1. ILLINOIS POLLUTION CONTROL BOARD
    2. SUBCHAPTER c: EMISSION STANDARDS AND LIMITATIONS FOR STATIONARY SOURCES PART 217 NITROGEN OXIDES EMISSIONS
    3. SUBPART A: GENERAL PROVISIONS
    4. SUBPART B: NEW FUEL COMBUSTION EMISSION SOURCES
      1. E = (AG + BL + CS) Q
    5. English
    6. Metric
    7. SUBPART C: EXISTING FUEL COMBUSTION EMISSION UNITS SOURCES
      1. E = (AG + BL + CS) Q
    8. English
    9. Metric
    10. UNact ≤ Nall
    11. UWhere:
    12. U1)U UActual emissions must be determined as follows:
    13. UWhen emission limits are prescribed in lb/mmBtu,
    14. UEMact(i) = Eact(i) x Hi/2000
    15. When emission limits are prescribed in lb/ton of processed product,
    16. EMact(i) = Eact(i) x Pi/2000
    17. 2) Allowable emissions must be determined as follows:
    18. When emission limits are prescribed in lb/mmBtu,
    19. EMall(i) = Eall(i) x Hi/2000
    20. When emission limits are prescribed in lb/ton of processed product,
    21. EMall(i) = Eall(i) x Pi/2000
    22. Where:

 
ILLINOIS POLLUTION CONTROL BOARD
August 20, 2009
IN THE MATTER OF:
NITROGEN OXIDES EMISSIONS FROM
VARIOUS SOURCE CATEGORIES:
AMENDMENTS TO 35 ILL. ADM. CODE
PARTS 211 AND 217
)
)
)
)
)
)
R08-19
(Rulemaking - Air)
Adopted Rule. Final Notice.
OPINION AND ORDER OF THE BOARD (by A.S. Moore):
Today the Board adopts its final order in this rulemaking amending Parts 211 and 217 of
its air pollution regulations and addressing emissions of nitrogen oxides (NO
x
).
On May 9, 2008, the Illinois Environmental Protection Agency (Agency or Illinois EPA
or IEPA) filed a proposal under the general rulemaking provisions of Sections 27 and 28 of the
Environmental Protection Act (Act) (415 ILCS 5/27, 28 (2008)). On both January 30, 2009, and
March 23, 2009, the Agency filed motions to amend the proposal, both of which the Board
granted. On April 2, 2009, the Board granted the Agency’s motion for expedited review of this
proposal.
After conducting three public hearings, the Board on May 7, 2009, adopted its first-notice
opinion and order in this proceeding.
See
33 Ill. Reg. 6896, 6921 (May 22, 2009). In that
opinion and order, the Board largely adopted the Agency’s proposal, including changes proposed
in the two motions to amend. At its meeting on August 18, 2009, the Joint Committee on
Administrative Rules (JCAR) considered the Board’s second notice proposal and issued its
Certificate of No Objection to the proposed rules. JCAR has proposed technical changes, which
the Board incorporates in its final rules.
Generally, the adopted rules amend Parts 211 and 217 of the Board’s air pollution
regulations (35 Ill. Adm. Code 211, 217) to control NO
x
emissions from major stationary sources
in the nonattainment areas and from emission units including industrial boilers, process heaters,
glass melting furnaces, cement kilns, lime kilns, furnaces used in steelmaking and aluminum
melting, and fossil fuel-fired stationary boilers at such sources.
In this opinion, the Board first provides the procedural history of this rulemaking and
background on regulation of NO
x
emissions. The Board then addresses technical and economic
consideration before reaching its conclusion. Finally, the Board’s order directs the Clerk to file
the adopted amendments with the Secretary of State for publication in the
Illinois Register
.
PROCEDURAL HISTORY

2
On May 9, 2008, the Agency filed a rulemaking proposal under the general rulemaking
provisions of Sections 27 and 28 of the Act. 415 ILCS 5/27, 28 (2008). A Statement of Reasons
(Statement) and a Technical Support Document accompanied the proposal. A motion for waiver
of copy requirements also accompanied the proposal. In an order dated June 5, 2008, the Board
accepted the Agency’s proposal for hearing and granted the Agency’s motion for waiver.
In a letter dated June 6, 2008, the Board requested that the Department of Commerce and
Economic Opportunity (DCEO) conduct an economic impact study (EcIS) of the Agency’s
rulemaking proposal.
See
415 ILCS 5/27(b) (2008). DCEO has not responded to the Board’s
request.
In an order dated June 12, 2008, the hearing officer scheduled a first hearing to begin on
October 14, 2008, in Springfield and a second hearing to begin December 9, 2008, in Chicago.
The order directed participants wishing to testify at the first hearing to pre-file their testimony no
later than September 2, 2008. The order also directed participants to pre-file questions based on
the Agency’s pre-filed testimony no later than September 16, 2008. Finally, the order directed
the Agency to pre-file written answers to those pre-filed questions no later than September 30,
2008.
On August 29, 2008, the Agency pre-filed testimony by Mr. Robert Kaleel, Mr. Vir
Gupta, and James E. Staudt, Ph.D.
On September 15, 2008, Midwest Generation filed questions for the Agency’s witnesses.
On September 16, 2008, ExxonMobil Oil Corporation (ExxonMobil) filed questions for the
Agency’s witnesses. Also on September 16, 2008, the Illinois Environmental Regulatory Group
(IERG) filed questions for the Agency’s witnesses. On September 30, 2008, the Agency filed
three documents: answers to questions submitted by Midwest Generation (MG Answers);
answers to questions submitted by ExxonMobil; and answers to questions submitted by IERG.
The first hearing took place as scheduled on October 14, 2008, in Springfield. At the first
hearing, the hearing officer admitted into the record four exhibits:
Finding of Failure to Submit State Implementation Plans Required for the 1997 8-Hour
Ozone NAAQS, 73 Fed. Reg. 15416-21 (Mar. 24, 2008) (Exh. 1);
[Illinois Environmental Protection] Agency Analysis of Economic and Budgetary Effects
of Proposed Rulemaking (35 Ill. Adm. Code 211) (Exh. 2);
[Illinois Environmental Protection] Agency Analysis of Economic and Budgetary Effects
of Proposed Rulemaking (35 Ill. Adm. Code 217) (Exh. 3); and
Cleaver Brooks letter dated May 19, 2006, to New Hampshire Division of Environmental
Services (Exh. 4).
On October 24, 2008, the Board received the transcript of the first hearing.

3
On November 5, 2008, the Agency filed its responses to questions raised at the first
hearing (PC 1).
On November 25, 2008, the Board received pre-filed testimony for the December 9,
2008, hearing from Mr. Scott Miller and Mr. Kent Wanninger on behalf of Midwest Generation,
from Ms. Deirdre K. Hirner and Mr. David J. Kolaz on behalf of IERG, from Mr. Larry G.
Siebenberger and Mr. Blake E. Stapper on behalf of U.S. Steel, and from Mr. David W. Dunn on
behalf of ConocoPhillips. Also on November 25, 2008, the Board received pre-filed comments
submitted by ArcelorMittal. In addition, on November 25, 2008, the Board received post-
hearing comments relating to the October 14, 2008 hearing from Saint-Gobain Containers, Inc.
(Saint-Gobain) (PC 2).
The second hearing took place as scheduled on December 9 and 10, 2008, in Chicago.
No one presented testimony concerning DCEO’s decision not to conduct an EcIS.
See
415 ILCS
5/27(a) (2008); Tr.3 at 96-97. Over the two days of the second hearing, the hearing officer
admitted into the record fourteen exhibits:
Pre-Filed Testimony of Deirdre K. Hirner on Behalf of the Illinois Environmental
Regulatory Group (Exh. 5);
Pre-Filed Testimony of David J. Kolaz on Behalf of the Illinois Environmental
Regulatory Group (Exh. 6);
from Final Rule to Implement the 8-Hour Ozone National Ambient Air Quality
Standard; Final Rule, 70 Fed. Reg. 71657 (Nov. 29, 2005) (Exh. 7);
Summary of NO
x
Budget Allocations and Usage 2004-2007 (Exh. 8);
Pre-Filed Testimony of David W. Dunn on Behalf of ConocoPhillips Company (Exh. 9);
Pre-Filed Testimony of Larry G. Siebenberger on Behalf of United States Steel
Corporation (Exh. 10);
Pre-Filed Testimony of Blake E. Stapper on Behalf of United States Steel Corporation
(Exh. 11);
Testimony of Scott Miller of Behalf of Midwest Generation (Exh. 12);
Testimony of Kent Wanninger on Behalf of Midwest Generation (Exh. 13);
IHS-CERA Power Capital Costs Index (PCCI) (Graph Included on Page 7 of Kent
Wanninger’s Testimony on Behalf of Midwest Generation) (Exh. 14);
Baldwin 3 graph (Exh. 15);
Joliet 71 boiler graph (Exh. 16);

4
Bureau of Labor Statistics Producer Price Index. Commodities Group: Metals and metal
products Item: Hot rolled bars, plates, and structural shapes (December 4, 2008) (Exh.
17); and
Bureau of Labor Statistics Producer Price Index. Commodities Group: Metals and metal
products Item: Carbon scrap steel (Dec. 4, 2008) (Exh. 18).
On December 30, 2008, the Board received the transcript of December 10, 2008, the second day
of the second hearing (Tr.3). On January 5, 2009, the Board received the transcript of December
9, 2008, the first day of the second hearing.
In an order dated December 23, 2008, the hearing officer scheduled a third hearing for
February 3, 2009, in Edwardsville and directed participants wishing to testify at the third hearing
to pre-file testimony no later than January 20, 2009.
On January 20, 2009, the Board received post-hearing comments from IERG (PC 3),
Saint-Gobain (PC 4), and ConocoPhillips (PC 5). Also on January 20, 2009, the Board received
pre-filed testimony on behalf of the Agency from Mr. Robert Kaleel (Kaleel Pre-filed Test. 2),
Mr. Michael Koerber, and James E. Staudt, Ph.D. Also on January 20, 2009, the Agency filed a
motion to correct the transcript of the second hearing.
On January 30, 2009, the Agency filed a motion to amend its rulemaking proposal.
On January 30, 2009, the Board received supporting materials from U.S. Steel. (PC 6).
On February 2, 2009, the Board received pre-filed testimony of Mr. Blake E. Stapper on behalf
of U.S. Steel. On February 3, 2009, the Board received a public comment from Mr. James L.
Kavanaugh of the Missouri Department of Natural Resources (PC 7).
The third hearing took place as scheduled on February 3, 2009, in Edwardsville. No one
presented testimony concerning DCEO’s decision not to conduct an EcIS.
See
415 ILCS 5/27(a)
(2008). During the third hearing, the hearing officer admitted into the record seven exhibits:
Western Michigan Ozone Study: Draft Report (January 21, 2009) (Exh. 19);
Calculation of Available COG after Consumption in Reheat Furnaces (Exh. 20);
Calculation of Siebenberger Exhibit A Information — COG burned in reheat furnaces per
Siebenberger December testimony (Exh. 21);
Total Boiler COG Usage from Attachment C (Exh. 22);
Calculation of Siebenberger Exhibit A Information — with 2008 COG rate, 35 day
scrubber maint. (Exh. 23);

5
Calculation of Siebenberger Exhibit A Information — with 2008 COG rate, no COG
scrubber maint. (Exh. 24); and
Pre-Filed Testimony of Blake E. Stapper on Behalf of United States Steel Corporation
(Exh. 25).
On February 11, 2009, the Board received the transcript of the third hearing.
In an order dated February 19, 2009, the Board granted the Agency’s motion to amend its
rulemaking proposal and also granted the Agency’s motion to correct the transcript of the second
hearing.
On March 19, 2009, the Agency filed a motion for expedited review. Also on March 19,
2009, the Agency forwarded to the Board’s Acting Chairman, Dr. G. Tanner Girard, a letter from
the United States Environmental Protection Agency (USEPA) (PC 8). On March 20, 2009, the
Board received Midwest Generation’s response to the Agency’s motion for expedited review.
On March 23, 2009, the Board received from Agency Director Douglas P. Scott a letter
regarding expedited review of the Agency’s amended proposal. On March 26, 2009, the Board
received IERG’s response to the Agency’s motion for expedited review. In an order dated April
2, 2009, the Board granted the Agency’s motion for expedited review.
On March 23, 2009, the Board received post-hearing comments from Midwest
Generation (PC 9), ArcelorMittal (PC 10), U.S. Steel (PC 12), IERG (PC 13), and
ConocoPhillips (PC 14). Also on March 23, 2009, the Board received post-hearing comments
from the Agency (PC 11), accompanied by the Agency’s second motion to amend its rulemaking
proposal.
On May 7, 2009, the Board issued its first notice opinion and order.
See
33 Ill. Reg.
6896, 6921 (May 22, 2009). Among other action, that opinion granted the Agency’s second
motion to amend its rulemaking proposal.
On July 1, 2009, the Board received a comment submitted by ArcelorMittal (PC 15). On
July 6, 2009, the Board received comments submitted by IERG (PC 16), the Agency (PC 17),
ConocoPhillips (PC 18), and U.S. Steel (PC 19). On July 7, 2009, ArcelorMittal filed a motion
for leave to file a response to the Agency’s first notice comment, accompanied by its response
(PC 20). On July 8, 2009 the Board received comments submitted by the U.S. Department of
Energy and the Argonne National Laboratory (PC 21). On July 15, 2009, the Agency filed a
motion for leave to file
instanter
a response to the first notice comments of U.S. Steel and
ArcelorMittal, accompanied by its response to those comments (PC 22).
On July 23, 2009, the Board adopted its second notice opinion and order. At its meeting
on August 18, 2009, JCAR considered the Board’s second notice proposal and issued its
Certificate of No Objection to the proposed rules. JCAR has proposed technical changes, which
the Board incorporates in its final rules.
BACKGROUND ON REGULATION OF NO
x
EMISSIONS

6
NO
x
is one of the primary precursors to the formation of ozone and is also a precursor to
the formation of PM
2.5
.
1
Statement at 2, 3.
The Agency reports that, “[o]n July 18, 1997, USEPA revised the NAAQS [National
Ambient Air Quality Standard] for ozone by replacing the 1-hour standard with an 8-hour
standard.” Statement at 3, citing 62 Fed. Reg. 38856 (July 18, 1997). Illinois includes two areas
designated as nonattainment for the 8-hour ozone standard. Statement at 3. The Chicago
nonattainment area includes Cook, DuPage, Kane, Lake, McHenry, and Will Counties, Goose
Lake and Aux Sable Townships in Grundy County, and Oswego Township in Kendall County.
Id
. The Metro East nonattainment area includes Jersey, Madison, Monroe, and St. Clair
Counties.
Id.
at 3, 5.
The Agency also reports that, “[o]n July 18, 1997, USEPA revised the NAAQS for
particulate matter to add new standards for fine particles, using PM
2.5
as the indicator, and
established primary annual and 24-hour standards for PM
2.5
.” Statement at 4, citing 62 Fed. Reg.
38652 (July 18, 1997). The Agency states that USEPA has recently strengthened the 24-hour
standard. Statement at 4, citing 71 Fed. Reg. 61144 (Oct. 17, 2006). Illinois includes two areas
designated nonattainment for the PM
2.5
standard. Statement at 4. The Chicago nonattainment
area includes Cook, DuPage, Kane, Lake, McHenry, and Will Counties, Goose Lake and Aux
Sable Townships in Grundy County, and Oswego Township in Kendall County.
Id
. at 4-5. The
Metro East nonattainment area includes Madison, Monroe, and St. Clair Counties and Baldwin
Township in Randolph County.
Id
. at 5, citing 40 C.F.R. § 81.314.
The Agency states that Section 110 of the Clean Air Act (CAA) and other related
provisions require states to submit for USEPA approval State Implementation Plans (SIP) “that
provide for the attainment and maintenance of standards established by USEPA through control
programs directed to sources of the pollutants involved.” Statement at 2, citing 42 U.S.C. §
7410. The Agency further states that “[t]he CAA also provides for the State to address emissions
sources on an area-specific basis through such requirements as reasonably available control
measures (“RACM”) and reasonable available control technology (“RACT”).” Statement at 2,
citing 42 U.S.C §§ 7502, 7511a. Specifically, the CAA requires Illinois for each nonattainment
area “to demonstrate that it has adopted ‘all reasonably available control measures as
expeditiously as possible (including such reductions in emissions from existing sources in the
area as may be obtained through the adoption, at a minimum, of reasonable available control
technology) and shall provide for attainment of the national primary ambient air quality
standards.’” Statement at 2, 5, citing 42 U.S.C. § 7502(c)(1).
The Agency characterizes RACT as “[a] subset of RACM.” Statement at 6, citing 44
Fed. Reg. 53762 (Sept. 17, 1979). The Agency defines RACT as “the lowest emission limitation
that a particular source can meet by applying a control technique that is reasonably available
considering technological and economic feasibility.” Statement at 6, citing 44 Fed. Reg. 53762
(Sept. 17, 1979). The Agency states that “Section 182(b)(2) of the CAA requires states to adopt
RACT rules for all areas designated nonattainment for ozone and classified as moderate or
1
“PM
2.5
refers to particulate matter that is 2.5 micrometers or smaller in size.” Statement at 4.

7
above.” Statement at 6-7, citing 42 U.S.C. § 7511a(b)(2). The Agency further states that Section
182(f) of the CAA requires each state in which all or part of a moderate nonattainment area is
located to adopt RACT for major NO
x
sources. Statement at 7, citing 42 U.S.C. § 7511a(f). The
Agency notes that “Section 302 of the CAA defines ‘major stationary source’ as any stationary
facility or source of air pollutants that directly emits, or has the potential to emit, one hundred
tons per year or more of any air pollutant.” Statement at 7, citing 42 U.S.C. § 7602.
The Agency argues that these authorities “establish the requirements for Illinois to submit
NO
x
RACT regulations for all major stationary sources of NO
x
in PM
2.5
nonattainment areas and
ozone nonattainment areas classified as moderate and above.” Statement at 7, citing 72 Fed.
Reg. 20586 (Apr. 25, 2007); 70 Fed. Reg. 71612 (Nov. 29, 2005). The Agency further argues
that, because Illinois includes nonattainment areas classified as moderate and above for the 8-
hour ozone NAAQS, it was “required to submit by September 15, 2006, a SIP demonstrating that
sources specified under the CAA were subject to RACT requirements.” Statement at 7-8, citing
70 Fed. Reg. 71612 (Nov. 29, 2005). The Agency claims that, “[o]n March 24, 2008, USEPA
made a finding that Illinois, among other states, failed to make a RACT submittal required under
Part D of Title I of the CAA for its two moderate nonattainment areas.” Statement at 8, citing 73
Fed. Reg. 15416 (Mar. 24, 2008). The Agency notes that “[s]uch finding starts the 18-month
emission offset sanctions clock and 24-month highway funding sanctions clock under Section
179(a) and (b) of the CAA and the 24-month clock for the promulgation by USEPA of a Federal
Implementation Plan under Section 110(c) of the CAA”. Statement at 8, citing 42 U.S.C. §§
7509(a) and (b), 7410(c).
In testimony for the third hearing, Mr. Kaleel stated that USEPA on December 22, 2008,
designated areas as nonattainment for the 24-hour PM
2.5
standard. Kaleel Pre-filed Test. 2 at 3.
He further stated that, in Illinois, USEPA has designated “the same areas designated previously
as nonattainment for the annual PM
2.5
standard.”
Id
. He added that “Illinois must develop an
attainment plan and adopt control measures needed to attain the 24-hour PM
2.5
standard within
three years of the effective date of U.S. EPA’s decision, and Illinois must attain the standards
within five years of the effective date.”
Id
.
Mr. Kaleel also addressed the establishment of nonattainment areas for the 2008 8-hour
ozone standard. He stated that the Agency’s “initial proposal is for Illinois to recommend to
USEPA to establish nonattainment boundaries for the 2008 standard that generally match the
boundaries already established for the 1997 ozone standard.” Kaleel Pre-filed Test. 2 at 3. He
anticipated that USEPA will complete nonattainment designations in 2010, “initiating a new
cycle of planning and regulatory development.”
Id
. at 3-4. He expects that, because NO
x
is a
precursor to both ozone and PM
2.5
, NO
x
emission reductions will improve air quality.
Id
. at 4.
He argues that “[t]he reductions provided by the subject NO
x
RACT proposal will help to meet
the new standards and should help to address any future requirements to implement RACT for
the new standards.”
Id
. Specifically, he claims that, “[u]nless USEPA issues new guidance
regarding NO
x
control technology, we expect that this RACT proposal will satisfy requirements
to implement NO
x
RACT under the revised NAAQS for the source categories and geographic
areas to which this proposal applies.” MG Answers at 1.
ECONOMIC REASONABLENESS AND TECHNICAL FEASIBILITY

8
Although the Board in a letter dated June 6, 2008, requested that DCEO conduct an
economic impact study of the Agency’s rulemaking proposal (
see
415 ILCS 5/27(b) (2008)), the
Board received no response to that request. At the second hearing, the Board received no
testimony or comment regarding the absence of a response to the request.
See
Tr.3 at 96-97.
In its first notice opinion and order, the Board addressed the economic reasonableness
and technical feasibility of the Agency’s proposal. The Board noted that the Agency had
negotiated with interested participants and agreed to revise certain provisions in order to
memorialize agreements with them. Amendments to 35 Ill. Adm. Code 217, Nitrogen Oxides
Emissions, and 35 Ill. Adm. Code 211, R08-19, slip op. at 20 (May 7, 2009), citing Mot. Amend
1 at 1-2; Mot. Amend 2 at 1-5. The Board noted that these amendments addressed issues
including, but not limited to, compliance deadlines, deadlines for installing CEMS, and
emissions limitations. Amendments to 35 Ill. Adm. Code 217, Nitrogen Oxides Emissions, and
35 Ill. Adm. Code 211, R08-19, slip op. at 20 (May 7, 2009). The Board found that, having
granted the Agency’s two motions to amend the proposal and having reviewed the entire record
in this proceeding, the proposed rules were technically feasible and economically reasonable.
Id
.
In its second notice opinion and order, the Board again addressed the economic
reasonableness and technical feasibility of the proposed rules. The Board noted that, in its first
notice comments, the Agency had proposed additional clarifications of and correction to its
proposal. Amendments to 35 Ill. Adm. Code 217, Nitrogen Oxides Emissions, and 35 Ill. Adm.
Code 211, R08-19, slip op. at 36 (July 23, 2009). The Board found that, having incorporated
those additional clarifications and corrections and having reviewed the entire record in this
proceeding, the proposed rules were technically feasible and economically reasonable.
Id
.
Since adopting that second notice opinion and order, the Board has adopted only non-
substantive amendments proposed by JCAR. Thus, the Board finds that the adopted regulations
technically feasible and economically reasonable and below directs the Clerk to file them with
the Secretary of State for publication in the
Illinois Register
.
ORDER
The Board directs the Clerk to file the following adopted amendments with the Secretary
of State for publication in the
Illinois Register
. Additions are underlined, and deletions appear
stricken.
TITLE 35: ENVIRONMENTAL PROTECTION
SUBTITLE B: AIR POLLUTION
CHAPTER I: POLLUTION CONTROL BOARD
SUBCHAPTER c: EMISSION STANDARDS AND LIMITATIONS FOR
STATIONARY SOURCES
PART 211
DEFINITIONS AND GENERAL PROVISIONS

9
SUBPART A: GENERAL PROVISIONS
Section
211.101
Incorporations by Reference
211.102
Abbreviations and Conversion Factors
SUBPART B: DEFINITIONS
Section
211.121
Other Definitions
211.122
Definitions (Repealed)
211.130
Accelacota
211.150
Accumulator
211.170
Acid Gases
211.210
Actual Heat Input
211.230
Adhesive
211.240
Adhesion Promoter
211.250
Aeration
211.270
Aerosol Can Filling Line
211.290
Afterburner
211.310
Air Contaminant
211.330
Air Dried Coatings
211.350
Air Oxidation Process
211.370
Air Pollutant
211.390
Air Pollution
211.410
Air Pollution Control Equipment
211.430
Air Suspension Coater/Dryer
211.450
Airless Spray
211.470
Air Assisted Airless Spray
211.474
Alcohol
211.479
Allowance
211.484
Animal
211.485
Animal Pathological Waste
211.490
Annual Grain Through-Put
211.495
Anti-Glare/Safety Coating
211.510
Application Area
211.530
Architectural Coating
211.550
As Applied
211.560
As-Applied Fountain Solution
211.570
Asphalt
211.590
Asphalt Prime Coat
211.610
Automobile
211.630
Automobile or Light-Duty Truck Assembly Source or Automobile or Light-Duty
Truck Manufacturing Plant
211.650
Automobile or Light-Duty Truck Refinishing
211.660
Automotive/Transportation Plastic Parts
211.665
Auxiliary Boiler

10
211.670
Baked Coatings
211.680
Bakery Oven
211.685
Basecoat/Clearcoat System
211.690
Batch Loading
211.695
Batch Operation
211.696
Batch Process Train
211.710
Bead-Dipping
211.730
Binders
211.740
Brakehorsepower (rated-bhp)
211.750
British Thermal Unit
211.770
Brush or Wipe Coating
211.790
Bulk Gasoline Plant
211.810
Bulk Gasoline Terminal
211.820
Business Machine Plastic Parts
211.830
Can
211.850
Can Coating
211.870
Can Coating Line
211.890
Capture
211.910
Capture Device
211.930
Capture Efficiency
211.950
Capture System
211.953
Carbon Adsorber
211.955
Cement
211.960
Cement Kiln
211.970
Certified Investigation
211.980
Chemical Manufacturing Process Unit
211.990
Choke Loading
211.995
Circulating Fluidized Bed Combustor
211.1010
Clean Air Act
211.1050
Cleaning and Separating Operation
211.1070
Cleaning Materials
211.1090
Clear Coating
211.1110
Clear Topcoat
211.1120
Clinker
211.1130
Closed Purge System
211.1150
Closed Vent System
211.1170
Coal Refuse
211.1190
Coating
211.1210
Coating Applicator
211.1230
Coating Line
211.1250
Coating Plant
211.1270
Coil Coating
211.1290
Coil Coating Line
211.1310
Cold Cleaning
211.1312
Combined Cycle System
211.1315
Combustion Tuning

11
211.1316
Combustion Turbine
211.1320
Commence Commercial Operation
211.1324
Commence Operation
211.1328
Common Stack
211.1330
Complete Combustion
211.1350
Component
211.1370
Concrete Curing Compounds
211.1390
Concentrated Nitric Acid Manufacturing Process
211.1410
Condensate
211.1430
Condensible PM-10
211.1435
Container Glass
211.1465
Continuous Automatic Stoking
211.1467
Continuous Coater
211.1470
Continuous Process
211.1490
Control Device
211.1510
Control Device Efficiency
211.1515
Control Period
211.1520
Conventional Air Spray
211.1530
Conventional Soybean Crushing Source
211.1550
Conveyorized Degreasing
211.1570
Crude Oil
211.1590
Crude Oil Gathering
211.1610
Crushing
211.1630
Custody Transfer
211.1650
Cutback Asphalt
211.1670
Daily-Weighted Average VOM Content
211.1690
Day
211.1710
Degreaser
211.1730
Delivery Vessel
211.1740
Diesel Engine
211.1750
Dip Coating
211.1770
Distillate Fuel Oil
211.1780
Distillation Unit
211.1790
Drum
211.1810
Dry Cleaning Operation or Dry Cleaning Facility
211.1830
Dump-Pit Area
211.1850
Effective Grate Area
211.1870
Effluent Water Separator
211.1875
Elastomeric Materials
211.1880
Electromagnetic Interference/Radio Frequency Interference (EMI/RFI) Shielding
Coatings
211.1885
Electronic Component
211.1890
Electrostatic Bell or Disc Spray
211.1900
Electrostatic Prep Coat
211.1910
Electrostatic Spray
211.1920
Emergency or Standby Unit

12
211.1930
Emission Rate
211.1950
Emission Unit
211.1970
Enamel
211.1990
Enclose
211.2010
End Sealing Compound Coat
211.2030
Enhanced Under-the-Cup Fill
211.2050
Ethanol Blend Gasoline
211.2070
Excess Air
211.2080
Excess Emissions
211.2090
Excessive Release
211.2110
Existing Grain-Drying Operation (Repealed)
211.2130
Existing Grain-Handling Operation (Repealed)
211.2150
Exterior Base Coat
211.2170
Exterior End Coat
211.2190
External Floating Roof
211.2210
Extreme Performance Coating
211.2230
Fabric Coating
211.2250
Fabric Coating Line
211.2270
Federally Enforceable Limitations and Conditions
211.2285
Feed Mill
211.2290
Fermentation Time
211.2300
Fill
211.2310
Final Repair Coat
211.2330
Firebox
211.2350
Fixed-Roof Tank
211.2355
Flare
211.2357
Flat Glass
211.2360
Flexible Coating
211.2365
Flexible Operation Unit
211.2370
Flexographic Printing
211.2390
Flexographic Printing Line
211.2410
Floating Roof
211.2420
Fossil Fuel
211.2425
Fossil Fuel-Fired
211.2430
Fountain Solution
211.2450
Freeboard Height
211.2470
Fuel Combustion Emission Unit or Fuel Combustion Emission Source
211.2490
Fugitive Particulate Matter
211.2510
Full Operating Flowrate
211.2530
Gas Service
211.2550
Gas/Gas Method
211.2570
Gasoline
211.2590
Gasoline Dispensing Operation or Gasoline Dispensing Facility
211.2610
Gel Coat
211.2620
Generator
211.2625
Glass Melting Furnace

13
211.2630
Gloss Reducers
211.2650
Grain
211.2670
Grain-Drying Operation
211.2690
Grain-Handling and Conditioning Operation
211.2710
Grain-Handling Operation
211.2730
Green-Tire Spraying
211.2750
Green Tires
211.2770
Gross Heating Value
211.2790
Gross Vehicle Weight Rating
211.2810
Heated Airless Spray
211.2815
Heat Input
211.2820
Heat Input Rate
211.2830
Heatset
211.2850
Heatset Web Offset Lithographic Printing Line
211.2870
Heavy Liquid
211.2890
Heavy Metals
211.2910
Heavy Off-Highway Vehicle Products
211.2930
Heavy Off-Highway Vehicle Products Coating
211.2950
Heavy Off-Highway Vehicle Products Coating Line
211.2970
High Temperature Aluminum Coating
211.2990
High Volume Low Pressure (HVLP) Spray
211.3010
Hood
211.3030
Hot Well
211.3050
Housekeeping Practices
211.3070
Incinerator
211.3090
Indirect Heat Transfer
211.3100
Industrial Boiler
211.3110
Ink
211.3130
In-Process Tank
211.3150
In-Situ Sampling Systems
211.3170
Interior Body Spray Coat
211.3190
Internal-Floating Roof
211.3210
Internal Transferring Area
211.3230
Lacquers
211.3250
Large Appliance
211.3270
Large Appliance Coating
211.3290
Large Appliance Coating Line
211.3300
Lean-Burn Engine
211.3310
Light Liquid
211.3330
Light-Duty Truck
211.3350
Light Oil
211.3355
Lime Kiln
211.3370
Liquid/Gas Method
211.3390
Liquid-Mounted Seal
211.3410
Liquid Service
211.3430
Liquids Dripping

14
211.3450
Lithographic Printing Line
211.3470
Load-Out Area
211.3475
Load Shaving Unit
211.3480
Loading Event
211.3483
Long Dry Kiln
211.3485
Long Wet Kiln
211.3487
Low-NOx Burner
211.3490
Low Solvent Coating
211.3500
Lubricating Oil
211.3510
Magnet Wire
211.3530
Magnet Wire Coating
211.3550
Magnet Wire Coating Line
211.3570
Major Dump Pit
211.3590
Major Metropolitan Area (MMA)
211.3610
Major Population Area (MPA)
211.3620
Manually Operated Equipment
211.3630
Manufacturing Process
211.3650
Marine Terminal
211.3660
Marine Vessel
211.3670
Material Recovery Section
211.3690
Maximum Theoretical Emissions
211.3695
Maximum True Vapor Pressure
211.3710
Metal Furniture
211.3730
Metal Furniture Coating
211.3750
Metal Furniture Coating Line
211.3770
Metallic Shoe-Type Seal
211.3780
Mid-Kiln Firing
211.3790
Miscellaneous Fabricated Product Manufacturing Process
211.3810
Miscellaneous Formulation Manufacturing Process
211.3830
Miscellaneous Metal Parts and Products
211.3850
Miscellaneous Metal Parts and Products Coating
211.3870
Miscellaneous Metal Parts or Products Coating Line
211.3890
Miscellaneous Organic Chemical Manufacturing Process
211.3910
Mixing Operation
211.3915
Mobile Equipment
211.3930
Monitor
211.3950
Monomer
211.3960
Motor Vehicles
211.3965
Motor Vehicle Refinishing
211.3970
Multiple Package Coating
211.3980
Nameplate Capacity
211.3990
New Grain-Drying Operation (Repealed)
211.4010
New Grain-Handling Operation (Repealed)
211.4030
No Detectable Volatile Organic Material Emissions
211.4050
Non-Contact Process Water Cooling Tower
211.4055
Non-Flexible Coating

15
211.4065
Non-Heatset
211.4067
NOx Trading Program
211.4070
Offset
211.4090
One Hundred Percent Acid
211.4110
One-Turn Storage Space
211.4130
Opacity
211.4150
Opaque Stains
211.4170
Open Top Vapor Degreasing
211.4190
Open-Ended Valve
211.4210
Operator of a Gasoline Dispensing Operation or Operator of a Gasoline
Dispensing Facility
211.4230
Organic Compound
211.4250
Organic Material and Organic Materials
211.4260
Organic Solvent
211.4270
Organic Vapor
211.4280
Other Glass
211.4290
Oven
211.4310
Overall Control
211.4330
Overvarnish
211.4350
Owner of a Gasoline Dispensing Operation or Owner of a Gasoline Dispensing
Facility
211.4370
Owner or Operator
211.4390
Packaging Rotogravure Printing
211.4410
Packaging Rotogravure Printing Line
211.4430
Pail
211.4450
Paint Manufacturing Source or Paint Manufacturing Plant
211.4470
Paper Coating
211.4490
Paper Coating Line
211.4510
Particulate Matter
211.4530
Parts Per Million (Volume) or PPM (Vol)
211.4550
Person
211.4590
Petroleum
211.4610
Petroleum Liquid
211.4630
Petroleum Refinery
211.4650
Pharmaceutical
211.4670
Pharmaceutical Coating Operation
211.4690
Photochemically Reactive Material
211.4710
Pigmented Coatings
211.4730
Plant
211.4740
Plastic Part
211.4750
Plasticizers
211.4770
PM-10
211.4790
Pneumatic Rubber Tire Manufacture
211.4810
Polybasic Organic Acid Partial Oxidation Manufacturing Process
211.4830
Polyester Resin Material(s)
211.4850
Polyester Resin Products Manufacturing Process

16
211.4870
Polystyrene Plant
211.4890
Polystyrene Resin
211.4910
Portable Grain-Handling Equipment
211.4930
Portland Cement Manufacturing Process Emission Source
211.4950
Portland Cement Process or Portland Cement Manufacturing Plant
211.4960
Potential Electrical Output Capacity
211.4970
Potential to Emit
211.4990
Power Driven Fastener Coating
211.5010
Precoat
211.5015
Preheater Kiln
211.5020
Preheater/Precalciner Kiln
211.5030
Pressure Release
211.5050
Pressure Tank
211.5060
Pressure/Vacuum Relief Valve
211.5061
Pretreatment Wash Primer
211.5065
Primary Product
211.5070
Prime Coat
211.5080
Primer Sealer
211.5090
Primer Surfacer Coat
211.5110
Primer Surfacer Operation
211.5130
Primers
211.5150
Printing
211.5170
Printing Line
211.5185
Process Emission Source
211.5190
Process Emission Unit
211.5195
Process Heater
211.5210
Process Unit
211.5230
Process Unit Shutdown
211.5245
Process Vent
211.5250
Process Weight Rate
211.5270
Production Equipment Exhaust System
211.5310
Publication Rotogravure Printing Line
211.5330
Purged Process Fluid
211.5340
Rated Heat Input Capacity
211.5350
Reactor
211.5370
Reasonably Available Control Technology (RACT)
211.5390
Reclamation System
211.5410
Refiner
211.5430
Refinery Fuel Gas
211.5450
Refinery Fuel Gas System
211.5470
Refinery Unit or Refinery Process Unit
211.5480
Reflective Argent Coating
211.5490
Refrigerated Condenser
211.5500
Regulated Air Pollutant
211.5510
Reid Vapor Pressure
211.5530
Repair

17
211.5550
Repair Coat
211.5570
Repaired
211.5580
Repowering
211.5590
Residual Fuel Oil
211.5600
Resist Coat
211.5610
Restricted Area
211.5630
Retail Outlet
211.5640
Rich-Burn Engine
211.5650
Ringelmann Chart
211.5670
Roadway
211.5690
Roll Coater
211.5710
Roll Coating
211.5730
Roll Printer
211.5750
Roll Printing
211.5770
Rotogravure Printing
211.5790
Rotogravure Printing Line
211.5810
Safety Relief Valve
211.5830
Sandblasting
211.5850
Sanding Sealers
211.5870
Screening
211.5880
Screen Printing on Paper
211.5890
Sealer
211.5910
Semi-Transparent Stains
211.5930
Sensor
211.5950
Set of Safety Relief Valves
211.5970
Sheet Basecoat
211.5980
Sheet-Fed
211.5990
Shotblasting
211.6010
Side-Seam Spray Coat
211.6025
Single Unit Operation
211.6030
Smoke
211.6050
Smokeless Flare
211.6060
Soft Coat
211.6070
Solvent
211.6090
Solvent Cleaning
211.6110
Solvent Recovery System
211.6130
Source
211.6140
Specialty Coatings
211.6145
Specialty Coatings for Motor Vehicles
211.6150
Specialty High Gloss Catalyzed Coating
211.6170
Specialty Leather
211.6190
Specialty Soybean Crushing Source
211.6210
Splash Loading
211.6230
Stack
211.6250
Stain Coating
211.6270
Standard Conditions

18
211.6290
Standard Cubic Foot (scf)
211.6310
Start-Up
211.6330
Stationary Emission Source
211.6350
Stationary Emission Unit
211.6355
Stationary Gas Turbine
211.6360
Stationary Reciprocating Internal Combustion Engine
211.6370
Stationary Source
211.6390
Stationary Storage Tank
211.6400
Stencil Coat
211.6410
Storage Tank or Storage Vessel
211.6420
Strippable Spray Booth Coating
211.6430
Styrene Devolatilizer Unit
211.6450
Styrene Recovery Unit
211.6470
Submerged Loading Pipe
211.6490
Substrate
211.6510
Sulfuric Acid Mist
211.6530
Surface Condenser
211.6540
Surface Preparation Materials
211.6550
Synthetic Organic Chemical or Polymer Manufacturing Plant
211.6570
Tablet Coating Operation
211.6580
Texture Coat
211.6590
Thirty-Day Rolling Average
211.6610
Three-Piece Can
211.6620
Three or Four Stage Coating System
211.6630
Through-the-Valve Fill
211.6650
Tooling Resin
211.6670
Topcoat
211.6690
Topcoat Operation
211.6695
Topcoat System
211.6710
Touch-Up
211.6720
Touch-Up Coating
211.6730
Transfer Efficiency
211.6750
Tread End Cementing
211.6770
True Vapor Pressure
211.6790
Turnaround
211.6810
Two-Piece Can
211.6830
Under-the-Cup Fill
211.6850
Undertread Cementing
211.6860
Uniform Finish Blender
211.6870
Unregulated Safety Relief Valve
211.6880
Vacuum Metallizing
211.6890
Vacuum Producing System
211.6910
Vacuum Service
211.6930
Valves Not Externally Regulated
211.6950
Vapor Balance System
211.6970
Vapor Collection System

19
211.6990
Vapor Control System
211.7010
Vapor-Mounted Primary Seal
211.7030
Vapor Recovery System
211.7050
Vapor-Suppressed Polyester Resin
211.7070
Vinyl Coating
211.7090
Vinyl Coating Line
211.7110
Volatile Organic Liquid (VOL)
211.7130
Volatile Organic Material Content (VOMC)
211.7150
Volatile Organic Material (VOM) or Volatile Organic Compound (VOC)
211.7170
Volatile Petroleum Liquid
211.7190
Wash Coat
211.7200
Washoff Operations
211.7210
Wastewater (Oil/Water) Separator
211.7230
Weak Nitric Acid Manufacturing Process
211.7250
Web
211.7270
Wholesale Purchase - Consumer
211.7290
Wood Furniture
211.7310
Wood Furniture Coating
211.7330
Wood Furniture Coating Line
211.7350
Woodworking
211.7400
Yeast Percentage
211.APPENDIX A
Rule into Section Table
211.APPENDIX B
Section into Rule Table
AUTHORITY: Implementing Sections 9, 9.1, 9.9 and 10 and authorized by Sections 27 and 28
of the Environmental Protection Act [415 ILCS 5/9, 9.1, 9.9, 10, 27 and 28].
SOURCE: Adopted as Chapter 2: Air Pollution, Rule 201: Definitions, 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 R78-3 and 4, 35 PCB 75 and 243, at 3 Ill. Reg. 30,
p. 124, effective July 28, 1979; amended in R80-5, at 7 Ill. Reg. 1244, effective January 21,
1983; codified at 7 Ill. Reg. 13590; amended in R82-1 (Docket A) at 10 Ill. Reg. 12624, effective
July 7, 1986; amended in R85-21(A) at 11 Ill. Reg. 11747, effective June 29, 1987; amended in
R86-34 at 11 Ill. Reg. 12267, effective July 10, 1987; amended in R86-39 at 11 Ill. Reg. 20804,
effective December 14, 1987; amended in R82-14 and R86-37 at 12 Ill. Reg. 787, effective
December 24, 1987; amended in R86-18 at 12 Ill. Reg. 7284, effective April 8, 1988; amended
in R86-10 at 12 Ill. Reg. 7621, effective April 11, 1988; amended in R88-23 at 13 Ill. Reg.
10862, effective June 27, 1989; amended in R89-8 at 13 Ill. Reg. 17457, effective January 1,
1990; amended in R89-16(A) at 14 Ill. Reg. 9141, effective May 23, 1990; amended in R88-
30(B) at 15 Ill. Reg. 5223, effective March 28, 1991; amended in R88-14 at 15 Ill. Reg. 7901,
effective May 14, 1991; amended in R91-10 at 15 Ill. Reg. 15564, effective October 11, 1991;
amended in R91-6 at 15 Ill. Reg. 15673, effective October 14, 1991; amended in R91-22 at 16
Ill. Reg. 7656, effective May 1, 1992; amended in R91-24 at 16 Ill. Reg. 13526, effective August
24, 1992; amended in R93-9 at 17 Ill. Reg. 16504, effective September 27, 1993; amended in
R93-11 at 17 Ill. Reg. 21471, effective December 7, 1993; amended in R93-14 at 18 Ill. Reg.

20
1253, effective January 18, 1994; amended in R94-12 at 18 Ill. Reg. 14962, effective September
21, 1994; amended in R94-14 at 18 Ill. Reg. 15744, effective October 17, 1994; amended in
R94-15 at 18 Ill. Reg. 16379, effective October 25, 1994; amended in R94-16 at 18 Ill. Reg.
16929, effective November 15, 1994; amended in R94-21, R94-31 and R94-32 at 19 Ill. Reg.
6823, effective May 9, 1995; amended in R94-33 at 19 Ill. Reg. 7344, effective May 22, 1995;
amended in R95-2 at 19 Ill. Reg. 11066, effective July 12, 1995; amended in R95-16 at 19 Ill.
Reg. 15176, effective October 19, 1995; amended in R96-5 at 20 Ill. Reg. 7590, effective May
22, 1996; amended in R96-16 at 21 Ill. Reg. 2641, effective February 7, 1997; amended in R97-
17 at 21 Ill. Reg. 6489, effective May 16, 1997; amended in R97-24 at 21 Ill. Reg. 7695,
effective June 9, 1997; amended in R96-17 at 21 Ill. Reg. 7856, effective June 17, 1997;
amended in R97-31 at 22 Ill. Reg. 3497, effective February 2, 1998; amended in R98-17 at 22 Ill.
Reg. 11405, effective June 22, 1998; amended in R01-9 at 25 Ill. Reg. 108, effective December
26, 2000; amended in R01-11 at 25 Ill. Reg. 4597, effective March 15, 2001; amended in R01-17
at 25 Ill. Reg. 5900, effective April 17, 2001; amended in R05-16 at 29 Ill. Reg. 8181, effective
May 23, 2005; amended in R05-11 at 29 Ill. Reg.8892, effective June 13, 2005; amended in R04-
12/20 at 30 Ill. Reg. 9654, effective May 15, 2006; amended in R07-18 at 31 Ill. Reg. 14254,
effective September 25, 2007; amended in R08-6 at 32 Ill. Reg. 1387, effective January 16,
2008; amended in R07-19 at 33 Ill. Reg. 11982, effective August 6, 2009; amended in R08-19 at
33 Ill. Reg. ____, effective __________.
SUBPART B: DEFINITIONS
Section 211.665 Auxiliary Boiler
“Auxiliary boiler” means, for purposes of Part 217, a boiler that is operated only when the main
boiler or boilers at a source are not in service and is used either to maintain building heat or to
assist in the startup of the main boiler or boilers. This term does not include emergency or
standby units and load shaving units.
(Source: Added at 33 Ill. Reg. _____, effective __________)
Section 211.995 Circulating Fluidized Bed Combustor
“Circulating fluidized bed combustor” means, for purposes of Part 217, a fluidized bed
combustor in which the majority of the fluidized bed material is carried out of the primary
combustion zone and is transported back to the primary zone through a recirculation loop.
(Source: Added at 33 Ill. Reg. _____, effective ___________)
Section 211.1315 Combustion Tuning
“Combustion tuning” means, for purposes of Part 217, review and adjustment of a combustion
process to maintain combustion efficiency of an emission unit, as performed in accordance with
procedures provided by the manufacturer or by a trained technician.
(Source: Added at 33 Ill. Reg. _____, effective ______________)

21
Section 211.1435 Container Glass
“Container glass” means, for purposes of Part 217, glass made of soda-lime recipe, clear or
colored, which is pressed or blown, or both, into bottles, jars, ampoules, and other products listed
in Standard Industrial Classification 3221.
(Source: Added at 33 Ill. Reg. _____, effective ___________)
Section 211.2355 Flare
“Flare” means an open combustor without enclosure or shroud.
(Source: Added at 33 Ill. Reg. _____, effective ___________)
Section 211.2357 Flat Glass
“Flat glass” means, for purposes of Part 217, glass made of soda-lime recipe and produced into
continuous flat sheets and other products listed in Standard Industrial Classification 3211.
(Source: Added at 33 Ill. Reg. _____, effective ___________)
Section 211.2625 Glass Melting Furnace
“Glass melting furnace” means, for purposes of Part 217, a unit comprising a refractory vessel in
which raw materials are charged and melted at high temperature to produce molten glass.
(Source: Added at 33 Ill. Reg. _____, effective ____________)
Section 211.3100 Industrial Boiler
“Industrial boiler” means, for purposes of Part 217, an enclosed vessel in which water is heated
and circulated either as hot water or as steam for heating or for power, or both. This term does
not include a heat recovery steam generator that captures waste heat from a combustion turbine
and boilers serving a generator that has a nameplate capacity greater than 25 MWe and produces
electricity for sale, if such boilers meet the applicability criteria under Subpart M of Part 217.
(Source: Added at 33 Ill. Reg. _____, effective ___________)
Section 211.3355 Lime Kiln
“Lime kiln” means, for purposes of Part 217, an enclosed combustion device used to calcine lime
mud, which consists primarily of calcium carbonate, into calcium oxide.
(Source: Added at 33 Ill. Reg. _____, effective ___________)

 
22
Section 211.3475 Load Shaving Unit
“Load shaving unit” means, for purposes of Part 217, a device used to generate electricity for
sale or use during high electric demand days, including but not limited to stationary reciprocating
internal combustion engines or turbines.
(Source: Added at 33 Ill. Reg. _____, effective ____________)
Section 211.4280 Other Glass
“Other glass” means, for purposes of Part 217, glass that is neither container glass, as that term is
defined in Section 211.1435, nor flat glass, as that term is defined in Section 211.2357.
(Source: Added at 33 Ill. Reg. _____, effective ____________)
Section 211.5195 Process Heater
“Process heater” means, for purposes of Part 217, an enclosed combustion device that burns
gaseous or liquid fuels only and that indirectly transfers heat to a process fluid or a heat transfer
medium other than water. This term does not include pipeline heaters and storage tank heaters
that are primarily meant to maintain fluids at a certain temperature or viscosity.
(Source: Added at 33 Ill. Reg. _____, effective ______________)
TITLE 35: ENVIRONMENTAL PROTECTION
SUBTITLE B: AIR POLLUTION
CHAPTER I: POLLUTION CONTROL BOARD
SUBCHAPTER c: EMISSION STANDARDS AND LIMITATIONS FOR STATIONARY
SOURCES
PART 217
NITROGEN OXIDES EMISSIONS
SUBPART A: GENERAL PROVISIONS
Section
217.100
Scope and Organization
217.101
Measurement Methods
217.102
Abbreviations and Units
217.103
Definitions
217.104
Incorporations by Reference
SUBPART B: NEW FUEL COMBUSTION EMISSION SOURCES
Section
217.121
New Emission Sources (Repealed)

23
SUBPART C: EXISTING FUEL COMBUSTION EMISSION UNITS SOURCES
Section
217.141
Existing Emission Units Sources in Major Metropolitan Areas
Section
217.150
Applicability
SUBPART D: NO
x
GENERAL REQUIREMENTS
217.152
Compliance Date
217.154
Performance Testing
217.155
Initial Compliance Certification
217.156
Recordkeeping and Reporting
217.157
Testing and Monitoring
217.158
Emissions Averaging Plans
SUBPART E: INDUSTRIAL BOILERS
Section
217.160
Applicability
217.162
Exemptions
217.164
Emissions Limitations
217.165
Combination of Fuels
217.166
Methods and Procedures for Combustion Tuning
SUBPART F: PROCESS HEATERS
Section
217.180
Applicability
217.182
Exemptions
217.184
Emissions Limitations
217.185
Combination of Fuels
217.186
Methods and Procedures for Combustion Tuning
SUBPART G: GLASS MELTING FURNANCES
Section
217.200
Applicability
217.202
Exemptions
217.204
Emissions Limitations
SUBPART H: CEMENT AND LIME KILNS
Section
217.220
Applicability
217.222
Exemptions
217.224
Emissions Limitations

24
SUBPART I: IRON AND STEEL AND ALUMINUM MANUFACTURING
Section
217.240
Applicability
217.242
Exemptions
217.244
Emissions Limitations
SUBPART K: PROCESS EMISSION SOURCES
Section
217.301
Industrial Processes
SUBPART M: ELECTRICAL GENERATING UNITS
Section
217.340
Applicability
217.342
Exemptions
217.344
Emissions Limitations
217.345
Combination of Fuels
SUBPART O: CHEMICAL MANUFACTURE
Section
217.381
Nitric Acid Manufacturing Processes
SUBPART Q: STATIONARY RECIPROCATING INTERNAL COMBUSTION
ENGINES AND TURBINES
Section
217.386
Applicability
217.388
Control and Maintenance Requirements
217.390
Emissions Averaging Plans
217.392
Compliance
217.394
Testing and Monitoring
217.396
Recordkeeping and Reporting
SUBPART T: CEMENT KILNS
Section
217.400
Applicability
217.402
Control Requirements
217.404
Testing
217.406
Monitoring
217.408
Reporting
217.410
Recordkeeping
SUBPART U: NOx CONTROL AND TRADING PROGRAM FOR
SPECIFIED NOx GENERATING UNITS

25
Section
217.450
Purpose
217.452
Severability
217.454
Applicability
217.456
Compliance Requirements
217.458
Permitting Requirements
217.460
Subpart U NOx Trading Budget
217.462
Methodology for Obtaining NOx Allocations
217.464
Methodology for Determining NOx Allowances from the New Source Set-Aside
217.466
NOx Allocations Procedure for Subpart U Budget Units
217.468
New Source Set-Asides for “New” Budget Units
217.470
Early Reduction Credits (ERCs) for Budget Units
217.472
Low-Emitter Requirements
217.474
Opt-In Units
217.476
Opt-In Process
217.478
Opt-In Budget Units: Withdrawal from NOx Trading Program
217.480
Opt-In Units: Change in Regulatory Status
217.482
Allowance Allocations to Opt-In Budget Units
SUBPART V: ELECTRIC POWER GENERATION
Section
217.521
Lake of Egypt Power Plant
217.700
Purpose
217.702
Severability
217.704
Applicability
217.706
Emission Limitations
217.708
NOx Averaging
217.710
Monitoring
217.712
Reporting and Recordkeeping
SUBPART W: NOx TRADING PROGRAM FOR ELECTRICAL
GENERATING UNITS
Section
217.750
Purpose
217.752
Severability
217.754
Applicability
217.756
Compliance Requirements
217.758
Permitting Requirements
217.760
NOx Trading Budget
217.762
Methodology for Calculating NOx Allocations for Budget Electrical
Generating Units (EGUs)
217.764
NOx Allocations for Budget EGUs
217.768
New Source Set-Asides for “New” Budget EGUs
217.770
Early Reduction Credits for Budget EGUs

26
217.774
Opt-In Units
217.776
Opt-In Process
217.778
Budget Opt-In Units: Withdrawal from NOx Trading Program
217.780
Opt-In Units: Change in Regulatory Status
217.782
Allowance Allocations to Budget Opt-In Units
SUBPART X: VOLUNTARY NOx EMISSIONS REDUCTION PROGRAM
Section
217.800
Purpose
217.805
Emission Unit Eligibility
217.810
Participation Requirements
217.815
NOx Emission Reductions and the Subpart X NOx Trading Budget
217.820
Baseline Emissions Determination
217.825
Calculation of Creditable NOx Emission Reductions
217.830
Limitations on NOx Emission Reductions
217.835
NOx Emission Reduction Proposal
217.840
Agency Action
217.845
Emissions Determination Methods
217.850
Emissions Monitoring
217.855
Reporting
217.860
Recordkeeping
217.865
Enforcement
217.APPENDIX A
Rule into Section Table
217.APPENDIX B
Section into Rule Table
217.APPENDIX C
Compliance Dates
217.APPENDIX D
Non-Electrical Generating Units
217.APPENDIX E
Large Non-Electrical Generating Units
217.APPENDIX F
Allowances for Electrical Generating Units
217.APPENDIX G
Existing Reciprocating Internal Combustion Engines Affected by the NO
x
SIP Call
217.APPENDIX H
Compliance Dates for Certain Emissions Units at Petroleum Refineries
AUTHORITY: Implementing Sections 9.9 and 10 and authorized by Sections 27 and 28 of the
Environmental Protection Act [415 ILCS 5/9.9, 10, 27 and 28].
SOURCE: Adopted as Chapter 2: Air Pollution, Rule 207: Nitrogen Oxides Emissions, R71-23,
4 PCB 191, April 13, 1972, filed and effective April 14, 1972; amended at 2 Ill. Reg. 17, p. 101,
effective April 13, 1978; codified at 7 Ill. Reg. 13609; amended in R01-9 at 25 Ill. Reg. 128,
effective December 26, 2000; amended in R01-11 at 25 Ill. Reg. 4597, effective March 15, 2001;
amended in R01-16 and R01-17 at 25 Ill. Reg. 5914, effective April 17, 2001; amended in R07-
18 at 31 Ill. Reg. 14271, effective September 25, 2007; amended in 07-19 at 33 Ill. Reg. 11999,
effective August 6, 2009; amended in R08-19 at 33 Ill. Reg. ____, effective _________.

 
27
SUBPART A: GENERAL PROVISIONS
Section 217.100 Scope and Organization
a)
This Part sets standards and limitations for emission of oxides of nitrogen from
stationary sources.
b)
Permits for sources subject to this Part may be required pursuant to 35 Ill. Adm.
Code 201 or Section 39.5 of the Act.
c)
Notwithstanding the provisions of this Part the air quality standards contained in
35 Ill. Adm. Code 243 may not be violated.
d)
These rules have been grouped for convenience of the public; the scope of each is
determined by its language and history.
(Source: Amended at 33 Ill. Reg. ___, effective ___________)
Section 217.104 Incorporations by Reference
The following materials are incorporated by reference. These incorporations do not include any
later amendments or editions.
a)
The phenol disulfonic acid procedures, as published in 40 CFR 60, Appendix A,
Method 7 (2000);
b)
40 CFR 96, subparts B, D, G, and H (1999);
c)
40 CFR 96.1 through 96.3, 96.5 through 96.7, 96.50 through 96.54, 96.55 (a) &
(b), 96.56 and 96.57 (1999);
d)
40 CFR 60, 72, 75 & 76 (2006);
e)
Alternative Control Techniques Document -- NO
x
Emissions from Cement
Manufacturing, EPA-453/R-94-004, U. S. Environmental Protection Agency-
Office of Air Quality Planning and Standards, Research Triangle Park, N. C.
27711, March 1994;
f)
Section 11.6, Portland Cement Manufacturing, AP-42 Compilation of Air
Emission Factors, Volume 1: Stationary Point and Area Sources, U.S.
Environmental Protection Agency-Office of Air Quality Planning and Standards,
Research Triangle Park, N. C. 27711, revised January 1995;
g)
40 CFR 60.13 (2001);
h)
40 CFR 60, Appendix A, Methods 3A, 7, 7A, 7C, 7D, 7E, 19, and 20 (2000);

 
28
i)
ASTM D6522-00, Standard Test Method for Determination of Nitrogen Oxides,
Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas-
Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters
Using Portable Analyzers (2000);
jk)
Standards of Performance for Stationary Combustion Turbines, 40 CFR 60,
Subpart KKKK, 60.4400 (2006);
kl)
Compilation of Air Pollutant Emission Factors: AP-42, Volume I: Stationary
Point and Area Sources (2000), USEPA;
l)
40 CFR 60, Appendix A, Methods 1, 2, 3, and 4 (2008);
m)
Alternative Control Techniques Document - NO
x
Emissions from
Industrial/Commercial/Institutional (ICI) Boilers, EPA-453/R-94-022, U. S.
Environmental Protection Agency, Office of Air and Radiation, Office of Air
Quality Planning and Standards, Research Triangle Park, N. C. 27711, March
1994;
n)
Alternative Control Techniques Document - NO
x
Emissions from Process Heaters
(Revised), EPA-453/R-93-034, U. S. Environmental Protection Agency, Office of
Air and Radiation, Office of Air Quality Planning and Standards, Research
Triangle Park, N. C. 27711, September 1993;
o)
Alternative Control Techniques Document - NO
x
Emissions from Glass
Manufacturing, EPA-453/R-94-037, U. S. Environmental Protection Agency,
Office of Air and Radiation, Office of Air Quality Planning and Standards,
Research Triangle Park, N. C. 27711, June 1994;
p)
Alternative Control Techniques Document - NO
x
Emissions from Iron and Steel
Mills, EPA-453/R-94-065, U. S. Environmental Protection Agency, Office of Air
and Radiation, Office of Air Quality Planning and Standards, Research Triangle
Park, N. C. 27711, September 1994;
q)
40 CFR 60 and 75 (2008); and
r)
40 CFR 60, Appendix B, Performance Specification 16, 74 FR 12575 (March 25,
2009).
(Source: Amended at 33 Ill. Reg. _____, effective ___________)
SUBPART B: NEW FUEL COMBUSTION EMISSION SOURCES
Section 217.121 New Emission Sources (Repealed)

 
29
No person shall cause or allow the emission of nitrogen oxides (NO
X
) into the atmosphere in any
one hour period from any new fuel combustion emission source with an actual heat input equal
to or greater than 73.2 MW (250 mmbtu/hr) to exceed the following standards and limitations:
a)
For gaseous fossil fuel firing, 0.310 kg/MW-hr (0.20 lbs/mmbtu) of actual heat
input;
b)
For liquid fossil fuel firing, 0.464 kg/MW-hr (0.30 lbs/mmbtu) of actual heat
input;
c)
For dual gaseous and liquid fossil fuel firing, 0.464 kg/MW-hr (0.30 lbs/mmbtu)
of actual heat input;
d)
For solid fossil fuel firing, 1.08 kg/MW-hr (0.7 lbs./mmbtu) of actual heat input;
e)
For fuel combustion emission sources burning simultaneously any combination of
solid, liquid and gaseous fossil fuels, an allowable emission rate shall be
determined by the following equation:
E = (AG + BL + CS) Q
Where:
E = Allowable nitrogen oxides emissions rate
Q = Actual heat input derived from all fossil fuels
G = Percent of actual heat input derived from gaseous fossil fuel
L = Percent of actual heat input derived from liquid fossil fuel
S = Percent of actual heat input derived from solid fossil fuel
G + L + S = 100.0
and, where A, B, C and appropriate metric and English units are determined from
the following table:
Metric
English
E
kg/hr
lbs/hr
Q
MW
mmbtu/hr
A
0.023
0.003
B
0.023
0.003
C
0.053
0.007
(Source: Repealed at 33 Ill. Reg. _____, effective ___________)
SUBPART C: EXISTING FUEL COMBUSTION EMISSION UNITS SOURCES
Section 217.141 Existing Emission Units Sources in Major Metropolitan Areas

 
30
No person shall cause or allow the emission of nitrogen oxides into the atmosphere in any one
hour period from any existing fuel combustion emission unit source with an actual heat input
equal to or greater than 73.2 MW (250 mmbtu/hr), located in the Chicago or St. Louis (Illinois)
major metropolitan areas to exceed the following limitations:
a)
For gaseous and/or liquid fossil fuel firing, 0.46 kg/MW-hr (0.3 lbs/mmbtu) of
actual heat input;
b)
For solid fossil fuel firing, 1.39 kg/MW-hr (0.9 lbs/mmbtu) of actual heat input;
c)
For fuel combustion emission units sources burning simultaneously any
combination of solid, liquid and gaseous fuel, the allowable emission rate shall be
determined by the following equation:
E = (AG + BL + CS) Q
Where:
E
= allowable nitrogen oxides emissions rate
Q
= actual heat input
G
= percent of actual heat input derived from gaseous fossil fuel
L
= percent of actual heat input derived from liquid fossil fuel
S
= percent of actual heat input derived from solid fossil fuel
G + L + S
= 100.0
and where A, B, and C and appropriate metric and English units are determined from the
following table:
Metric
English
E
kg/hr
lbs/hr
Q
MW
mmbtu/hr
A
0.023
0.003
B
0.023
0.003
C
0.068
0.009
d)
Exceptions: This Section rule shall not apply to the following:
1)
Existing existing fuel combustion units sources that which are either
cyclone fired boilers burning solid or liquid fuel, or horizontally opposed
fired boilers burning solid fuel; or.
2)
Emission units that are subject to the emissions limitations of Subpart E,
F, G, H, M, or Q of this Part.
(Source: Amended at 33 Ill. Reg. _____, effective ______________)

31
SUBPART D: NO
x
GENERAL REQUIREMENTSINDUSTRIAL BOILERS
Section 217.150 Applicability
a)
Applicability
1)
The provisions of this Subpart and Subparts E, F, G, H, I and M of this
Part apply to the following:
A)
All sources that are located in either one of the following areas and
that emit or have the potential to emit NO
x
in an amount equal to
or greater than 100 tons per year:
i)
The area composed of the Chicago area counties of Cook,
DuPage, Kane, Lake, McHenry, and Will, the Townships
of Aux Sable and Goose Lake in Grundy County, and the
Township of Oswego in Kendall County; or
ii)
The area composed of the Metro East area counties of
Jersey, Madison, Monroe, and St. Clair, and the Township
of Baldwin in Randolph County; and
B)
Any industrial boiler, process heater, glass melting furnace, cement
kiln, lime kiln, iron and steel reheat, annealing, or galvanizing
furnace, aluminum reverberatory or crucible furnace, or fossil fuel-
fired stationary boiler at such sources described in subsection
(a)(1)(A) of this Section that emits NO
x
in an amount equal to or
greater than 15 tons per year and equal to or greater than five tons
per ozone season.
2)
For purposes of this Section, “potential to emit” means the quantity of
NO
x
that potentially could be emitted by a stationary source before add-on
controls based on the design capacity or maximum production capacity of
the source and 8,760 hours per year or the quantity of NO
x
that potentially
could be emitted by a stationary source as established in a federally
enforceable permit.
b)
If a source ceases to fulfill the emissions criteria of subsection (a) of this Section,
the requirements of this Subpart and Subpart E, F, G, H, I or M of this Part
continue to apply to any emission unit that was ever subject to the provisions of
any of those Subparts.
c)
The provisions of this Subpart do not apply to afterburners, flares, and
incinerators.
d)
Where a construction permit, for which the application was submitted to the
Agency prior to the adoption of this Subpart, is issued that relies on decreases in

32
emissions of NO
x
from existing emission units for purposes of netting or emission
offsets, such NO
x
decreases remain creditable notwithstanding any requirements
that may apply to the existing emission units pursuant to this Subpart and Subpart
E, F, G, H, I or M of this Part .
e)
The owner or operator of an emission unit that is subject to this Subpart and
Subpart E, F, G, H, I or M of this Part must operate such unit in a manner
consistent with good air pollution control practice to minimize NO
x
emissions.
(Source: Added at 33 Ill. Reg. _____, effective ______________)
Section 217.152 Compliance Date
a)
Compliance with the requirements of Subparts E, F, G, H, I and M by an owner or
operator of an emission unit that is subject to any of those Subparts is required
beginning January 1, 2012.
b)
Notwithstanding subsection (a) of this Section, compliance with the requirements
of Subpart G of this Part by an owner or operator of an emission unit subject to
Subpart G of this Part shall be extended until December 31, 2014, if such units are
required to meet emissions limitations for NOx, as measured using a continuous
emissions monitoring system, and included within a legally enforceable order on
or before December 31, 2009, whereby such emissions limitations are less than 30
percent of the emissions limitations set forth under Section 217.204.
c)
Notwithstanding subsection (a) of this Section, the owner or operator of emission
units subject to Subpart E or F of this Part and located at a petroleum refinery must
comply with the requirements of this Subpart and Subpart E or F of this Part, as
applicable, for those emission units beginning January 1, 2012, except that the
owner or operator of emission units listed in Appendix H must comply with the
requirements of this Subpart, including the option of demonstrating compliance
with the applicable Subpart through an emissions averaging plan under Section
217.158 and Subpart E or F of this Part, as applicable, for the listed emission units
beginning on the dates set forth in Appendix H. With Agency approval, the owner
or operator of emission units listed in Appendix H may elect to comply with the
requirements of this Subpart and Subpart E or F of this Part, as applicable, by
reducing the emissions of emission units other than those listed in Appendix H,
provided that the emissions limitations of such other emission units are equal to or
more stringent than the applicable emissions limitations set forth in Subpart E or F
of this Part, as applicable, by the dates set forth in Appendix H.
(Source: Added at 33 Ill. Reg. _____, effective ______________)
Section 217.154 Performance Testing

33
a)
Performance testing of NO
x
emissions for emission units constructed on or before
July 1, 2011, and subject to emissions limitations under Subpart E, F, G, H or I of
this Part must be conducted in accordance with Section 217.157 of this Subpart.
Except as provided for under Section 217.157(a)(4) and (e)(1), this subsection
does not apply to owners and operators of emission units demonstrating
compliance through a continuous emissions monitoring system, predictive
emission monitoring system, or combustion tuning.
b)
Performance testing of NO
x
emissions for emission units for which construction
or modification occurs after July 1, 2011, and that are subject to emissions
limitations under Subpart E, F, G, H or I of this Part must be conducted within 60
days of achieving maximum operating rate but no later than 180 days after initial
startup of the new or modified emission unit, in accordance with Section 217.157
of this Subpart. Except as provided for under Section 217.157(a)(4) and (e)(1),
this subsection does not apply to owners and operators of emission units
demonstrating compliance through a continuous emissions monitoring system,
predictive emission monitoring system, or combustion tuning.
c)
Notification of the initial startup of an emission unit subject to subsection (b) of
this Section must be provided to the Agency no later than 30 days after initial
startup.
d)
The owner or operator of an emission unit subject to subsection (a) or (b) of this
Section must notify the Agency of the scheduled date for the performance testing
in writing at least 30 days before such date and five days before such date.
e)
If demonstrating compliance through an emissions averaging plan, at least 30
days before changing the method of compliance, the owner or operator of an
emission unit must submit a written notification to the Agency describing the new
method of compliance, the reason for the change in the method of compliance,
and the scheduled date for performance testing, if required. Upon changing the
method of compliance, the owner or operator of an emission unit must submit to
the Agency a revised compliance certification that meets the requirements of
Section 217.155.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.155 Initial Compliance Certification
a)
By the applicable compliance date set forth under Section 217.152, an owner or
operator of an emission unit subject to Subpart E, F, G, H or I of this Part who is
not demonstrating compliance through the use of a continuous emissions
monitoring system must certify to the Agency that the emission unit will be in
compliance with the applicable emissions limitation of Subpart E, F, G, H or I of
this Part beginning on such applicable compliance date. The performance testing
certification must include the results of the performance testing performed in

34
accordance with Section 217.154(a) and (b) and the calculations necessary to
demonstrate that the subject emission unit will be in initial compliance.
b)
By the applicable compliance date set forth under Section 217.152, an owner or
operator of an emission unit subject to Subpart E, F, G, H, I or M of this Part who
is demonstrating compliance through the use of a continuous emissions
monitoring system must certify to the Agency that the affected emission units will
be in compliance with the applicable emissions limitation of Subpart E, F, G, H, I,
or M of this Part beginning on such applicable compliance date. The compliance
certification must include a certification of the installation and operation of a
continuous emissions monitoring system required under Section 217.157 and the
monitoring data necessary to demonstrate that the subject emission unit will be in
initial compliance.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.156 Recordkeeping and Reporting
a)
The owner or operator of an emission unit subject to Subpart E, F, G, H, I or M of
this Part must keep and maintain all records used to demonstrate initial
compliance and ongoing compliance with the requirements of those Subparts.
1)
Except as otherwise provided under this Subpart or Subpart E, F, G, H, I
or M of this Part, copies of such records must be submitted by the owner
or operator of the source to the Agency within 30 days after receipt of a
written request by the Agency.
2)
Such records must be kept at the source and maintained for at least five
years and must be available for immediate inspection and copying by the
Agency.
b)
The owner or operator of an emission unit subject to Subpart E, F, G, H, I or M of
this Part must maintain records that demonstrate compliance with the
requirements of those Subparts, as applicable, that include the following:
1)
Identification, type (e.g., gas-fired), and location of each unit.
2)
Calendar date of the record.
3)
Monthly, seasonal, and annual operating hours.
4)
Type and quantity of each fuel used monthly, seasonally, and annually.
5)
Product and material throughput, as applicable.

35
6)
Reports for all applicable emissions tests for NO
x
conducted on the unit,
including results.
7)
The date, time, and duration of any startup, shutdown, or malfunction in
the operation of any emission unit subject to Subpart E, F, G, H, I or M of
this Part or any emissions monitoring equipment. The records must
include a description of the malfunction and corrective maintenance
activity.
8)
A log of all maintenance and inspections related to the unit’s air pollution
control equipment for NO
x
that is performed on the unit.
9)
A log for the NO
x
monitoring device, if present, including periods when
not in service and maintenance and inspection activities that are performed
on the device.
10)
Identification of time periods for which operating conditions and pollutant
data were not obtained by the continuous emissions monitoring system,
including the reasons for not obtaining sufficient data and a description of
corrective actions taken.
11)
If complying with the emissions averaging plan provisions of Section
217.158, copies of the calculations used to demonstrate compliance with
the ozone season and annual control period limitations, noncompliance
reports for the ozone season, and ozone and annual control period
compliance reports submitted to the Agency.
c)
The owner or operator of an industrial boiler subject to Subpart E of this Part
must maintain records in order to demonstrate compliance with the combustion
tuning requirements under Section 217.166.
d)
The owner or operator of a process heater subject to Subpart F of this Part must
maintain records in order to demonstrate compliance with the combustion tuning
requirements under Section 217.186.
e)
The owner or operator of an emission unit subject to Subpart E, F, G, H, I or M of
this Part must maintain records in order to demonstrate compliance with the
testing and monitoring requirements under Section 217.157.
f)
The owner or operator of an emission unit subject to Subpart E, F, G, H or I of
this Part must provide the following information with respect to performance
testing pursuant to Section 217.157:
1)
Submit a testing protocol to the Agency at least 60 days prior to testing;

36
2)
Notify the Agency at least 30 days in writing prior to conducting
performance testing for NO
x
emissions and five days prior to such testing;
3)
Not later than 60 days after the completion of the test, submit the results of
the test to the Agency; and
4)
If, after the 30-days’ notice for an initially scheduled test is sent, there is a
delay (e.g., due to operational problems) in conducting the test as
scheduled, the owner or operator of the unit must notify the Agency as
soon as practicable of the delay in the original test date, either by
providing at least seven days’ prior notice of the rescheduled date of the
test or by arranging a new test date with the Agency by mutual agreement.
g)
The owner or operator of an emission unit subject to Subpart E, F, G, H, I or M of
this Part must notify the Agency of any exceedances of an applicable emissions
limitation of Subpart E, F, G, H, I or M of this Part by sending the applicable
report with an explanation of the causes of such exceedances to the Agency
within 30 days following the end of the applicable compliance period in which the
emissions limitation was not met.
h)
Within 30 days after the receipt of a written request by the Agency, the owner or
operator of an emission unit that is exempt from the requirements of Subpart E, F,
G, H, I or M of this Part must submit records that document that the emission unit
is exempt from those requirements to the Agency.
i)
If demonstrating compliance through an emissions averaging plan, by March 1
following the applicable calendar year, the owner or operator must submit to the
Agency a report that demonstrates the following:
1)
For all units that are part of the emissions averaging plan, the total mass of
allowable NOx emissions for the ozone season and for the annual control
period;
2)
The total mass of actual NOx emissions for the ozone season and annual
control period for each unit included in the averaging plan;
3)
The calculations that demonstrate that the total mass of actual NOx
emissions are less than the total mass of allowable NOx emissions using
equations in Section 217.158(f); and
4)
The information required to determine the total mass of actual NOx
emissions.
j)
The owner or operator of an emission unit subject to the requirements of Section
217.157 and demonstrating compliance through the use of a continuous emissions

37
monitoring system must submit to the Agency a report within 30 days after the
end of each calendar quarter. This report must include the following:
1)
Information identifying and explaining the times and dates when
continuous emissions monitoring for NO
x
was not in operation, other than
for purposes of calibrating or performing quality assurance or quality
control activities for the monitoring equipment; and
2)
An excess emissions and monitoring systems performance report in
accordance with the requirements of 40 CFR 60.7(c) and (d) and 60.13, or
40 CFR 75, or an alternate procedure approved by the Agency and
USEPA.
k)
The owner or operator of an emission unit subject to Subpart M of this Part must
comply with the compliance certification and recordkeeping and reporting
requirements in accordance with 40 CFR 96, or an alternate procedure approved
by the Agency and USEPA.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.157 Testing and Monitoring
a)
Industrial Boilers and Process Heaters
1)
The owner or operator of an industrial boiler subject to Subpart E of this
Part with a rated heat input capacity greater than 250 mmBtu/hr must
install, calibrate, maintain, and operate a continuous emissions monitoring
system on the emission unit for the measurement of NO
x
emissions
discharged into the atmosphere in accordance with 40 CFR 75, as
incorporated by reference in Section 217.104. However, the owner or
operator of an industrial boiler subject to Subpart E of this Part with a
rated heat input capacity greater than 250 mmBtu/hr that combusts blast
furnace gas with up to 10% natural gas on an annual basis and located at a
source that manufactures iron and steel is not required to install, calibrate,
maintain, and operate a continuous emissions monitoring system on such
industrial boiler, provided the heat input from natural gas does not exceed
10% on an annual basis and the owner or operator complies with the
performance test requirements under this Section and demonstrates, during
each performance test, that NO
x
emissions from such industrial boiler are
less than 70% of the applicable emissions limitation under Section
217.164. In the event such owner or operator is unable to meet the
requirements of this paragraph, a continuous emissions monitoring system
is required within 12 months of such event, or by December 31, 2012,
whichever is later.

38
2)
The owner or operator of an industrial boiler subject to Subpart E of this
Part with a rated heat input capacity greater than 100 mmBtu/hr but less
than or equal to 250 mmBtu/hr must install, calibrate, maintain, and
operate a continuous emissions monitoring system on such emission unit
for the measurement of NO
x
emissions discharged into the atmosphere in
accordance with 40 CFR 60, subpart A and appendix B, Performance
Specifications 2 and 3, and appendix F, Quality Assurance Procedures, as
incorporated by reference in Section 217.104.
3)
The owner or operator of a process heater subject to Subpart F of this Part
with a rated heat input capacity greater than 100 mmBtu/hr must install,
calibrate, maintain, and operate a continuous emissions monitoring system
on the emission unit for the measurement of NO
x
emissions discharged
into the atmosphere in accordance with 40 CFR 60, subpart A and
appendix B, Performance Specifications 2 and 3 and appendix F, Quality
Assurance Procedures, as incorporated by reference in Section 217.104.
4)
If demonstrating compliance through an emissions averaging plan, the
owner or operator of an industrial boiler subject to Subpart E of this Part,
or a process heater subject to Subpart F of this Part, with a rated heat input
capacity less than or equal to 100 mmBtu/hr and not demonstrating
compliance through a continuous emissions monitoring system must have
an initial performance test conducted pursuant to subsection (a)(4)(B) of
this Section and Section 217.154.
A)
An owner or operator of an industrial boiler or process heater must
have subsequent performance tests conducted pursuant to
subsection (a)(4)(B) of this Section at least once every five years.
When in the opinion of the Agency or USEPA, it is necessary to
conduct testing to demonstrate compliance with Section 217.164 or
217.184, as applicable, the owner or operator of an industrial boiler
or process heater must, at his or her own expense, have such test
conducted in accordance with the applicable test methods and
procedures specified in this Section within 90 days of receipt after
a notice to test from the Agency or USEPA.
B)
The owner or operator of an industrial boiler or process heater
must have a performance test conducted using 40 CFR 60, subpart
A and appendix A, Method 1, 2, 3, 4, 7E, or 19, as incorporated by
reference in Section 217.104, or other alternative USEPA methods
approved by the Agency. Each performance test must consist of
three separate runs, each lasting a minimum of 60 minutes. NO
x
emissions must be measured while the industrial boiler is operating
at maximum operating capacity or while the process heater is
operating at normal maximum load. If the industrial boiler or
process heater has combusted more than one type of fuel in the

39
prior year, a separate performance test is required for each fuel. If
a combination of fuels is typically used, a performance test may be
conducted, with Agency approval, on such combination of fuels
typically used. Except as provided under subsection (e) of this
Section, this subsection (a)(4)(B) does not apply if such owner or
operator is demonstrating compliance with an emissions limitation
through a continuous emissions monitoring system under
subsection (a)(1), (a)(2), (a)(3), or (a)(5) of this Section.
5)
Instead of complying with the requirements of subsection (a)(4) of this
Section, an owner or operator of an industrial boiler subject to Subpart E
of this Part, or a process heater subject to Subpart F of this Part, with a
rated heat input capacity less than or equal to 100 mmBtu/hr may install
and operate a continuous emissions monitoring system on such emission
unit in accordance with the applicable requirements of 40 CFR 60, subpart
A and appendix B, Performance Specifications 2 and 3 and appendix F,
Quality Assurance Procedures, as incorporated by reference in Section
217.104. The continuous emissions monitoring system must be used to
demonstrate compliance with the applicable emissions limitation or
emissions averaging plan on an ozone season and annual basis.
6)
Notwithstanding subsection (a)(2) of this Section, the owner or operator of
an auxiliary boiler subject to Subpart E of this Part with a rated heat input
capacity less than or equal to 250 mmBtu/hr and a capacity factor of less
than or equal to 20% is not required to install, calibrate, maintain, and
operate a continuous emissions monitoring system on such boiler for the
measurement of NO
x
emissions discharged into the atmosphere, but must
comply with the performance test requirements under subsection (a)(4) of
this Section.
b)
Glass Melting Furnaces; Cement Kilns; Lime Kilns; Iron and Steel Reheat,
Annealing, and Galvanizing Furnaces; and Aluminum Reverberatory and
Crucible Furnaces
1)
An owner or operator of a glass melting furnace subject to Subpart G of
this Part, cement kiln or lime kiln subject to Subpart H of this Part, iron
and steel reheat, annealing, or galvanizing furnace subject to Subpart I of
this Part, or aluminum reverberatory or crucible furnace subject to Subpart
H of this Part that has the potential to emit NO
x
in an amount equal to or
greater than one ton per day must install, calibrate, maintain, and operate a
continuous emissions monitoring system on such emission unit for the
measurement of NO
x
emissions discharged into the atmosphere in
accordance with 40 CFR 60, subpart A and appendix B, Performance
Specifications 2 and 3, and appendix F, Quality Assurance Procedures, as
incorporated by reference in Section 217.104.

40
2)
An owner or operator of a glass melting furnace subject to Subpart G of
this Part, cement kiln or lime kiln subject to Subpart H of this Part, iron
and steel reheat, annealing, or galvanizing furnace subject to Subpart I of
this Part, or aluminum reverberatory or crucible furnace subject to Subpart
I of this Part that has the potential to emit NO
x
in an amount less than one
ton per day must have an initial performance test conducted pursuant to
subsection (b)(4) of this Section and Section 217.154.
3)
An owner or operator of a glass melting furnace subject to Subpart G of
this Part, cement kiln or lime kiln subject to Subpart H of this Part, iron
and steel reheat, annealing, galvanizing furnace subject to Subpart I of this
Part, or aluminum reverberatory or crucible furnace subject to Subpart I of
this Part that has the potential to emit NO
x
in an amount less than one ton
per day must have subsequent performance tests conducted pursuant to
subsection (b)(4) of this Section as follows:
A)
For all glass melting furnaces subject to Subpart G of this Part,
cement kilns or lime kilns subject to Subpart H of this Part, iron
and steel reheat, annealing, or galvanizing furnace subject to
Subpart I of this Part, or aluminum reverberatory or crucible
furnaces subject to Subpart I of this Part, including all such units
included in an emissions averaging plan, at least once every five
years; and
B)
When, in the opinion of the Agency or USEPA, it is necessary to
conduct testing to demonstrate compliance with Section 217.204,
217.224, or 217.244, of this Part, as applicable, the owner or
operator of a glass melting furnace, cement kiln, lime kiln, iron and
steel reheat, annealing, or galvanizing furnace, or aluminum
reverberatory or crucible furnace must, at his or her own expense,
have such test conducted in accordance with the applicable test
methods and procedures specified in this Section within 90 days
after receipt of a notice to test from the Agency or USEPA.
4)
The owner or operator of a glass melting furnace, cement kiln, or lime kiln
must have a performance test conducted using 40 CFR 60, subpart A and
appendix A, Methods 1, 2, 3, 4, and 7E, as incorporated by reference in
Section 217.104 of this Part, or other alternative USEPA methods
approved by the Agency. The owner or operator of an iron and steel
reheat, annealing, or galvanizing furnace, or aluminum reverberatory or
crucible furnace must have a performance test conducted using 40 CFR
60, subpart A and appendix A, Method 1, 2, 3, 4, 7E, or 19, as
incorporated by reference in Section 217.104 of this Part, or other
alternative USEPA methods approved by the Agency. Each performance
test must consist of three separate runs, each lasting a minimum of 60
minutes. NO
x
emissions must be measured while the glass melting

41
furnace, cement kiln, lime kiln, iron and steel reheat, annealing, or
galvanizing furnace, or aluminum reverberatory or crucible furnace is
operating at maximum operating capacity. If the glass melting furnace,
cement kiln, lime kiln, iron and steel reheat, annealing, or galvanizing
furnace, or aluminum reverberatory or crucible furnace has combusted
more than one type of fuel in the prior year, a separate performance test is
required for each fuel. Except as provided under subsection (e) of this
Section, this subsection (b)(4) does not apply if such owner or operator is
demonstrating compliance with an emissions limitation through a
continuous emissions monitoring system under subsection (b)(1) or (b)(5)
of this Section.
5)
Instead of complying with the requirements of subsections (b)(2), (b)(3),
and (b)(4) of this Section, an owner or operator of a glass melting furnace
subject to Subpart G of this Part, cement kiln or lime kiln subject to
Subpart H of this Part, iron and steel reheat, annealing, or galvanizing
furnace subject to Subpart I of this Part, or aluminum reverberatory or
crucible furnace subject to Subpart I of this Part that has the potential to
emit NO
x
in an amount less than one ton per day may install and operate a
continuous emissions monitoring system on such emission unit in
accordance with the applicable requirements of 40 CFR 60, subpart A and
appendix B, Performance Specifications 2 and 3, and appendix F, Quality
Assurance Procedures, as incorporated by reference in Section 217.104 of
this Part. The continuous emissions monitoring system must be used to
demonstrate compliance with the applicable emissions limitation or
emissions averaging plan on an ozone season and annual basis.
c)
Fossil Fuel-Fired Stationary Boilers. The owner or operator of a fossil fuel-fired
stationary boiler subject to Subpart M of this Part must install, calibrate, maintain,
and operate a continuous emissions monitoring system on such emission unit for
the measurement of NO
x
emissions discharged into the atmosphere in accordance
with 40 CFR 96, subpart H.
d)
Common Stacks. If two or more emission units subject to Subpart E, F, G, H, I,
M, or Q of this Part are served by a common stack and the owner or operator of
such emission units is operating a continuous emissions monitoring system, the
owner or operator may, with written approval from the Agency, utilize a single
continuous emissions monitoring system for the combination of emission units
subject to Subpart E, F, G, H, I,M , or Q of this Part that share the common stack,
provided such emission units are subject to an emissions averaging plan under this
Part.
e)
Compliance with the continuous emissions monitoring system (CEMS)
requirements by an owner or operator of an emission unit who is required to
install, calibrate, maintain, and operate a CEMS on the emission unit under
subsection (a)(1), (a)(2), (a)(3), or (b)(1) of this Section, or who has elected to

42
comply with the CEMS requirements under subsection (a)(5) or (b)(5) of this
Section, or who has elected to comply with the predictive emission monitoring
system (PEMS) requirements under subsection (f) of this Section, is required by
the following dates:
1)
For the owner or operator of an emission unit that is subject to a
compliance date in calendar year 2012 under Section 217.152, compliance
with the CEMS or PEMS requirements, as applicable, under this Section
for such emission unit is required by December 31, 2012, provided that,
during the time between the compliance date and December 31, 2012, the
owner or operator must comply with the applicable performance test
requirements under this Section and the applicable recordkeeping and
reporting requirements under this Subpart. For the owner or operator of
an emission unit that is in compliance with the CEMS or PEMS
requirements, as applicable, under this Section on January 1, 2012, such
owner or operator is not required to comply with the performance test
requirements under this Section.
2)
For the owner or operator of an emission unit that is subject to a
compliance date in a calendar year other than calendar year 2012 under
Section 217.152 of this Subpart, compliance with the CEMS or PEMS
requirements, as applicable, under this Section for such emission unit is
required by the applicable compliance date, and such owner or operator is
not required to comply with the performance test requirements under this
Section.
f)
As an alternative to complying with the requirements of this Section, other than
the requirements under subsections (a)(1) and (c) of this Section, the owner or
operator of an emission unit who is not otherwise required by any other statute,
regulation, or enforceable order to install, calibrate, maintain, and operate a
CEMS on the emission unit may comply with the specifications and test
procedures for a predictive emission monitoring system (PEMS) on the emission
unit for the measurement of NO
x
emissions discharged into the atmosphere in
accordance with the requirements of 40 CFR 60, subpart A and appendix B,
Performance Specification 16. The PEMS must be used to demonstrate
compliance with the applicable emissions limitation or emissions averaging plan
on an ozone season and annual basis.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.158
Emissions Averaging Plans
a)
Notwithstanding any other emissions averaging plan provisions under this Part, an
owner or operator of a source with certain emission units subject to Subpart E, F,
G, H, I or M of this Part, or subject to Subpart Q of this Part that are located in
either one of the areas set forth under Section 217.150(a)(1)(A)(i) or (ii), may

43
demonstrate compliance with the applicable Subpart through an emissions
averaging plan. An emissions averaging plan can only address emission units that
are located at one source and each unit may only be covered by one emissions
averaging plan. Such emission units at the source are affected units and are
subject to the requirements of this Section.
1)
The following units may be included in an emissions averaging plan:
A)
Units that commenced operation on or before January 1, 2002.
B)
Units that the owner or operator may claim as exempt pursuant to
Section 217.162, 217.182, 217.202, 217.222, 217.242, or 217.342
of this Part, as applicable, but does not claim exempt. For as long
as such a unit is included in an emissions averaging plan, it will be
treated as an affected unit and subject to the applicable emissions
limitations, and testing, monitoring, recordkeeping and reporting
requirements.
C)
Units that commence operation after January 1, 2002, if the unit
replaces a unit that commenced operation on or before January 1,
2002, or it replaces a unit that replaced a unit that commenced
operation on or before January 1, 2002. The new unit must be
used for the same purpose and have substantially equivalent or less
process capacity or be permitted for less NO
x
emissions on an
annual basis than the actual NO
x
emissions of the unit or units that
are replaced. Within 90 days after permanently shutting down a
unit that is replaced, the owner or operator of such unit must
submit a written request to withdraw or amend the applicable
permit to reflect that the unit is no longer in service before the
replacement unit may be included in an emissions averaging plan.
2)
The following types of units may not be included in an emissions
averaging plan:
A)
Units that commence operation after January 1, 2002, except as
provided by subsection (a)(1)(C) of this Section.
B)
Units that the owner or operator is claiming are exempt pursuant to
Section 217.162, 217.182, 217.202, 217.222, 217.242, or 217.342
of this Part, as applicable.
C)
Units that are required to meet emission limits or control
requirements for NO
x,
as provided for in an enforceable order,
unless the order allows for emissions averaging. In the case of
petroleum refineries, this subsection (a)(2)(C) does not prohibit
including industrial boilers or process heaters, or both, in an

44
emissions averaging plan when an enforceable order does not
prohibit the reductions made under the order from also being used
for compliance with any rules or regulations designed to address
regional haze or the non-attainment status of any area.
b)
An owner or operator must submit an emissions averaging plan to the Agency by
January 1, 2012. The plan must include, but is not limited to, the following:
1)
The list of affected units included in the plan by unit identification
number; and
2)
A sample calculation demonstrating compliance using the methodology
provided in subsection (f) of this Section for the ozone season (May 1
through September 30) and calendar year (January 1 through December
31).
c)
An owner or operator may amend an emissions averaging plan only once per
calendar year. Such an amended plan must be submitted to the Agency by
January 1 of the applicable calendar year. If an amended plan is not received by
the Agency by January 1 of the applicable calendar year, the previous year’s plan
will be the applicable emissions averaging plan.
d)
Notwithstanding subsection (c) of this Section:
1)
If a unit that is listed in an emissions averaging plan is taken out of
service, the owner or operator must submit to the Agency, within 30 days
after such occurrence, an updated emissions averaging plan; or
2)
If a unit that was exempt from the requirements of Subpart E, F, G, H, I,
or M of this Part pursuant to Section 217.162, 217.182, 217.202, 217.222,
217.242 or 217.342, of this Part, as applicable, no longer qualifies for an
exemption, the owner or operator may amend its existing averaging plan
to include such unit within 30 days after the unit no longer qualifies for the
exemption.
e)
An owner or operator must:
1)
Demonstrate compliance for the ozone season (May 1 through September
30) and the calendar year (January 1 through December 31) by using the
methodology and the units listed in the most recent emissions averaging
plan submitted to the Agency pursuant to subsection (b) of this Section,
the monitoring data or test data determined pursuant to Section 217.157,
and the actual hours of operation for the applicable averaging plan period;
and

 
45
2)
Submit to the Agency, by March 1 following each calendar year, a
compliance report containing the information required by Section
217.156(i).
f)
The total mass of actual NOx emissions from the units listed in the emissions
averaging plan must be equal to or less than the total mass of allowable NOx
emissions for those units for both the ozone season and calendar year. The
following equation must be used to determine compliance:
N
act
≤ N
all
Where:
N
act
=
=
n
i
act i j
k
1
j
( , )
=
1
EM
N
all
=
=
n
i
all i j
k
1
j
( , )
=
1
EM
N
act
=
Total sum of the actual NOx mass emissions from units
included in the averaging plan for each fuel used (tons per
ozone season and year).
N
all
=
Total sum of the allowable NOx mass emissions from units
included in the averaging plan for each fuel used (tons per
ozone season and year).
EM
act(i)
=
i
=
Subscript denoting an individual unit.
Total mass of actual NO
X
emissions in tons for a unit as
determined in subsection (f)(1) of this Section.
J
=
Subscript denoting the fuel type used.
K
=
Number of different fuel types.
n
=
Number of different units in the averaging plan.
EM
all(i)
=
Total mass of allowable NOx emissions in tons for a unit
as determined in subsection (f)(2) of this Section.
For each unit in the averaging plan, and each fuel used by such unit, determine
actual and allowable NOx emissions using the following equations:
1)
Actual emissions must be determined as follows:
When emission limits are prescribed in lb/mmBtu,
EM
act(i)
=
E
act(i)
x H
i
/2000
When emission limits are prescribed in lb/ton of processed
product,
EM
act(i)
=
E
act(i)
x P
i
/2000
2)
Allowable emissions must be determined as follows:

 
46
When emission limits are prescribed in lb/mmBtu,
EM
all(i)
=
E
all(i)
x H
i
/2000
When emission limits are prescribed in lb/ton of processed
product,
EM
all(i)
=
E
all(i)
x P
i
/2000
Where:
EM
act(i)
=
Total mass of actual NOx emissions in tons for a
unit.
EM
all(i)
=
Total mass of allowable NOx emissions in tons for
a unit.
E
act
=
Actual NOx emission rate (lbs/mmBtu or lbs/ton of
product) as determined by a performance test, a
continuous emissions monitoring system, or an
alternative method approved by the Agency.
E
all
=
Allowable NOx emission rate (lbs/mmBtu or lbs/ton
of product) as provided in Section 217.164,
217.184, 217.204, 217.224, 217.244, or 217.344, as
applicable. For an affected industrial boiler subject
to Subpart E of this Part, or process heater subject
to Subpart F of this Part, with a rated heat input
capacity less than or equal to 100 mmBtu/hr
demonstrating compliance through an emissions
averaging plan, the allowable NOx emission rate is
to be determined from a performance test after such
boiler or heater has undergone combustion tuning.
For all other units in an emissions averaging plan,
an uncontrolled NOx emission rate from USEPA’s
AP-42, as incorporated by reference in Section
217.104, or an uncontrolled NOx emission rate as
determined by an alternative method approved by
the Agency, will be used.
H
=
Heat input (mmBtu/ozone season or mmBtu/year)
calculated from fuel flow meter and the heating
value of the fuel used.
P
=
weight in tons of processed product.
g)
An owner or operator of an emission unit subject to Subpart Q of this Part that is
located in either one of the areas set forth under Section 217.150(a)(1)(A)(i) or (ii)
that is complying through an emissions averaging plan under this Section must

47
comply with the applicable provisions for determining actual and allowable
emissions under Section 217.390, the testing and monitoring requirements under
Section 217.394, and the recordkeeping and reporting requirements under Section
217.396.
h)
The owner or operator of an emission unit located at a petroleum refinery who is
demonstrating compliance with an applicable Subpart through an emissions
averaging plan under this Section may exclude from the calculation demonstrating
compliance those time periods when an emission unit included in the emissions
averaging plan is shut down for a maintenance turnaround, provided that such
owner or operator notify the Agency in writing at least 30 days in advance of the
shutdown of the emission unit for the maintenance turnaround and the shutdown
of the emission unit does not exceed 45 days per ozone season or calendar year
and NO
x
pollution control equipment, if any, continues to operate on all other
emission units operating during the maintenance turnaround.
i)
The owner or operator of an emission unit that combusts a combination of coke
oven gas and other gaseous fuels and that is located at a source that manufactures
iron and steel who is demonstrating compliance with an applicable Subpart
through an emissions averaging plan under this Section may exclude from the
calculation demonstrating compliance those time periods when the coke oven gas
desulfurization unit included in the emissions averaging plan is shut down for
maintenance, provided that such owner or operator notify the Agency in writing at
least 30 days in advance of the shutdown of the coke oven gas desulfurization unit
for maintenance and such shutdown does not exceed 35 days per ozone season or
calendar year and NO
x
pollution control equipment, if any, continues to operate
on all other emission units operating during the maintenance period.
j)
The owner or operator of an emission unit located at a petroleum refinery who is
demonstrating compliance with an applicable Subpart through an emissions
averaging plan under this Section may exclude from the calculation demonstrating
compliance those time periods when NO
x
pollution control equipment that
controls one or more emission units included in the emissions averaging plan is
shut down for a maintenance turnaround, provided that: 1) the owner or operator
notify the Agency in writing, at least 30 days in advance of the shutdown, of the
NO
x
pollution control equipment for the maintenance turnaround; 2) the shutdown
of the NO
x
pollution control equipment does not exceed 45 days per ozone season
or calendar year; and 3) except for those emission units vented to the NO
x
pollution control equipment undergoing the maintenance turnaround, NO
x
pollution control equipment, if any, continues to operate on all other emission
units operating during the maintenance turnaround.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
SUBPART E: INDUSTRIAL BOILERS

48
Section 217.160 Applicability
a)
The provisions of Subpart D of this Part and this Subpart apply to all industrial
boilers located at sources subject to this Subpart pursuant to Section 217.150,
except as provided in subsections (b) and (c) of this Section.
b)
The provisions of this Subpart do not apply to boilers serving a generator that has
a nameplate capacity greater than 25 MWe and produces electricity for sale, if
such boilers meet the applicability criteria under Subpart M of this Part.
c)
The provisions of this Subpart do not apply to fluidized catalytic cracking units,
their regenerator and associated CO boiler or boilers and CO furnace or furnaces
where present, if such units are located at a petroleum refinery and such units are
required to meet emission limits or control requirements for NO
x
as provided for
in an enforceable order.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.162 Exemptions
Notwithstanding Section 217.160 of this Subpart, the provisions of this Subpart do not apply to
an industrial boiler operating under a federally enforceable limit of NO
x
emissions from such
boiler to less than 15 tons per year and less than five tons per ozone season.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.164 Emissions Limitations
a)
Except as provided for under Section 217.152, on and after January 1, 2012, no
person shall cause or allow emissions of NO
x
into the atmosphere from any
industrial boiler to exceed the following limitations. Compliance must be
demonstrated with the applicable emissions limitation on an ozone season and
annual basis.
Fuel
Emission Unit Type and
Rated Heat Input Capacity
(mmmBtu/hr)
NO
x
Emissions
Limitation (lb/mmmBtu
or Requirement
Natural Gas or Other
Gaseous Fuels
Industrial boiler greater
than 100
0.08
Industrial boiler less than
equal to 100
Combustion tuning
Distillate Fuel Oil
Industrial boiler greater
0.10

49
than 100
Industrial boiler less than
or equal to 100
Combustion tuning
Other Liquid Fuels
Industrial boiler greater
than 100
0.15
Industrial boiler less than
or equal to 100
Combustion tuning
Solid Fuel
Industrial boiler greater
than 100, circulating
fluidized bed combustor
0.12
Industrial boiler greater
than 250
0.18
Industrial boiler greater
than 100 but less than or
equal to 250
0.25
Industrial boiler less than
or equal to 100
Combustion tuning
b)
For an industrial boiler combusting a combination of natural gas, coke oven gas,
and blast furnace gas, the NO
x
emissions limitation shall be calculated using the
following equation:
NO
x
emissions limitation for period in lb/MMBtu= (
NO
xNG
* Btu
NG
+
NO
xCOG
* Btu
COG
+ NO
xBFG
* Btu
BFG
) /
(
Btu
NG
+ Btu
COG
+ Btu
BFG
)
Where:
NO
xNG
= 0.084 lb/MMBtu for natural gas
Btu
NG
= the heat input of natural gas in Btu over that period
NO
xCOG
= 0.144 lb/MMBtu for coke oven gas
Btu
COG
= the heat input of coke oven gas in Btu over that period
NO
xBFG
= 0.0288 lb/MMBtu for blast furnace gas

50
Btu
BFG
= the heat input of blast furnace gas in Btu over that period
(Source: Added at 33 Ill. Reg. ____, effective _______)
Section 217.165 Combination of Fuel
s
The owner or operator of an industrial boiler subject to this Subpart and operated with any
combination of fuels must comply with a heat input weighted average emissions limitation to
demonstrate compliance with Section 217.164.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.166 Methods and Procedures for Combustion Tuning
The owner or operator of an industrial boiler subject to the combustion tuning requirements of
Section 217.164 must have combustion tuning performed on the boiler at least annually. The
combustion tuning must be performed by an employee of the owner or operator or a contractor
who has successfully completed a training course on the combustion tuning of boilers firing the
fuel or fuels that are fired in the boiler. The owner or operator must maintain the following
records that must be made available to the Agency upon request:
a)
The date the combustion tuning was performed;
b)
The name, title, and affiliation of the person who performed the combustion
tuning;
c)
Documentation demonstrating the provider of the combustion tuning training
course, the dates the training course was taken, and proof of successful
completion of the training course;
d)
Tune-up procedure followed and checklist of items (such as burners, flame
conditions, air supply, scaling on heating surface, etc.) inspected prior to the
actual tune-up; and
e)
Operating parameters recorded at the start and at conclusion of combustion
tuning.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
SUBPART F: PROCESS HEATERS
Section 217.180 Applicability
The provisions of Subpart D of this Part and this Subpart apply to all process heaters located at
sources subject to this Subpart pursuant to Section 217.150.

51
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.182 Exemptions
Notwithstanding Section 217.180, the provisions of this Subpart do not apply to a process heater
operating under a federally enforceable limit of NO
x
emissions from such heater to less than 15
tons per year and less than five tons per ozone season.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.184 Emissions Limitations
Except as provided for under Section 217.152, on and after January 1, 2012, no person shall
cause or allow emissions of NO
x
into the atmosphere from any process heater to exceed the
following limitations. Compliance must be demonstrated with the applicable emissions
limitation on an ozone season and annual basis.
Fuel
Emission Unit Type andRated
Heat Input Capacity(mmmBtu/hr)
NO
x
Emissions Limitation
(lb/mmmBtu
or Requirement
Natural Gas or
Other Gaseous
Fuels
Process heater greater
than 100
0.08
Process heater less than
or equal to 100
Combustion tuning
Residual Fuel
Oil
Process heater greater
than 100, natural draft
0.10
Process heater greater than
100, mechanical draft
0.15
Process heater less than
or equal to 100
Combustion tuning
Other Liquid
Fuels
Process heater greater
than 100, natural draft
0.05
Process heater greater than
100, mechanical draft
0.08
(Source: Added at 33 Ill. Reg. ____, effective ______________)

52
Section 217.185 Combination of Fuels
The owner or operator of a process heater subject to this Subpart and operated with any
combination of fuels must comply with a heat input weighted average emissions limitation to
demonstrate compliance with Section 217.184.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.186 Methods and Procedures for Combustion Tuning
The owner or operator of a process heater subject to the combustion tuning requirements of
Section 217.184 must have combustion tuning performed on the heater at least annually. The
combustion tuning must be performed by an employee of the owner or operator or a contractor
who has successfully completed a training course on the combustion tuning of heaters firing the
fuel or fuels that are fired in the heater. The owner or operator must maintain the following
records that must be made available to the Agency upon request:
a)
The date the combustion tuning was performed;
b)
The name, title, and affiliation of the person who performed the
combustion tuning;
c)
Documentation demonstrating the provider of the combustion tuning
training course, the dates the training course was taken, and proof of
successful completion of the training course;
d)
Tune-up procedure followed and checklist of items (such as burners, flame
conditions, air supply, scaling on heating surface, etc.) inspected prior to
the actual tune-up; and
e)
Operating parameters recorded at the start and at conclusion of
combustion tuning.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
SUBPART G: GLASS MELTING FURNACES
Section 217.200 Applicability
The provisions of Subpart D of this Part and this Subpart apply to all glass melting furnaces
located at sources subject to this Subpart pursuant to Section 217.150.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.202 Exemptions

53
Notwithstanding Section 217.200, the provisions of this Subpart do not apply to a glass melting
furnace operating under a federally enforceable limit of NO
x
emissions from such furnace to less
than 15 tons per year and less than five tons per ozone season.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.204 Emissions Limitations
a)
On and after January 1, 2012, no person shall cause or allow emissions of NO
x
into the atmosphere from any glass melting furnace to exceed the following
limitations. Compliance must be demonstrated with the emissions limitation on
an ozone season and annual basis.
Product
Emission Unit Type
Nox Emissions Limitation
(lb/ton glass produced)
Container Glass
Glass melting furnace
5.0
Flat Glass
Glass melting furnace
7.9
Other Glass
Glass melting furnace
11.0
b)
The emissions during glass melting furnace startup (not to exceed 70 days) or
furnace idling (operation at less than 35% of furnace capacity) shall be excluded
from calculations for the purpose of demonstrating compliance with the seasonal
and annual emissions limitations under this Section, provided that the owner or
operator, at all times, including periods of startup and idling, to the extent
practicable, maintain and operate any affected emission unit, including associated
air pollution control equipment, in a manner consistent with good air pollution
control practice for minimizing emissions. The owner or operator of a glass
melting furnace must maintain records that include the date, time, and duration of
any startup or idling in the operation of the glass melting furnace.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
SUBPART H: CEMENT AND LIME KILNS
Section 217.220 Applicability
a)
Notwithstanding Subpart T of this Part, the provisions of Subpart D of this Part
and this Subpart apply to all cement kilns located at sources subject to this
Subpart pursuant to Section 217.150.
b)
The provisions of Subpart C of this Part and this Subpart apply to all lime kilns
located at sources subject to this Subpart pursuant to Section 217.150.

54
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.222 Exemptions
Notwithstanding Section 217.220, the provisions of this Subpart do not apply to a cement kiln or
lime kiln operating under a federally enforceable limit of NO
x
emissions from such kiln to less
than 15 tons per year and less than five tons per ozone season.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.224 Emissions Limitations
a)
On and after January 1, 2012, no person shall cause or allow emissions of NO
x
into the atmosphere from any cement kiln to exceed the following limitations.
Compliance must be demonstrated with the applicable emissions limitation on an
ozone season and annual basis.
Emission Unit Type
NO
x
Emissions Limitation
(lb/ton clinker produced)
Long dry kiln
5.1
Short dry kiln
5.1
Preheater kiln
3.8
Preheater/precalciner kiln
2.8
b)
On and after January 1, 2012, no person shall cause or allow emissions of NO
x
into the atmosphere from any lime kiln to exceed the following limitations.
Compliance must be demonstrated with the applicable emissions limitation on an
ozone season and annual basis.
Fuel
Emission Unit Type
Nox Emissions Limitation
(lb/ton lime produced)
Gas
Rotary kiln
2.2
Coal
Rotary kiln
2.5
(Source: Added at 33 Ill. Reg. ____, effective ______________)
SUBPART I: IRON AND STEEL AND ALUMINUM MANUFACTURING
Section 217.240 Applicability

55
a)
The provisions of Subpart D of this Part and this Subpart apply to all reheat
furnaces, annealing furnaces, and galvanizing furnaces used in iron and steel
making located at sources subject to this Subpart pursuant to Section 217.150.
b)
The provisions of Subpart D of this Part and this Subpart apply to all
reverberatory furnaces and crucible furnaces used in aluminum melting located at
sources subject to this Subpart pursuant to Section 217.150.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.242 Exemptions
Notwithstanding Section 217.240, the provisions of this Subpart do not apply to an iron and steel
reheat furnace, annealing furnace, or galvanizing furnace, or aluminum reverberatory furnace or
crucible furnace operating under a federally enforceable limit of NO
x
emissions from such
furnace to less than 15 tons per year and less than five tons per ozone season.
(Source: Added at 33 Ill. Reg. ____, effective ______________)_________)
Section 217.244 Emissions Limitations
a)
On and after January 1, 2012, no person shall cause or allow emissions of NO
x
into the atmosphere from any reheat furnace annealing furnace, or galvanizing
furnace used in iron and steel making to exceed the following limitations.
Compliance must be demonstrated with the applicable emissions limitation on an
ozone season and annual basis.
NO
x
Emissions Limitation
Emission Unit Type
(lb/mmBtu)_________
Reheat furnace, regenerative
0.18
Reheat recuperative, combusting
0.09
natural gas
Reheat furnace, recuperative, combusting a
0.142
combination of natural gas and coke oven
gas
Reheat furnace, cold-air
0.03
Annealing furnace, regenerative
0.38
Annealing furnace, recuperative
0.16
Annealing furnace, cold-air
0.07

56
Galvanizing furnace, regenerative
0.46
Galvanizing furnace, cuperative
0.16
Galvanizing furnace, cold-air
0.06
b)
On and after January 1, 2012, no person shall cause or allow emissions of NO
x
into the atmosphere from any reverberatory furnace or crucible furnace used in
aluminum melting to exceed the following limitations. Compliance must be
demonstrated with the applicable emissions limitation on an ozone season and
annual basis.
Emission Unit Type
NO
x
Emissions
Limitation (lb/mmmBtu)
Reverberatory furnace
0.08
Crucible furnace
0.16
(Source: Added at 33 Ill. Reg. ____, effective ______________)
SUBPART M: ELECTRICAL GENERATING UNITS
Section 217.340 Applicability
Notwithstanding Subpart V or W of this Part, the provisions of Subpart D of this Part and this
Subpart apply to any fossil fuel-fired stationary boiler serving at any time a generator that has a
nameplate capacity greater than 25 MWe and produces electricity for sale, excluding any units
listed in Appendix D of this Part, located at sources subject to this Subpart pursuant to Section
217.150.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.342 Exemptions
a)
Notwithstanding Section 217.340, the provisions of this Subpart do not apply to a
fossil fuel-fired stationary boiler operating under a federally enforceable limit of
NO
x
emissions from such boiler to less than 15 tons per year and less than five
tons per ozone season.
b)
Notwithstanding Section 217.340, the provisions of this Subpart do not apply to a
coal-fired stationary boiler that commenced operation before January 1, 2008, that
is complying with Part 225.Subpart B through the multi-pollutant standard or the
combined pollutant standard.

57
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.344 Emissions Limitations
On and after January 1, 2012, no person shall cause or allow emissions of NO
x
into the
atmosphere from any fossil fuel-fired stationary boiler to exceed the following limitations.
Compliance must be demonstrated with the applicable emissions limitation on an ozone season
and annual basis.
Fuel
Emission Unit Type
NO
x
Emissions
Limitation (lb/mmmBtu)
Solid
Boiler
0.12
Natural gas
Boiler
0.06
Liquid
Boiler that commenced
operation before January 1,
2008.
0.10
Boiler that commenced
Operation on or after
January 1, 2008
0.08
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.345 Combination of Fuels
The owner or operator of a fossil fuel-fired stationary boiler subject to this Subpart and operated
with any combination of fuels must comply with a heat input weighted average emissions
limitation to demonstrate compliance with Section 217.344.
(Source: Added at 33 Ill. Reg. ____, effective ______________)
Section 217.APPENDIX H: Compliance Dates for Certain Emission Units at Petroleum
Refineries
ExxonMobil Oil Corporation (Facility ID 197800AAA)
Point
Emission Unit Description
Compliance Date
0019
Crude Vacuum Heater (13-B-2)
December 31,2014
0038
Alky Iso-Stripper Reboiler (7-B-1)
December 31,2014
0033
CHD Charge Heater (3-B-1)
December 31,2014
0034
CHD Stripper Reboiler (3-B-2)
December 31,2014

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0021
Coker East Charge Heater (16-B-1A)
December 31,2014
0021
Coker East Charge Heater (16-B-1B)
December 31,2014
0018
Crude Atmospheric Heater (1-B-1A)
December 31,2014
0018
Crude Atmospheric Heater (1-B-1B)
December 31,2014
ConocoPhillips Company Wood River Refinery (Facility ID 119090AAA)
Point
Emission Unit Description
Compliance Date
0017
BEU-HM-1
December 31, 2012
0018
BEU-HM-2
December 31, 2012
0004
CR-1 Feed Preheat, H-1
December 31, 2012
0005
CR-1 1st Interreactor Heater, H-2
December 31, 2012
0009
CR-1 3rd Interreactor Heater, H-7
December 31, 2012
0091
CR-3 Charge Heater
December 31, 2012
0092
CR-3 1st Reheat Heater, H-5
December 31, 2012
0082
Boiler 17
December 31, 2012
0080
Boiler 15
December 31, 2012
0073
Alky HM-2 Heater
December 31, 2012
0662
VF-4 Charge Heater, H-28
December 31, 2012
0664
DU-4 Charge Heater, H-24
December 31, 2014
0617
DCU Charge Heater, H-20
December 31, 2014
0014
HCU Fractionator Reboil, H-3
December 31, 2016
0024
DU-1 Primary Heater South, F-301
December 31, 2016
0025
DU-1 Secondary Heater North, F-302
December 31, 2016
0081
Boiler 16
December 31, 2016
0083
Boiler 18
December 31, 2016
0095
DHT Charge Heater
December 31, 2016
0028
DU-2 Lube Crude Heater F-200
December 31, 2016
0029
DU-2 Mixed Crude Heater West, F 202
December 31, 2016
0030
DU-2 Mixed Crude Heater East, F-203
December 31, 2016
0084
CR-2 North Heater
December 31, 2016
0661
CR-2 South Heater
December 31, 2016
(Source: Added at 33 Ill. Reg. _____, effective __________)
IT IS SO ORDERED.

59
I, John T. Therriault, Assistant Clerk of the Illinois Pollution Control Board, certify that
the Board adopted the above opinion and order on August 20, 2009, by a vote of 5-0.
___________________________________
John T. Therriault, Assistant Clerk
Illinois Pollution Control Board

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