 225 .230(a) of this Subpart, the owner or operator of an EGU

555

may comply with the emission standards of this Subpart by means of an

556

Averaging Demonstration (Demonstration) that shows that the actual emissions of

557

mercury from the EGU and other EGUs at the source and other EGUs at other

558

sources covered by the Demonstration are less than the allowable emissions of

559

mercury from all EGUs covered by the Demonstration on a rolling 12-month

560

basis.

561

562

b)

The EGUs at each source covered by a Demonstration must also comply with one

563

of the following emission standards on a source-wide basis for the period covered

564

by the Demonstration :

565

566

1)

An emission standard of 0 .020 lb mercury/GWh gross electrical output

; or

567

568

2)

A minimum 75 percent reduction of input mercury .

569

570

c)

For the purpose of this Section, compliance shall be determined using the

571

equations in Section 225 .230(a)(2), (a)(3), or (d)(2) of this Subpart, as applicable,

572

addressing all EGUs at the sources covered by the Demonstration, rather than

573

only EGUs at one source .

574

575

d)

Limitations on Demonstrations

576

577

1)

The owners or operators of more than one existing source with EGUs can

578

only participate in Demonstrations that include other existing sources that

579

they own or operate .

580

581

2)

Single Existing Source Demonstrations

582

583

A)

The owner or operator of only a single existing source with EGUs

584

(i.e., City, Water, Light & Power, City of Springfield,

ID

585

167120AAO; Electric Energy, Inc

., ID 127855AAC ; Kincaid

586

Generating Station, ID 021814AAB; and Southern Illinois Power

---

JCAR350225-0605957r01

587

Cooperative/Marion Generating Station, ID 199856AAC) can only

588

participate in Demonstrations with other such owners or operators

589

of a single existing source of EGUs .

590

591

B)

Participation in Demonstrations under this Section by the owner or

592

operator of only a single existing source with EGUs must be

593

authorized through federally enforceable permit conditions for

594

each such source participating in the Demonstration .

595

596

A source may be included in only one Demonstration during each rolling 12-

597

month period.

598

599

f)

The owner or operator of EGUs using Demonstrations to show compliance with

600

this Subpart must complete the detenuiination of compliance for each 12-month

601

rolling period no later than 60 days following the end of the period .

602

603

g)

If averaging is used to demonstrate compliance with this Subpart, the effect of a

604

failure to demonstrate compliance shall be that the compliance status of each

605

source shall be determined under Section 225

.230 of this Subpart as if the sources

606

were not covered by a Demonstration .

607

608

For purposes of this Section, if the owner or operator of any source that

609

participates in a Demonstration with an owner or operator of a source that does

610

not maintain the required records, data, and reports for the EGUs at the source, or

611

does not submit copies of such records, data, or reports to the Agency upon

612

request, then the effect of this failure will be deemed to be a failure to

613

demonstrate compliance and the compliance status of each source shall be

614

determined under Section 225 .230 of this Subpart as if the sources were not

615

covered by a Demonstration .

616

617

Section 225.235 Units Scheduled for Permanent Shut Down

618

619

a)

The emission standards of Section 225 .230(a) of this Subpart are not applicable to

620

an EGU that will be permanently shut down as follows :

621

622

1)

The owner or operator of an EGU for which this Section is being relied

623

upon shall by no later than June 30, 2009

:

624

625

A)

Have notified the Illinois EPA that it is planning to permanently

626

shut down the EGU by the applicable date specified in subsection

627

(a)(3)

or (4) of this Section . This notification shall be

628

accompanied by a description of the actions that have already been

629

taken to allow the shut down of the EGU and a description of the

---

JCAR350225-0605957r01

630

future actions that must be accomplished to complete the shut

631

down of the EGU, with the anticipated schedule for those actions

632

and the anticipated date of permanent shut down of the unit

.

633

634

B)

Have applied for a construction permit or be actively pursuing a

635

federally enforceable agreement that requires the EGU to be

636

permanently shut down in accordance with this Section .

637

638

C)

Have applied for revisions to the operating permit(s) for the EGU

639

to include provisions that terminate the authorization to operate the

640

unit in accordance with this Section .

641

642

2)

The owner or operator of an EGU for which this Section is being relied

643

upon shall by no later than June 30, 2010 :

644

645

A)

Have obtained a construction permit or entered into a federally

646

enforceable agreement as addressed by subsection

(a)(1)(B) of this

647

Section; or

648

649

B)

Have obtained revised operating permit(s) in accordance with

650

subsection (a)(1)(C)

of this Section .

651

652

3)

The plan for peiiuanent shut down of the EGU must provide for the EGU

653

to be permanently shut down by no later than the applicable date specified

654

below

:

655

656

A)

If the owner or operator of the EGU is not constructing a new EGU

657

or other generating units to specifically replace the existing EGU,

658

by December 31, 2010 .

659

660

If the owner or operator of the EGU is constructing a new EGU or

661

other generating units to specifically replace the existing EGU, by

662

December 31, 2011 .

663

664

4)

The owner or operator of the EGU must permanently shut down the EGU

665

by the date specified in subsection (a)(3)

of this Section, unless the owner

666

or operator submits a demonstration to the Illinois EPA before such date

667

showing that circumstances beyond its reasonable control (such as

668

protracted delays in construction activity, unanticipated outage of another

669

EGU, or protracted shakedown of a replacement unit) have occurred that

670

interfere with the plan for permanent shut down of the EGU, in which case

671

the date for shut down of the EGU may be extended as follows :

672

---

JCAR350225-0605957r01

673

A)

If the owner or operator of the EGU is not constructing a new EGU

674

or other generating units to specifically replace the existing EGU,

675

for up to one year, i

.e., permanent shut down of the EGU to occur

676

by no later than December 31, 2011 .

677

678

B)

If the owner or operator of the EGU is constructing a new EGU or

679

other generating units to specifically replace the existing EGU, for

680

up to 18 months, i.e.,

permanent shutdown of the EGU to occur by

681

no later than June 30, 2013

; provided, however, that after

682

December 31, 2012, the existing EGU shall only operate as a back-

683

up unit to address periods when the new generating units are not in

684

service .

685

686

Notwithstanding Sections 225.230 and 225

.232 of this Subpart, any EGU that is

687

not required to comply with Section 225

.230 of this Subpart pursuant to this

688

Section shall not be included when determining whether any other EGUs at the

689

source or other sources are in compliance with Section 225.230

of this Subpart .

690

691

If an EGU, for which the owner or operator of the source has relied upon this

692

Section in lieu of complying with Section 225 .230(a) of this Subpart, is not

693

permanently shut down as required by this Section, the EGU shall be considered

694

to be a new EGU subject to the emission standards in Section 225

.237(a) of this

695

Subpart beginning in the month after the EGU was required to be permanently

696

shut down, in addition to any other penalties that may be imposed for failure to

697

permanently shut down the EGU in accordance with this Section

.

698

699

Section 225.237 Emission Standards for New

Sources with EGUs

700

701

a)

Standards

702

703

1)

The owner or operator of a source with one or more EGUs, but that

704

previously had not had any EGUs that commenced commercial operation

705

before January 1, 2009, shall comply with one of the following emission

706

standards for each EGU on a rolling 12-month basis :

707

708

A)

An emission standard of 0 .0080 lb mercury/GWh gross electrical

709

output; or

710

711

B)

A minimum 90 percent reduction of input mercury

.

712

713

2)

For this purpose, compliance may be demonstrated using the equations in

714

Section 225 .230(a)(2), (a)(3), or (b)(2) of this Subpart.

715

---

Install all monitoring systems required under this Section and Sections

225

.250 through 225 .290 of this Subpart for monitoring mercury mass

emissions (including all systems required to monitor mercury

concentration, stack gas moisture content, stack gas

flow rate, and CO2 or

O

oncentration, as applicable, in accordance with 40 CFR 75

.81 and

75 .82).

JCAR350225-0605957r01

716

b)

The initial 12-month rolling period for which compliance with the emission

717

standards of subsection (a)(1)

of this Section must be demonstrated for a new

718

EGU shall commence on the date that the initial performance test for the mercury

719

emission standard under 40 CFR 60

.45a also commences . The continuous

720

emission monitoring systems required by this Subpart for mercury emissions from

721

the EGU must be certified prior to this date

. Thereafter, compliance shall be

722

demonstrated on a rollingl2-month basis in terms of calendar months .

723

724 Section

225.240

General Monitoring and Reporting Requirements

725

726

The owner or operator of an EGU shall comply with the monitoring, recordkeeping, and

727

reporting requirements as provided in this Section, Sections 225.250

through 225 .290 of this

728

Subpart, and Subpart I of 40 CFR 75

. If the EGU utilizes a common stack with units that are not

729 EGUs and the owner or operator of the EGU does not conduct emissions monitoring in the duct

730 to the common stack from each EGU, the owner or operator of the EGU shall conduct emissions

731

oring in accordance with 40 CFR 75

.82(b)(2) and this Section, including monitoring in the

732

duct to the common stack from each unit that is not an EGU, unless the owner or operator of the

733

EGU counts the combined emissions measured at the common stack as the mass emissions of

734

mercury for the EGUs for recordkeeping and compliance purposes .

735

736

a)

Requirements for installation, certification, and data accounting

. The owner or

737

operator of each EGU shall:

738

739

1)

740

741

742

743

744

745

746

2)

Successfu ly complete all e

cation tests required under Section

747

225

.250 and meet all other requirements of this Section, Sections 225 .250

748

through 225 .290 of this Subpart, and Subpart I of 40 CFR 75 applicable to

749

. ring systems required under subsection (a)(1)

of this Section.

750

751

3)

752

753

754

4)

If the owner or operator elects to use the low mass emissions excepted

755

monitoring methodology for an EGU that emits no more than 464 ounces

756

(29 pounds) of mercury per year pursuant to 40 CFR 75 .81(b), also

757

perform emissions testing in accordance with 40 CFR 75 .81(c) to

758

demonstrate that the EGU is eligible to use this excepted emissions

Record, report, and quality-assure the data from the monitoring systems

required under subsection

(a)(1) of this Section .

---

JCAR350225-0605957r01

759

monitoring methodology, as well as comply with all other applicable

760

requirements of 40 CFR 75 .81(b) through (f), and submit a copy of any

761

information required to be submitted to the USEPA under these provisions

762

to the Illinois EPA. The initial emissions testing to demonstrate eligibility

763

of an EGU for the low mass emissions excepted methodology shall be

764

conducted by the following dates :

765

766

A)

If the EGU has commenced commercial operation before July 1,

767

2008, at least by January 1, 2009, or 45 days prior to relying on the

768

low mass emissions excepted methodology, whichever date is

769

later.

770

771

B)

If the EGU has commenced commercial operation on or after July

772

1, 2008, at least 45 days prior to the applicable date specified under

773

subsection (b)(2)

of this Section or 45 days prior to relying on the

774

low mass emissions excepted methodology, whichever date is

775

later

.

776

777

b)

Emissions Monitoring Deadlines. The owner or operator shall meet the emissions

778

monitoring system certification and other emissions monitoring requirements of

779

subsections (a)(1) and (a)(2)

of this Section on or before the following dates . The

780

owner or operator shall record, report, and quality-assure the data from the

781

emissions monitoring systems required under subsection

(a)(1) of this Section on

782

and after the following dates :

783

784

1)

For the owner or operator of an EGU that commences commercial

785

operation before July 1, 2008, by January 1, 2009 .

786

787

2)

For the owner or operator of an EGU that commences commercial

788

operation on or after July 1, 2008, by 90 unit operating days or 180

789

calendar days, whichever occurs first, after the date on which the EGU

790

commences commercial operation

.

791

792

3)

For the owner or operator of an EGU for which construction of a new

793

stack or flue or installation of add-on mercury emission controls, a flue

794

gas desulfurization system, a selective catalytic reduction system, a fabric

795

filter, or a compact hybrid particulate collector system is completed after

796

the applicable deadline under subsection (b)(1)

or (2) of this Section, by

797

90 unit operating days or 180 calendar days, whichever occurs first, after

798

the date on which emissions first exit to the atmosphere through the new

799

stack or flue, add-on mercury emissions controls, flue gas desulfurization

800

system, selective catalytic reduction system, fabric filter, or compact

801

hybrid particulate collector system .

---

802

803

c)

804

805

806

807

808

809

810

811

812

813

814

815

816

817

818

819

820

821

822

823

824

825

826

d)

Prohibitions

827

828

829

830

831

832

833

834

835

836

2)

837

838

839

840

841

842

3)

843

844

Reporting Data

1)

2)

1)

JCAR350225-0605957r0I

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

---

845

846

847

848

849

850

851

852

853

854

855

856

857

858

859

860

861

862

863

864

865

866

867

868

869

870

871

872

873

874

875 Section 225.250

876

Monitoring

877

878

879

880

881

882

883

884

885

886

a)

JCAR350225-0605957r01

mass emissions discharged into the atmosphere, except for periods of

recertification or periods when calibration, quality assurance testing, or

maintenance is performed in accordance with the applicable provisions of

this Section, Sections 225

.250 through 225 .290 of this Subpart, and

Subpart I of 40 CFR 75

.

4)

No owner or operator of an EGU shall retire or permanently discontinue

use of the continuous emission monitoring system or any component

thereof, or any other approved monitoring system under this Subpart,

except under any one of the following circumstances

:

A)

The owner or operator is monitoring emissions from the EGU with

another certified monitoring system that has been approved, in

accordance with the applicable provisions of this Section, Sections

225 .250 through 225 .290 of this Subpart, and Subpart I of 40 CFR

75, by the Agency for use at that EGU and that provides emission

data for the same pollutant or parameter as the retired or

discontinued monitoring system ; or

B)

The owner or operator or designated representative submits

notification of the date of certification testing of a replacement

monitoring system for the retired or discontinued monitoring

system in accordance with Section 225.250(a)(3)(A) of this

Subpart.

e)

Long-term Cold Storage

The owner or operator of an EGU that is in long-term cold storage is subject to

the applicable provisions of 40 CFR 75 for monitoring, recordkeeping, and

reporting for units in long-term cold storage .

Initial Certification and Recertification Procedures for Emissions

The owner or operator of an EGU shall comply with the following initial

certification and recertification procedures for a continuous emissions monitoring

system (i.e., a continuous emission monitoring system or an excepted monitoring

system (sorbent trap monitoring system) under 40 CFR 75 .15) required by Section

225 .240(a)(1) . The owner or operator of an EGU that qualifies for, and for which

the owner or operator elects to use, the low mass emissions excepted

methodology under 40 CFR 75 .81(b) shall comply with the procedures in

subsection (c) of this Section .

---

JCAR350225-0605957r01

887

1)

Requirements for Initial Certification

. The owner or operator of an EGU

888

shall ensure that, for each continuous emissions monitoring system

889

required by Section 225.240(a)(l)

of this Subpart (including the automated

890

data acquisition and handling system), the owner or operator successfully

891

completes all of the initial certification testing required under 40 CFR

892

75

.80(d) by the applicable deadline in Section 225

.240(b) of this Subpart.

893

In addition, whenever the owner or operator of an EGU installs a

894

monitoring system to meet the requirements of this Subpart in a location

895

where no such monitoring system was previously installed, the owner or

896

operator must successfully complete the initial certification requirements

897

of 40 CFR 75 .80(d).

898

899

2)

Requirements for Recertification

. Whenever the owner or operator of an

900

EGU makes a replacement, modification, or change in any certified

901

continuous emission monitoring system, or an excepted monitoring system

902

(sorbent trap monitoring system) under 40 CFR 75

.15, and required by

903

Section 225

.240(a)(1) of this Subpart, that may significantly affect the

904

ability of the system to accurately measure or record mercury mass

905

emissions or heat input rate or to meet the quality-assurance and quality-

906

control requirements of 40 CFR 75

.21 or Appendix B to 40 CFR 75, the

907

owner or operator of an EGU shall recertify the monitoring system in

908

accordance with 40 CFR 75

.20(b). Furthermore, whenever the owner or

909

operator of an EGU makes a replacement, modification, or change to the

910

flue gas handling system or the EGU's operation that may significantly

911

change the stack flow or concentration profile, the owner or operator shall

912

recertify each continuous emission monitoring system, and each excepted

913

monitoring system (sorbent trap monitoring system) under 40 CFR 75

.15,

914

whose accuracy is potentially affected by the change, all in accordance

915

with 40 CFR 75 .20(b)

. Examples of changes to a continuous emission

916

monitoring system that require recertification include replacement of the

917

analyzer, complete replacement of an existing continuous emission

918

monitoring system, or change in location or orientation of the sampling

919

probe or site.

920

921

3)

Approval Process for Initial Certification and Recertification . Subsections

922

(a)(3)(A)

through (D) of this Section apply to both initial certification and

923

recertification of a continuous monitoring system required by Section

924

225

.240(a)(1) of this Subpart . For recertifications, replace the words

925

"certification" and "initial certification" with the word "recertification",

926

replace the word "certified" with the word "recertified", and follow the

927

procedures in 40 CFR 75 .20(b)(5) in lieu of the procedures in subsection

928

(a)(3)(E) of this Section .

929

---

JCAR350225-0605957r01

930

A)

Notification of Certification

. The owner or operator shall submit

931

to the Agency, USEPA Region 5, and the Administrator of the

932

USEPA written notice of the dates of certification testing, in

933

accordance with Section 225.270

of this Subpart.

934

935

B)

Certification Application

. The owner or operator shall submit to

936

the Agency a certification application for each monitoring system .

937

A complete certification application shall include the information

938

specified in 40 CFR 75 .63.

939

940

C)

Provisional Certification Date

. The provisional certification date

941

for a monitoring system shall be deteniiined in accordance with 40

942

CFR 75 .20(a)(3)

. A provisionally certified monitoring system may

943

be used under this Subpart for a period not to exceed 120 days

944

after receipt by the Agency of the complete certification

945

application for the monitoring system under subsection (a)(3)(B)

of

946

this Section . Data measured and recorded by the provisionally

947

certified monitoring system, in accordance with the requirements

948

of 40 CFR 75, will be considered valid quality-assured data

949

(retroactive to the date and time of provisional certification),

950

provided that the Agency does not invalidate the provisional

951

certification by issuing a notice of disapproval within 120 days

952

after the date of receipt by the Agency of the complete certification

953

application .

954

955

D)

Certification Application Approval Process . The Agency will

956

issue a written notice of approval or disapproval of the certification

957

application to the owner or operator within 120 days after receipt

958

of the complete certification application required by subsection

959

(a)(3)(B)

of this Section . In the event the Agency does not issue

960

such a notice within the 120-day period, each monitoring system

961

that meets the applicable performance requirements of 40 CFR 75

962

and is included in the certification application will be deemed

963

certified for use under this Subpart .

964

965

Approval Notice

. If the certification application is

966

complete and shows that each monitoring system meets the

967

applicable perfoi niance requirements of 40 CFR 75, then

968

the Agency will issue a written notice of approval of the

969

certification application within 120 days after receipt .

970

971

Incomplete Application Notice . If the certification

972

application is not complete, then the Agency will issue a

---

JCAR350225-0605957r01

973

written notice of incompleteness that sets a reasonable date

974

by which the owner or operator must submit the additional

975

information required to complete the certification

976

application . If the owner or operator does not comply with

977

the notice of incompleteness by the specified date, then the

978

Agency may issue a notice of disapproval under subsection

979

(a)(3)(D)(iii)

of this Section . The 120-day review period

980

shall not begin before receipt of a complete certification

981

application .

982

983

iii)

Disapproval Notice . If the certification application shows

984

that any monitoring system does not meet the performance

985

requirements of 40 CFR 75 or if the certification

986

application is incomplete and the requirement for

987

disapproval under subsection (a)(3)(D)(ii) of this Section is

988

met, then the Agency will issue a written notice of

989

disapproval of the certification application . Upon issuance

990

of such notice of disapproval, the provisional certification

991

is invalidated by the Agency and the data measured and

992

recorded by each uncertified monitoring system shall not be

993

considered valid quality-assured data beginning with the

994

date and hour of provisional certification (as defined under

995

40 CFR 75

.20(a)(3)) .

The owner or operator shall follow

996

the procedures for loss of certification in subsection

997

(a)(3)(E) of this Section for each monitoring system that is

998

disapproved for initial certification .

999

1000

Audit Decertification . The Agency may issue a notice of

1001

disapproval of the certification status of a monitor in

1002

accordance with Section 225

.260(b) of this Subpart

.

1003

1004

E)

Procedures for Loss of Certification . If the Agency issues a notice

1005

of disapproval of a certification application under subsection

1006

(a)(3)(D)(iii) of this Section or a notice of disapproval of

1007

certification status under subsection (a)(3)(D)(iv) of this Section,

1008

then:

1009

1010

i)

The owner or operator shall substitute the following values,

1011

for each disapproved monitoring system, for each hour of

1012

EGU operation during the period of invalid data specified

1013

under 40 CFR 75 .20(a)(4)(iii) or 75

.21(e) and continuing

1014

until the applicable date and hour specified under 40 CFR

1015

75.20(a)(5)(i) . For a disapproved mercury pollutant

---

1016

1017

1018

1019

1020

1021

1022

1023

1024

1025

1026

1027

1028

1029

1030

1031

1032

1033

1034

1035

1036

1037

1038

1039

1040

1041

1042

1043

1044

b)

1045

1046

1047

1048

1049

1050

1051

1052

1053

1054

1055

1056

1057

c)

Initial certification and recertification procedures for EGUs using the mercury low

1058

mass emissions excepted methodology under 40 CFR 75 .81(b). The owner or

JCAR350225-0605957r01

concentration monitor and disapproved flow monitor,

respectively, the maximum potential concentration of

mercury and the maximum potential flow rate, as defined in

Sections 2.1.7.1 and 2.1 .4.1 of Appendix A to 40 CFR 75 .

For a disapproved moisture monitoring system and

disapproved diluent gas monitoring system, respectively,

the minimum potential moisture percentage and either the

maximum potential CO2 concentration or the minimum

potential

02

concentration (as applicable), as defined in

Sections 2.1 .5, 2.1 .3.1, and 2 .1 .3 .2 of Appendix A to 40

CFR 75. For a disapproved excepted monitoring system

(sorbent trap monitoring system) under 40 CFR 75 .15 and

disapproved flow monitor, respectively, the maximum

potential concentration of mercury and maximum potential

flow rate, as defined in Sections 2.1 .7.1 and 2 .1 .4.1 of

Appendix A to 40 CFR 75.

ii)

The owner or operator shall submit a notification of

certification retest dates and a new certification application

in accordance with subsections (a)(3)(A) and (B) of this

Section.

Exemption

The owner or operator shall repeat all certification tests or

other requirements that were failed by the monitoring

system, as indicated in the Agency's notice of disapproval,

no later than 30 unit operating days after the date of

issuance of the notice of disapproval .

1)

If an emissions monitoring system has been previously certified in

accordance with 40 CFR 75 and the applicable quality assurance and

quality control requirements of 40 CFR 75 .21 and Appendix B to 40 CFR

75 are fully met, the monitoring system shall be exempt from the initial

certification requirements of this Section .

2)

The recertification provisions of this Section shall apply to an emissions

monitoring system required by Section 225

.240(a)(1) of this Subpart

exempt from initial certification requirements under subsection (a)(1) of

this Section.

---

JCAR350225-0605957r01

1059

operator of an EGU qualified to use the mercury low mass emissions excepted

1060

methodology under 40 CFR 75 .81(b) shall meet the applicable certification and

1061

recertification requirements in 40 CFR 75

.81(c) through (f) .

1062

1063

d)

Certification Applications. The owner or operator of an EGU shall submit an

1064

application to the Agency within 45 days after completing all initial certification

1065

or recertification tests required under this Section, including the infoiniation

1066

required under 40 CFR 75 .63 .

1067

1068 Section 225.260 Out of Control Periods for Emission Monitors

1069

1070

a)

Whenever any emissions monitoring system fails to meet the quality-assurance

1071

and quality-control requirements or data validation requirements of 40 CFR 75,

1072

data shall be substituted using the applicable missing data procedures in Subparts

1073

D and I of 40 CFR 75 .

1074

1075

b)

Audit Decertification . Whenever both an audit of an emissions monitoring

1076

system and a review of the initial certification or recertification application reveal

1077

that any emissions monitoring system should not have been certified or recertified

1078

because it did not meet a particular performance specification or other

1079

requirement under Section 225 .250 of this Subpart or the applicable provisions of

1080

40 CFR 75, both at the time of the initial certification or recertification application

1081

submission and at the time of the audit, the Agency will issue a notice of

1082

disapproval of the certification status of such monitoring system . For the

1083

purposes of this subsection, an audit shall be either a field audit or an audit of any

1084

information submitted to the Agency

. By issuing the notice of disapproval, the

1085

Agency revokes prospectively the certification status of the emissions monitoring

1086

system. The data measured and recorded by the monitoring system shall not be

1087

considered valid quality-assured data from the date of issuance of the notification

1088

of the revoked certification status until the date and time that the owner or

1089

operator completes subsequently approved initial certification or recertification

1090

tests for the monitoring system

. The owner or operator shall follow the applicable

1091

initial certification or recertification procedures in Section 225

.250 of this Subpart

1092

for each disapproved monitoring system .

1093

1094 Section 225.261 Additional Requirements to Provide Heat Input Data

1095

1096

The owner or operator of an EGU that monitors and reports mercury mass emissions using a

1097

mercury concentration monitoring system and a flow monitoring system shall also monitor and

1098 report heat input rate at the EGU level using the procedures set forth in 40 CFR 75

.

1099

1 100 Section 225

.263 Monitoring of Gross Electrical Output

1101

---

JCAR350225-0605957r01

1102 The owner or operator of an EGU complying with this Subpart by means of Section

1103

225 .230(a)(1) or using electrical output (0) and complying by means of Section 225 .230(b) or

1104

(d) or Section 225 .232 of this Subpart shall monitor gross electrical output of the associated

1105

generator(s) in MWh on an hourly basis.

1106

1107 Section 225.265 Coal Analysis for Input Mercury Levels

1108

1109

a)

The owner or operator of an EGU complying with this Subpart by means of

1110

Section 225 .230(a)(2) or using input mercury levels (Ii) and complying by means

1111

of Section 225 .230(b) or (d) or Section 225 .232 of this Subpart shall :

1112

1113

1)

Perform daily sampling of the coal combusted in the EGU for mercury

1114

content. The owner or operator of such EGU shall collect a minimum of

1115

one 2-lb grab sample per day of operation from the belt feeders anywhere

1116

between the crusher house or breaker building and the boiler . The sample

1117

shall be taken in such a manner so as to provide a representative mercury

1118

content for the coal burned on that day .

1119

1120

2)

Analyze the grab coal sample for the following :

1121

1122

A)

Deteiiiiine the heat content using ASTM D5865-04 or equivalent

1123

approved in writing by the Agency .

1124

1125

B)

Determine the moisture content using ASTM D3173-03 or

1126

equivalent approved in writing by the Agency .

1127

1128

C)

Measure the mercury content using ASTM D6414-01, ASTM

1129

D3684-01, or equivalent approved in writing by the Agency .

1130

1131

3)

The owner or operator of multiple EGUs at the same source using the

1 132

same crusher house or breaker building may take one sample per crusher

1 133

house or breaker building, rather than one per EGU .

1134

1 135

4)

The owner or operator of an EGU shall use the data analyzed under

1 136

subsection (b) of this Section to determine the mercury content in teens of

1137

lbs/trillion Btu .

1138

1 139

The owner or operator of an EGU that must conduct sampling and analysis of coal

1140

pursuant to subsection (a) of this Section shall begin such activity by the

1141

following date :

1142

1143

1)

If the EGU is in daily service, at least 30 days before the start of the month

1144

for which such activity will be required .

---

jCAR350225-0605957r0l

1145

1146

2)

If the EGU is not in daily service, on the day that the EGU resumes

1147

operation.

1148

1149

Section 225 .270 Notifications

1150

1151

The owner or operator of asoorce with one or more EGUs shall submit written notice to the

1152 Agency according to the provisions in 40 CFR 75 .6lforeach EGU or group of EGUs monitored

1153 at a common stack and each non-EGU monitored under 40 CFR 75 .82(b)(2)(ii) .

1154

1155 Section 225.290 Recordkeeping and Reporting

1156

1157

a)

General Provisions

1158

1159

1)

The owner or operator of an EGU and its designated representative shall

1160

comply with all applicable recordkeeping and reporting requirements in

1161

this Section and with all applicable recordkeeping and reporting

1162

requirements of 40 CFR 75 .84.

1163

1164

2)

The owner or operator of an EGU shall maintain records for each month

1165

identiting the emission standard in Section 225 .,230(a) or 225 .237(a) of

1166

this Section with which it is complying or that is applicable for the EGU

1167

and the following records related to the emissions of mercury that the

1168

EGLKs allowed to emit :

1169

1170

A)

Foruo]BG\lfocwhich thcowner oroperator iacoozplv~ng with

1171

this Subpart by means of Section 225 .230(a)(2) or

1172

225 .23 7/a)(l)(}3\or

Jay

,, ,

using input mercury levels to determine t~

c

1173

allowable emissions of the EGU, records of the daily mercury

1174

content of coal used (lbs/trillion Btu) and the daily and monthly

1175

input mercury (lbs), which shall be kept in the file required under

1170

40 CFR 75.84(a).

1177

1178

B)

For an EGU for which the owner or operator of an EGU complying

1179

with this Subpart by means of Section 225 .230(a)(1) or

1180

225 23 7/a)(l\/~\) or using electrical output to determinet

, ,, ,, ,

~

~~

c

1181

allowable emissions of the EGU, records of the daily and monthly

1182

gross c{cctrical output (GWh), which shall be kept in the file

1183

required under 40 CFR 75 .84(a).

1184

1185

3)

The owner or operator of an EGU shall maintain records of the following

1186

Areuch EGTl:

1187

---

JCAR350225-0605957r01

1188

A)

Monthly emissions of mercury from the EGU

.

1189

1190

B)

For an EGU for which the owner or operator is complying by

1191

means of Section 225

.230(b) or (d) of this Subpart, records of the

1192

monthly allowable emissions of mercury from the EGU

.

1193

1194

4)

The owner or operator of an EGU that is participating in an Averaging

1195

Demonstration pursuant to Section 225

.232 of this Subpart shall maintain

1196

records identifying all sources and EGUs covered by the Demonstration

1197

for each month and, within 60 days after the end of each calendar month,

1198

calculate and record the actual and allowable mercury emissions of the

1199

EGU for the month and the applicable 12-month rolling period

.

1200

1201

5)

The owner or operator of an EGU shall maintain the following records

1202

related to quality assurance activities conducted for emissions monitoring

1203

systems :

1204

1205

A)

The results of quarterly assessments conducted under Section 2

.2

1206

of Appendix B of 40 CFR 75 ; and

1207

1208

B)

1209

Daily/weekly system integrity checks under Section 2

.6 of

Appendix B of 40 CFR 75

.

1210

1211

6)

1212

The owner or operator of an EGU shall maintain an electronic

copy of all

electronic submittals to the USEPA under 40 CFR 75

.84(f).

1213

1214

7)

The owner or operator of an EGU shall retain all records required by this

1215

Section at the source unless otherwise provided in the CAAPP permit

1216

issued for the source and shall make a copy of any record available to the

1217

Agency upon request

.

1218

1219

b)

Quarterly Reports

. The owner or operator of a source with one or more EGUs

1220

1221

shall submit quarterly reports to the Agency as follows

:

1222

1)

These reports shall include the following information for operation of the

1223

EGUs during the quarter

:

1224

1225

A)

The total operating hours of each EGU and the mercury CEMS, as

1226

1227

also reported in accordance with 40 CFR 75

.

1228

A discussion of any significant changes in the measures used to

1229

control emissions of mercury from the EGUs or the coal supply to

1230

the EGUs, including changes in the source of coal .

---

JCAR350225-0605957r01

1231

1232

C)

Summary information on the performance of the mercury CEMS .

1233

When the mercury CEMS was not inoperative, repaired, or

1234

adjusted, except for routine zero and span checks, this shall be

1235

stated in the report

.

1236

1237

D)

If the CEMS downtime was more than 5 .0 percent of the total

1238

operating time for the EGU: the date and time identifying each

1239

period during which the CEMS was inoperative, except for routine

1240

zero and span checks ; the nature of CEMS repairs or adjustments

1241

and a summary of quality assurance data consistent with 40 CFR

1242

75, i.e., the dates and results of the Linearity Test(s) and any

1243

Relative Accuracy Test Audit(s) during the quarter

; a listing of any

1244

days when a required daily calibration was not performed ; and the

1245

date and duration of any periods when the CEMS was out-of-

1246

control as addressed by Section 225 .260 of this Subpart .

1247

1248

2)

The owner or operator shall submit each quarterly report to the Agency

1249

within 45 days following the end of the calendar quarter covered by the

1250

report.

1251

1252

c)

Compliance Certification . The owner or operator of a source with one or more

1253

EGUs shall submit to the Agency a compliance certification in support of each

1254

quarterly report based on reasonable inquiry of those persons with primary

1255

responsibility for ensuring that all of the EGUs' emissions are correctly and fully

1256

monitored. The certification shall state :

1257

1258

1)

That the monitoring data submitted were recorded in accordance with the

1259

applicable requirements of this Section, Sections 225 .240 through 225 .270

1260

and 40 CFR 75, including the quality assurance procedures and

1261

specifications ; and

1262

1263

2)

For an EGU with add-on mercury emission controls, a flue gas

1264

desulfurization system, a selective catalytic reduction system, or a

1265

compact hybrid particulate collector system and for all hours where

1266

mercury data are substituted in accordance with 40 CFR 75 .34(a)(1):

1267

1268

A)

That:

1269

1270

i)

The mercury add-on emission controls, flue gas

1271

desulfurization system, selective catalytic reduction system,

1272

or compact hybrid particulate collector system was

1273

operating within the range of parameters listed in the

---

1274

1275

1276

1277

1278

1279

1280

1281

1282

1283

1284

1285

1286

1287

1288

1289

d)

Annual Certification of Compliance

1290

1291

1292

1293

1294

1295

1296

1297

1298

2)

1299

1300

1301

1302

1303

1304

1305

1306

1307

1308

1309

1310

1311

1312

1313

1314

1315

1316

1)

JCAR350225-0605957r0I

quality assurance/quality control program under Appendix

B to 40 CFR 75 ; or

ii)

With regard to a flue gas desulfurization system or a

selective catalytic reduction system, quality-assured SO2

emission data recorded in accordance with 40 CFR 75

document that the flue gas desulfurization system was

operating properly, or quality-assured 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 .

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 ;

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

Actual emissions, in Ibs, and gross electrical output, in

GWh, for each month in the year covered by the

Certification and in the previous year .

---

JCAR350225-0605957r01

1317

1318

B)

If complying with this Subpart by means of Section

1319

225 .230(a)(1)(B) or 225 .237(a)(1)(B):

1320

1321

i)

Actual control efficiency for emissions for each 12-month

1322

rolling period ending in the year covered by the

1323

Certification, expressed as a percent

;

1324

1325

Actual emissions, in ibs, and mercury content in the fuel

1326

fired in such EGU, in lbs, for each 12-month rolling period

1327

ending in the year covered by the Certification; and

1328

1329

iii)

Actual emissions, in lbs, and mercury content in the fuel

1330

fired in such EGU, in lbs, for each month in the year

1331

covered by the Certification and in the previous year

.

1332

1333

C)

If complying with this Subpart by means of Section 225 .230(b) :

1334

1335

i)

Actual emissions and allowable emissions for each 12-

1336

month rolling period ending in the year covered by the

1337

Certification; and

1338

1339

ii)

Actual emissions and allowable emissions, and which

1340

standard of compliance the owner or operator was utilizing

1341

for each month in the year covered by the Certification and

1342

in the previous year.

1343

1344

D)

1345

If complying with this Subpart by means of Section 225

.230(d):

1346

i)

Actual emissions and allowable emissions for all EGUs at

1347

the source for each 12-month rolling period ending in the

1348

1349

year covered by the Certification ; and

1350

Actual emissions and allowable emissions, and which

1351

standard of compliance the owner or operator was utilizing

1352

for each month in the year covered by the Certification and

1353

in the previous year.

1354

1355

E)

If complying with this Subpart by means of Section 225 .232 :

1356

1357

i)

1358

Actual emissions and allowable emissions for all EGUs at

the source in an Averaging Demonstration for each 12-

---

1359

1360

1361

1362

1363

1364

1365

1366

1367

1368

1369

1370

1371

1372

1373

1374

1375

1376

1377

1378

1379

1380

1381

1382

1383

1384

1385

1386

1387

1388

1389

1390

1391

1392

1393

1394

1395

1396

1397

1398

1399

1400

ii)

JCAR350225-0605957r01

month rolling period ending in the year covered by the

Certification; and

Actual emissions and allowable emissions, with the

standard of compliance the owner or operator was utilizing

for each EGU at the source in an Averaging Demonstration

for each month for all EGUs at the source in an Averaging

Demonstration in the year covered by the Certification and

in the previous year

.

F)

Any deviations, data substitutions, or exceptions each month and

discussion of the reasons for such deviations, data substitutions, or

exceptions .

3)

All Annual Certifications of Compliance required to be submitted shall

include the following certification by a responsible official

:

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 infoi ination submitted . Based on my inquiry,of the person or persons

directly responsible for gathering the infounation, 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.

4)

The owner or operator of an EGU shall submit its first Annual

Certification of Compliance to address calendar year 2009 or the calendar

year in which the EGU commences commercial operation, whichever is

later. Notwithstanding subsection

(d)(2) of this Section, in the Annual

Certifications of Compliance that are required to be submitted by May 1,

2010 and May 1, 2011 to address calendar years 2009 and 2010,

respectively, the owner or operator is not required to provide 12-month

rolling data for any period that ends before June 30, 2010

.

Deviation Reports

. For each EGU, the owner or operator shall promptly notify

the Agency of deviations from requirements of this Subpart . At a minimum, these

notifications shall include a description of such deviations within 30 days after

discovery of the deviations, and a discussion of the possible cause of such

deviations, any corrective actions, and any preventative measures taken .

---

JCAR350225-0605957r01

1401

f)

Quality Assurance RATA Reports

. The owner or operator of an EGU shall

1402

submit to the Agency, Air Compliance and Enforcement Section, the quality

1403

assurance RATA report for each EGU or group of EGUs monitored at a common

1404

stack and each non-EGU under 40 CFR 75

.82(b)(2)(ii) within 45 days after

1405

completing a quality assurance RATA.

1406

1407

Section 225 .295

Treatment of Mercury Allowances

1408

1409

Any mercury allowances allocated to the Agency by the USEPA shall be treated as follows

:

1410

1411

a)

No such allowances shall be allocated to any owner or operator of an EGU or

1412

other sources of mercury emissions into the atmosphere or discharges into the

1413

waters of the State

.

1414

1415

b)

The Agency shall hold all allowances allocated by the USEPA to the State

. At the

1416

end of each calendar year, the Agency shall instruct the USEPA to retire

1417

permanently all such allowances

.