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Proposed Rule. First Notice.

OPINION AND ORDER OF THE BOARD (by G.T. Girard, A.S. Moore):

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SUBTITLE B: AIR POLLUTION

225.230  Emission Standards for EGUs at Existing Sources

225.235  Units Scheduled for Permanent Shut Down

225.237  Emission Standards for New Sources with EGUs

225.261  Additional Requirements to Provide Heat Input Data

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.

The definitions contained in this Section apply only to the provisions of this Part. Unless otherwise defined herein 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 Part 211.

"Averaging demonstration" means, with regard to Subpart B of this Part, a demonstration of compliance that is based on the combined performance of EGUs at two or more sources.

"Boiler" means an enclosed fossil or other fuel-fired combustion device used to produce heat and to transfer heat to recirculating water, steam, or other medium.

"Bottoming-cycle cogeneration unit" means a cogeneration unit in which the energy input to the unit is first used to produce useful thermal energy and at least some of the reject heat from the useful thermal energy application or process is then used for electricity production.

"Coal" means any solid fuel classified as anthracite, bituminous, subbituminous, or lignite by the American Society for Testing and Materials (ASTM) Standard Specification for Classification of Coals by Rank D388-77, 90, 91, 95, 98a, or 99 (Reapproved 2004).

"Coal-derived fuel" means any fuel (whether in a solid, liquid or gaseous state) produced by the mechanical, thermal, or chemical process.

"Coal-fired" means combusting any amount of coal or coal-derived fuel, alone or in combination with any amount of any other fuel, during a specified year.

"Cogeneration unit" means a stationary, fossil fuel-fired boiler or stationary, fossil fuel-fired combustion turbine:

Having equipment used to produce electricity and useful thermal energy for industrial, commercial, heating, or cooling purposes through the sequential use of energy; and

Producing during the 12-month period starting on the date the unit first produces electricity and during any calendar year after the calendar year in which the unit first produces electricity:

     For a topping-cycle cogeneration unit,

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 then 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 and any other coal-fired technology capable of controlling multiple combustion emissions simultaneously with improved boiler or generation efficiency and with significantly greater waste reduction relative to the performance of technology in widespread commercial use as of January 1, 2005.

"Rolling 12-month basis" means, with regard to Subpart B of this Part, a determination made on a monthly basis from the relevant data for a particular calendar month and the preceding 11 calendar months (total of 12 months of data), with two exceptions. For determinations involving one EGU, calendar months in which the EGU does not operate (zero EGU operating hours) shall not be included in the determination, and shall be replaced by a preceding month or months in which the EGU does operate, so that the determination is still based on 12 months of data. For determinations involving two or more EGUs, calendar months in which none of the EGUs covered by the determination operates (zero EGU operating hours) shall not be included in the determination, and shall be replaced by preceding months in which at least one of the EGU covered by the determination does operate, so that the determination is still based on 12 months of data.

Section 225.202  Measurement Methods

Measurement of mercury shall be according to the following:

c)  Mercury Emission Reduction Requirements

The owner or operator of any EGU subject to this Subpart shall comply with applicable requirements for control of mercury emissions under Section 225.230 or Section 225.237 of this Subpart.

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.

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.

on or before December 31, 2008, the owner or operator of such EGUs must submit an initial permit application or application for CAAPP permit modification that meets the requirements of this Section by December 31, 2008.

In addition to other information required for a complete application for CAAPP permit or CAAPP permit modification, the application shall include the following information:

Section 225.230  Emission Standards for EGUs at Existing Sources

or more EGUs subject to this Subpart that commenced commercial operation on or before December 31, 2008, shall comply with one of the following standards for each EGU on a rolling 12-month basis:

B)  A minimum 90-percent reduction of input mercury.

Where:

Where:

Where:

A₁₂ = Allowable mercury emissions of the EGU for the particular 12-month rolling period.

E_i = Actual mercury emissions of the EGU in an individual month in the 12-month rolling period.

A_i = Allowable mercury emissions of the EGU in an individual month in the 12-month rolling period, based on either the input mercury to the unit (A_{Input i}) or the electrical output from the EGU (A_{Output i}), as selected by the owner or operator of the EGU for that given month.

A_{Input i} = 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.

A_{Output i} = 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.

Where:

E_S = Sum of the actual mercury emissions of the EGUs at the source.

A_S = Sum of the allowable mercury emissions of the EGUs at the source.

E_i = Actual mercury emissions of an individual EGU at the source, as determined in accordance with subsection (b)(2) of this Section.

A_i = 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.

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.

B)  A minimum 90-percent reduction of input mercury.

Section 225.240  General Monitoring and Reporting Requirements

The owner or operator of an EGU shall comply with the monitoring, recordkeeping, and reporting requirements as provided in this Section, Sections 225.250 through 225.290 of this Subpart, and Subpart I of 40 CFR Part 75. If the EGU utilizes a common stack with units that are not EGUs and the owner or operator of the EGU does not conduct emissions monitoring in the duct to the common stack from each EGU, the owner or operator of the EGU shall conduct emissions monitoring in accordance with 40 CFR 75.82(b)(2) and this Section, including monitoring in the duct to the common stack from each unit that is not an EGU, unless the owner or operator of the EGU counts the combined emissions measured at the common stack as the mass emissions of mercury for the EGUs for recordkeeping and compliance purposes.

 c)  Reporting data

 d)  Prohibitions

The owner or operator of an EGU that is in long-term cold storage is subject to the applicable provisions of 40 CFR Part 75 for monitoring, recordkeeping, and reporting for units in long-term cold storage.

Section 225.260  Out of Control Periods for Emission Monitors

Section 225.261  Additional Requirements to Provide Heat Input Data

The owner or operator of an EGU that monitors and reports mercury mass emissions using a mercury concentration monitoring system and a flow monitoring system shall also monitor and report heat input rate at the EGU level using the procedures set forth in 40 CFR Part 75.

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.

Section 225.270  Notifications

Section 225.290  Recordkeeping and Reporting

 d)  Annual Certification of Compliance

I certify under penalty of law that this document and all attachments were prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the information submitted. Based on my inquiry of the person or persons directly responsible for gathering the information, the information submitted is, to the best of my knowledge and belief, true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment for knowing violations.

Section 225.295  Treatment of Mercury Allowances

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

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