JLI

TITLE

35:

ENVIRONMENTAL

PROTECTION

SUBTITLE

B:

AIR

POLLUTION

CHAPTER

I:

POLLUTION

CONTROL

BOARD

SUBCHAPTER

C:

EMISSION

STANDARDS

AND

LIMITATIONS

FOR

STATIONARY

SOURCES

PART

225

CONTROL

OF

EMISSIONS

FROM

LARGE

COMBUSTION

SOURCES

SUBPART

A:

GENERAL

PROVISIONS

Section

225.100

Severability

225.120

Abbreviations

and

Acronyms

225.130

Definitions

225.140

Incorporations

by

Reference

225.150

Commence

Commercial

Operation

SUBPART

B:

CONTROL

OF

MERCURY

EMISSIONS

FROM

COAL-FIRED

ELECTRIC

GENERATING

UNITS

Section

225.200

Purpose

225.202

Measurement

Methods

225.205

Applicability

225.210

Compliance

Requirements

225.220

Clean

Air

Act Permit

Program

(CAAPP)

Permit

Requirements

225

.230

Emission

Standards

for EGUs

at

Existing

Sources

225.232

Averaging

Demonstrations

for Existing

Sources

225.233

Multi-Pollutant

Standard

(MPS)

225.234

Temporary

Technology-Based

Standard

for

EGUs

at

Existing

Sources

225.23

5

Units

Scheduled

for

Permanent

Shut

Down

225.237

Emission

Standards

for

New

Sources

with

EGUs

225.23

8

Temporary

Technology-Based

Standard

for

New

Sources

with

EGUs

225.239

Periodic

Emissions

Testing

Alternative

Requirements

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

1

---

225.291

Combined

Pollutant

Standard:

Purpose

225

.292

Applicability

of

the

Combined

Pollutant

Standard

225.293

Combined

Pollutant

Standard:

Notice

of

Intent

225

.294

Combined

Pollutant

Standard:

Control

Technology Requirements

and

Emissions

Standards

for

Mercury

225 .295

Combined

Pollutant

Standard:

Emissions

Standards for

NO

and

SO

2

225

.296

Combined

Pollutant

Standard:

Control

Technology Requirements

for

SO

and

PM

Emissions

225.297

Combined

Pollutant

Standard:

Permanent

Shut-Downs

225.298

Combined

Pollutant

Standard:

Requirements

for

NQ

and

SO

2

Allowances

225.299

Combined

Pollutant

Standard:

Clean

Air

Act

Requirements

SUBPART

C: CLEAN

AIR

ACT

INTERSTATE

RULE

(CAIR)

SO

2

TRADING

PROGRAM

Section

225

.300

Purpose

225

.305

Applicability

225.3

10

Compliance

Requirements

225.3

15

Appeal

Procedures

225.320

Permit

Requirements

225

.325

Trading

Program

SUBPART

D:

CAIR

NO

ANNUAL

TRADING

PROGRAM

Section

225

.400

Purpose

225

.405

Applicability

225

.410

Compliance

Requirements

225.415

Appeal

Procedures

225.420

Permit

Requirements

225.425

Annual

Trading

Budget

225

.430

Timing

for Annual Allocations

-

225

.435

Methodology

for

Calculating

Annual

Allocations

225

.440

Annual

Allocations

225.445

New

Unit

Set-Aside (NUSA)

225

.450

Monitoring,

Recordkeeping

and

Reporting

Requirements

for

Gross

Electrical

Output

and

Useful

Thermal Energy

225

.455

Clean

Air

Set-Aside

(CASA)

225.460

Energy

Efficiency

and

Conservation,

Renewable

Energy,

and

Clean

Technology

Projects

225.465

Clean

Air

Set-Aside

(CASA)

Allowances

225.470

Clean

Air Set-Aside

(CASA)

Applications

225.475

Agency

Action

on

Clean

Air

Set-Aside

(CASA)

Applications

225

.480

Compliance

Supplement

Pool

SUBPART

E:

CAIR

NO

OZONE

SEASON

TRADiNG

PROGRAM

2

---

Section

225.500

Purpose

225.505

Applicability

225.510

Compliance

Requirements

225.515

Appeal

Procedures

225

.520

Permit

Requirements

225.525

Ozone

Season

Trading

Budget

225.530

Timing

for

Ozone

Season

Allocations

225.535

Methodology

for

Calculating

Ozone

Season

Allocations

225.540

Ozone

Season

Allocations

225.545

New

Unit

Set-Aside

(NUSA)

225.550

Monitoring,

Recordkeeping

and

Reporting

Requirements

for

Gross

Electrical

Output

and

Useful

Thermal

Energy

225.555

Clean

Air

Set-Aside

(CASA)

225.560

Energy

Efficiency

and

Conservation,

Renewable

Energy,

and

Clean

Technology

Projects

225.565

Clean Air

Set-Aside

(CASA)

Allowances

225.570

Clean

Air

Set-Aside

(CASA)

Applications

225

.575

Agency

Action

on

Clean

Air

Set-Aside

(CASA)

Applications

SUEPAPT

F

CO4TTNFfl

POT

TTTTANT

TANTAPTh

225.600

Purpose

‘‘C

ff

A_.1

LU

.UUJ

n.ppuCablflty

‘9S

61fl

Nctir

nfTntAl,t

225.615

Control Technology

Requirements

and

Emissions

Standards

for

Mercury

225.620

Emissions

Standards

for

NO

and

SO

2

225

.625

Control Technology

Requirements

for

NO-SO

2

,

and

PM

Emissions

225.630

Permanent

Shut

Downs

for

CA

SO

2

,

C

NO,

and

C

NO%

Onn

nnn

Allowances

225.640

Clean Air

Act

Requirements

225.APPENDIX

A

Specified

EGUs

for

Purposes

of

the

CPSSubpart

F (Midwest

Generation’s

Coal-Fired

Boilers

as

of

July

1,

2006)

225

.APPENDIX

B

Continuous

Emission

Monitoring

Systems

for

Mercury

AUTHORITY:

Implementing

and

authorized

by

Section

27

of

the

Environmental

Protection

Act

[415

ILCS

5/27].

SOURCE:

Adopted

in

R06-25

at

31111.

Reg.

129,

effective

December

21,

2006;

amended

in

R06-26

at

31111. Reg.

12864,

effective

August

31,

2007.

3

---

SUBPART

A: GENERAL

PROVISIONS

Section

225.100

Severability

If any

Section,

subsection

or

clause

of this

Part

is found

invalid,

such

finding

must

not

affect

the

validity

of

this

Part as

a whole

or

any Section,

subsection

or

clause

not found

invalid.

Section

225.120

Abbreviations

and

Acronyms

Unless

otherwise

specified

within

this

Part,

the

abbreviations

used

in

this Part

must

be the

same

as

those

found

in 35

Iii.

Adm.

Code

211.

The

following

abbreviations

and

acronyms

are

used

in

this Part:

Act

Environmental

Protection

Act

[415

ILCS 5]

ACI

activated

carbon

injection

AETB

Air

Emission

Testing

Body

Agency

Illinois

Environmental

Protection

Agency

Btu

British

thermal

unit

CAA

Clean

Air

Act [42

USC

7401

et seq.]

CAAPP

Clean

Air

Act

Permit

Program

CAR

Clean

Air Interstate

Rule

CASA

Clean

Air Set-Aside

CEMS

continuous

emission

monitoring

system

CO

2

carbon

dioxide

CPS

Combined

Pollutant

Standard

-

CGO

converted

gross

electrical

output

CRM

certified

reference

materials

CUTE

converted

useful

thermal

energy

DAHS

data acquisition

and

handling

system

dscm

dry

standard

cubic

meters

EGU

electric

generating

unit

ESP

electrostatic

precipitator

FGD

flue gas

desulfurization

1l,m

feet

per

minute

GO

gross electrical

output

GWh

gigawatt

hour

HI

heat

input

Hg

mercury

hr

hour

ISO

International

Organization

for

Standardization

kg

kilogram

lb

pound

MPS

Multi-Pollutant

Standard

MSDS

Material

Safety

Data Sheet

4

---

MW

megawatt

Mwe

megawatt

electrical

MWh

megawatt

hour

NAAQS

National

Ambient

Air

Quality

Standards

NIST

National

Institute

of

Standards

and

Technology

N0

nitrogen

oxides

NTRM

NIST

Traceable

Reference

Material

NUSA

New

Unit

Set-Aside

ORIS

Office

of

Regulatory

Information

Systems

02

oxygen

PM

2

.

5

particles

less

than

2.5

micrometers

in

diameter

QA

quality

assurance

OC

quality

certification

RATA

relative

accuracy

test

audit

RGFM

reference

gas

flow

meter

SO

2

sulfur

dioxide

SNCR’

selective

noncatalytic

reduction

TTBS

Temporary

Technology

Based

Standard

TCGO

total

converted

useful

thermal

energy

UTE

useful

thermal

energy

USEPA

United

States

Environmental

Protection

Agency

yr

year

(Source:

Amended

at

effective

Section

225.130

Definitions

The

following

definitions

apply

for

the

purposes

of

this

Part.

Unless

otherwise

defined

in

this

Section

or

a

different

meaning

for

a

term

is

clear

from

its

context,

the

terms

used

in

this

Part

have

the

meanings

specified

in

35

Iii.

Adm.

Code 211.

-

“Agency”

means

the

Illinois

Environmental

Protection

Agency.

[415

ILCS

5/3.105]

“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.

“Base

Emission

Rate”

means,

for

a

group

of

EGUs

subject

to

emission

standards

for

NOx

and

SO

2

pursuant

to

Section

225.233,

the

average

emission

rate

of

N0

or

SO

2

from

the

EGUs,

in

pounds

per

million

Btu

heat input,

for

calendar

years

2003

through

2005

(or,

for

seasonal

N0,

the

2003

through

2005

ozone

seasons),

as

determined

from

the

data

collected

and

quality

assured

by

the

USEPA,

pursuant

to

the

40

CFR

72

and

96

federal

Acid Rain

and

N0

Budget

Trading

Programs,

for

the

emissions

and

heat

input

of

that

group

of

EGUs.

5

---

“Board”

means

the

Illinois

Pollution

Control

Board.

[415

ILCS

5/3.1301

“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.

“CA]E. authorized

account

representative”

means,

for

the

purpose

of

general

accounts,

a

responsible

natural person

who

is

authorized,

in

accordance

with

40

CFR

96,

subparts

BB,

FF,

BBB,

FFF,

BBBB,

and

FFFF

to transfer

and

otherwise

dispose

of

CAIR

NON,

SO

2

,

and

NO

Ozone

Season

allowances,

as

applicable,

held

in

the

CAR

NON,

SO

2

,

and

NO

Ozone

Season

general

account,

and

for

the

purpose

of

a

CAIR

NO

compliance

account,

a

CAR

SO

2

compliance

account,

or a

CAIR

NO

Ozone

Season

compliance

account,

the

CAR

designated

representative

of

the

source.

“CAR

designated

representative”

means,

for

a

CAR

NO

source,

a CAR

SO

2

source,

and

a

CAR

NO

Ozone

Season

source

and

each

CAR

NO

unit,

CAR

SO

2

unit

and

CAR

NO

Ozone

Season

unit

at

the

source,

the

natural

person

who

is

authorized

by

the

owners

and

operators

of

the

source

and

all

such

units

at

the

source,

in

accordance

with

40

CFR

96,

subparts

BB,

FF,

BBB,

FFF,

BBBB,

and

FFFF

as

applicable,

to

represent

and

legally

bind

each

owner

and

operator

in

matters

pertaining

to

the

CAR

NO

Annual

Trading

Program,

CAR

SO

2

Trading

Program,

and

CAR

NO

Ozone

Season

Trading

Program, as

applicable.

For

any

unit

that

is

subject

to

one

or

more

of

the

following

programs:

CAR

NO

Annual

Trading

Program,

CAR

SO

2

Trading

Program,

CAR

NO

Ozone

Season

Trading

Program,

or

the

federal

Acid

Rain

Program,

the

designated

representative

for

the

unit

must

be

the

same

natural

person

for

all programs

applicable

to

the

unit.

“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

processing

of

coal.

“Coal-fired”

means:

•

For

purposes

of Subpart&

B

and

F,

or

for

purposes

of

allocating

allowances

under

Sections

225.435,

225.445, 225.535,

and

225.545,

combusting

any

amount

of

coal

or

coal-derived

fuel,

alone

or

in

combination

with

any

amount

of

any

other

fuel,

during

a

specified

year;

6

---

Except

as provided

above,

combusting

any

amount

of

coal

or

coal-derived

fuel,

alone

or

in

combination

with

any

amount

of any

other

fuel.

“Cogeneration

unit”

means,

for

the

purposes

of

Subparts

C,

D,

and

E,

a stationary,

fossil

fuel-fired

boiler

or

a stationary,

fossil

fuel-fired

combustion

turbine

of

which

both

of

the

following

conditions

are

true:

It uses

equipment

to

produce

electricity

and

useful

thermal

energy

for

industrial,

commercial,

heating,

or

cooling

purposes

through the

sequential

use of

energy;

and

It produces

either

of

the

following

during

the 12-month

period

beginning

on

the

date

the

unit

first

produces

electricity

and

during

any

subsequent

calendar

year

after

that

in

which

the

unit

first

produces

electricity:

For

a topping-cycle

cogeneration

unit,

both

of

the

following:

Useful

thermal

energy

not

less

than

five

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;

or

For

a

bottoming-cycle

cogeneration

unit,

useful

power

not

less

than

45

percent

of

total

energy

input.

“Combined

cycle

system”

means

a system

comprised

of

one.

or

more

combustion

turbines,

heat

recovery

steam

generators,

and

steam

turbines

configured

to improve

overall

efficiency of

electricity

generation

or steam

production.

“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

described

in

the

above

paragraph

of

this

definition

is

combined cycle,

any

associated

duct

burner,

heat

recovery

steam

generator

and

steam

turbine.

“Commence

commercial

operation”

means,

for

the

purposes

of Subparts

B and

F of

this

Part,

with

regard

to an

EGU

that

serves

a

generator,

to

have

begun

to

produce

steam,

gas,

7

---

or

other

heated

medium

used

to generate

electricity

for

sale

or

use,

including

test

generation.

Such

date

must

remain

the

unit’s

date

of

commencement

of

operation

even

if

the

EGU

is

subsequently

modified,

reconstructed

or

repowered.

For

the

purposes

of

Subparts

C, D

and

E,

“commence

commercial operation”

is

as

defined

in

Section

225.150.

“Commence

construction”

means,

for

the

purposes

of

Section 225.460(f),

225.470,

225.560(f),

and

225.570,

that

the

owner

or owner’s

designee has

obtained

all

necessary

preconstruction

approvals

(e.g.,

zoning)

orpermits

and

either

has:

Begun,

or

caused

to

begin,

a

continuous

program

of

actual

on-site

construction

of

the

source,

to

be completed

within

a reasonable

time;

or

Entered into

binding

agreements

or

contractual

obligations,

which cannot

be

cancelled

or

modified

without

substantial

loss,

to

the

owner

or

operator,

to

undertake

a program

of actual

construction

of

the

source

to be

completed

within

a

reasonable

time.

For

purposes

of this

definition:

“Construction”

shall

be

determined

as

any

physical

change

or

change

in

the

method

of

operation,

including

but

not

limited

to

fabrication,

erection,

installation,

demolition,

or

modification

of projects

eligible for

CASA

allowances,

as

set

forth

in

Sections

225

.460

and

225.560.

“A

reasonable

time”

shall

be

determined

considering

but

not

limited

to the

following

factors:

the

nature

and

size

of

the

project,

the

extent

of design

engineering,

the

amount

of

off-site

preparation,

whether

equipment

can

be

fabricated

or

can

be

purchased,

when

the

project

begins

(considering

both

the

seasonal

nature

of

the

construction

activity

and

the

existence

of

other

projects

competing

for

construction

labor

at the

same

time,

the

place

of

the

environmental

permit

in

the

sequence

of corporate

and

overall

governmental

approval),

and

the

nature

of

the

project

sponsor

(e.g.,

private, public,

regulated).

“Commence

operation”,

for

purposes

of

Subparts

C,

D

and

B,

means:

To

have

begun

any

mechanical,

chemical,

or electronic

process,

including,

for

the

purpose of a

unit,

start-up of

a

unit’s

combustion

chamber,

except

as

provided

in

40

CFR

96.105,

96.205,

or

96.305, as

incorporated

by

reference

in

Section

225.140.

For

a unit

that

undergoes

a

physical

change

(other

than

replacement

of

the

unit

by

a

unit

at

the

same

source) after

the

date

the

unit

commences

operation

as

set

forth

in

the

first

paragraph

of this

definition,

such

date

will

remain

the

date

of

commencement

of

operation

of

the

unit,

which

will

continue

to

be

treated

as

the

same

unit.

8

---

For

a

unit

that

is

replaced

by

a

unit

at

the

same

source

(e.g.,

repowered),

after

the

date

the

unit

commences

operation

as

set

forth

in

the

first

paragraph

of

this

definition,

such

date

will

remain

the

replaced

unit’s

date

of

commencement

of

operation,

and

the

replacement

unit

will

be

treated

as a

separate

unit

with

a

separate

date

for

commencement

of

operation

as

set

forth

in

this

definition

as

appropriate.

“Common

stack”

means

a

single

flue

through

which

emissions

from

two

or

more

units

are

exhausted.

“Compliance

account”

means:

For

the

purposes

of

Subparts

D

and

E,

a CAR

NO

Allowance

Tracking

System

account,

established

by

USEPA

for

a CAR

NO

source

or CAR

NO

Ozone

Season source

pursuant

to 40

CFR

96,

subparts

FF

and

FFFF

in

which

any

CAR

NO

allowance

or

CAR

NO

Ozone

Season

allowance

allocations

for

the

CAR

NO

units

or

CAR

NO

Ozone

Season

units

at the

source

are

initially

recorded

and

in

which

are

held

any

CAR

NO

or

CAR

NO

Ozone

Season

allowances

available

for

use

for

a control

period

in

order

to

meet

the

source’s

CAR

NO

or

CAR

NO

Ozone

Season

emissions

limitations

in

accordance

with

Sections

225.410 and

225.510,

and

40

CFR

96.154

and

96.354,

as

incorporated

by

reference

in

Section

225.140.

CAR

NO

allowances

may

not

be

used for

compliance

with

the

CAR

NO

Ozone

Season

Trading

Program

and

CAIR

NO

Ozone

Season

allowances

may

not

be

used

for

compliance

with

the

CAR

NO

Annual Trading

Program; or

For

the

purposes

of

Subpart

C, a

“compliance

account”

means a

CAR

SO

2

compliance

account,

established

by

the

USEPA

for

a

CAR

SO

2

source

pursuant

to

40

CFR

96,

subpart

FFF,

in

which

any

SO

2

units

at

the

source

are

initially

recorded

and

in

which

are

held

any

SO

2

allowances

available

for

use

for

a

control

period in order

to

meet

the

source’s

CAR

SO

2

emissions

limitations

in

accordance

with

Section

225.3

10

and

40

CFR

96.254,

as

incorporated

by

reference in

Section

225.140.

“Control period”

means:

For

the

CAR

SO

2

and

NO

Annual

Trading

Programs

in Subparts

C

and

D,

the

period

beginning

January

1

of

a

calendar

year,

except

as

provided

in

Sections

225.3

10(d)(3)

and

225.4

10(d)(3),

and

ending

on

December31

of

the

same

year,

inclusive;

or

For

the

CAR

NO

Ozone

Season

Trading

Program

in

Subpart

E,

the

period

beginning

May

1

of a

calendar

year,

except

as

provided

in

Section

225.5

10(d)(3),

and

ending on

September

30

of the

same

year,

inclusive.

9

---

“Designated

representative”

means,

for

the

purposes

of

Subpart

B of

this

Part,

the

natural

person

as

defmed

in

40

CFR

60.4

102,

and

is

the

same

natural

person

as

the

person

who

is

the

designated

representative

for

the

CAR

trading

and

Acid

Rain

programs.

“Electric

generating

unit”

or

“EGU”

means

a

fossil

fuel-fired

stationary

boiler,

combustion

turbine

or

combined

cycle

system

that

serves

a

generator

that

has

a

nameplate

capacity

greater

than

25

MWe

and

produces

electricity

for

sale.

“Flue”

means

a

conduit

or

duct

through

which

gases

or

other

matter

is exhausted

to

the

atmosphere.

“Fossil

fuel”

means

natural

gas,

petroleum,

coal,

or

any

form

of solid,

liquid,

or

gaseous

fuel

derived

from

such

material.

“Fossil

fuel-fired”

means

the

combusting

of

any

amount

of

fossil

fuel,

alone

or

in

combination

with

any

other

fuel

in

any

calendar

year.

“Generator”

means

a

device

that

produces

electricity.

“Gross

electrical

output”

means

the

total

electrical

output

from

an

EGU

before

making

any

deductions

for

energy

output

used

in

any

way

related

to

the

production

of

energy.

For

an

EGU

generating

only

electricity,

the

gross

electrical output

is

the

output

from

the

turbine/generator

set.

“Heat

input” means,

for

the

purposes

of

Subparts

C,

D,

and

E,

a

specified

period

of time,

the

product

(in

mrnBtu!hr)

of

the

gross

calorific

value

of

the

fuel

(in

Btu/lb)

divided

by

1,000,000

Btu/mrnBtu

and

multiplied

by

the

fuel

feed

rate

into

a

combustion

device

(in

lb

of

fuelltime),

as

measured,

recorded

and

reported

to

USEPA

by

the

CAR

designated

representative

and

determined

by

USEPA

in

accordance

with

40

CFR

96,

subpart

HH,

HHH,

or

HHHH, if

applicable,

and

excluding

the

heat

derived

from

preheated

combustion

air,

recirculated

flue

gases,

or

exhaust

from

other

sources.

“Higher

heating

value”

or

“HHV”

means

the

total

heat

liberated

per

mass

of

fuel

burned

(BtuJlb),

when

fuel

and

dry

air

at

standard

conditions

undergo

complete

combustion

and

all

resultant

products are

brought

to

their

standard

states

at

standard

conditions.

“Input

mercury”

means

the

mass

of

mercury that

is

contained

in

the

coal

combusted

within

an

EGU.

“Integrated

gasification

combined

cycle”

or

“IGCC”

means

a

coal-fired

electric

utility

steam

generating

unit

that

bums

a

synthetic

gas

derived

from

coal

in a

combined-cycle

gas

turbine.

No

coal

is

directly

burned

in the

unit

during

operation.

“Long-term

cold

storage”

means

the

complete

shutdown

of

a

unit

intended

to

last

for

an

extended

period

of

time

(at

least

two

calendar

years)

where

notice

for

long-term

cold

10

---

storage

is

provided

under

40

CFR

75.6

1(a)(7).

“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

of such

installation

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

of

completion

as

specified

by

the

person conducting

the

physical

change.

“MST traceable

elemental

mercury

standards”

means either:

(1)

Compressed

gas

cylinders having

known

concentrations

of

elemental

mercury,

which

have

been

prepared

according

to the

“EPA

Traceability

Protocol

for

Assay

and

Certification

of

Gaseous

Calibration

Standards”

or

(2)

Calibration

gases having

known

concentrations

of

elemental

mercury,

produced

by

a

generator

that

fully

meets

the

performance

requirements

of

the

“EPA

Traceability

Protocol

for

Qualification

and

Certification

of Elemental

Mercury

Gas

Generators.”

“NIST

traceable

source

of

oxidized

mercury”

means

a

generator

that

is

capable

of

providing

known

concentrations

of vapor

phase

mercuric

chloride

(HgCI

2

),

and

that

fully

meets

the

performance

requirements

of

the

“EPA Traceability

Protocol

for

Qualification

and

Certification

of

Oxidized

Mercury

Gas

Generators.”

“Oil-fired

unit” means

a

unit

combusting

fuel

oil

for

more

than

15.0

percent

of

the

annual

heat

input

in

a

specified year

and

not

qualifying

as

coal-fired.

“Output-based

emission

standard”

means,

for

the

purposes

of

Subpart

B

of this

Part,

a

maximum

allowable

rate

of

emissions

of

mercury

per

unit

of

gross

electrical

output

from

an

EGU.

“Potential

electrical

output

capacity”

means

33

percent

of

a

unit’s

maximum

design

heat

input,

expressed

in

mniBtu/hr

divided

by

3.4

13

mmBtu/MWh,

and

multiplied

by

8,760

hr/yr.

“Project sponsor”

means

a person

or

an

entity,

including

but

not

limited

to

the

owner

or

operator

of

an

EGU

or

a

not-for-profit

group,

that

provides

the

majority

of

funding

for

an

energy

efficiency

and

conservation,

renewable

energy,

or

clean

technology

project

as

listed

in

Sections

225.460

and

225.560,

unless

another

person

or entity

is designated

by

a

written

agreement

as

the

project

sponsor

for

the

purpose

of

applying

for

NO allowances

or

NO

Ozone

Season

allowances

from

the

CASA.

11

---

“Rated-energy

efficiency”

means

the

percentage

of

thermal

energy

input

that

is

recovered

as

useable

energy

in the

form

of gross

electrical

output,

useful

thermal

energy,

or

both

that

is

used

for

heating,

cooling,

industrial

processes,

or

other

beneficial

uses

as

follows:

For

electric

generators,

rated-energy

efficiency

is

calculated

as one

kilowatt

hour

(3,413

Btu)

of electricity

divided

by

the

unit’s

design

heat

rate

using

the

higher

heating

value

of the

fuel,

and

expressed

as

a

percentage.

For

combined

heat

and

power

projects,

rated-energy

efficiency

is

calculated

using

the

following

formula:

REE

=

((GO

+

UTE)fHI)

x

100

Where:

REE

=

Rated-energy

efficiency,

expressed

as percentage.

GO

Gross

electrical

output

of the

system

expressed

in BtuJhr.

UTE

=

Useful

thermal

output

from

the

system

that

is used

for

heating,

cooling,

industrial

processes

or other

beneficial

uses,

expressed

in

BtuThr.

HI

=

Heat

input,

based

upon

the

higher

heating

value

of

fuel,

in

Btu/hr.

“Repowered”

means,

for

the

purposes

of

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;

Magnetohydroclynamics;

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,

for the

purposes

of

Subparts

B

and

F

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

12

---

exceptions.

For

determinations

involving

one

EGU,

calendar

months

in

which

the

EGU

does

not

operate

(zero

EGU

operating

hours)

must

not

be

included

in

the

determination,

and

must

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)

must

not

be

included

in

the

determination,

and

must

be

replaced

by

preceding

months

in

which

at

least

one

of

the

EGUs

covered

by

the

determination

does

operate,

so that

the

determination

is still

based

on

12 months

of

data.

“Total

energy

output”

means,

with

respect

to a

cogeneration

unit,

the

sum

of

useful

power

and

useful

thermal

energy

produced

by

the

cogeneration

unit.

“Useful

thermal

energy”

means,

for

the

purpose

of

a

cogeneration

unit,

the

thermal

energy

that

is made

available

to

an

industrial

or

commercial

process,

excluding

any

heat

contained

in condensate

return

or makeup

water:

Used

in

a

heating

application

(e.g.,

space

heating

or

domestic

hot

water

heating);

or

Used

in

a space

cooling

application

(e.g.,

thermal

energy

used

by

an

absorption

chiller).

(Source:

Amended

at

effective

Section

225.140

Incorporations

by

Reference

The

following

materials

are

incorporated

by

reference.

These

incorporations

do not

include

any

later

amendments

or editions.

a)

Appendix

A,

Subpart

A, and

Performance

Specifications

2

and

3

of Appendix

B

of

40

CFR

60,

60.17,

60.45a,

60.49a(k)(1)

and

(p),

60.50a(h), and

60.4170

through

60.4176

(2005).

b)

40

CFR

72.2

(2005).

cb)

40

CFR

75.4,

75.11 through

75.14,

75.16

through

75.19,

75.30,

75.34

through

75.37,

75.40 through

75.48,

75.53(e),

75.57(c)(2)(i)

through

75.57(c)(2)(yj)

1

75.60

through

75.67.

75.71,

75.74(c),

Sections

2.1.1.5,

2.1.1.2,

7.7,

and

7.8

of

Appendix

A

to

40

CFR

75,

Appendix

C to

40

CFR

75,

Section

3.3.5

of

Appendix

F

to

40

CFR

75

(2006).40

CFR

75

(2006).

de)

40

CFR

78

(2006).

e4)

40

CFR

96,

CAIR

SO

2

Trading

Program,

subparts

AAA

(excluding

40

CFR

96.204

and

96.206),

BBB,

FFF,

GGG,

and

HHH

(2006).

13

---

fe)

40

CFR

96,

CAIR

NO

Annual

Trading

Program,

subparts

AA

(excluding

40

CFR

96.104,

96.105(b)(2),

and

96.106),

BB,

FF,

GG,

and

HH

(2006).

gf)

40

CFR

96,

CAIR

NO

Ozone

Season

Trading

Program,

subparts

AAAA

(excluding

40

CFR

96.304,

96.305(b)(2),

and

96.306), BBBB,

FFFF,

GGGG,

and

RHHH

(2006).

hg)

ASTM.

The

following

methods

from

the

American

Society

for

Testing

and

Materials,

100

Barr

Harbor

Drive,

P.O.

Box

C700,

West

Conshohocken

PA

19428-2959,

(610)

832-9585:

1)

ASTM D388-77

(approved

February

25,

1977), D388-90

(approved

March

30,

1990),

D388-91a

(approved

April

15,

1991),

D388-95

(approved

January

15,

1995),

D388-98a

(approved

September

10,

1998),

or

D388-99

(approved

September

10,

1999,

reapproved

in

2004),

Classification

of

Coals

by

Rank.

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 D4840-99,

Standard

Guide

for

Sampling

Chain-of-Custody

Procedures

(Reapproved

2004).

54)

ASTM

D5865-04,

Standard

Test

Method

for

Gross

Calorific

Value

of

Coal

and

Coke

(Approved

April

1, 2004).

6)

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).

7)

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).

8)

ASTM

D691

1-03,

Standard

Guide

for

Packaging

and

Shipping

Environmental

Samples

for

Laboratory

Analysis.

9)

ASTM

D7036-04,

Standard

Practice

for

Competence

of

Air

Emission

Testing

Bodies.

14

---

ih)

Federal

Energy

Management

Program,

M&V

Guidelines:

Measurement

and

Verification

for

Federal

Energy

Projects,

US

Department

of

Energy,

Office

of

Energy

Efficiency

and

Renewable

Energy,

Version

2.2,

DOE/GO-102000-0960

(September

2000).

(Source:

Amended

at

effective

Section

225.150

Commence

Commercial

Operation

Commence

commercial

operation

means,

for

the

purposes

of

Subparts

C,

D

and

E,

with

regard

to

a

unit:

a)

To

have

begun

to

produce

steam,

gas,

or

other

heated

medium

used

to

generate

electricity

for

sale or

use, including

test

generation,

except

as

provided

in

40

CFR

96.105,

96.205,

or

96.305,

as

incorporated

by

reference

in

Section.

225.140.

1)

For

a

unit

that

is a

CAR

SO

2

unit,

CAR

NO

unit,

or

a

CAR

NO

Ozone

Season

unit

pursuant

to

Sections

225.305,

225.405,

and

225.505,

respectively,

on

the

date

the

unit

commences

commercial

operation

on

the

later

of

November

15,

1990

or

the

date

the

unit

commences

commercial

operation

as

defined

in

subsection

(a)

of

this

Section

and

that

subsequently

undergoes

a

physical

change

(other

than

replacement

of

the

unit

by

a

unit

at

the

same

source),

such date

will

remain

the

unit’s

date

of

commencement

of

commercial

operation,

which

will

continue

to

be

treated

as

the

same

unit.

2)

For

a

unit

that

is

a

CAR

SO

2

unit,

CAIR

NO

unit,

or

a

CAR

NO

Ozone

Season

unit

pursuant

to

Sections

225.305,

225

.405,

and

225.505,

respectively,

on

the

later

of

November

15

1990

or

the

date

the

unit

commences

commercial

operation

as

defined

in

subsection

(a)

of

this Section

and

that

is

subsequently

replaced

by

a

unit

at

the

same

source

(e.g.,

repowered),

such

date

will

remain

the

replaced

unit’s

date

of

commencement

of

commercial

operation,

and

the replacement

unit

will

be

treated

as

a

separate

unit

with

a

separate

date for

commencement

of

commercial

operation

as

defined

in

subsection

(a)

or

(b)

of

this

Section

as

appropriate.

b)

Notwithstanding

subsection

(a)

of

this

Section

and

except

as

provided

in

40

CFR 96.105,

96.205,

or

96.305

for a

unit

that

is

not

aCAIR

SO

2

unit,

CAR

NO

unit,

or

a

CAR

NO

Ozone

Season

unit

pursuant

to

Section

225.305,

225.405,

or

225.505,

respectively,

on

the

later

of

November

15,

1990

or

the date

the

unit

commences

commercial

operation

as

defined

in

subsection

(a)

of

this

Section,

the

unit’s

date

for

commencement

of

15

---

commercial

operation

will

be the

date

on

which

the

unit

becomes

a

CAR

SO

2

unit,

CAR

NO

unit,

or CAR

NO

Ozone

Season

unit

pursuant

to

Section

225.305,

225.405,

or

225.505,

respectively.

1)

For

a

unit

with

a

date

for

commencement

of commercial

operation

as defined

in

subsection

(b)

of

this

Section

and

that

subsequently

undergoes

a

physical

change

(other

than

replacement

of

the

unit

by

a

unit

at

the

same

source),

such

date

will

remain

the

unit’s

date

of

commencement

of

commercial

operation,

which

shall

continue

to

be

treated

as

the

same

unit.

.2)

For

a

unit

with

a

date

for

commencement

of

commercial

operation

as defined

in

subsection

(b)

of

this

Section

and

that

is

subsequently

replaced

by

a

unit

at

the

same

source

(e.g.,

repowered),

such

date

will

remain

the

replaced

unit’s

date

of

commencement

of

commercial

operation,

and

the

replacement

unit

will

be

treated

as

a

separate

unit

with

a

separate

date

for

commencement

of

commercial

operation

as

defined

in subsection

(a)

or

(b)

of

this

Section

as

appropriate.

(Source:

Added

at

31111.

Reg.

12864,

effective

August

31,

2007)

SUBPART

B:

CONTROL

OF

MERCURY

EMISSIONS

FROM

COAL-FIRED

ELECTRIC

GENERATING

UNITS

Section

225.200

Purpose

The

purpose of

this

Subpart

B is

to

control

the

emissions

of

mercury

from

coal-fired

EGU

operating

in

Illinois.

Section

225.202

Measurement

Methods

Measurement

of

mercury

must

be

according

to

the

following:

a)

Continuous

emission

monitoring

pursuant

to

Appendix

B

to

this

Part

or

an

alternative

emissions

monitoring

system,

alternative

reference

method

for

measuring emissions,

or

other

alternative

to

the

emissions

monitoring

and

measurement

requirements

of Sections

225.240

through

225

.290,

if

such

alternative

is

submitted

to

the

Agency

in

writing

and

approved

in

writing

by

the

Manager

of

the

Bureau

of

Air’s

Compliance

Section.

40

CFR

75 (2005).

16

---

b)

ASTM

D3173-03,

Standard

Test

Method

for

Moisture

in the

Analysis

Sample

of

Coal

and

Coke

(Approved

April

10,

2003),

incorporated

by

reference

in

Section

225.140.

c)

ASTM

D3684-0l,

Standard

Test

Method

for

Total

Mercury

in

Coal

by

the

Oxygen

Bomb

Combustion/Atomic

Absorption

Method

(Approved

October

10,

2001),

incorporated

by

reference

in

Section

225.140.

d)

ASTM

D5865-04,

Standard

Test

Method

for

Gross Calorific

Value

of

Coal

and

Coke

(Approved

April 1, 2004),

incorporated

by

reference

in

Section

225.140.

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),

incorporated

by

reference

in

Section

225.140.

f)

ASTM

D6784-02,

Standard

Test

Method

for

Elemental,

Oxidized,

Partible-Bound

and

Total

Mercury

in

Flue

Gas

Generated

from

Coal-Fired

Stationary

Sources

(Ontario

Hydro

Method)

(Approved

April

10,

2002),

incorporated

by

reference

in

Section 225.140.

g)

Emissions

testing

pursuant

to

Appendix

A

of

40

CFR

60.

(Source:

Amended

at

effective

Section

225.205

Applicability

The

following

stationary

coal-fired

boilers

and

stationary

coal-fired

combustion

turbines

are

EGUs

and

are

subject

to this

Subpart

B:

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.

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

co generation

unit,

a

co

generation

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

must

be

subject

to

subsection

(a)

of

this

Section

starting

on

the

day

on

which the

unit

first

no

longer

qualifies

as

a cogeneration

unit.

17

---

Section

225.210

Compliance

Requirements

a)

Permit

Requirements.

The

owner

or

operator

of

each

source

with

one

or

more

EGUs

subject

to this

Subpart

B at

the

source

must

apply

for

a

CAAPP

permit

that

addresses

the

applicable

requirements

of

this

Subpart

B.

b)

Monitoring

and

Testing

Requirements.

1)

The

owner

or

operator

of

each

source

and

each

EGU

at

the

source

must

comply

with

either

the monitoring

requirements

of Sections

225.240

through

225.290

of

this

Subpart

B, the

periodic

emissions

testing

requirements

of

Section

225.239

of this

Subpart

B. or

an alternative

emissions

monitoring

system,

alternative

reference

method

for

measuring

emissions,

or

other

alternative

to

the

emissions

monitoring

and

measurement

requirements

of Sections

225.240

through

225.290,

if

such

alternative

is submitted

to the

Agency

in

writing

and

approved

in

writing

by

the Manager

of

the

Bureau

of

Air’s

Compliance

Section.

2)

The

compliance

of

each

EGU

with

the

mercury

requirements

of

Sections

225.230

and

225.237

of

this

Subpart

B

must

be

determined

by the

emissions

measurements

recorded

and

reported

in

accordance

with

either

Sections

225.240

through

225.290

of this

Subpart

B, Section

225.239

of

this

Subpart

B,

or

an

alternative

emissions

monitoring

system,

alternative

reference

method

for

measuring

emissions,

or

other

alternative

to

the

emissions

monitoring

and

measurement

requirements

of

Sections

225.240

through

225.290,

if

such

alternative

is submitted

to the

Agency

in

writing

and

approved

in

writing

by the

Manager

of the

Bureau

of

Air’s

Compliance

Section.

c)

Mercury

Emission

Reduction

Requirements

-

The

owner

or operator

of

any

EGU

subject

to

this

Subpart

B

must

comply

with

applicable

requirements

for

control

ofmercury

emissions

of

Section

225.230

or

Section

225

.237

of

this

Subpart

B.

d)

Recordkeeping

and

Reporting

Requirements

Unless

otherwise

provided,

the

owner

or

operator

of

a

source

with

one

or

more

EGUs

at the

source

must

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,

in

writing

by

the

Agency,

for

cause,

at

any

time

prior

to

the

end

of

five

years.

18

---

1)

All

emissions

monitoring

information

gathered in

accordance

with

Sections

225

.240

through

225

.290

and

all

periodic

emissions

testing

information

gathered

in

accordance

with

Section

225.239.

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

B.

3)

Copies

of

all

documents

used

to

complete a permit

application

and

any

other

submission

under

this

Subpart B.

e)

Liability.

1)

The

owner

or

operator

of

each

source

with

one

or

more

EGUs

must

meet

the

requirements

of

this

Subpart

B.

2)

Any

provision

of

this

Subpart

B

that

applies

to

a source

must

also

apply

to

the

owner

and

operator

of such

source

and

to

the

owner

or operator

of

each

EGU

at the

source.

3)

Any

provision

of

this

Subpart

B that

applies

to an

EGU

must

also

apply

to

the

owner

or

operator

of such

EGU.

f)

Effect

on

Other Authorities.

No

provision of

this

Subpart

B

maybe

construed

as

exempting

or

excluding

the

owner

or

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.

(Source: Amended

at

effective

)

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

B

is

required

to

submit

a

CAAPP

permit

application

that

addresses

all

applicable

requirements

of

this

Subpart

B,

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

such

EGUs must

submit

an

initial

permit

application

or

application

for

CAAPP permit

modification

that

meets

the

requirements

of

this

Section

on

or

before

December

31,

2008.

19

---

B)

after

December

31,

2008,

the

owner

or

operator

of

any

such

EGU

must

submit

an

initial

CAAPP

permit

application

or

application

for

CAAPP

modification

that

meets

the

requirements

of

this

Section

not

later

than

180

days

before

initial

startup

of

the

EGU,

unless

the

construction

permit

issued

for the

EGU addresses

the

requirements

of

this Subpart

B.

b)

Contents

of

Permit

Applications.

In

addition

to

other

information

required

for

a

complete

application

for

CAAPP

permit

or

CAAPP

permit

modification,

the

application

must

include

the

following

information:

1)

The

ORIS (Office

of

Regulatory

Information

Systems)

or

facility

code

assigned

to

the

source

by

the

U.S. Department

of

Energy,

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

B,

or,

in

the

alternative,

the

applicant

may

include

its

intended

approach

to

the

testing

requirement

of

Section

225

.239

of

this

Subpart

B.

4)

The

intended

approach

to

the

mercury

emission

reduction

requirements

of

Section

225

.230

or

225.237

of

this

Subpart

B,

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

B

must contain

federally

enforceable

conditions

addressing

all

applicable

requirements

of

this

Subpart

B,

which

conditions

must

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

B,

each such

CAAPP

permit

must

also

contain

the

information

specified

under

subsection

(b)

of

this

Section.

(Source:

Amended

at

effective

Section

225.230

Emission

Standards

for

EGUs

at

Existing

Sources

a)

Emission

Standards.

20

---

1)

Except

as

provided

in

Sections

225.230(b)

and

(d).

225.232

through

225.234,

225.239,

and

225.291

through

225.299 of

this

Subpart

B,

beginning

Beginning

July

1,

2009,

the

owner

or

operator

of

a

source

with

one

or

more

EGUs

subject

to

this

Subpart

B

that

commenced

commercial

operation

on

or

before

December

31,

2008, must

comply

with

one

of

the

following

standards

for

each

EGU

on

a

rolling

12-month

basis:

A)

An

emission

standard

of

0.0080

lb

mercury/GWh

gross

electrical

output;

or

B)

A

minimum

90-percent

reduction

of

input

mercury.

2)

For

an

EGU complying

with subsection

(a)(1)(A)

of

this

Section,

the

actual

mercury

emission

rate

of

the

EGU for

each 12-month

rolling

period,

as

monitored

in

accordance

with

this

Subpart

B

and

calculated

as

follows,

must

not

exceed

the

applicable

emission

standard:

ERE

1

÷O

Where:

ER

=

Actual

mercury

emissions

rate

of

the

EGU for

the

particular

12-

month rolling

period,

expressed

in

lb/GWh.

E

=

Actual

mercury

emissions

of

the

EGU,

in

ibs,

in

an

individual

month

in

the

12-month

rolling

period,

as

determined

in

accordance

with

the

emissions

monitoring

provisions

of

this

Subpart

B.

=

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

B.

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

B

and

calculated

as

follows,

must

meet

or

exceed

the

applicable

efficiency

requirement:

CE=100x{1—(E

1

÷J)}

Where:

CE

Actual

control

efficiency

for

mercury

emissions

of the

EGU

for

the

particular

12-month

rolling

period,

expressed

as

a percent.

21

---

E

1

=

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

B.

=

Amount

of

mercury

in

the

fuel

fired in

the

EGU, in

lbs,

in

an

individual

month

in

the

12-month

rolling

period,

as

determined

in

accordance

with

Section

225.265

of

this Subpart

B.

b)

Alternative

Emission

Standards

for

Single

EGUs.

1)

As

an

alternative

to

compliance

with

the

emission

standards

in

subsection

(a)

of

this

Section,

the

owner

or

operator

of

the

EGU may

comply

with

the

emission

standards

of

this

Subpart

B

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

the purpose

of

demonstrating

compliance

with

the

alternative

emission

standards

of

this

subsection

(b), for

each

rolling

12-month

period,

the

actual

emissions

of

mercury

from

the

EGU,

as

monitored

in

accordance

with

this

Subpart

B,

must

not

exceed

the

allowable

emissions

of

mercury

from

the

EGU,

as

further

provided

by

the

following

formulas:

E

12

A

12

E

12

=E

1

A

12

=A

1

Where:

=

Actual

mercury

emissions

of

the

EGU

for

the

particular

12-month

rolling

period.

A

12

=

Allowable

mercury

emissions

of

the

EGU

for

the

particular

12-

month

rolling

period.

E

1

=

Actual

mercury

emissions

of

the

EGU

in

an

individual

month

in

the

12-month

rolling

period.

A

=

Allowable

mercury

emissions

of

the

EGU in

an

individual

month

in

the 12-month

rolling

period,

based

on

either

the

input

mercury

to

the

unit

(Aj’)

or

the electrical

output

from the

EGU

),

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

22

---

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

B,

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

Sections

1.14

through

1.18

of

Appendix

B

to

this

Part,

40

CFR

75,

Subpart

Isuch

that

the

mercury

emissions

of

each

EGU are

not

determined

separately,

compliance

of

the

EGUs with

the

applicable

emission

standards

of

this

Subpart

B

must be

determined

as

if

the

EGUs

were

a

single

EGU.

d)

Alternative

Emission

Standards

for

Multiple

EGUs.

1)

As

an

alternative

to

compliance

with

the

emission

standards

of

subsection

(a)

of

this

Section,

the

owner

or

operator

of

a

source

with

multiple

EGUs

may

comply

with

the

emission

standards

of

this

Subpart

B

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

the

purposes

of

the

alternative

emission

standard

of

subsection

(d)(

1)

of

this

Section,

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

B,

must

not

exceed

the

sum

of

the

allowable

emissions

of

mercury

from

all

the

EGUs

at

the

source,

as

further

provided

by

the

following

formulas:

E

A

A=A

1

Where:

E

5

=

Sum

of

the

actual

mercury

emissions

of

the

EGUs

at

the

source.

A

=

Sum of

the

allowable

mercury

emissions

of

the

EGUs

at

the

source.

23

---

=

Actual

mercury

emissions

of

an

individual

EGU

at

the

source,

as

determined

in

accordance

with

subsection

(b)(2)

of

this

Section.

A

Allowable

mercury

emissions

of

an

individual

EGU

at

the

source,

as

determined

in accordance

with

subsection

(b)(2)

of

this

Section.

n

Number

of

EGUs

covered

by

the

demonstration.

3)

If

an

owner

or

operator

of

a

source

with

two

or

more

EGUs

that

is relying

on

this

subsection

(d)

to

demonstrate

compliance

fails

to meet

the

requirements

of

this

subsection

(d)

in

a

given

12-month

rolling

period,

all

EGUs at

such

source

covered

by

the

compliance

demonstration

are

considered

out

of

compliance

with

the

applicable

emission standards

of

this

Subpart

B

for

the

entire

last

month

of

that

period.

(Source:

Amended

at

effective

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

B,

the

owner

or

operator

of

an

EGU

may

comply

with the

emission

standards

of this

Subpart

B

by

means

of

an

Averaging

Demonstration

(Demonstration)

that

demonstrates

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:

1)

An

emission

standard

of

0.020

lb

mercury/GWh

gross

electrical

output;

or

2)

A

minimum

75

percent

reduction

of

input

mercury.

c)

For

the

purpose

of

this

Section,

compliance

must

be

demonstrated

using

the

equations

in

Section 225

.230(a)(2),

(a)(3),

or

(d)(2),

as

applicable,

addressing

all

EGUs at

the

sources

covered

by

the

Demonstration,

rather

than

by

using

only

the

EGUs

at

one

source.

d)

Limitations

on

Demonstrations.

1)

The

owners

or

operators

of

more

than

one

existing

source

with

EGUs

can

only

participate

in

Demonstrations

that

include

other

existing

sources

that

they

own

or

operate.

2)

Single

Existing

Source

Demonstrations

24

---

A)

The

owner

or

operator

of

only

a

single

existing source

with

EGUs

(i.e.,

City,

Water,

Light

&

Power,

City

of Springfield,

ID

167

12OAAO;

Kincaid

Generating

Station,

1D

0218

14AAB;

and

Southern

Illinois

Power

Cooperative/Marion

Generating

Station,

ID

1

99856AAC)

can

only

participate

in

Demonstrations

with

other

such

owners

or

operators

of

a single existing

source

of

EGUs.

B)

Participation

in

Demonstrations

under

this

Section

by

the

owner

or

operator

of

only a

single

existing

source with

EGUs

must

be

authorized

through

federally

enforceable

permit

conditions

for

each

such

source

participating

in

the

Demonstration.

e)

A

source

may

be

included

in only

one

Demonstration

during

each

rolling

12-

month

period.

1)

The

owner

or

operator

of

EGUs

using

Demonstrations

to

show

compliance

with

this

Subpart

B

must

complete

the

detennination

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

B,

the

effect

of

a

failure

to

demonstrate

compliance

will

be

that

the

compliance

status

of

each

source

must

be

determined

under

Section

225.230 of

this

Subpart

B 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

that

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

must

be

determined

under

Section

225.230

of

this

Subpart

B

as

if

the

sources

were

not

covered

by

a

Demonstration.

Section

225.233

Multi-Pollutant

Standards

(MPS)

a)

General.

1)

As

an

alternative

to

compliance

with

the

emissions

standards

of

Section

225.230(a),

the

owner

of

eligible

EGUs

may

elect

for

those

EGUs

to

demonstrate

compliance

pursuant

to

this

Section,

which

establishes

control

requirements

and

standards

for

emissions

of

NO

and

SO

2

,

as

well

as

for

emissions

of

mercury.

2)

For

the

purpose

of

this

Section,

the

following

requirements

apply:

25

---

A)

An

eligible

EGU

is an

EGU

that

is

located

in

Illinois

and

which

commenced

commercial

operation

on

or

before

December

31,

2004;

and

B)

Ownership

of

an

eligible

EGU

is

determined

based

on

direct

ownership,

by

the