TITLE 35: ENVIRONMENTAL PROTECTION

SUBPART B: NEW FUEL COMBUSTION EMISSION SOURCES
SUBPART K: PROCESS EMISSION SOURCES
SUBPART P: STONE, CLAY, GLASS AND CONCRETE PRODUCTS
SUBPART X: UTILITIES
1. SUBPART A: GENERAL PROVISIONS

TITLE 35: ENVIRONMENTAL PROTECTION

SUBTITLE B: AIR POLLUTION

CHAPTER I: POLLUTION CONTROL BOARD

SUBCHAPTER c: EMISSION STANDARDS AND LIMITATIONS

FOR STATIONARY SOURCES

SULFUR LIMITATIONS

SUBPART A: GENERAL PROVISIONS

214.100 Scope and Organization

214.101 Measurement Methods

214.102 Abbreviations and Units

214.103 Definitions

214.104 Incorporations by Reference

SUBPART B: NEW FUEL COMBUSTION EMISSION SOURCES

214.121 Large Sources

214.122 Small Sources

SUBPART C: EXISTING SOLID FUEL COMBUSTION EMISSION

Sources Located in Metropolitan Areas

Small Sources Located Outside Metropolitan Areas

Large Sources Located Outside Metropolitan Areas

SUBPART D: EXISTING LIQUID OR MIXED FUEL COMBUSTION

EMISSION SOURCES

Liquid Fuel Burned Exclusively

214.162 Combination of Fuels

SUBPART E: AGGREGATION OF SOURCES OUTSIDE

METROPOLITAN AREAS

214.181 Dispersion Enhancement Techniques

214.182 Prohibition

214.183 General Formula

214.184 Special Formula

214.185 Alternative Emission Rate

214.186 New Operating Permits

SUBPART F: ALTERNATIVE STANDARDS FOR SOURCES INSIDE

METROPOLITAN AREAS

Alternative Standards for Sources in Metropolitan Areas

214.202 Dispersion Enhancement Techniques

SUBPART K: PROCESS EMISSION SOURCES

214.301 General Limitation

Exception for Air Pollution Control Equipment

Use of Sulfuric Acid

Fuel Burning Process Emission Source

SUBPART O: PETROLEUM REFINING, PETROCHEMICAL AND

CHEMICAL MANUFACTURING

214.381 Sulfuric Acid Manufacturing

Petroleum and Petrochemical Processes

214.383 Chemical Manufacturing

Sulfate and Sulfite Manufacturing

SUBPART P: STONE, CLAY, GLASS AND CONCRETE PRODUCTS

Glass Melting and Heat Treating

214.402 Lime Kilns

SUBPART Q: PRIMARY AND SECONDARY METAL MANUFACTURING

Combination of Fuels at Steel Mills in Metropolitan Areas

Secondary Lead Smelting in Metropolitan Areas

Slab Reheat Furnaces in St. Louis Area

SUBPART V: ELECTRIC POWER PLANTS

214.521 Winnetka Power Plant

SUBPART X: UTILITIES

E. D. Edwards Electric Generating Station

214.562 Coffeen Generating Station

Rule into Section Table

Section into Rule Table

Method used to Determine Average Actual Stack Height and Effective

Height of Effluent Release

Past Compliance Dates

AUTHORITY: Implementing Section 10 and authorized by Section 27 of the

Environmental Protection Act [415 ILCS 5/10 and 27].

SOURCE: Adopted as Chapter 2: Air Pollution, Rule 204: Sulfur Emission Standards

and Limitations, R71-23, 4 PCB 191, filed and effective April 14, 1972; amended in

R74-2 and R75-5, 32 PCB 295, at 3 Ill. Reg. 5, p. 777, effective February 3, 1979;

amended in R74-2, R75-5, 38 PCB 129, at 4 Ill. Reg. 28, p. 417, effective June 26, 1980;

amended in R78-17, 40 PCB 291, at 5 Ill. Reg. 1892, effective February 17, 1981;

amended in R77-15, 44 PCB 267, at 6 Ill. Reg. 2146, effective January 28, 1982;

amended and renumbered in R80-22(A), at 7 Ill. Reg. 4219, effective March 28, 1983;

codified 7 Ill. Reg. 13597; amended in R80-22(B), at 8 Ill. Reg. 6172, effective April 24,

1984; amended in R84-28, at 10 Ill. Reg. 9806, effective May 20, 1986; amended in R86-

31, at 12 Ill. Reg. 17387, effective October 14, 1988; amended in R86-30, at 12 Ill. Reg.

20778, effective December 5, 1988; amended in R87-31 at 15 Ill. Reg. 1017, effective

January 15, 1991; amended in R02-21 at 27 Ill. Reg. 12101, effective July 11, 2003.

SUBPART A: GENERAL PROVISIONS

Section 214.100 Scope and Organization

a) This Part sets standards and limitations for emission of sulfur from

stationary sources.

b) Permit for sources subject to this Part may be required pursuant to 35 Ill.

c) Notwithstanding the provisions of this Part, the air quality standards

contained in 35 Ill. Adm. Code 243 may not be violated.

d) This Part is divided into Subparts which are grouped as follows:

1) Subpart A: General Provisions

2) Subparts B - J: Fuel Combustion Emission Sources and

3) Subparts K - M: Process Emission Sources

4) Subparts N - End: Industry and site specific rules.

e) These rules have been grouped for the convenience of the public; the

scope of each is determined by its language and history.

Section 214.101 Measurement Methods

A determination of non-compliance based on any subsection of this Section shall not be

refuted by evidence of compliance with any other subsection.

a) Sulfur Dioxide Measurement. Measurement of sulfur dioxide emissions

from stationary sources shall be made according to an applicable method

specified in 40 CFR 60, Appendix A, Method 6, 6A, 6B, or 6C,

incorporated by reference in Section 214.104(a), or by measurement

procedures established pursuant to 40 CFR 60.8(b), incorporated by

reference in Section 214.104(b). (Ill. Rev. Stat. 1989, ch. 111 1/2, par.

b) Sulfuric Acid Mist and Sulfur Trioxide Measurement. Measurement of

sulfuric acid mist and sulfur trioxide shall be according to the barium-

thorin titration method specified in 40 CFR 60, Appendix A, Method 8,

incoporated by reference in Section 214.104(a).

c) Solid Fuel Averaging Measurement Daily Analysis Method. This

subsection applies to sources at plants with total solid fuel-fired heat input

capacity exceeding 439.5 MW (1500 million Btu/hr). If daily fuel analysis

is used to demonstrate compliance or non-compliance with Sections

214.122, 214.141, 214.142(a) 214.162, 214.186 and 214.421, the sulfur

dioxide emission rate to be compared to the emission limit shall be

considered to be the result of averaging daily samples taken over any

consecutive two-month period provided no more than 5 percent of the

sample values are greater than 20 percent above the sample average. If

samples from a source cannot meet this statistical criterion, each

individual daily sample analysis for such source shall be compared to the

source's emission limit to determine compliance. The specific ASTM

procedures, incorporated by reference in Section 214.104(c), shall be used

for solid fuel sampling, sulfur, and heating value determinations.

e) Weekly Analysis Method. This subsection applies to sources at plants

with total solid fuel-fired heat input capacity exceeding 146.5 MW (500

million Btu/hr) but not exceeding 439.5 MW (1500 million Btu/hr). These

plants shall demonstrate compliance or non-compliance with Sections

214.122, 214.141, 214.142(a), 214.162, 214.186 and 214.421 by either an

analysis of calendar weekly composites of daily fuel samples or by

compliance with subsection (c) above, at the option of the plant. The

specific ASTM procedures incorporated by reference in Section

214.104(c), shall be used for sulfur and heating value determinations.

e) Monthly Analysis Method. This subsection applies to sources at plants

with total fuel-fired heat input capacity exceeding 14.65 MW (50 millions

Btu/hr) but not exceeding 146.5 MW (500 million Btu/hr). These plants

shall demonstrate compliance or non-compliance with Sections 214.122,

214.141, 214.142(a), 214.162, 214.186 and 214.421 by either an analysis

of calendar monthly composites of daily fuel samples or by compliance

with subsection (c) above, at the option of the plant. ASTM procedures

incorporated by reference in Section 214.104(c), shall be used for sulfur

and heating value determinations.

f) Small Source Alternative Method. This subsection applies to sources at

plants with total solid fuel-fired heat input capacity not exceeding 14.65

MW (50 million Btu/hr). Compliance or non-compliance with Sections

214.122, 214.141, 214.142(a), 214.162, 214.186 and 214.421 shall be

demonstrated by a calendar month average sulfur dioxide emission rate.

g) Exemptions. Subsections (c) through (f) shall not apply to sources

controlling sulfur dioxide emissions by flue gas desulfurization equipment

or by sorbent injection.

h) Hydrogen Sulfide Measurement. For purposes of determining compliance

with Section 214.382(c), the concentration of hydrogen sulfide in

petroleum refinery fuel gas shall be measured using the Tutwiler

Procedure specified in 40 CFR 60.648, incorporated by reference in

Section 214.104(d).

(Source: Amended at 15 Ill. Reg. 1017, effective January 15, 1991)

a?Section 214.102 Abbreviations and Units

a) The following abbreviations are used in this Part:

British thermal units (60 F)

kilograms per megawatt-hour

pounds per million btu

megagram, metric ton or tonne

million British thermal units

million British thermal units per

megawatt; one million watts

nanogram, one billionth of a

nanograms per Joule

parts per million

standard cubic foot

standard cubic meter

b) The following conversion factors have been used in this Part:

(Source: Amended at 12 Ill. Reg. 20778, effective December 5, 1988)

Section 214.103 Definitions

The definitions of 35 Ill. Adm. Code 201 and 211 apply to this Part.

Section 214.104 Incorporations by Reference

The following materials are incorporated by reference. These incorporations do not

include any later amendments or editions.

a) 40 CFR 60, Appendix A (1989):

1) Method 6: Determination of Sulfur Dioxide Emissions From

Stationary Sources;

2) Method 6A: Determination of Sulfur Dioxide, Moisture, and

Carbon Dioxide Emissions From Fossil Fuel Combustion Sources;

3) Method 6B: Determination of Sulfur Dioxide and Carbon Dioxide

Daily Average Emissions From Fossil Fuel Combustion Sources;

4) Method 6C: Determination of Sulfur Dioxide Emissions From

Stationary Sources (Instrumental Analyzer Procedure);

5) Method 8: Determination of Sulfuric Acid Mist and Sulfur Dioxide

Emissions From Stationary Sources.

b) 40 CFR 60.8(b) (1989), Performance Tests.

c) American Society for Testing and Materials, 1916 Race Street,

Philadelphia, PA 19103:

1) For solid fuel sampling:

ASTM D-2234 (1989)

ASTM D-2013 (1986)

2) For sulfur determinations:

ASTM D-3177 (1984)

ASTM D-2622 (1987)

ASTM D-3180 (1984)

ASTM D-4239 (1985)

3) For heating value determinations:

ASTM D-2015 (1985)

ASTM D-3286 (1985)

d) Tutwiler Procedure for hydrogen sulfide, 40 CFR 60.648 (1989).

(Source: Amended at 15 Ill. Reg. 1017, effective January 15, 1991)

SUBPART B: NEW FUEL COMBUSTION EMISSION SOURCES

Section 214.120 Scope

Subparts B through F contain general rules for sulfur emissions from fuel combustion

emission sources. These may be modified by industry and site specific rules in Subparts

Section 214.121 Large Sources

This section applies to new fuel combustion emission sources with actual heat input

greater than 73.2 MW (250 mmbtu/hr).

a) Solid Fuel Burned Exclusively. No person shall cause or allow the

emission of sulfur dioxide into the atmosphere in any one hour period

from any new fuel combustion emission source greater than 73.2 MW

(250 mmbtu/hr), burning solid fuel exclusively, to exceed 1.86 kg of

sulfur dioxide per MW-hr of actual heat input (1.2 lbs/mmbtu).

(Board Note: This section was invalidated in Commonwealth Edison v.

PCB, 25 Ill. App. 3d 271, 62 Ill.2d 494, 43 N.E.2d 459, 323 N.E. 2d 84,

Ashland Chemical Corp. v. PCB, 64 Ill. App.3d 169, and Illinois State

Chamber of Commerce v. PCB, 67 Ill. App.3d 839, 384 N.E.2d 922, 78

Ill.2d 1, 398 N.E.2d 9.)

b) Liquid Fuel Burned Exclusively. No person shall cause or allow the

emission of sulfur dioxide into the atmosphere in any one hour period

from any new fuel combustion emission source greater than 73.2 MW

(250 mmbtu/hr), burning liquid fuel exclusively:

1) To exceed 1.2 kg of sulfur dioxide per MW-hr of actual heat input

when residual fuel oil is burned (0.8 lbs/mmbtu); and

2) To exceed 0.46 kg of sulfur dioxide per MW-hr of actual heat

input when distillate fuel oil is burned (0.3 lbs/mmbtu).

(Source: Amended at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.122 Small Sources

This section applies to new fuel combustion emission sources with actual heat input

smaller than, or equal to, 73.2 MW (250 mmbtu/hr).

a) Solid Fuel Burned Exclusively. No person shall cause or allow the

emission of sulfur dioxide into the atmosphere in any one hour period

from any new fuel combustion source with actual heat input smaller than,

or equal to, 73.2 MW (250 mmbtu/hr), burning solid fuel exclusively, to

exceed 2.79 kg of sulfur dioxide per MW-hr of actual heat input (1.8

b) Liquid Fuel Burned Exclusively. No person shall cause or allow the

emission of sulfur dioxide into the atmosphere in any one hour period

from any new fuel combustion source with actual heat input smaller than,

or equal to, 73.2 MW (250 mmbtu/hr), burning liquid fuel exclusively:

1) To exceed 1.55 kg of sulfur dioxide per MW-hr of actual heat

input when residential fuel oil is burned (1.0 lbs/mmbtu); and

2) To exceed 0.46 kg of sulfur dioxide per MW-hr of actual heat

input when distillate fuel oil is burned (0.3 lbs/mmbtu).

(Source: Amended at 4 Ill. Reg. 28, p. 417, effective June 26, 1980)

SUBPART C: EXISTING SOLID FUEL COMBUSTION EMISSION SOURCES

Section 214.140 Scope

This Subpart contains rules which establish general sulfur emissions standards for

existing solid fuel emission sources. These may be modified by industry and site-specific

rules in Subparts N, et seq.

(Source: Added at 10 Ill. Reg. 9806, effective May 20, 1986)

b?Section 214.141 Sources Located in Metropolitan Areas

Except as otherwise provided in this Part, no person shall cause or allow the emission of

sulfur dioxide into the atmosphere in any one hour period from any existing fuel

combustion source, burning solid fuel exclusively, located in the Chicago, St. Louis

(Illinois) or Peoria major metropolitan areas, to exceed 1.8 pounds of sulfur dioxide per

mmBtu of actual heat input (774 nanograms per joule).

a) Sources located in Kankakee or McHenry Counties shall not exceed 6.8

pounds of sulfur dioxide per mmBtu of actual heat input (2,924 nanograms

per joule) in any one hour period.

b) Existing industrial sources, not equipped with flue gas desulfurization

systems as of December 1, 1980, located in the Peoria major metropolitan

area, shall not exceed 5.5 pounds of sulfur dioxide per mmBtu of actual

heat input (2,365 nanograms per joule) in any one hour period, provided

the emissions from any such source located in the City of Peoria exit from

a stack which is at least 154 feet (47 meters) in height.

c) Sections 214.122 and 214.101(c) shall not apply to any fuel combustion

emission sources equipped with flue gas desulfurization systems as of

December 1, 1980, and located in the City of East Peoria as the city

boundaries were then defined. No person shall cause or allow the emission

of sulfur dioxide into the atmosphere in any one hour period from any

such sources to exceed 1.4 pounds of sulfur dioxide per mmBtu of actual

heat input (602 nanograms per joule).

d) Sections 214.122 and 214.101(c) shall not apply to any fuel combustion

emission sources which are capable of firing solid fuel at a heat input of

more than 125 mmBtu per hour (36.6 megawatts) and which as of

December 1, 1980, are equipped with flue gas desulfurization systems and

are located in Hollis Township, Peoria County, as the township boundaries

were then defined. No person shall cause or allow the emission of sulfur

dioxide into the atmosphere in any one hour period from any such sources

to exceed 1.1 pounds of sulfur dioxide per mmBtu of actual heat input

(473 nanograms per joule).

(Source: Amended at 10 Ill. Reg. 9806, effective May 20, 1986)

c?Section 214.142 Small Sources Located Outside Metropolitan Areas

This section applies to existing fuel combustion sources with actual heat input less than,

or equal to, 73.2 MW (250 mmbtu/hr) located outside the Chicago, St. Louis (Illinois) or

Peoria major metropolitan areas. No person shall cause or allow the emission of sulfur

dioxide into the atmosphere in any one hour period from any existing fuel combustion

source with actual heat input less than, or equal to, 73.2 MW (250 mmbtu/hr), burning

solid fuel exclusively, located outside the Chicago, St. Louis (Illinois) or Peoria major

metropolitan areas, to exceed either of the following, whichever such person determines

a) 10.5 kg of sulfur dioxide per MW-hr of actual heat input (6.8 lbs/mmbtu),

provided such owner or operator complies with all applicable provisions

of Section 214.186, or

b) The emission limit provided by Subpart E.

(Source: Amended at 4 Ill. Reg. 28, p. 217, effective June 26, 1980)

d?Section 214.143 Large Sources Located Outside Metropolitan Areas

This section applies to existing fuel combustion sources with actual heat input greater

than 73.2 MW (250 mmbtu/hr) located outside the Chicago, St. Louis (Illinois) or Peoria

major metropolitan areas. No person shall cause or allow the emission of sulfur dioxide

into the atmosphere in any one hour period from any existing fuel combustion source

with actual heat input greater than 73.2 MW (250 mmbtu/hr), burning solid fuel

exclusively, located outside the Chicago, St. Louis (Illinois) or Peoria major metropolitan

areas, to exceed the emission limit provided by Subpart E.

(Source: Amended at 4 Ill. Reg. 28, p. 417, effective June 26, 1980)

a?SUBPART D: EXISTING LIQUID OR MIXED FUEL COMBUSTION

EMISSION SOURCES

e?Section 214.161 Liquid Fuel Burned Exclusively

No person shall cause or allow the emission of sulfur dioxide into the atmosphere in any

one hour period from any existing fuel combustion emission source, burning liquid fuel

a) To exceed 1.55 kg of sulfur dioxide per MW-hr of actual heat input when

residual fuel oil is burned (1.0 lbs/mmbtu);

b) To exceed 0.46 kg of sulfur dioxide per MW-hr of actual heat input when

distillate fuel oil is burned (0.3 lbs/mmbtu).

f? Section 214.162 Combination of Fuels

a) No person shall cause or allow the emission of sulfur dioxide into the

atmosphere in any one hour period from any fuel combustion emission

source burning simultaneously any combination of solid, liquid and

gaseous fuels to exceed the allowable emission rate determined by the

following equation:

E = AX + BY + CZ

b) Symbols in the equation mean the following:

E = allowable sulfur dioxide emission rate;

A = solid fuel sulfur dioxide emission standard which is

B = distillate oil sulfur dioxide emission standard determined

from the table in subsection (d);

C = residual fuel oil sulfur dioxide emission standard which is

X = actual heat input from solid fuel;

Y = actual heat input from distillate fuel oil;

Z = actual heat input from residual fuel oil;

c) That portion of the actual heat input that is derived:

1) From the burning of gaseous fuels produced by the gasification of

solid fuels shall be included in X;

2) From the burning of gaseous fuels produced by the gasification of

distillate fuel oil shall be included in Y;

3) From the burning of gaseous fuels produced by the gasification of

residual fuel oil shall be included in Z;

4) From the burning of gaseous fuels produced by the gasification of

any other liquid fuel shall be included in Z; and,

5) From the burning of by-product gases such as those produced from

a blast furnace or a catalyst regeneration unit in a petroleum

refinery shall be included in Z.

d) Metric or English units may be used in the equation of subsection (a) as

(Source: Amended at 7 Ill. Reg. 4219, effective March 28, 1983)

b?SUBPART E: AGGREGATION OF SOURCES OUTSIDE

METROPOLITAN AREAS

g?Section 214.181 Dispersion Enhancement Techniques

No owner or operator of an existing fuel combustion emission source shall comply with

the emission standards of this Subpart by the use of dispersion enhancement techniques.

Dispersion enhancement techniques shall include, but not be limited to, an intermittent

control system or an increase of: stack height in excess of good engineering practice

necessary to prevent downwash or fumigation conditions, stack diameter, exit gas

velocity, or exit gas temperature, except as provided by Section 123 of the Clean Air Act

(42 U.S.C. 7423) and regulations promulgated thereunder. Flue gas may be reheated

where air pollution control equipment results in a reduction of flue gas temperature,

provided that the degree of reheat does not exceed the temperature drop across such air

pollution control equipment.

(Source: Amended at 3 Ill. Reg. 5, p. 777, effective February 3, 1979)

h?Section 214.182 Prohibition

No person shall cause or allow the total emissions of sulfur dioxide into the atmosphere

in any one hour period from all fuel combustion emission sources, located outside of the

Chicago, St. Louis (Illinois) or Peoria major metropolitan areas, owned or operated by

such person and located within a one mile radius (1.6 km) from the center point of any

such fuel combustion emission source to exceed the emissions determined by the

following Sections 214.183 through 214.185, whichever is applicable.

i? Section 214.183 General Formula

a) The general formula is:

b) Symbols used in the general formula mean the following:

E = Total allowable emission of sulfur dioxide into the atmosphere in

any one-hour period from all fuel combustion emission sources

owned or operated by such person and located within a 1.6 km (1

mile) radius from the center point of any such emission source.

X = Average actual stack height as determined by method outlined in

Y = Effective height of effluent release as determined by method

outlined in Appendix C.

c) The general formula may be used with either metric or English units as

0.007813 lbs/hr

(Source: Amended at 4 Ill. Reg. 28, p. 417, effective June 26, 1980)

j? Section 214.184 Special Formula

a) If the maximum total emissions of sulfur dioxide into the atmosphere in

any one hour period from all fuel combustion emission sources owned or

operated by any person and located within a 1 mile (1.6 km) radius from

the center point of any such fuel combustion emission sources exceed,

during normal cyclical variations in firing rate and fuel, the emissions

allowed under Section 214.183 but, as of April 1, 1978, were in

compliance with either the formula detailed below or a Pollution Control

Board (Board) order, then the owner or operator of the emission sources

shall not cause or allow such emissions to exceed the emissions allowed

under Section 214.183 or the formula detailed below, whichever the

owner or operator of the emission sources determines shall apply.

H = P1 H1 + P2 H2 + ... Pn Hn

(Note: P1 + P2 ... Pn = 1)

c) As used in these equations, symbols mean the following:

E = total emission of sulfur dioxide, in pounds per hour, into the

atmosphere in any one hour period from all fuel combustion

emission sources owned or operated by such person and located

within a 1 mile radius from the center point of any such emission

Pi, i = 1, 2,...,

percentage of total emissions E

emitted from source I divided by

Hi, i = 1, 2,...,

physical height in feet above grade

(Source: Amended at 4 Ill. Reg. 28, p. 417, effective June 26, 1980)

Section 214.185 Alternative Emission Rate

Any owner or operator of a fuel combustion emission source may petition the Board for

approval of an emission rate applicable to any one hour period for all fuel combustion

emission sources owned or operated by such person and located within a one mile (1.6

km) radius from the center point of any such fuel combustion emission source. Such

person shall prove in an adjudicative hearing before the Board that the proposed emission

rate will not under any forseeable operating conditions and potential meteorological

conditions cause or contribute to a violation of any applicable primary or secondary

sulfur dioxide ambient air quality standard or violate any applicable prevention of

significant deterioration (PSD) increment. An emission rate approved pursuant to this

Section shall be a substitute for that standard determined by Section 214.183 or 214.184.

a) Every owner or operator of a fuel combustion emission source petitioning

the Board for approval of an emission standard pursuant to this Section

shall follow the applicable procedures described in 35 Ill. Adm. Code

Subtitle A, Chapter I.

b) Any emission standard approved pursuant to this Section shall be included

as a condition to operating permits issued pursuant to 35 Ill. Adm. Code

201. Any owner or operator of a fuel combustion emission source who

receives Board approval of an emission standard pursuant to this Section

shall apply to the Illinois Environmental Agency (Agency) within 30 days

of approval of such standard for a revision of its operating permit for such

c) The Agency shall impose as a condition to a permit to operate a source

pursuant to an emission standard approved pursuant to this Section an

ambient sulfur dioxide monitoring and dispersion modeling program

designed to verify that such emission standard will not cause or contribute

to violations of any applicable primary or secondary sulfur dioxide

ambient air quality standard. Such ambient monitoring and dispersion

modeling program shall be operated for at least one year commencing no

later than 6 months after the date of approval of an emission rate pursuant

to this Section.

d) No more than 15 months after the commencement of the ambient

monitoring and dispersion modeling program of subsection (c) the owner

or operator shall apply for a new operating permit. The owner or operator

shall submit, at the time of the application, a report containing the results

of the ambient monitoring and dispersion modeling program.

(Source: Amended at 4 Ill. Reg. 28, p. 417, effective June 26, 1980)

Section 214.186 New Operating Permits

No owner or operator of a fuel combustion emission source whose sulfur dioxide

emission limitation is determined by Section 214.142, 214.183 or 214.184 shall cause or

allow the total emissions of sulfur dioxide into the atmosphere from all fuel combustion

emission sources owned or operated by such person and located within 1 mile radius (1.6

km) from the center point of any such fuel combustion source to exceed the level of

sulfur dioxide emission allowed under the previous Rule 204 (effective April 14, 1972

until December 14, 1978) without first obtaining a new operating permit from the

Agency. The application for a new operating permit shall include a demonstration that

such total emissions will not violate any applicable PSD increment.

(Source: Amended at 4 Ill. Reg. 28, p. 417, effective June 26, 1980)

SUBPART F: ALTERNATIVE STANDARDS FOR SOURCES INSIDE

METROPOLITAN AREAS

Section 214.201 Alternative Standards for Sources in Metropolitan Areas

Any owner or operator of an existing fuel combustion emission source located in the

Chicago, St. Louis (Illinois) or Peoria major metropolitan areas may petition the Board

for approval of an alternate emission rate specified in emissions of pounds of sulfur

dioxide per mmbtu of actual heat input for any such fuel combustion emission source, up

to a maximum or 6.8 pounds of sulfur dioxide per mmbtu of actual heat input (10.5

kg/MW-hr). Such person shall prove in an adjudicative hearing before the Board that the

proposed emission rate will not, under predictable worst case conditions cause or

contribute to a violation of any applicable primary or secondary sulfur dioxide ambient

air quality standard or of any applicable prevention of significant deterioration increment.

An emission rate approved pursuant to this Section shall be a substitute for that standard

otherwise required by this Part.

a) Every owner or operator of an existing fuel combustion emission source

so petitioning the Board for approval of an emission standard shall follow

the applicable procedures described in 35 Ill. Adm. Code, Subtitle A,

b) Any emission standard so approved shall be included as a condition in

operating permits issued pursuant to 35 Ill. Adm. Code 201. Any owner or

operator of a fuel combustion emission source who receives Board

approval of such an emission standard shall apply to the Agency within 30

days of approval of such standard for a revision of its operating permit for

c) No owner or operator of an existing fuel combustion emission source shall

seek such an exemption or comply with the emission standard so granted

by the use of dispersion enhancement techniques referred to in Section

(Source: Adopted at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.202 Dispersion Enhancement Techniques

No owner or operator of an existing fuel combustion emission source shall comply with

the emission standards of this Subpart by the use of dispersion enhancement techniques.

Dispersion enhancement techniques shall include, but not be limited to, an intermittent

control system or an increase of: stack height in excess of good engineering practice

necessary to prevent downwash or fumigation conditions, stack diameter, exit gas

velocity, or exit gas temperature, except as provided by Section 123 of the Clean Air Act

(42 U.S.C.A. 7423) and regulations promulgated thereunder. Flue gas may be reheated

where air pollution control equipment results in a reduction of flue gas temperature,

provided that the degree of reheat does not exceed the temperature drop across such air

pollution control equipment.

(Source: Amended at 7 Ill. Reg. 4219, effective March 28, 1983)

SUBPART K: PROCESS EMISSION SOURCES

Section 214.300 Scope

Subpart K contains general rules for sulfur emissions from process sources. These may

be modified by industry and site specific rules in Subparts N et seq.

Section 214.301 General Limitation

Except as further provided by this Part, no person shall cause or allow the emission of

sulfur dioxide into the atmosphere from any process emission source to exceed 2000

(Source: Amended at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.302 Exception for Air Pollution Control Equipment

Section 214.301 shall not apply to processes designed to remove sulfur compounds from

the flue gases of fuel combustion emission sources.

(Source: Amended at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.303 Use of Sulfuric Acid

With the exception of fuel combustion emission sources and acid manufacturing, no

person using sulfuric acid shall cause or allow the emission of sulfuric acid and/or sulfur

trioxide from all other similar emission sources at a plant or premises to exceed:

a) 45.4 grams in any one hour period for sulfuric acid usage less than 1180

Mg/yr (100 percent acid basis) (0.10 lbs/hr up to 1300 T/yr);

b) 250 grams per metric ton of acid used for sulfuric acid usage greater than

or equal to 1180 Mg/yr (100 percent acid basis) (0.50 lbs/T over 1300

(Source: Amended at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.304 Fuel Burning Process Emission Source

The emissions from the burning of fuel at process emission sources located in the

Chicago or St. Louis (Illinois) major metropolitan areas shall comply with applicable

Subparts B through F, except as follows: No person shall cause or allow the emissions of

sulfur into the atmosphere in any one hour period from burning tea leaves as fuel to

exceed 0.70 pounds of sulfur dioxide per mmbtu of actual heat input.

(Source: Added at 7 Ill. Reg. 4219, effective March 28, 1983)

SUBPART O: PETROLEUM REFINING, PETROCHEMICAL AND

CHEMICAL MANUFACTURING

Section 214.380 Scope

a) This Subpart contains rules which modify the general sulfur emission

rules of Subparts A through M as applied to a given industry or at a given

site. General rules include:

1) Subparts B through I, fuel combustion emission sources and

2) Subparts K through M, process emission sources.

b) These rules have been grouped for the convenience of the public; the

scope of each is determined by its language and history. Rules placed in

this Subpart include those which appear to be primarily directed at the

following major industry groups:

1) Chemicals and allied products;

2) Petroleum refining and related industries;

3) Rubber and miscellaneous plastics products.

Section 214.381 Sulfuric Acid Manufacturing

a) No person shall cause or allow the emission of sulfur dioxide into the

atmosphere from any new sulfuric acid manufacturing plant to exceed 4.0

pounds of sulfur dioxide per ton of acid produced (2.0 kg/Mg).

b) No person shall cause or allow the emission of sulfuric acid mist into the

atmosphere from any process emission source to exceed 0.15 pounds of

acid mist per ton of acid manufactured (75 g/Mg).

c) No person shall cause or allow the emission of sulfur dioxide into the

atmosphere from any sulfuric acid manufacturing process in the City of

Chicago to exceed 500 ppm.

(Source: Amended at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.382 Petroleum and Petrochemical Processes

a) Section 214.301 shall not apply to existing processes designed to remove

sulfur compounds from the flue gases of petroleum and petrochemical

b) No person shall cause or allow the emission of more than 1,000 ppm of

sulfur dioxide into the atmosphere from any process emission source in

the St. Louis (Illinois) major metropolitan area designed to remove sulfur

compounds from the flue gases of petroleum and petrochemical processes.

c) The following limitations apply to any petroleum refinery in the Village of

1) No person shall cause or allow the combustion of refinery flasher

pitch containing more than 3.0% (three percent) sulfur by weight.

This shall be demonstrated by daily sampling of refinery flasher

2) No person shall burn petroleum refinery fuel gas in any fuel gas

combustion device if that refinery fuel gas contains more than 39

grains hydrogen sulfide per 100 dry standard cubic feet (893

mg/scm). This shall be demonstrated by sampling the refinery fuel

gas once every eight hours, pursuant to the Tutwiler Procedure

(Section 214.104(c)).

3) No person shall cause or allow the total emission of sulfur dioxide

into the atmosphere from the following source groupings to exceed

the following amounts:

A) All process heaters at distilling unit No. 1 - 459 lbs/hr (208

B) All process heaters at distilling unit No. 2 - 1260 lbs/hr

C) All gas plant process heaters - 159 lbs/hr (72.1 kg/hr).

D) All vacuum flasher unit heaters - 378 lbs/hr (171 kg/hr).

E) All process heaters at the alkylation, benzene extraction

unit and catalytic feed hydrotreating units - 346 lbs/hr (157

F) All boilers generating steam for general plant use - 2,400

lbs/hr (1,090 kg/hr).

G) All heaters serving the hydrocracker unit catalytic reformer

No. 1, and the saturates gas plant - 1,660 lbs/hr (753 kg/hr).

H) All process heaters at the aromatics east process - 768

lbs/hr (348 kg/hr).

I) All catalytic cracking units - 3,430 lbs/hr (1,560 kg/hr).

J) All asphalt converters, distilling unit No. 1, the aromatics

east process, all boilers generating steam for general plant

use, and all gas plant process heaters - 2,710 lbs/hr (1,230

d) Compliance with the emission limitations of subsections (b) and (c)(3) of

this Section shall be demonstrated on a three-hour block average basis.

Such demonstrations shall require, as a permit condition, that data as

required by the Illinois Environmental Protection Agency (35 Ill. Adm.

Code 201.161) be maintained in order to adequately determine the sulfur

dioxide emission rate from each source operations group.

e) Sources in the Village of Roxana are not subject to the emission

limitations of Section 214.162 when burning refinery flasher pitch or

refinery fuel gas.

f) Individual process emission sources in the Village of Roxana are still

subject to the emission limitation of Section 214.301 notwithstanding their

inclusion in a source operations group.

g) Notwithstanding the provisions of 35 Ill. Adm. Code 201.102 of this

Chapter, any physical change in any emission source subject to subsection

(b), (c), (d), or (e) of this Section which alters the height of release,

temperature or volumetric flow rate of the effluent gases of such source, or

alters the diameter of the exit stack, shall be deemed a modification for the

purposes of 35 Ill. Adm. Code 201.142 of this Chapter.

(Source: Amended at 12 Ill. Reg. 20778, effective December 5, 1988)

Section 214.383 Chemical Manufacturing

Section 214.301 shall not apply to existing hydrogen sulfide flares at a chemical

manufacturing plant provided:

a) Said flares are operative on existing batch type processes; and

b) The hydrogen sulfide emissions being flared are not, as of September 11,

1975, passed through existing processes designed to remove sulfur

compounds from the flue gases as provided in Section 214.382(a); and

c) The emission of sulfur dioxide into the atmosphere from said flares does

not exceed 500 pounds per hour and 3500 pounds per eight-hour period

(230 kg/hr and 1590 kg/8 hrs); and

d) Provided, however, that if emission controls for said flares become

economically reasonable and technically feasible the owner/operator of

such hydrogen sulfide flares shall install such controls.

(Source: Amended at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.384 Sulfate and Sulfite Manufacturing

Section 214.301 shall not apply to sodium aluminum sulfate and sodium sulfite

manufacturing process emission sources in the St. Louis (Illinois) major metropolitan

(Source: Adopted at 7 Ill. Reg. 4219, effective March 28, 1983)

SUBPART P: STONE, CLAY, GLASS AND CONCRETE PRODUCTS

Section 214.400 Scope

a) This Subpart contains rules which modify the general sulfur emission

rules of Subparts A through M as applied to a given industry or at a given

site. General rules include:

1) Subparts B through I, fuel combustion emission sources and

2) Subparts K through M, process emission sources.

b) These rules have been grouped for the convenience of the public; the

scope of each is determined by its language and history. Rules placed in

this Subpart include those which appear to be primarily directed at the

following major industry group: stone, clay, glass and concrete products.

Section 214.401 Glass Melting and Heat Treating

Section 214.301 shall not apply to:

a) Glass melting furnaces in the Chicago or St. Louis (Illinois) major

metropolitan areas.

b) Glass heat treating with sulfur dioxide in the St. Louis (Illinois) major

metropolitan area.

(Source: Adopted at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.402 Lime Kilns

Section 214.304 notwithstanding, lime kilns (Standard Industrial Code 32) are not subject

to limitations for sulfur dioxide emission.

(Source: Adopted at 7 Ill. Reg. 4219, effective March 28, 1983)

SUBPART Q: PRIMARY AND SECONDARY METAL

MANUFACTURING

Section 214.420 Scope

a) This Subpart contains rules which modify the general sulfur emission

rules of Subparts A through M as applied to a given industry or at a given

site. General rules include:

1) Subparts B through I, fuel combustion emission sources and

2) Subparts K through M, process emission sources.

b) These rules have been grouped for the convenience of the public; the

scope of each is determined by its language and history. Rules placed in

this Subpart include those which appear to be primarily directed at the

following major industry groups:

1) Primary metal industries (including primary and secondary

production of ferrous and nonferrous metals);

2) Fabricated metal products.

Section 214.421 Combination of Fuels at Steel Mills in Metropolitan Areas

a) Section 214.162 notwithstanding, no person shall cause or allow the

emission of sulfur dioxide into the atmosphere in any one hour period

from any existing fuel combustion emission source at a steel mill located

in the Chicago or St. Louis (Illinois) major metropolitan area burning any

solid, liquid or gaseous fuel, or any combination thereof, to exceed the

allowable emission rate determined by the following equation:

E = AW + BX + CY + DZ

b) Symbols in the equation mean the following:

E = allowable sulfur dioxide emission rate;

A = solid fuel sulfur dioxide emission standard which is

B = distillate oil sulfur dioxide emission standard determined

from the table in subsection (d);

C = residual oil sulfur dioxide emission standard which is

D = maximum by-product gas sulfur dioxide emissions which

would result if the applicable by-product gas which was

burned had been burned alone at any time during the 12

months preceding the latest operation, on or before March

28, 1983, of an emission source using any by-product gas.

W = actual heat input from solid fuel;

X = actual heat input from distillate fuel oil;

Y = actual heat input from residual fuel oil;

Z = actual heat input from by-product gases, such as those

produced from a blast furnace.

c) That portion of the actual heat input that is derived:

1) From the burning of gaseous fuels produced by the gasification of

solid fuels shall be included in W;

2) From the burning of gaseous fuels produced by the gasification of

distillate fuel oil shall be included in X;

3) From the burning of gaseous fuels produced by the gasification of

residual fuel oil shall be included in Y; and

4) From the burning of gaseous fuels produced by the gasification of

any other liquid fuel shall be included in Z.

d) Metric or English units may be used in the equation of subsection (a) as

(Source: Adopted at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.422 Secondary Lead Smelting in Metropolitan Areas

Section 214.301 shall not apply to secondary lead smelting process emission sources in

the Chicago or St. Louis (Illinois) major metropolitan areas.

(Source: Adopted at 7 Ill. Reg. 4219, effective March 28, 1983)

Section 214.423 Slab Reheat Furnaces in St. Louis Area

Section 214.304 notwithstanding, slab reheat furnaces in the St. Louis (Illinois) major

metropolitan area with fuel burning capacities in excess of 650 mmbtu/hr and burning

any residual fuel shall not be subject to the applicable Subpart B through F so long as the

total sulfur dioxide emissions resulting from the burning of residual fuel oil in all such

furnaces at any one steel mill do not exceed 730 lbs/hr.

(Source: Adopted at 7 Ill. Reg. 4219, effective March 28, 1983)

SUBPART V: ELECTRIC POWER PLANTS

Section 214.521 Winnetka Power Plant

Notwithstanding Sections 214.101 and 214.141, the Village of Winnetka Electric Utility

Plant shall not cause or allow the emission of sulfur dioxide into the atmosphere in any

one hour period from its existing fuel combustion sources, burning solid fuel exclusively,

to exceed 5.7 pounds of sulfur dioxide per mmbtu of actual heat input (8.8 kg/MW-hour).

Compliance with this limitation shall be demonstrated on the basis of a daily average.

(Source: Added at 8 Ill. Reg. 6172, effective April 24, 1984)

SUBPART X: UTILITIES

Section 214.560 Scope

a) This Subpart contains rules which modify the general sulfur emission

rules of Subparts A through M as applied to a given industry or at a given

site. General rules include:

1) Subparts B through I: Fuel combustion emission sources and

2) Subparts K through M: Process emission sources.

b) These rules have been grouped for the convenience of the public; the

scope of each is determined by its language and history. Rules placed in

this Subpart include those which appear to be primarily directed at the

following major industry groups: electric, gas and sanitary services.

(Source: Added at 10 Ill. Reg. 9806, effective May 20, 1986)

Section 214.561 E. D. Edwards Electric Generating Station

Sulfur dioxide emissions from Boiler Nos. 1, 2, and 3 at the Edwards Station may not

exceed the limits listed in this Section. CILCO must determine compliance with these

limits on a daily basis using the sulfur dioxide methodology of the Phase II Acid Rain

Program set forth in 40 CFR 75.

a) The average sulfur dioxide emissions from Boiler Nos. 1, 2, and 3, as a group

may not exceed 4.71 pounds per million British thermal units (lb/mmBtu) of

actual heat input;

b) The average sulfur dioxide emissions from any one boiler may not exceed 6.6

lb/mmBtu of actual heat input; and

c) Sulfur dioxide emissions for all three boilers, as a group, may not exceed

34,613 pounds per hour, on a 24-hour average basis.

(Source: Amended at 27 Ill. Reg. 12101, effective July 11, 2003)

Section 214.562 Coffeen Generating Station

a) The emission standards of this subsection shall apply only if the

requirements of subsections (b), (c), and (d) are fulfilled. Notwithstanding

any other limitation contained in this Part, whenever the coal burned is

mined exclusively from the mine that is presently known as Monterey

Coal Company's No. 1 Mine located south of Carlinville, emission of

sulfur dioxide from Units 1 and 2 at the Central Illinois Public Service

Company's (CIPS) Coffeen Generating Station (Coffeen), located in

Montgomery County, shall not exceed either of the following emission

1) 29,572 kilograms of sulfur dioxide in any one hour (65,194 lbs/hr);

2) 11.29 kilograms of sulfur dioxide per megawatt-hour of heat input

(7.29 lbs/mmbtu).

b) CIPS shall conduct an ambient sulfur dioxide monitoring and dispersion

modeling program designed to demonstrate that the emission standards of

subsection (a) will not cause or contribute to violations of any applicable

primary or secondary sulfur dioxide ambient air quality standard as set

forth in Section 243.122. Such ambient monitoring and dispersion

modeling program shall be operated for at least one year commencing no

later than 6 months after Coffeen is legally able and begins to operate at

an emission rate greater than 55,555 pounds of sulfur dioxide per hour.

c) No more than 15 months after the commencement of the ambient

monitoring and dispersion modeling program of subsection (b), CIPS shall

apply for a new operating permit. CIPS shall submit to the Environmental

Protection Agency (Agency), at the time of the application, a report

containing the results of the ambient monitoring and dispersion modeling

program of subsection (b) and the results of all relevant stack tests

conducted prior to the report's submission.

d) No later than six months after Coffeen is legally able and begins to operate

at an emission rate greater than 55,555 pounds of sulfur dioxide per hour,

a stack test shall be conducted in accordance with Section 214.101(a), in

order to determine compliance with emission standards set forth in

subsection (a). After the stack test is conducted, the results shall be

submitted to the Agency within 90 days. The requirements of this

subsection do not preclude the Agency from requiring additional stack

(Source: Added at 12 Ill. Reg. 17387, effective October 14, 1988)

Rule into Section Table

214.183, Appendix C

204(c)(2)(A) and (B)

214.181, 212.202

Section into Rule Table

Added in Codification

Added in Codification

Added in Codification

Added in Codification

Added in Codification

204(c)(2)(A)&(B)

Added in Codification

204(j)(intro)&(2)

Added in Codification

204(k)(1)(D)&(E)

Added in Codification

204(k)(1)(G)&(H)

Added in Codification

Added in Codification

Added in Codification

Method used to Determine Average Actual

Stack Height and Effective Height

of Effluent Release

Q (Btu/sec) = Heat emission rate as determined by method outlined below.

H (feet) = Plume rise.

H = Physical height in feet, above grade of each stack, except that for purposes of this

calculation the value used for such stack height shall not exceed good engineering

practice as defined by Section 123 of the Clean Air Act and Regulations

promulgated thereunder, unless the owner or operator of the source demonstrates

to the Agency that a greater height is necessary to prevent downwash or

fumigation conditions.

T (Degrees Rankine) = Exit temperature of stack gases from each source during

operating conditions which would cause maximum

V (feet/sec) = Exit velocity of stack gases from each source under operating

conditions which would cause maximum emissions.

D (feet) = Diameter of stack.

P = Percentage of total emissions expressed as decimal equivalents emitted from each

source. Example: 21% = 0.21. NOTE: The sum of P1 + P2 ... + Pn = 1. The

emission values to be used are those which occur during operating conditions

which would cause maximum emissions.

X = Average actual stack height.

Y = Effective height of effluent release.

STEP 1: Determine weighted average stack parameters utilizing the following

D = P1 D1 + P2 D2 + ... + Pn Dn

V = P1 V1 + P2 V2 + ... + Pn Vn

T = P1 T1 + P2 T2 + ... + Pn Tn

X = P1 H1 + P2 H2 + ... + Pn Hn

P1, D1, V1, T1, and H1 are the percentage of total emissions, stack diameter, exit

velocity of gases, exit temperature of stack gases, and physical stack height, respectively,

for the first source; P2, D2, V2, T2, and H2 are the respective values for the second

source; similarly, Pn, Dn, Vn, Tn and Hn are the respective values for the nth source,

where n is the number of the last source.

STEP 2: Calculate heat emission rate utilizing the following formula and the

weighted average stack parameters obtained in Step 1:

Q + 7.54D2V (T - 515)

STEP 3: Calculate plume rise utilizing the appropriate formula given below and the

total heat emission rate obtained in Step 2:

for Q 6000 btu/sec.

for Q 6000 btu/sec.

STEP 4: Calculate the weighted average facility effective height of effluent release

utilizing the plume rise obtained in Step 3, the average stack height

obtained in Step 1 and the formula given below:

STEP 5: Calculate the total facility hourly emission limitation utilizing the

weighted actual stack height obtained in Step 1, the effective stack height

given in Step 4, and the following formula:

Past Compliance Dates

Compliance Date

New fuel combustion emission sources.

St. Louis (Illinois) and Peoria MMA's with

actual heat input less than, or equal to, 250 million

(a) Sources determining that the 6.8

lbs/MMBTU standard shall apply

December 14, 1978

(b) Sources determining that Rule 204(e) shall

See Rule 204(e)

Existing sources outside the Chicago, St. Louis

(Illinois) and Peoria MMA's with actual heat input

greater than 250 million Btu per hour

See Rule 204(e)

Fuel combustion sources located outside

Chicago, St. Louis (Illinois) and Peoria MMA's

which obtain an alternate emission rate

December 14, 1978

(a) If source is in compliance with the previous

Rule 204(e) (effective April 14, 1972 until

December 14, 1978) prior to December 14, 1978

commencement of

modeling pursuant to

Rule 204(e)(3)(C)

(b) If source is not in compliance with the

previous Rule 204(e) (effective from April 14,

1972 until December 14, 1978) prior to December

Date of approval of

alternate standard

Existing sources in the Chicago, St. Louis

(Illinois) or Peoria MMA's burning solid fuel

Existing sources in the Chicago, St. Louis

(Illinois) or Peoria MMA's burning solid fuel

exclusively which obtain an alternate emission rate

Date of approval of

alternate standard

Existing sources burning liquid fuel exclusively

Combination of fuels sources except at a steel

Combination of fuels sources at a steel mill

Fuel burning process emission sources

Process emission sources

Existing sources

December 31, 1973

December 14, 1978

Process emission sources

New sources in the St. Louis (Illinois) MMA

designed to remove sulfur compounds from the

flue gases of petroleum and petrochemical

processes and sulfuric acid manufacturing

processes in the City of Chicago

Sources having emissions of sulfuric acid mist

Existing sources

December 31, 1973

December 14, 1978