ILLINOIS REGISTER
1
09
POLLUTION CONTROL
BOARD
NOTICE OF PROPOSED
AMENDMENTS
1)
Heading
of the Part:
Definitions and General Procedures
2)
Code Citation: 35 Iii. Adm. Code 211
3)
211.665Section
Numbers:
New
Proposed
Section
Action:
AY
1
9
2o0
211.995
New Section
pollution
c.LLINoIs
211.1315
NewSection
211.1435
New Section
211.2355
New Section
211.2357
New Section
211.2625
New Section
211.3100
New Section
211.3355
New Section
211.3475
New Section
211.4280
New Section
211.5195
New Section
4)
Statutory Authority: Implementing Section 10 and
authorized by Sections 27 and 28
of
the Environmental Protection Act [415 ILCS 5/10, 27, and 28]
5)
A
Complete Description of the Subjects
and Issues Involved:
The
Board’s May
7,
2009 opinion
and order (Amendments to 35 Ill. Adm. Code 217,
Nitrogen Oxides Emissions, and 35 Ill. Adm. Code 211,
R08-19, slip op. at 21-27
(summarizing twelve proposed new definitions))
describes the twelve new Sections
of
Part 211 proposed in
this
rulemaking.
This
rulemaking is based on
a proposal filed with the Board
by
the Illinois
Environmental
Protection Agency (Agency) on May
9,
2008. The Agency
proposes to amend Parts 211
and 217 of
the Board’s air pollution
regulations (35 Ill. Adm. Code 211, 217)
to control
nitrogen oxides
(NO)
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 Part 211, the Agency proposes
to add
twelve new definitions of terms employed in proposed
new Sections of Part 217.
On April 2,
2009, the Board granted
the Agency’s motion to
expedite
review
of this
proposal
in order to meet federal deadlines
for submission of State Implementation
Plans
for
NOR.
In its May 7, 2009, opinion and order, the Board
stated that, having granted
the
ILLINOIS
REGISTER
2
09
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED AMENDMENTS
motion
for expedited review, it is highly unlikely to grant any motion for an extension
of
the first-notice comment period. The Board strongly encouraged participants who wish
to file a
public
comment to do so within the statutory 45-day period.
6)
Published studies or reports, and sources of underlying data, used to compose this
rulemaking:
The Agency stated
that it relied on the
following
68 sources
in
preparing its
proposal to the Board:
1.
The Clean Air Act, as amended in 1990 (42
USC
7401 et seq.);
2.
Illinois Environmental Protection Act (415 ILCS 5);
3.
Energy & Environmental Analysis, Inc., “Characterization of the
U.S.
Boiler
Industrial Commercial Boiler Population”, submitted to Oak Ridge National
Laboratory, May 2005;
4.
http
://commons.wikimedia.org/wiki/Image:Water tube boiler schematic.png;
5.
http ://en.wikipedia.org!wiki/Image:Locomotive fire tube boiler schematic.png;
6.
Babcock &
Wilcox Company;
Steam, Its
Generation
and Use,
40
th
Edition, 1992;
7.
Neil Johnson, “Fundamentals of Stoker Fired Boiler Design and Operation”,
presented at CIBO Emission Controls Technology Conference, July 15-17,
2002;
8.
Letter
to Mr. Regulator, New Hampshire Division of Environmental Services,
from Daniel J.
Willems,
Product Development, Cleaver Brooks, dated May 19,
2006;
9.
http
://wwwl.eere.energy.gov/industryfbestpractices/pdfs/steam4_boiler_
efficiency.pdf
10.
http
://www.energysolutionscenter.orglboilerbumer/Eff_Improve/
Efficiency/Oxygen_Control.asp;
11.
http://files.asme.org/asmeorg/Codes/CertifAccred/Personnel12971
.pdf;
12.
http
://www.coen.comli_html/white_lowcostnoxpm.html;
ILLINOIS REGISTER
3
09
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED AMENDMENTS
13.
Rajani Varagani (n.d.),
“A
Cost Effective
Low
NO
Retrofit Technology for
Industrial Boilers,” cited within CIBO Industrial Emissions
Control Technology
III, August
1-3, 2005;
14.
Email from Jim Staudt, Andover Technology,
to R. Gifford
Broderick,
Combustion
Components Associates, Based on estimate for a 4-burner project,
dated October 16, 2003;
15.
http ://www.johnziuk.com!products/burners/htmltoddlburntoddcsl
04.htm;
16.
Sacramento
General Services Heating Plant Case Study: COEN web site:
http :!/www.coen.comlmrktli/ibrochures/pdf/qla.pdf;
17.
Zink, John (2003)
“U.S.
Borax TODD Ultra Low Emissions
Burner Installment”;
18.
Zink, John (2003) “TODD Ultra
Low Emissions Burner Installment”;
19.
Coen Company, “Ultra Low
NO
Gas-Fired Burner with
Air Preheat”, Final
Report, prepared for California Air Resources Board, November 23, #2000;
20.
Memorandum from Jim Staudt, Andover
Technology Partners, to Sikander Khan,
United States Environmental Protection Agency, providing
comments in response
to
September 10, 2003
email, dated October 24, 2003;
21.
Memorandum from
Chad
Whiteman,
Institute of Clean Air Companies to
Christopher Recchia, Ozone Transport Commission,
regarding Selective Non-
Catalytic Reduction Technology
Costs
for
Industrial Sources, dated October
6,
2006;
22.
Northeast
States
for
Coordinated Air Use Management (NESCAUM),
“Status
Report on
NOR:
Control Technologies and
Cost Effectiveness for Utility Boilers”,
prepared
by Jim Staudt, Andover Technology Partners, June 1998;
23.
Northeast States for Coordinated Air
Use Management (NESCAUM), “Status
Report on
NOX
Controls”, prepared by Jim Staudt,
Andover Technology Partners,
December 2000
(“NESCAUM 2000 report”);
24.
Institute to Clean Air Companies, Inc.,
“White Paper: Selective Catalytic
Reduction (SCR) Control of
NO
Emissions”, November
1997;
ILLINOIS
REGISTER
4
09
POLLUTION CONTROL
BOARD
NOTICE
OF PROPOSED AMENDMENTS
25.
http ://www.cormetech.comlexperience.htm;
26.
“Economic Indicators”, Chemical
Engineering,
p.
102, September 2006;
27.
Vatatuck,
William M., “Updating the CE Plant Cost Index”, Chemical
Engineering,
p.
69,
January 2002;
28.
State and Territorial Air Pollution
(STAPPA)
and Association
of Local Air
Pollution
Control Offices (ALAPCO), “Controlling Fine Particulate Matter
Under
the Clean Air Act: A Menu of Options”, March 2006;
29.
Erickson, C., and Staudt,
J.,
“Selective Catalytic Reduction System Perfonnance
and Reliability Review”, presented
at the EPRI-EPA-DOE-AWMA Combined
Utility Air Pollution Control Conference, the Mega Conference, Baltimore,
August 28-3
1,
2006;
30.
Cichanowicz, E.J., “Current Capital Cost and Cost-Effectiveness
of Power Plant
Emissions Control Technologies”, prepared for Utility Air Regulatory Group,
June
2007.
31.
http://www.mobotecusa.com/projects/vermillion-sellsheet.pdf
32.
http
://www.mobotecusa.comlproj
ects/capefear6-sellsheet.pdf;
33.
STAPPA!ALAPCO, “Controlling
Nitrogen Oxides under the Clean Air Act:
A
Menu of Options”, July 1994;
34.
Khan, Sikander,
United
States Environmental Protection Agency, “Methodology,
Assumptions, and References Preliminary
NO
Controls
Cost Estimates for
Industrial Boilers”,
October-November 2003;
35.
MACTEC
Federal
Programs/MACTEC Engineering and Consulting,
Inc.,
“Midwest Regional Planning
Organization (RPO): Petroleum Refinery Best
Available Retrofit Technology (BART)”, Engineering
Analysis, prepared for The
Lake Michigan Air Directors Consortium (LADCO), March
30, 2005. (“LADCO
2005”);
36.
http ://www.epa. gov/air/ozonepollutionlSlPToolkit/documents/
stationary_nox_list.pdf;
ILLiNOIS REGISTER
5
09
POLLUTION
CONTROL BOARD
NOTICE
OF PROPOSED AMENDMENTS
37.
http://www.callidus.com!pages/next_gen.htm;
38.
Heat Input Affects
NO
Emissions from Internal Flue Gas Re-Circulation
Burners
http ://texasiof.ces.utexas.edu/texasshowcase/pdfs/presentations/c
1 /dbishop.pdf
39.
http
://www.andovertechno1ogy.com1HGA_Market_Report_secure.pdf
40.
http://vvww.valleyair.org/rules/currntrules/r4304.pdf;
41.
www.perf.org/ppt/Bishop.ppt;
42.
State of New Jersey Department of Environmental
Protection, State of the Art
Manual for Boilers and
Process Heaters, July 1997 (revised February 22, 2004).
www.state.nj .us/dep/aqpp/downloads/sotalsotal 2
.pdf;
43.
Partha Ganguli, Workgroup
Recommendations and Other Potential Control
Measures Stationary Combustion
Sources Workgroup, May 11, 2006.
http ://www.nj .gov/dep/airworkgroups/docs/wps/SCSOO4A_fin.pdf
44.
Sun, W.H., Bisnett, M.J., et al., “Reduction of
NO
Emissions
from Cement
KilnlCalciner through the
Use of the
NOXOUT
Process”, International Specialty
Conference on Waste Combustion in Boilers and Industrial
Furnaces, April 21,
1994;
45.
http ://www.cadencerecycling.comlpdf/6-PageComplete.pdf
46.
Hansen, E., Cadence Environmental
Energy Inc., “Staged Combustion
for
NO
Reduction Using High Pressure Air Injection”, undated.
http
://www.cadencerecycling.comlpdf/IEEE2002.pdf
47.
Sabo,
E., MACTEC Federal Programs,
Inc., “Candidate Control Measures
for
Cement Plants”, LADCO/MRPO, Regional Air Quality
Workshop, June 28, 2005;
48.
United
States Environmental Protection
Agency, Office of Air Quality, Planning
and
Standards, Technical Bulletin: Nitrogen
Oxides
(NOr),
Why and How They
Are Controlled, EPA-456/F-99-006R, November
1999.
http
://www. epa.gov/ttn!catc/dir1/fhoxdoc.pdf
ILLINOIS REGISTER
6
09
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED
AMENDMENTS
49.
Finding of Significant
Contribution and Rulemaking for Certain
States in the
Ozone Transport Assessment Group
Region for Purposes of Reducing
Regional
Transport
of Ozone, Rule, 63 Fed. Reg.
57356, October 27, 1998;
50.
State of Michigan v. USEPA, 213
F.3d 663 (D.C. Cir. 2000);
51.
Federal Implementation Plans to
Reduce the Regional Transport
of Ozone;
Proposed Rule,
63 Fed. Reg. 56394, October
21, 1998;
52.
United States Environmental
Protection Agency, Office
of Air and Radiation,
Regulatory Impact Analysis for the
NO
SIP Call, FTP, and Section 126
Petitions,
Volume 1: Costs and
Economic Impacts, September 1998;
53.
Waible, R., Price, D.,
Tish, P., Halpern, M., “Advanced
Burner Technology
for
Stringent NOx Regulations”, presented
at the American Petroleum Institute
Midyear Refining Meeting, Orlando, FL,
May 8, 1990;
54.
Nguyen, Quang, Koppang,
Richard, Energy and Environmental
Research
Corporation, Advanced Steel Reheat
Furnaces Research and Development,
Final
Report, prepared for
U.S.
Department
of Energy, January 14, 1999;
55.
Rowlan, Steven
J.
and Sun,
William H.,
“NO
Control on Preheat
and Radiant
Furnaces at Nucor Steel Mills through
Urea SNCR, SCR, and Hybrid
Processes”,
presented at ICAC Forum,
Houston, TX, February 12-13, 2002.
http ://www.icac.com!Files/Rowlan.pdf
56.
Kobayashi, H., “Advances in Oxy-Fuel Fired
Glass Melting Technology”,
presented at XX International
Congress on Glass
(ICG),
Kyoto,
Japan, September
26- October
1,
2004;
57.
http ://wwwl.eere.energy.gov/industry/glass/pdfs/airstaging.pdf;
58.
http
://www.gastechnology.org/webroot/app/xn!xd.aspx?it=enweb&xd=
4reportspubs%5C4_8focus%5Coxygenenrichedairstaging.xml;
59.
http ://www.osti.gov/energycitations/product.biblio.j
sp?osti
id=6 16314;
60.
Midwest RPO Candidate Control Measures,
Interim White Paper,
Source
Category: Glass Manufacturing,
December 2, 2005;
ILLINOIS REGISTER
7
09
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED AMENDMENTS
61.
Energetics, Inc., Energy
and
Environmental Profile
of the
U.S.
Aluminum
Industry, prepared for
U.S.
Department of Energy, July 1997;
62.
http ://wwwl.eere.energy.
gov/industry/aluminum!pdfs/aluminum.pdf;
63.
Schalles, David
G., The Next Generation of Combustion Technology for
Aluminum Melting, undated. http ://www.bloomeng.comltmspaper-FINAL.doc;
64.
http://www.bloomeng.com/1 1501 umiflame.pdf;
65.
http ://www.eere.energy.gov!industry/combustion!pdfs/oscllcomb.pdf;
66.
California South Coast Rule 2002, Allocations for oxides of Nitrogen
(NO)
and
oxides of Sulfur
(SO),
amended January
7,
2005;
67.
http
://www.epa.gov/ttnlemc/cem.html;
and
68.
Alternative Control Techniques Document
— NO
Emissions
from Cement
Manufacturing, EPA-453/R-94-004,
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.
7)
Will this rulemaking replace any emergency rulemaking currently in effect?
No
8)
Does this rulemaking contain an automatic repeal date? No
9)
Does this
rulemaking contain incorporations
by reference? Yes
10)
Are there any
other proposed rulemakings pending on this
Part?
Section
Number:
Proposed Action:
Illinois
Register Citation:
211.1920
Amend
32 Iii. Reg. 17055
(Oct. 31, 2008)
11)
Statement of
Statewide
Policy
Objectives: This
proposed rulemaking does not create
or
enlarge a
State mandate, as defined in Section
3(b)
of the State
Mandates Act [30 ILCS
805/3(b)].
12)
Time, Place,
and Manner in which interested
persons may comment on this proposed
rulemaking: The Board will accept written public comment
on this proposal for 45 days
after the date of publication in the Illinois Register. Comments should reference
Docket
ILLINOIS REGISTER
8
09
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED
AMENDMENTS
R08-19 and be addressed to:
Clerk’s Office
Illinois Pollution Control Board
100 W. Randolph St., Suite 11-500
Chicago, IL 60601
Interested persons may request copies of the Board’s opinion and order
by calling the
Clerk’s office at
312-814-3620,
or download from the Board’s Web site at
www.ipcb.state.il.us.
For more information contact Tim Fox at 312/814-6085 or email at
foxt@ipcb.state.il.us.
13)
Initial Regulatory Flexibility Analysis: In Part 211, the Agency proposes to add
twelve
new definitions of terms employed in the proposed new Sections of Part 217.
A)
Types of small businesses, small
municipalities
and not for
profit
corporations
affected: None expected.
B)
Reporting,
bookkeeping
or other procedures required for compliance: The
proposed rulemaking requires the owner
or operator of an affected source to
perform emissions monitoring, complete required tests, and maintain
records and
make reports as
required.
C)
Types of
Professional skills
necessary for compliance: No professional skills
beyond those currently required by the existing state and federal air
pollution
control
regulations applicable
to affected sources will be required.
14)
Regulatory
Agenda on which this rulemaking was
summarized: July 2006
The full text of the
Proposed Amendments begins on
the next page:
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
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
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
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-b
211.1435
Container
Glass
211.1465
Continuous
Automatic Stoking
Continuous Coater
Continuous Process
Control Device
Control Device Efficiency
Control Period
Conventional Air
Spray
Conventional Soybean Crushing
Source
Conveyorized Degreasing
Crude Oil
Crude Oil Gathering
Crushing
Custody Transfer
Cutback Asphalt
Daily-weighted Average VOM Content
Fill
Final Repair Coat
211.1467
211.1470
211.1490
211.1510
211 . 1515
211.1520
211.1530
211.1550
211.1570
211.1590
211.1610
211.1630
211.1650
211.1670
211.1690
211.1710
211.1730
211.1740
211.1750
211.1770
211.1780
211.1790
211.1810
211.1830
211.1850
211.1870
211.1875
211.1880
Shielding
211. 1885
211.1890
211.1900
211.1910
211.1920
211.1930
211.1950
211.1970
211.1990
211.2010
211.2030
211.2050
211.2070
211.2080
211.2090
211.2110
211.2130
211.2150
211.2170
211.2190
211.2210
211.2230
211.2250
211.2270
211.2285
211.2290
211.2300
211.2310
Day
Degreaser
Delivery Vessel
Diesel Engine
Dip Coating
Distillate Fuel Oil
Distillation Unit
Drum
Dry
Cleaning Operation
or
Dry
Cleaning Facility
Dump-Pit
Area
Effective Grate Area
Effluent water Separator
Elastomeric Materials
Electromagnetic
Interference/Radio Frequency Interference (EMI/RFI)
Coatings
Electronic Component
Electrostatic Bell or Disc Spray
Electrostatic Prep Coat
Electrostatic Spray
Emergency
or
Standby Unit
Emission Rate
Emission Unit
Enamel
Enclose
End
Sealing Compound
Coat
Enhanced Under-the-Cup Fill
Ethanol Blend Gasoline
Excess
Air
Excess
Emissions
Excessive Release
Existing Grain-Drying
Operation (Repealed)
Existing Grain-Handling
Operation (Repealed)
Exterior Base
Coat
Exterior End
Coat
External Floating Roof
Extreme Performance
Coating
Fabric
Coating
Fabric Coating Line
Federally Enforceable Limitations and Conditions
Feed Mill
Fermentation Time
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
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
Large Appliance
Large Appliance
Large Appliance
Lean-Burn Engine
Light Liquid
Light-Duty Truck
Light Oil
Lime Kiln
Liquid/Gas Method
Liquid-Mounted Seal
Liquid Service
Liquids
Dripping
Lithographic Printing
Line
Load-Out
Area
Load Shaving Unit
Loading Event
Long Dry Kiln
Long Wet Kiln
Low-NOx Burner
Low Solvent Coating
Lubricating Oil
Magnet Wire
Magnet Wire Coating
Magnet Wire Coating
Line
Major Dump Pit
Major Metropolitan
Area
(MMA)
Major
Population Area
(MPA)
Manually Operated Equipment
Manufacturing Process
Marine Terminal
Marine Vessel
Material Recovery Section
Maximum Theoretical Emissions
Maximum True Vapor Pressure
Metal Furniture
Metal Furniture
Coating
Metal Furniture
Coating Line
Metallic Shoe-Type
Seal
Mid-Kiln Firing
Miscellaneous
Miscellaneous
Miscellaneous
Miscellaneous
Miscellaneous
Miscellaneous
Mixing Operation
Mobile Equipment
Monitor
Monomer
Motor Vehicles
Motor Vehicle Refinishing
Multiple Package Coating
Nameplate Capacity
New
Grain-Drying
Operation (Repealed)
New Grain-Handling Operation (Repealed)
No Detectable Volatile Organic Material
Emissions
Non-Contact
Process
Water
Cooling Tower
Coating
Coating Line
211.3250
211.3270
211.3290
211.3300
211.3310
211.3330
211.3350
211.3355
211.3370
211.3390
211.3410
211.3430
211.3450
211.3470
211.3475
211.3480
211.3483
211.3485
211.3487
211.3490
211.3500
211.3510
211.3530
211.3550
211.3570
211.3590
211.3610
211.3620
211.3630
211.3650
211.3660
211.3670
211.3690
211.3695
211.3710
211.3730
211.3750
211.3770
211.3780
211.3790
211.3810
211.3830
211.3850
211.3870
211.3890
211.3910
211.3915
211.3930
211.3950
211.3960
211.3965
211.3970
211.3980
211.3990
211.4010
211.4030
211.4050
Fabricated Product
Manufacturing Process
Formulation Manufacturing
Process
Metal Parts and Products
Metal Parts and Products
Coating
Metal Parts or Products
Coating Line
Organic Chemical Manufacturing
Process
Non-Flexible Coating
Non-Heatset
NOx Trading Program
Off
set
One Hundred Percent Acid
One-Turn Storage Space
Opacity
Opaque Stains
Open
Top Vapor Degreasing
Open-Ended Valve
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-la
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
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
211.4055
211.4065
211.4067
211.4070
211.4090
211.4110
211.4130
211.4150
211.4170
211.4190
211.4210
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
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
211.5910
211
.5930
211.5950
211.5970
211.5980
211.5990
211.
6010
211.6025
211.6030
211.6050
211.6060
211.6070
211.6090
211.6110
211. 6130
211.6140
211.6145
211.6150
211.6170
211.6190
211.6210
211.6230
211. 6250
211.6270
211.6290
211.6310
211.6330
211.6350
211.6355
211.6360
211.6370
211.6390
211.6400
211.6410
211.6420
211.6430
211.6450
211.6470
211.6490
211.6510
211.6530
211.6540
211. 6550
211.6570
211.6580
211.6590
211.6610
211.6620
211.6630
211. 6650
211. 6670
211. 6690
211. 6695
211.6710
211.6720
211.6730
Sealer
Semi-Transparent Stains
Sensor
Set
of Safety Relief Valves
Sheet Basecoat
Sheet-Fed
Shotblasting
Side-Seam Spray Coat
Single Unit Operation
Smoke
Smokeless Flare
Soft Coat
Solvent
Solvent Cleaning
Solvent
Recovery
System
Source
Specialty Coatings
Specialty Coatings for Motor Vehicles
Specialty High Gloss Catalyzed Coating
Specialty Leather
Specialty Soybean Crushing Source
Splash Loading
Stack
Stain
Coating
Standard Conditions
Standard
Cubic Foot
(scf)
Start-Up
Stationary Emission Source
Stationary Emission Unit
Stationary Gas Turbine
Stationary
Reciprocating Internal
Combustion Engine
Stationary
Source
Stationary Storage Tank
Stencil
Coat
Storage
Tank or Storage Vessel
Strippable Spray Booth Coating
Styrene Devolatilizer Unit
Styrene Recovery Unit
Submerged Loading
Pipe
Substrate
Sulfuric Acid
Mist
Surface Condenser
Surface Preparation
Materials
Synthetic Organic
Chemical or Polymer
Manufacturing Plant
Tablet Coating Operation
Texture Coat
Thirty-Day Rolling
Average
Three-Piece Can
Three
or Four Stage Coating System
Through-the-Valve Fill
Tooling Resin
Topcoat
Topcoat Operation
Topcoat System
Touch-Up
Touch-Up
Coating
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
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
21l.APPENDIX A
Rule into Section Table
21l.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, R7l-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-l
(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-lO 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 ii
R89-l6(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-l4
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 R9l-22 at 16 Ill. Reg.
7656, effective May 1, 1992; amended in R9l-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-ll at 17 Iii.
Reg.
21471,
effective December 7, 1993;
amended
in
R93-l4
at
18 in.
Reg. 1253, effective January 18, 1994; amended in
R94-12
at 18
Ill. Reg. 14962,
effective September 21, 1994; amended in R94-14
at
18 in.
Reg.
15744, effective
October 17, 1994; amended in R94-l5 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, R94-3l and R94—32
at
19 in.
Reg. 6823,
effective
May 9, 1995; amended in R94-33
at
19 in. 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—l7 at 21 Ill.
Reg. 6489, effective May 16, 1997; amended in R97-24
at 21 in. 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 in.
Rcg.Reci.
11405, effective June 22, 1998; amcndcd
in
ROl 9 at 25 Ill. Rcg. 128, cffcctivc Dcccmbcr 2C, 2000; amended in R01--l
at 25
Ill. Reg.
4-5-9---l08, effective December 26. 2000:
amended
in
ROl-il
at
25 111.
Rep. 4582. 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-ll
at
29 Ill. Reg. 8892, effective
June 13, 2005;
amended
in R04-l2/20 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
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 —
Section
211.1435
Container Glass
“Container glass” means,
for purposes
of Part 217, glass made of
soda-lime
recipe, clear
or
colored, w
ethat
is pressed or blown, or both, into
bottles,
jars, ampoules,
and other products listed
in Standard Industrial Classification
3221.
(Source:
Added at 33 Iii. Reg.
, effective —
Section 211.2355 Flare
“Flare” means an open combustor without enclosure
or shroud.
(Source:
Added at 33 111. 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, and cogeneration
units, 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
—
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
—)
ILLINOIS
RECISTER
POLLUTION
CONTROL EOD
NOTICE OF PROPOSED 4ENDMENTS
ILLINOIS RECISTER
ID(,T T TVP T(T ff1!O,ThT
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Inserted cell
Deleted cell
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SplitlMerqed
Padding cell
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1
JCAR35O21 1-0906896r01
1
TITLE 35:
ENVIRONMENTAL
PROTECTION
2
SUBTITLE
B: AIR
POLLUTION
3
CHAPTER I:
POLLUTION
CONTROL BOARD
4
SUBCHAPTER c: EMISSION
STANDARDS AND
LIMITATIONS
5
FOR STATIONARY
SOURCES
6
7
PART211
8
DEFINITIONS AND
GENERAL PROVISIONS
9
10
SUBPART A:
GENERAL
PROVISIONS
11
12
Section
13
211.101
Incorporations
by
Reference
14
211.102
Abbreviations and Conversion
Factors
15
16
SUBPART B:
DEFINITIONS
17
18
Section
19
211.121
OtherDefinitions
20
211.122
Definitions (Repealed)
21
211.130
Accelacota
22
211.150
Accumulator
23
211.170
AcidGases
24
211.210
Actual Heat Input
25
211.230
Adhesive
26
211.240
Adhesion Promoter
27
211.250
Aeration
28
211.270
Aerosol Can Filling Line
29
211.290
Afterburner
30
211.310
AirContaminant
31
211.330
AirDriedCoatings
32
211.350
Air Oxidation Process
33
211.370
Air Pollutant
34
211.390
Air
Pollution
35
211.410
Air Pollution Control Equipment
36
211.430
Air Suspension Coater/Dryer
37
211.450
Airless Spray
38
211.470
Air Assisted Airless Spray
39
211.474
Alcohol
40
211.479
Allowance
41
211.484
Animal
42
211.485
Animal Pathological Waste
43
211.490
Annual Grain Through-Put
JCAR35O21
1-0906896r01
44
211.495
Anti-Glare/Safety
Coating
45
211.510
Application Area
46
211.530
Architectural Coating
47
211.550
As Applied
48
211.560
As-Applied Fountain Solution
49
211.570
Asphalt
50
211.590
Asphalt Prime Coat
51
211.610
Automobile
52
211.630
Automobile or Light-Duty Truck Assembly
Source or Automobile or Light-Duty
53
Truck Manufacturing Plant
54
211.650
Automobile or Light-Duty Truck Refinishing
55
211.660
Automotive/Transportation
Plastic Parts
56
211.665
Auxiliary Boiler
57
211.670
Baked
Coatings
58
211.680
BakeryOven
59
211.685
Basecoat/Clearcoat
System
60
211.690
Batch Loading
61
211.695
Batch
Operation
62
211.696
Batch Process Train
63
211.710
Bead-Dipping
64
211.730
Binders
65
211.740
Brakehorsepower (rated-bhp)
66
211.750
British Thermal Unit
67
211.770
Brush or Wipe Coating
68
211.790
Bulk Gasoline Plant
69
211.810
Bulk Gasoline
Terminal
70
211.820
Business Machine Plastic Parts
71
211.830
Can
72
211.850
Can Coating
73
211.870
Can Coating
Line
74
211.890
Capture
75
211.910
CaptureDevice
76
211.930
Capture Efficiency
77
211.950
Capture
System
78
211.953
Carbon Adsorber
79
211.955
Cement
80
211.960
CementKiln
81
211.970
Certified
Investigation
82
211.980
Chemical
Manufacturing
Process Unit
83
211.990
Choke
Loading
84
211.995
Circulating
Fluidized Bed Combustor
85
211.1010
Clean Air Act
86
211.1050
Cleaning
and Separating
Operation
JCAR35O21
l-0906896r01
87
211.1070
Cleaning
Materials
88
211.1090
Clear
Coating
89
211.1110
ClearTopcoat
90
211.1120
Clinker
91
211.1130
Closed
Purge
System
92
211.1150
Closed Vent
System
93
211.1170
CoalRefuse
94
211.1190
Coating
95
211.1210
Coating
Applicator
96
211.1230
CoatingLine
97
211.1250
CoatingPlant
98
211.1270
Coil
Coating
99
211.1290
Coil
Coating
Line
100
211.1310
Cold
Cleaning
101
211.1312
Combined
Cycle
System
102
211.1315
CombustionTuning
103
211.1316
Combustion
Turbine
104
211.1320
Commence
Commercial
Operation
105
211.1324
Commence
Operation
106
211.1328
Common
Stack
107
211.1330
Complete
Combustion
108
211.1350
Component
109
211.1370
Concrete
Curing
Compounds
110
211.1390
Concentrated
Nitric Acid
Manufacturing
Process
111
211.1410
Condensate
112
211.1430
CondensiblePM-10
113
211.1435
ContainerGiass
114
211.1465
Continuous
Automatic
Stoking
115
211.1467
Continuous
Coater
116
211.1470
Continuous
Process
117
211.1490
ControlDevice
118
211.1510
Control
Device
Efficiency
119
211.1515
Control Period
120
211.1520
Conventional
Air Spray
121
211.1530
Conventional
Soybean
Crushing
Source
122
211.1550
Conveyorized
Degreasing
123
211.1570
Crude
Oil
124
211.1590
Crude
Oil
Gathering
125
211.1610
Crushing
126
211.1630
Custody
Transfer
127
211.1650
Cutback
Asphalt
128
211.1670
Daily-Weighted
Average
VOM
Content
129
211.1690
Day
JCAR35O21 1-0906896r01
130
211.1710
Degreaser
131
211.1730
Delivery
Vessel
132
211.1740
Diesel Engine
133
211.1750
Dip Coating
134
211.1770
Distillate
Fuel Oil
135
211.1780
Distillation
Unit
136
211.1790
Drum
137
211.1810
Dry Cleaning Operation or Dry Cleaning
Facility
138
211.1830
Dump-Pit
Area
139
211.1850
EffectiveGrateArea
140
211.1870
Effluent
Water Separator
141
211.1875
Elastomeric Materials
142
211.1880
Electromagnetic
Interference/Radio Frequency
Interference (EMIIRFI) Shielding
143
Coatings
144
211.1885
Electronic Component
145
211.1890
Electrostatic Bell or Disc Spray
146
211.1900
Electrostatic Prep
Coat
147
211.1910
Electrostatic Spray
148
211.1920
Emergency
or Standby Unit
149
211.1930
EmissionRate
150
211.1950
EmissionUnit
151
211.1970
Enamel
152
211.1990
Enclose
153
211.2010
End
Sealing
Compound Coat
154
211.2030
Enhanced Under-the-Cup Fill
155
211.2050
Ethanol Blend Gasoline
156
211.2070
Excess
Air
157
211.2080
Excess Emissions
158
211.2090
Excessive
Release
159
211.2110
Existing Grain-Drying Operation
(Repealed)
160
211.2130
Existing Grain-Handling
Operation (Repealed)
161
211.2150
ExteriorBase Coat
162
211.2170
Exterior End Coat
163
211.2190
External Floating Roof
164
211.2210
Extreme Performance Coating
165
211.2230
Fabric Coating
166
211.2250
Fabric Coating
Line
167
211.2270
Federally Enforceable Limitations
and Conditions
168
211.2285
FeedMill
169
211.2290
Fermentation Time
170
211.2300
Fill
171
211.2310
FinalRepairCoat
172
211.2330
Firebox
JCAR35O21 1-0906896r01
173
211.2350
Fixed-Roof Tank
174
211.2355
Flare
175
211.2357
FlatGlass
176
211.2360
Flexible Coating
177
211.2365
Flexible Operation
Unit
178
211.2370
Flexographic Printing
179
211.2390
Flexographic
Printing Line
180
211.2410
FloatingRoof
181
211.2420
Fossil Fuel
182
211.2425
Fossil Fuel-Fired
183
211.2430
Fountain Solution
184
211.2450
Freeboard Height
185
211.2470
Fuel Combustion Emission
Unit or Fuel Combustion
Emission Source
186
211.2490
Fugitive Particulate
Matter
187
211.2510
Full Operating Flowrate
188
211.2530
Gas Service
189
211.2550
Gas/GasMethod
190
211.2570
Gasoline
191
211.2590
Gasoline Dispensing
Operation or Gasoline Dispensing
Facility
192
211.2610
Gel Coat
193
211.2620
Generator
194
211.2625
Glass Melting
Furnace
195
211.2630
Gloss Reducers
196
211.2650
Grain
197
211.2670
Grain-Drying Operation
198
211.2690
Grain-Handling and
Conditioning Operation
199
211.2710
Grain-Handling Operation
200
211.2730
Green-Tire
Spraying
201
211.2750
Green Tires
202
211.2770
Gross
Heating Value
203
211.2790
Gross Vehicle Weight Rating
204
211.2810
Heated Airless Spray
205
211.2815
Heat Input
206
211.2820
Heat Input Rate
207
211.2830
Heatset
208
211.2850
Heatset Web Offset
Lithographic Printing Line
209
211.2870
Heavy Liquid
210
211.2890
HeavyMetals
211
211.2910
Heavy
Off-Highway Vehicle Products
212
211.2930
Heavy Off-Highway
Vehicle Products Coating
213
211.2950
Heavy Off-Highway Vehicle
Products Coating
Line
214
211.2970
High Temperature Aluminum
Coating
215
211.2990
High Volume
Low Pressure (HVLP)
Spray
JCAR35O21 1-0906896r01
216
211.3010
Hood
217
211.3030
Hot
Well
218
211.3050
Housekeeping Practices
219
211.3070
Incinerator
220
211.3090
Indirect Heat Transfer
221
211.3100
Industrial
Boiler
222
211.3110
Ink
223
211.3130
Tn-Process Tank
224
211.3150
In-Situ
Sampling Systems
225
211.3170
Interior Body Spray Coat
226
211.3190
Internal-Floating Roof
227
211.3210
Internal Transferring Area
228
211.3230
Lacquers
229
211.3250
Large Appliance
230
211.3270
Large
Appliance Coating
231
211.3290
Large Appliance Coating Line
232
211.3300
Lean-Burn Engine
233
211.3310
Light Liquid
234
211.3330
Light-Duty Truck
235
211.3350
Light Oil
236
211.3355
LimeKiln
237
211.3370
Liquid/Gas Method
238
211.3390
Liquid-Mounted Seal
239
211.3410
Liquid Service
240
211.3430
Liquids
Dripping
241
211.3450
Lithographic Printing Line
242
211.3470
Load-Out Area
243
211.3475
Load Shaving Unit
244
211.3480
Loading Event
245
211.3483
LongDryKiln
246
211.3485
Long WetKiln
247
211.3487
Low-NO
Burner
248
211.3490
Low Solvent
Coating
249
211.3500
Lubricating Oil
250
211.3510
Magnet Wire
251
211.3530
Magnet Wire Coating
252
211.3550
Magnet Wire Coating Line
253
211.3570
MajorDumpPit
254
211.3590
Major
Metropolitan Area
(MMA)
255
211.3610
Major Population Area (MPA)
256
211.3620
Manually Operated Equipment
257
211.3630
Manufacturing Process
258
211.3650
Marine
Terminal
JCAR35O21
1-0906896r01
259
211.3660
Marine
Vessel
260
211.3670
Material
Recovery Section
261
211.3690
Maximum
Theoretical
Emissions
262
211.3695
Maximum
True Vapor Pressure
263
211.3710
MetalFurniture
264
211.3730
Metal
Furniture
Coating
265
211.3750
Metal Furniture
Coating Line
266
211.3770
Metallic Shoe-Type
Seal
267
211.3780
Mid-KilnFiring
268
211.3790
Miscellaneous
Fabricated Product
Manufacturing
Process
269
211.3810
Miscellaneous
Formulation
Manufacturing Process
270
211.3830
Miscellaneous
Metal
Parts and
Products
271
211.3850
Miscellaneous
Metal Parts and
Products Coating
272
211.3870
Miscellaneous
Metal Parts
or
Products
Coating
Line
273
211.3890
Miscellaneous
Organic Chemical
Manufacturing
Process
274
211.3910
Mixing Operation
275
211.3915
Mobile
Equipment
276
211.3930
Monitor
277
211.3950
Monomer
278
211.3960
Motor
Vehicles
279
211.3965
Motor Vehicle
Refinishing
280
211.3970
Multiple
Package
Coating
281
211.3980
Nameplate
Capacity
282
211.3990
New Grain-Drying
Operation
(Repealed)
283
211.4010
New
Grain-Handling
Operation (Repealed)
284
211.4030
No Detectable Volatile
Organic Material
Emissions
285
211.4050
Non-Contact Process
Water
Cooling Tower
286
211.4055
Non-Flexible Coating
287
211.4065
Non-Heatset
288
211.4067
NO
Trading Program
289
211.4070
Offset
290
211.4090
One Hundred Percent
Acid
291
211.4110
One-Turn Storage
Space
292
211.4130
Opacity
293
211.4150
Opaque Stains
294
211.4170
Open Top Vapor Degreasing
295
211.4190
Open-Ended Valve
296
211.4210
Operator of
a Gasoline Dispensing
Operation
or Operator
of
a Gasoline
297
Dispensing Facility
298
211.4230
Organic Compound
299
211.4250
Organic
Material and Organic
Materials
300
211.4260
Organic
Solvent
301
211.4270
Organic
Vapor
JCAR35O21 1-0906896r01
302
211.4280
OtherGiass
303
211.4290
Oven
304
211.4310
Overall Control
305
211.4330
Overvarnish
306
211.4350
Owner of a Gasoline Dispensing
Operation or Owner
of a
Gasoline
Dispensing
307
Facility
308
211.4370
Owner or Operator
309
211.4390
Packaging Rotogravure
Printing
310
211.4410
Packaging Rotogravure Printing Line
311
211.4430
Pail
312
211.4450
Paint Manufacturing Source or Paint
Manufacturing Plant
313
211.4470
Paper Coating
314
211.4490
Paper Coating Line
315
211.4510
Particulate Matter
316
211.4530
Parts Per Million
(Volume) or PPM (Vol)
317
211.4550
Person
318
211.4590
Petroleum
319
211.4610
Petroleum Liquid
320
211.4630
Petroleum Refinery
321
211.4650
Pharmaceutical
322
211.4670
Pharmaceutical Coating
Operation
323
211.4690
Photochemically Reactive Material
324
211.4710
Pigmented Coatings
325
211.4730
Plant
326
211.4740
Plastic Part
327
211.4750
Plasticizers
328
211.4770
PM-b
329
211.4790
Pneumatic Rubber Tire Manufacture
330
211.4810
Polybasic Organic Acid Partial Oxidation
Manufacturing Process
331
211.4830
Polyester Resin Material(s)
332
211.4850
Polyester
Resin Products Manufacturing Process
333
211.4870
Polystyrene Plant
334
211.4890
Polystyrene Resin
335
211.4910
Portable Grain-Handling Equipment
336
211.4930
Portland Cement Manufacturing
Process Emission
Source
337
211.4950
Portland Cement Process or Portland
Cement Manufacturing
Plant
338
211.4960
Potential
Electrical Output Capacity
339
211.4970
Potential to Emit
340
211.4990
Power Driven Fastener Coating
341
211.5010
Precoat
342
211.5015
PreheaterKiln
343
211.5020
Preheater/Precalciner
Kiln
344
211.5030
Pressure Release
JCAR35O21 1-0906896r01
345
211.5050
Pressure Tank
346
211.5060
Pressure/Vacuum
Relief Valve
347
211.5061
Pretreatment Wash Primer
348
211.5065
Primary Product
349
211.5070
Prime Coat
350
211.5080
Primer Sealer
351
211.5090
Primer Surfacer
Coat
352
211.5110
Primer Surfacer Operation
353
211.5130
Primers
354
211.5150
Printing
355
211.5170
Printing Line
356
211.5185
Process Emission
Source
357
211.5190
Process Emission Unit
358
211.5195
Process Heater
359
211.5210
Process Unit
360
211.5230
Process Unit Shutdown
361
211.5245
Process Vent
362
211.5250
Process Weight Rate
363
211.5270
Production Equipment Exhaust
System
364
211.5310
Publication Rotogravure Printing Line
365
211.5330
Purged
Process
Fluid
366
211.5340
Rated
Heat Input
Capacity
367
211.5350
Reactor
368
211.5370
Reasonably Available Control
Technology (RACT)
369
211.5390
Reclamation System
370
211.5410
Refiner
371
211.5430
RefineryFuel Gas
372
211.5450
Refinery Fuel Gas System
373
211.5470
Refinery Unit or Refinery
Process Unit
374
211.5480
Reflective Argent Coating
375
211.5490
Refrigerated Condenser
376
211.5500
Regulated Air Pollutant
377
211.5510
Reid Vapor Pressure
378
211.5530
Repair
379
211.5550
RepairCoat
380
211.5570
Repaired
381
211.5580
Repowering
382
211.5590
Residual Fuel Oil
383
211.5600
Resist Coat
384
211.5610
Restricted Area
385
211.5630
Retail Outlet
386
211.5640
Rich-Bum Engine
387
211.5650
Ringelmann Chart
JCAR35O21 1-0906896r01
388
211.5670
Roadway
389
211.5690
Roll
Coater
390
211.5710
Roll Coating
391
211.5730
RollPrinter
392
211.5750
RollPrinting
393
211.5770
Rotogravure Printing
394
211.5790
Rotogravure Printing
Line
395
211.5810
SafetyReliefValve
396
211.5830
Sandblasting
397
211.5850
Sanding Sealers
398
211.5870
Screening
399
211.5880
Screen Printing on Paper
400
211.5890
Sealer
401
211.5910
Semi-Transparent Stains
402
211.5930
Sensor
403
211.5950
Set of Safety Relief Valves
404
211.5970
Sheet Basecoat
405
211.5980
Sheet-Fed
406
211.5990
Shotblasting
407
211.6010
Side-Seam SprayCoat
408
211.6025
Single Unit Operation
409
211.6030
Smoke
410
211.6050
Smokeless
Flare
411
211.6060
SoftCoat
412
211.6070
Solvent
413
211.6090
Solvent Cleaning
414
211.6110
Solvent Recovery
System
415
211.6130
Source
416
211.6140
Specialty Coatings
417
211.6145
Specialty Coatings for Motor Vehicles
418
211.6150
Specialty High Gloss
Catalyzed Coating
419
211.6170
Specialty
Leather
420
211.6190
Specialty Soybean Crushing
Source
421
211.6210
Splash Loading
422
211.6230
Stack
423
211.6250
Stain
Coating
424
211.6270
Standard Conditions
425
211.6290
Standard Cubic Foot (scf)
426
211.6310
Start-Up
427
211.6330
Stationary Emission
Source
428
211.6350
Stationary Emission
Unit
429
211.6355
Stationary Gas Turbine
430
211.6360
Stationary Reciprocating Internal
Combustion Engine
JCAR35O21
1 -0906896r01
431
211.6370
Stationary
Source
432
211.6390
Stationary
Storage
Tank
433
211.6400
Stencil
Coat
434
211.6410
Storage
Tank
or Storage
Vessel
435
211.6420
Strippable
Spray
Booth
Coating
436
211.6430
Styrene Devolatilizer
Unit
437
211.6450
Styrene
Recovery
Unit
438
211.6470
Submerged
Loading
Pipe
439
211.6490
Substrate
440
211.6510
Sulfuric
AcidMist
441
211.6530
Surface
Condenser
442
211.6540
Surface
Preparation
Materials
443
211.6550
Synthetic
Organic
Chemical
or
Polymer
Manufacturing
Plant
444
211.6570
Tablet
Coating
Operation
445
211.6580
Texture
Coat
446
211.6590
Thirty-Day
Rolling
Average
447
211.6610
Three-Piece
Can
448
211.6620
Three
or Four
Stage
Coating
System
449
211.6630
Through-the-Valve
Fill
450
211.6650
Tooling
Resin
451
211.6670
Topcoat
452
211.6690
Topcoat
Operation
453
211.6695
Topcoat
System
454
211.6710
Touch-Up
455
211.6720
Touch-Up
Coating
456
211.6730
Transfer
Efficiency
457
211.6750
Tread
End
Cementing
458
211.6770
True
Vapor
Pressure
459
211.6790
Turnaround
460
211.6810
Two-Piece
Can
461
211.6830
Under-the-Cup
Fill
462
211.6850
Undertread
Cementing
463
211.6860
Unifonn
Finish
Blender
464
211.6870
Unregulated
Safety
Relief
Valve
465
211.6880
Vacuum Metallizing
466
211.6890
Vacuum
Producing
System
467
211.6910
Vacuum Service
468
211.6930
Valves Not
Externally
Regulated
469
211.6950
Vapor
Balance
System
470
211.6970
Vapor
Collection
System
471
211.6990
Vapor
Control System
472
211.7010
Vapor-Mounted
Primary
Seal
473
211.7030
Vapor
Recovery
System
JCAR35O21 1-0906896r01
474
211.7050
Vapor-Suppressed
Polyester Resin
475
211.7070
Vinyl Coating
476
211.7090
Vinyl
Coating Line
477
211.7110
Volatile Organic Liquid
(VOL)
478
211.7130
Volatile Organic Material
Content (VOMC)
479
211.7150
Volatile Organic Material
(VOM)
or
Volatile Organic Compound (VOC)
480
211.7170
Volatile
Petroleum Liquid
481
211.7190
WashCoat
482
211.7200
Washoff Operations
483
211.7210
Wastewater (Oil/Water) Separator
484
211.7230
Weak Nitric Acid Manufacturing
Process
485
211.7250
Web
486
211.7270
Wholesale Purchase — Consumer
487
211.7290
Wood
Furniture
488
211.7310
Wood Furniture Coating
489
211.7330
Wood
Furniture Coating
Line
490
211.7350
Woodworking
491
211.7400
Yeast Percentage
492
493
21 1.APPENDIX A
Rule into Section Table
494
211 .APPENDIX B
Section into Rule Table
495
496
AUTHORITY:
Implementing Sections
9, 9.1, 9.9 and 10 and authorized
by
Sections 27
and 28
497
of
the Environmental Protection Act [415 ILCS
5/9, 9.1, 9.9, 10, 27 and 28].
498
499
SOURCE: Adopted as Chapter 2: Air Pollution, Rule 201: Definitions, R71-23, 4
PCB 191,
500
filed
and effective April 14, 1972; amended in R74-2
and R75-5, 32 PCB 295, at 3 Ill. Reg.
5,
p.
501
777,
effective February 3, 1979; amended in R78-3 and 4, 35 PCB
75
and 243,
at 3 Ill. Reg.
30,
502
p.
124, effective July 28, 1979; amended in R80-5,
at 7 Ill. Reg. 1244, effective January 21,
503
1983; codified at 7 Ill. Reg. 13590; amended in R82-1 (Docket A) at
10
Ill.
Reg. 12624, effective
504
July 7,
1986; amended in R85-21(A) at 11111. Reg. 11747,
effective June 29, 1987; amended
in
505
R86-34 at 11111. Reg.
12267,
effective July 10, 1987; amended in R86-39 at 11111.
Reg. 20804,
506
effective December 14, 1987; amended in R82-14 and
R86-37 at 12 Ill. Reg. 787, effective
507
December 24, 1987;
amended
in R86-18 at
12
Ill. Reg. 7284, effective April
8,
1988;
amended
508
in
R86-lO at 12 Ill. Reg. 7621, effective April 11, 1988;
amended in R88-23 at 13 Ill. Reg.
509
10862, effective June
27,
1989; amended in R89-8 at 13 Ill. Reg. 17457,
effective January 1,
510
1990; amended in
R89-16(A) at 14 Ill. Reg. 9141,
effective May 23, 1990; amended in
R88-
511
30(B) at
15
Ill.
Reg. 5223, effective March 28, 1991;
amended in R88-14 at 15 Ill. Reg.
7901,
512
effective May 14, 1991; amended in R91-10 at 15 Ill. Reg. 15564,
effective October 11, 1991;
513
amended in R91-6 at
15 Ill.
Reg. 15673, effective October 14, 1991;
amended in R91-22 at 16
514
Ill.
Reg. 7656,
effective May 1, 1992; amended
in R91-24 at 16 Ill. Reg. 13526,
effective August
515
24, 1992; amended
in R93-9 at 17 Ill. Reg. 16504,
effective September 27, 1993; amended
in
516
R93-1 1
at 17
Ill.
Reg.
21471,
effective December
7,
1993;
amended in R93-l4 at 18 Ill. Reg.
JCAR35O21
1-0906896r01
517
1253,
effective January
18, 1994; amended
in R94-12
at
18 Iii. Reg.
14962, effective
September
518
21, 1994; amended in
R94-14
at 18
Iii. Reg. 15744,
effective October
17, 1994; amended
in
519
R94-15
at 18 Ill.
Reg. 16379, effective
October 25,
1994;
amended
in R94-16
at 18 Ill. Reg.
520
16929,
effective
November
15, 1994;
amended
in R94-21, R94-31
and R94-32 at
19 Iii.
Reg.
521
6823, effective May
9, 1995; amended
in R94-33
at 19 Ill. Reg. 7344,
effective
May 22, 1995;
522
amended in R95-2
at 19 111.
Reg. 11066, effective
July 12, 1995;
amended
in R95-16 at 19 Ill.
523
Reg. 15176,
effective October
19, 1995; amended
in
R96-5
at 20 Iii. Reg.
7590, effective May
524
22,
1996; amended in R96-16
at 21111.
Reg. 2641, effective
February 7, 1997;
amended
in R97-
525
17 at 21111.
Reg.
6489, effective
May 16,
1997; amended
in R97-24
at
21111. Reg. 7695,
526
effective
June
9,
1997; amended
in R96-17
at 21111. Reg.
7856, effective
June 17,
1997;
527
amended
in R97-31 at 22
Ill. Reg. 3497, effective
February
2, 1998;
amended
in R98-17 at
22
Ill.
528
Reg.
11405, effective June
22, 1998;
amended
in R01-9
at 25 Ill. Reg. 108,
effective
December
529
26, 2000;
amended in ROl-il
at 25 Ill. Reg.
4582,
effective
March
15,
2001;
amended in R01-17
530
at 25
Ill. Reg. 5900, effective
April
17,
2001; amended in
R05-16 at 29 111.
Reg. 8181,
effective
531
May 23,
2005; amended in
R05-11 at 29 111.
Reg.
8892,
effective June 13, 2005;
amended in
532
R04-12/20
at 30 111. Reg.
9654, effective
May 15, 2006; amended
in R07-18
at 31111. Reg.
533
14254, effective
September 25,
2007;
amended
in
R08-6
at 32 111. Reg. 1387,
effective January
534
16, 2008;
amended in R08-19
at 33 Ill.
Reg.
effective
535
536
SUBPART
B:
DEFINITIONS
537
538
Section
211.665 Auxiliary Boiler
539
540
“Auxiliary
boiler”
means, for
purposes of Part 217,
a boiler that
is operated
only
541
when the main
boiler or boilers at
a
source are
not in service and
is used either
to
542
maintain building
heat or
to
assist in the startup
of the main boiler
or boilers.
This
543
term
does
not
include emergency
or standby units
and load
shaving units.
544
545
(Source: Added at
33 Ill. Reg.
effective
546
547
Section 211.995
Circulating
Fluidized
Bed
Combustor
548
549
“Circulating
fluidized bed combustor”
means,
for purposes
of Part 217, a
550
fluidized bed combustor
in which
the majority
of the fluidized bed
material
is
551
carried out
of the primary combustion
zone and
is transported
back to the primary
552
zone through a
recirculation
loop.
553
554
(Source:
Added
at 33 Ill. Reg.
effective
555
556
Section
211.1315
Combustion Tuning
557
558
“Combustion tuning”
means,
for
purposes of Part 217,
review and adjustment
of
a
559
combustion
process
to maintain
combustion efficiency
of an emission
unit,
as
JCAR35O21
1-0906896r01
560
performed
in accordance with
procedures
provided by the manufacturer
or by
a
561
trained technician.
562
563
(Source:
Added at 33 Ill. Reg.
effective
564
565
Section
211.1435 Container
Glass
566
567
“Container glass”
means, for
purposes of Part 217,
glass made of soda-lime
568
recipe, clear
or
colored,
that is pressed
or blown,
or both, into bottles,
jars,
569
ampoules, and
other
products
listed in Standard Industrial
Classification
3221.
570
571
(Source:
Added at 33
Ill. Reg.
effective
572
573
Section 211.2355 Flare
574
575
“Flare” means an
open combustor
without enclosure
or shroud.
576
577
(Source:
Added at 33
Iii. Reg.
effective
578
579
Section 211.2357 Flat
Glass
580
581
“Flat glass”
means, for purposes
of
Part 217,
glass made of soda-lime
recipe
and
582
produced
into continuous
flat sheets and other
products listed
in Standard
583
Industrial
Classification
3211.
584
585
(Source:
Added at 33 Ill. Reg.
effective
586
587
Section
211.2625 Glass Melting
Furnace
588
589
“Glass melting furnace”
means, for
purposes of Part 217,
a unit comprising
a
590
refractory
vessel in which
raw materials
are charged and
melted at high
591
temperature to produce
molten glass.
592
593
(Source:
Added at 33 Ill. Reg.
effective
594
595
Section 211.3100
Industrial
Boiler
596
597
“Industrial boiler” means,
for purposes
of Part 217, an
enclosed
vessel
in which
598
water
is heated
and circulated
either as hot water or
as steam for
heating or for
599
power, or both.
This term does not
include a heat
recovery steam
generator that
600
captures
waste heat from a combustion
turbine
and boilers serving
a generator
that
601
has
a
nameplate
capacity
greater than 25 MWe
and produces
electricity for
sale,
JCAR35O21
1-0906896r01
602
and cogeneration
units, if such
boilers meet
the applicability
criteria under
603
Subpart M
of
Part 217.
604
605
(Source:
Added at 33 Ill. Reg.
effective
606
607
Section
211.3355 Lime Kiln
608
609
“Lime kiln” means,
for purposes
of Part 217,
an enclosed combustion
device
used
610
to calcine
lime
mud, which consists
primarily
of calcium carbonate,
into calcium
611
oxide.
612
613
(Source:
Added at 33
Ill.
Reg.
effective
614
615
Section 211.3475 Load
Shaving Unit
616
617
“Load shaving
unit” means,
for purposes
of Part 217, a device used
to
generate
618
electricity
for sale or use during
high
electric
demand
days,
including but not
619
limited to stationary
reciprocating
internal
combustion engines
or
turbines.
620
621
(Source:
Added
at 33 Ill. Reg.
effective
622
623
Section 211.4280
Other Glass
624
625
“Other glass” means,
for
purposes
of Part 217, glass
that is neither container
glass,
626
as
that
term is defined
in Section 211.1435,
nor flat
glass, as that
term is defined
627
in Section 211.2357.
628
629
(Source:
Added at
33 Ill. Reg.
effective
630
631
Section
211.5195
Process
Heater
632
633
‘Process heater”
means, for purposes
of Part 217,
an enclosed
combustion device
634
that burns gaseous
or
liciuid
fuels only and that indirectly
transfers
heat
to a
635
process fluid
or a heat transfer medium
other than
water. This term
does not
636
include pipeline
heaters
and
storage tank heaters
that are primarily
meant
to
637
maintain fluids
at a certain temperature
or viscosity.
638
639
(Source: Added at
33 Ill. Reg.
effective
ILLiNOIS
REGISTER
09
POLLUTION
CONTROL
BOARD
NOTICE
OF PROPOSED
AMENDMENTS
1)
Heading
of
the
Part: Nitrogen
Oxides
Emissions
2)
Code
Citation:
35
Iii. Adm. Code
217
t4/
4y
19
2009
3)
Section
Numbers:
Proposed Action:
ILLglj
18
217.100
Amended
ontro,.
217.104
Amended
217.121
Repealed
217.141
Amended
217.150
New
Section
217.152
New
Section
217.154
New
Section
217.155
New
Section
217.156
New
Section
217.157
New
Section
217.158
New Section
217.160
New
Section
217.162
New Section
217.164
New Section
217.165
New
Section
217.166
New
Section
217.180
New
Section
217.182
New
Section
217.184
New
Section
217.185
New
Section
217.186
New
Section
2 17.200
New
Section
2 17.202
New
Section
2 17.204
New
Section
217.220
New
Section
217.222
New Section
217.224
New
Section
2
17.240
New
Section
217.242
New
Section
217.244
New
Section
217.340
New
Section
217.342
New
Section
217.344
New
Section
2 17.345
New
Section
217.APPENDIX
H
New Section
ILLINOIS REGISTER
2
09
POLLUTION
CONTROL BOARD
NOTICE
OF PROPOSED
AMENDMENTS
4)
Statutory
Authority:
Implementing
Section 10
and authorized by Sections 27 and 28
of
the Environmental Protection
Act [415 ILCS 5/10, 27, and 28]
5)
A
Complete
Description
of the
Subjects
and
Issues Involved: The Board’s May
7, 2009
opinion and order (Amendments
to 35 Ill. Adm. Code 217, Nitrogen
Oxides Emissions,
and 35 Ill.
Adm.
Code
211,
R08-19, slip
op.
at 27-58
(sununarizing twelve proposed
new
definitions)) discusses in details the
amendments to Part 217 proposed in
this rulemaking.
This rulemaking is based on a proposal
filed with the Board by the Illinois
Environmental
Protection Agency (Agency)
on May 9, 2008. The Agency
proposes to amend Parts 211
and 217 of the Board’s air pollution regulations
(35 Iii. Adm. Code 211, 217) to
control
nitrogen oxides
(NO)
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.
On April 2, 2009, the Board granted the Agency’s
motion to expedite review
of this
proposal in
order
to meet federal deadlines for submission
of State Implementation
Plans
for
NOR.
In
its May
7,
2009,
opinion and order, the Board
stated that, having granted
the
motion for expedited review, it is highly
unlikely to grant any motion
for an extension
of
the first-notice comment period. The Board strongly
encouraged participants who
wish
to file a
public comment to
do so within the statutory 45-day
period.
6)
Published
studies or reports, and
sources of underlying data, used
to compose this
rulemaking: The Agency stated that it relied
on the following 68 sources in preparing
its
proposal
to
the Board:
1.
The Clean Air Act, as amended
in 1990 (42
USC
7401 et seq.);
2.
Illinois Environmental Protection
Act (415 ILCS 5);
3.
Energy
&
Environmental
Analysis, Inc., “Characterization
of the
U.S.
Boiler
Industrial Commercial Boiler
Population”, submitted to Oak Ridge
National
Laboratory, May
2005;
4.
http ://commons.wikimedia.org/wiki/Image:Water tube
boiler schematic.png;
5.
http ://en.wikipedia.org/wiki/Image:Locomotive
fire tube boiler schematic.png;
ILLINOIS
REGISTER
3
09
POLLUTION
CONTROL
BOARD
NOTICE
OF PROPOSED
AMENDMENTS
6.
Babcock &
Wilcox Company; Steam,
It’s
Generation
and Use,
Edition, 1992;
7.
Neil Johnson,
“Fundamentals
of Stoker Fired
Boiler Design and
Operation”,
presented
at C]BO Emission
Controls
Technology
Conference,
July 15-17, 2002;
8.
Letter
to Mr. Regulator, New
Hampshire
Division of Environmental
Services,
from
Daniel
J. Willems,
Product Development,
Cleaver
Brooks,
dated May 19,
2006;
9.
http :/!wwwl.eere.
energy. gov/industry/bestpractices/pdfs!steam4_boiler
efficiency.pdf;
10.
http :!/www.energysolutionscenter.org/boilerburner/Eff
Improve!
Efficiency/Oxygen_Control.asp;
11.
http
://files.asme.org!asmeorg!Codes/CertifAccred!Personnel/297
1 .pdf;
12.
http ://www.coen.com!i_html!whitejowcostnoxpm.html;
13.
Rajani
Varagani
(n.d.), “A Cost Effective
Low
NO
Retrofit
Technology
for
Industrial Boilers”,
cited within
CIBO Industrial Emissions
Control Technology
III, August
1-3, 2005;
14.
Email from
Jim Staudt, Andover
Technology,
to R. Gifford Broderick,
Combustion
Components Associates,
Based on estimate
for a 4-burner project,
dated October
16, 2003;
15.
http :llwww.johnzink.comlproducts!burners!htmljodd!burn_todd_csj
04.htm;
16.
Sacramento
General Services Heating
Plant Case Study:
COEN
web
site:
http :fiwww.coen.com!mrktli!ibrochures!pdf!qla.pdf
17.
Zink,
John (2003)
“U.S. Borax
TODD Ultra Low
Emissions Burner Installment”;
18.
Zink, John
(2003) “TODD Ultra
Low Emissions Burner
Installment”;
19.
Coen Company, “Ultra
Low
NO
Gas-Fired
Burner with Air Preheat”,
Final
Report,
prepared for California
Air Resources
Board, November
23, 2000;
20.
Memorandum from
Jim Staudt, Andover
Technology Partners,
to
Sikander
Khan,
ILLINOIS REGISTER
4
09
POLLUTION CONTROL
BOARD
NOTICE OF PROPOSED
AMENDMENTS
United States Environmental
Protection Agency,
providing comments in response
to September 10, 2003 email,
dated October 24, 2003;
21.
Memorandum from
Chad Whiteman, Institute
of Clean Air Companies
to
Christopher Recchia, Ozone
Transport Commission,
regarding Selective Non-
Catalytic Reduction
Technology Costs
for Industrial Sources, dated
October 6,
2006;
22.
Northeast States for Coordinated
Air Use Management
(NESCAUM), “Status
Report on
NOR:
Control Technologies and
Cost Effectiveness for Utility Boilers”,
prepared
by Jim Staudt, Andover Technology
Partners, June
1998;
23.
Northeast
States for Coordinated Air
Use Management (NESCAUM),
“Status
Report on
NO
Controls”, prepared by Jim
Staudt, Andover Technology Partners,
December 2000 (“NESCAUM 2000
report”);
24.
Institute to Clean
Air Companies, Inc.,
“White Paper: Selective Catalytic
Reduction (SCR) Control
of
NO
Emissions”,
November 1997;
25.
http://www.cormetech.com/experience.htm;
26.
“Economic Indicators”,
Chemical Engineering,
p.
102,
September 2006;
27.
Vatatuck, William
M., “Updating the CE Plant
Cost Index”, Chemical
Engineering,
p.
69, January 2002;
28.
State and Territorial Air Pollution (STAPPA)
and Association of Local
Air
Pollution Control Offices
(ALAPCO), “Controlling Fine
Particulate Matter
Under
the
Clean Air
Act: A Menu of Options”, March
2006;
29.
Erickson,
C., and Staudt,
J.,
“Selective Catalytic
Reduction System Performance
and Reliability Review”, presented
at the EPRI-EPA-DOE-AWMA
Combined
Utility Air Pollution Control Conference,
the Mega Conference, Baltimore,
August 28-3
1, 2006;
30.
Cichanowicz, E.J., “Current
Capital Cost and Cost-Effectiveness
of Power Plant
Emissions Control Technologies”,
prepared for Utility Air
Regulatory Group,
June
2007.
31.
http://www.mobotecusa.com/proj
ects/vermillion-sellsheet.pdf;
ILLINOIS
REGISTER
5
09
POLLUTION
CONTROL
BOARD
NOTICE OF
PROPOSED
AMEINIDMENTS
32.
http ://www.mobotecusa.comlproj ects/capefear6-sellsheet.pdf;
33.
STAPPA!ALAPCO, “Controlling Nitrogen Oxides under the Clean Air Act: A
Menu of Options”, July 1994;
34.
Khan, Sikander, United States Environmental Protection Agency, “Methodology,
Assumptions,
and References Preliminary
NO
Controls Cost Estimates for
Industrial Boilers”, October-November 2003;
35.
MACTEC Federal Programs/MACTEC Engineering
and Consulting, Inc.,
“Midwest Regional Planning Organization (RPO): Petroleum Refinery Best
Available Retrofit Technology (BART)”,
Engineering Analysis, prepared for
The
Lake Michigan Air Directors Consortium (LADCO), March 30, 2005. (“LADCO
2005”);
36.
http
://www.epa. gov/air/ozonepollution/SIPToolkit/documents/
stationary fox list.pdf
37.
http://www.callidus.com/pages/next_gen.htm;
38.
Heat Input Affects
NO
Emissions from Internal Flue Gas Re-Circulation Burners
http
://texasiof.ces.utexas.edu/texasshowcase/pdfs/presentations/c 1 /dbishop.pdf;
39.
http://www.andovertechnology.com/HGA_Market_Report_secure.pdf;
40.
http
://vvww.valleyair.org/rules/curmtrules/r4304.pdf
41.
www.perf.org/ppt/Bishop.ppt;
42.
State of
New Jersey Department of Environmental Protection, State of the Art
Manual for Boilers and Process Heaters, July 1997 (revised
February 22, 2004).
www. state.nj
.us/dep/aqpp/downloads/sotalsotal2.pdf;
43.
Partha Ganguli, Workgroup Reconmiendations and Other Potential Control
Measures Stationary Combustion Sources Workgroup, May
11, 2006.
http
://www.nj .gov/dep/airworkgroups/docs/wps/SCSOO4Afin.pdf;
44.
Sun, W.H., Bisnett, M.J., et al., “Reduction of
NO
Emissions from Cement
KilnlCalciner through the Use of
the
NOXOUT
Process”,
International Specialty
ILLNOIS REGISTER
6
09
POLLUTION CONTROL BOARD
NOTICE OF PROPOSED AMENDMENTS
Conference on Waste Combustion
in Boilers and Industrial Furnaces, April 21,
1994;
45.
http
://www.cadencerecycling.comlpdf/6-PageComplete.pdf;
46.
Hansen,
B., Cadence Environmental Energy Inc., “Staged Combustion for
NO
Reduction Using High Pressure Air Injection”, undated.
http ://www.cadencerecycling.comlpdf/IEEE2002.pdf;
47.
Sabo, E., MACTEC Federal Programs,
Inc., “Candidate Control Measures for
Cement Plants”, LADCO!MRPO, Regional Air Quality Workshop, June 28, 2005;
48.
United States Environmental Protection Agency, Office of Air Quality, Planning
and Standards, Technical Bulletin: Nitrogen
Oxides
(NO),
Why and How They
Are Controlled, EPA-456TF-99-006R, November 1999.
http
://www.epa.gov/ttnlcatc/dirl
/fhoxdoc.pdf;
49.
Finding of Significant Contribution and Rulemaking
for Certain States in the
Ozone Transport Assessment Group Region for Purposes of Reducing Regional
Transport of Ozone, Rule, 63 Fed. Reg. 57356, October 27, 1998;
50.
State of Michigan v. USEPA, 213 F.3d 663 (D.C. Cir. 2000);
51.
Federal Implementation Plans to Reduce the
Regional Transport of Ozone;
Proposed Rule, 63 Fed. Reg. 56394, October 21, 1998;
52.
United
States Environmental
Protection Agency, Office of Air and Radiation,
Regulatory Impact Analysis for the
NO
SIP Call, FIP, and Section 126
Petitions,
Volume 1: Costs and Economic Impacts,
September 1998;
53.
Waible, R., Price, D., Tish, P., Halpern,
M., “Advanced Burner Technology for
Stringent NOx Regulations”, presented at the American Petroleum Institute
Midyear Refining
Meeting,
Orlando, FL, May 8, 1990;
54.
Nguyen, Quang, Koppang, Richard, Energy and
Environmental Research
Corporation, Advanced Steel Reheat Furnaces Research and Development,
Final
Report, prepared
for
U.S. Department of Energy, January 14, 1999;
55.
Rowlan, Steven
J.
and Sun, William
H.,
“NO
Control on Preheat and Radiant
Furnaces at Nucor Steel Mills through Urea SNCR, SCR, and Hybrid Processes”,
ILL1NOIS REGISTER
7
09
POLLUTION CONTROL BOARD
NOTICE
OF PROPOSED AMENDMENTS
presented at
ICAC Forum, Houston, TX,
February 12-13, 2002.
http
://www.icac.com!Files/Rowlan.pdf;
56.
Kobayashi, H.,
“Advances in Oxy-Fuel Fired Glass Melting
Technology”,
presented at
XX International Congress on Glass
(ICG), Kyoto, Japan, September
26-
October 1, 2004;
57.
http
://wwwLeere.energy.gov/industry/glass/pdfs/airstaging.pdf;
58.
http
://www.
gastechnology.orglwebroot/app/xnlxd.aspx?it=enweb&xd=
4reportspubs%5C4_8focus%5Coxygenenrichedairstaging.xml;
59.
http
://www.osti.gov/energycitations/product.biblio.j
sp?osti_id6 16314;
60.
Midwest RPO
Candidate Control Measures,
Interim White Paper, Source
Category:
Glass Manufacturing,
December 2, 2005;
61.
Energetics, Inc., Energy
and Environmental Profile of the U.S.
Aluminum
Industry, prepared
for
U.S.
Department of Energy,
July 1997;
62.
http
://wwwl.eere.energy.gov/industry/aluminum!pdfs/aluminum.pdf
63.
Schalles, David G.,
The Next Generation of
Combustion Technology for
Aluminum Melting, undated. http
://www.bloomeng.comltmspaper-FINAL.doc;
64.
http
://www.bloomeng.com!1
1501 umiflame.pdf;
65.
http
://www.eere.energy.gov/industry/combustion!pdfs/oscllcomb.pdf
66.
California
South
Coast Rule 2002, Allocations
for oxides of Nitrogen (NOx) and
oxides of
Sulfur
(SOy),
amended
January 7, 2005;
67.
http ://www.epa.
gov/ttn!emc/cem.html; and
68.
Alternative Control Techniques
Document- —
NO
Emissions from
Cement
Manufacturing,
EPA-453/R-94-004,
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.
7)
Will
this
rulemaking
replace any emergency rulemaking
currently in effect? No
ILLINOIS
REGISTER
8
09
POLLUTION
CONTROL BOARD
NOTICE
OF
PROPOSED
AMENDMENTS
8)
Does this rulemaking
contain
an automatic repeal
date? No
9)
Does
this
rulemaking
contain
incorporations
by reference?
Yes. See 35 Ill.
Adm.
Code
217.104 (incorporating
11 sources).
1)
40
CFR
60,
Appendix
A, Methods 1,
2,
3, and 4 (2007);
2)
Alternative
Control
Techniques Document
—
NO
Emissions
from
Industrial/Commercial/Institutional
(ICI) Boilers,
EPA-45 3/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;
3)
Alternative
Control
Techniques Document
—
NO
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;
4)
Alternative
Control
Techniques
Document
— NO
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; and
5)
Alternative
Control
Techniques Document
— NO
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.
10)
Are
there any other
proposed
rulemakings
pending
on this Part? Yes
Section
Numbers:
Proposed
Action:
Illinois Register
Citation:
217.386
Amend
32
Ill. Reg.
17075 (Oct.
31, 2008)
217.392
Amend
32 Ill.
Reg. 17075 (Oct. 31,
2008)
217.396
Amend
32 Ill.
Reg. 17075 (Oct.
31, 2008)
11)
Statement
of Statewide Policy
Objectives:
This
proposed
rulemaking
does not create
or
enlarge
a State mandate,
as defined
in Section
3(b)
of
the State Mandates
Act
[30 ILCS
805/3(b)].
ILLINOIS REGISTER
9
09
POLLUTION
CONTROL
BOARD
NOTICE
OF PROPOSED
AMENDMENTS
12)
Time,
Place, and Manner in
which interested
persons may comment
on this
proposed
rulemaking:
The Board
will accept written
public comment
on this proposal for
45
days
after the date of publication
in the Illinois
Register.
Comments
should reference
Docket
R08-19
and be addressed
to:
Clerk’s Office
Illinois
Pollution
Control Board
100
W. Randolph St.,
Suite 11-500
Chicago,
IL 60601
Interested persons
may request copies of
the
Board’s
opinion and order by
calling the
Clerk’s
office at 312/814-3620,
or download
from the Board’s
Web site at
www.ipcb.state.il.us.
For more information,
contact Tim Fox
at
312/814-6085
or email at
foxt@ipcb.state.il.us.
13)
Initial Regulatory
Flexibility Analysis:
A)
Types
of small businesses,
small municipalities
and not for
profit corporations
affected: None expected
B)
Reporting, bookkeeping
or other
procedures required for
compliance:
The
proposed rulemaking
requires the owner
or operator
of an affected source
to
perform emissions
monitoring, complete
required tests,
and maintain
records and
make reports as
required.
C)
Types of Professional
skills necessary
for compliance:
No professional
skills
beyond those currently
required
by the existing State and
federal air pollution
control regulations
applicable to affected
sources will be required.
14)
Regulatory
Agenda on
which this rulemaking
was summarized: July
2006
The full
text of the Proposed Amendments
begin on
the next page:
TITLE 35:
ENVIRONMENTAL
PROTECTION
SUBTITLE B:
AIR POLLUTION
CHAPTER I:
POLLUTION CONTROL BOARD
SUBCHAPTER
G:
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
(Rcpcalcd)
Section
217.121
New Emission Sources (Repealed)
SUBPART
BGC:
EXISTING FUEL COMBUSTION EMISSION UNITS SOURCES
Section
217.141
Existing Emission Units Sources in Major Metropolitan Areas
SUBPART
GD:
NOx
GENERAL REQUIREMENTS
Section
217.150
Applicability
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
DG:
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
RE:
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
3:
GLASS MELTING FURNANCES
Section
217.200
Applicability
217.202
Exemptions
217.204
Emissions Limitations
SUBPART
GIL:
CEMENT AND LIME KILNS
Section
217.220
Applicability
217.222
Exemptions
217.224
Emissions Limitations
SUBPART
HI:
IRON AND STEEL AND ALUMINUN
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 0:
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
Purpose
Severability
Applicability
Compliance Requirements
Permitting Requirements
Subpart
U
NOx Trading
Budget
Methodology for
Obtaining NOx Allocations
Methodology for Determining NOx Allowances
from the New Source Set
NOx Allocations Procedure for Subpart
U
Budget
Units
New Source Set-Asides for “New” Budget Units
Early Reduction Credits
(ERCs)
for Budget Units
Low-Emitter Requirements
Opt-In Units
Opt-In Process
Opt-In Budget Units:
Opt-In Units: Change
Allowance Allocations
Withdrawal
from NOx Trading Program
in Regulatory
Status
to
Opt-In Budget
Units
SUBPART V:
SUBPART W:
ELECTRIC POWER
GENERATION
NOx TRADING PROGRAM FOR
ELECTRICAL GENERATING UNITS
Section
217.750
217.752
217.754
217.756
217
.758
217
.760
217.762
Generating
217
.764
217.768
217.770
217.774
217.776
217.778
217.780
217.782
Purpose
Severability
Applicability
Compliance Requirements
Permitting Requirements
NOx Trading Budget
Methodology for Calculating NOx Allocations
Units
(EGU5)
NOx Allocations for Budget EGUs
New Source Set-Asides for ‘New” Budget EGUs
Early Reduction Credits for Budget EGUs
Opt-In Units
Opt-In Process
Budget Opt-In Units:
Opt-In
Units:
Change
Allowance Allocations
Section
217.450
217 .452
217.454
217.456
217.458
217.460
217.462
217.464
Aside
217.466
217.468
217.470
217 .472
217.474
217.476
217.478
217.480
217.482
Section
217.521
217.700
217.702
217.704
217.706
217.708
217
.710
217
.712
Lake of Egypt Power Plant
Purpose
Severability
Applicability
Emission Limitations
NOx Averaging
Monitoring
Reporting and Recordkeeping
for Budget Electrical
Withdrawal from NOx Trading Program
in Regulatory Status
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
S252j2.
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
2l7.APPENDIX
F
Allowances
for Electrical
Generating Units
2l7.APPENDIX G
Existing Reciprocating
Internal
Combustion
Engines
Affected
by
the
NOx SIP Call
2l7.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
281
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 R0l-9
at
25 Ill. Reg. 128,
effective
December 26,
2000; amended
in ROl-ll at 25
Ill.
Reg.
4597, effective March
15,
2001;
amended
in ROl-l6 and R0l—17
at 25 Ill.
Reg.
5914,
effective April 17,
2001;
amended
in
R07-l8
at 31 Ill.
Reg. 14271, effective
September
25, 2007; amended
in R08-19
at
33
Ill.
Reg.
,
effective
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, U, 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
-— NOx 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)
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 nalyzers
(2000)
+ki=)
Standards of Performance for Stationary Combustion Turbines, 40 CFR
60,
Subpart KKKK, 60.4400 (2006); and
kik)
Compilation of Air Pollutant Emission Factors: AP-42, Volume
I:
Stationary
Point and Area Sources
(2000),
USEPA;-
1)
40 CFR 60, Appendix A, Methods 1, 2,
3,
and 4 (2007);
m)
Alternative Control
Techniques Document -— NOx 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 -— NOx 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;
—
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unit
sourcc 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 sourccs 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
emissionsQ
rateQ= actual heat input G
= percent
of
actual heat
input derived from gaseous fossil
fuclL
LuelL=
percent
of actual
heat input
derived from liquid fossil
fuclS fuelS=
percent of actual
heat input
derived
from
solid fossil
fuclCfuelG
+ L + S = 100.0
and,
whcrc A, B,
C
and appropriatc mctric and English units arc
dctcrmincd
from
thc following
tablc:
MctricEnglishEkg,’hrlbs/hrQMWmmbtuMetricEnlishEK/hrlls/hrOMWMmbtu/hrA0.0230.003
B0.0230. 003C0 .0680.009
d)
Exceptions: This Section rulc shall not apply to the following:
1)
Existing cxisting fuel combustion units
sources
whichtha
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 P-—
E,
F,
G,
H, M,
or
Q
of this Part.
(Source:
Amended
at 33
Ill. Reg.
—, effective
—)
SUBPART
C:
NOx CENERAL REQUIREMENTSD:
INDUSTRIAL BOILERS
Section
217.150 Applicability
a)
Aoolicabilitv
IL
The
provisions of this Subpart
and Subparts P--—E, F,
G,
H, and M of
this Part
apply to the following:
a-A)
All
sources that are located in either one
of the following areas and
that
emit or have
the potential to emit NOx in an amount
equal
to
or greater than
100
tons per
year:
Ai)
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
Bli)
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)
(lLj) of this Section that emits NOx in
an amount equal to or greater than 15 tons per year and equal
to
or greater than
five tons per ozone season.
32)
For
purposes of this Section,
potential
to emit’ means the quantity of
NOx 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 NOx 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 P-—E,
F, G,
or
M of this
Part continue
to
apply
to
any emission unit that was ever
subject to
the provisions of Subpart D, E, F,
C,
H, or H of thic Partanv of those
Suboarts.
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 emissions of NOx from existing emission units for purposes of
netting or emission offsets, such NOx decreases remain creditable
notwithstanding any requirements that may apply to the existing emission units
pursuant to this Subpart and Subpart
D—E,
F, G, H,, 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, or M of this Part must operate such unit in a
manner consistent with good air pollution control practice to minimize NOx
emissions.
(Source:
Added at 33 Ill. Reg.
effective
Section
217.152 Compliance Date
a)
Compliance
with the requirements of Subparts —E,
F,
G, H,1
and P4
by an
owner or
operator of an emission unit that is
subject to
Subpart D, E, F,
C, H,
or Many
of those Suboarts 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
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
2l7.20 of Subpart F of
this
Part.2l7.204.
c)
Notwithstanding subsection
(a)
of this Section, the owner or operator
of
emission
units subject to Subpart
or
EE
of this Part and located at a
petroleum
refinery must comply with the requirements of this Subpart and
Subpart
E
or
E
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
of
this
Subpart,
and Subpart
P
or HE
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
BE
or
HE
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
B or
HE 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
a)
Performance
testing
of
NOx emissions for
emission units
constructed
on or
before July 1,
2011, and subject
to
Subpart
D-—E,
F, G, j,or
HI of
this
Part
must
be
conducted
in accordance
with Section
217.157
of this
Subpart.217.157.
This
subsection
does not
apply to
owners
and operators
of emission
units
demonstrating
compliance
through a
continuous emissions
monitoring
system.
b)
Performance
testing of NOx
emissions
for emission units
for which
construction
or modification
occurs after
July 1, 2011,
and that are subject
to
Subpart
P---E, F, G, er—H.
or I
of this Part
must
be
conducted
within 60
days
o-f-after
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.2l7.157.
This
subsection
does
not apply
to owners and
operators
of
emission units demonstrating
compliance through
a continuous
emissions
monitoring system.
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
writinc
at
least
30 days in writing
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
of this Subpart.
(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
of this
5ubpart,2
an
owner or operator
of an
emission
unit
subject
to Subpart —
E,
F,
G,
,or
HI
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, 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 accordance
with SectionsSection
217.154(a)
and
(b)
of this Subpart 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 of this
Subpart,217.l52.
an
owner
or operator of an emission
unit subject to Subpart
n-—
E, F,
G, H, 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
D---E,
F,
G,
H,
or P4 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 2l7.l57—ef—-his—-Sibpe
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, or N
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,, or M of this Part must maintain records that demonstrate
compliance
with the requirements of
Subpart 0,
E, F, C, I-I, or Mthose Subtarts,
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.
6)
Reports
for all applicable
emissions tests for NOx 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 P-—-E, F,
G,
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
unitTs
air
pollution control equipment for NOx that is performed on
the unit.
9)
A log for the NOx 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
of this
Subpart,217.l58.
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
PE
of this Part must
maintain records
in order to demonstrate compliance with the
combustion
tuning
requirements
under Section
217.1CC of thic Part.2l7.l66.
d)
The owner or operator of a process heater subject to Subpart
EE
of this
Part must maintain records in order to demonstrate compliance with the
combustion
tuning requirements under Section 217.186 of this
Part.22JLll6
e)
The owner or operator of an emission unit subject
to
Subpart P—E,
F,
G,
Hj,
or M of this Part must maintain records in order
to
demonstrate compliance
with
the testing and monitoring requirements under Section 217.157 of this
.157.
f)
The owner
or operator of an emission unit
subject to Subpart P-
7
--—E,
F, G,
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;
2)
Notify the
Agency
at
least
30 days
in writing prior
to conducting
performance
testing for NOx 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 B---E,
F, G,
H,
or M of this
Part must notify
the
Agency
of any
exceedances
of an
applicable
emissions
limitation of
Subpart D--—E,
F,
G, H,
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
eftr
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 B--—E,
F, G,
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)
of this
Subpart;
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
of this Subpart and
demonstrating compliance
through
the use of a continuous
emissions 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 NOx
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
Part
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 Part
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
PE
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 NOx emissions
discharged into the atmosphere
in
accordance with 40 CFP. Part 75,
as
incorporated by
reference
in Section 217.104 of thic Part.217.l04.
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 NOx emissions
discharged into the atmosphere in
accordance
with 40 CFR Part
60,
Subpartsuboart
A-
7- and Appe4*a1Doendix B,
Performance Specifications 2 and
3, and Appondixaendix F, Quality Assurance
Procedures, as
incorporated
by
reference
in Section
2l7.lO’l of thic
Part .217.104.
3)
The owner or operator of a process heater
subject to
Subpart
E
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 NOx emissions discharged into
the atmosphere muct monitor cmiccionc of NOx dicchargcd into thc atmocphcrc in
accordance with 40 CFR Part 60, Subpartsubtart A-
7- and Appcndixj B,
Performance
Specifications 2
and 3, and
Appcndixaooendix
F, Quality Assurance
Procedures, as
incorporated
by
reference
in
Section
217.104 of thiz
Part
.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
E
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 of thic
SuDpart.211.L54_
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, of thic Part, 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
ef-after
receipt of 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
Part 60,
Subpartsuboart
A-
7-
and
Appcndixaooendix A,
Method 1, 2,
3,
4, 7E, or 19,
as
incorporated
by
reference
in Section
217.104 of thiø Part,2l7.l04, 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. NOx 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
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)
of this Section
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
subsections
(a)
(4),
(a) (4) (A),
and
(a) (4) (B)
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
RE
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
Part
60,
Subpartsubnart
A-r
and Appcndixaooendix
B, Performance
Specifications
2
and
3,
and Appcndixaeoendix
F,
Quality Assurance
Procedures,
as incorporated
by
reference
in Section
217.104
of this Part.2l7.104.
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 NOx
emissions
discharged into the
atmosphere,
but must comply
with
the
performance
test requirements
under subsections
(a) (4),
(a) (4) (A),
and
(a) (4)
(B)
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
R
of this Part, cement
kiln or
lime kiln subject
to Subpart
Gil
of this
Part, iron and
steel reheat, annealing,
or
galvanizing furnace
subject
to
Subpart
RI
of this
Part, or aluminum
reverberatory or
crucible
furnace subject
to Subpart
RI
of this
Part that has the
potential
to
emit
NOx 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 NOx emissions
discharged
into the atmosphere
in accordance
with
40
CFR Part
60,
Subpartp
A-r
and
Appcndixaoeendix
B, Performance
Specifications
2 and 3, and Appcndixaooendix
F, Quality Assurance
Procedures,
as
incorporated by
reference in Section
217.104
of this
Part.217.104.
2)
An owner or operator
of a glass melting
furnace
subject to Subpart
R
of
this
Part,
cement kiln or
lime kiln
subject to Subpart
Gil
of this Part,
iron
and
steel
reheat,
annealing, or galvanizing
furnace
subject
to Subpart
RI
of
this
Part,
or aluminum
reverberatory
or crucible
furnace subject
to
Subpart
RI of
this Part
that has
the potential
to emit
NOx
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
of this
Subpart.
3)
An
owner
or operator of
a
glass
melting
furnace subject
to Subpart
R
of
this Part,
cement kiln
or lime kiln
subject to
Subpart
Gil
of this
Part, iron
and
steel reheat,
annealing,
rgalvanizing
furnace
subject
to
Subpart
RI
of
this
Part,
or
aluminum reverberatory
or crucible
furnace subject
to
Subpart
RI of
this Part that has the potential to emit
NOx 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
of this Part, cement
kilns or lime kilns subject to Subpart
Gil
of
this Part, iron
and steel reheat,
annealing, or galvanizing furnace subject
to
Subpart
HI
of this
Part, or
aluminum
reverberatory
or crucible furnaces subject
to
Subpart
HI
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
217.244,211,244
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 ofafter
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 Dart
60, Subpartsubart
A-
7- and
2’ppcndixaooendix
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 Part
60,
Subpartsubnart
A-7-
and Appondixanoendix 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. NOx emissions must
be
measured
while the glass melting
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)
of this Scction
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
of
this Part, cement kiln or lime kiln subject to Subpart
Gil
of this Part,
iron
and steel reheat, annealing, or galvanizing furnace
subject to Subpart HI of this Part, or aluminum reverberatory or crucible
furnace
subject to Subpart HI of this Part that has the potential
to
emit NOx
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 Part
60,
Subpartsuboart
A-7- and
Appcndixaooendix B, Performance Specifications 2 and
3,
and Appcndixaooendix
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 NOx emissions
discharged
into the
atmosphere
in accordance with
40 CFR Dart
96, Subpartsuboart
H.
d)
Common Stacks.
If two
or
more
emission
units
subject
to Subpart B---—E,
F,
G, H,
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
B-
7
--E, F,
G, H, 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 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
of thiz
Subpart,2l7.l52.
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
anothcrthex
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 NOx emissions
discharged
into
the atmosphere
in accordance with
the
requirements
of 40 CFR
Part
60,
Subpartsubtart
A-r
and
Appcndixaooendix
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 B-—E, F, G, H, 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)
or
(B)
of thic Subpart,
may
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
217.342,217.342
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 NOx emissions on an annual
basis than the
actual NOx
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 217.342,217.342
of this
Part, as
applicable.
C)
Units that are required to meet emission limits or control requirements
for NOx as
provided for in an enforceable order, unless such order allows for
emissions
averaging.
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
eaf.tr
such
occurrence, an
updated emissions
averaging
plan;
or
2)
If
a
unit that was
exempt from
the requirements
of Subpart
-—E,
F,
G, H,
M of
this Part pursuant
to Section
217.162, 217.182,
217.202,
217.222,
217.242,
or
-l---3-4-2-7-2l7.342
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
eafter the
unit no longer
qualifyingaualifies
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
of this Subpart,2l7.l57.
and
the actual
hours of operation
for the applicable
averaging
plan period;
and
2)
Submit
to the Agency by
March 1 following
each calendar
year,
a
compliance
report
containing the
information required
by Section
217.156(i)
of
this Subpart.
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:
Nact =
Nall
Where:
Nact
Nall
Nact
-
.saaTotal
sum of the actual
NOx
mass
emissions
from units included
in the averaging
plan for
each fuel used
(tons
per ozone
season
and year)
.Nall
=
aTotal
sum of the allowable
NOx mass
emissions
from
units
included
in the averaging
plan for
each fuel
used
(tons
per ozone
season
and
year)
.EMact(i)=
aTotal
mass
of actual
NGNQx
emissions
in tons for
a
unit
as
determined in subsection
(f) (1)
of this Section.i
—
aSubscript
denoting
an
individual
unit.j
=
Subscript
denoting
the
fuel
type
used.k
-
aNumber
of different
fuel
types.n
=
Number
of
different
units in the averaging plan.EMall(i)
= Tota1 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,
dctcrmincactualdetermine
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,
EMact(i)
Eact(i)
x Hi,’2000
When emission limits are prescribed in lb/ton of processed
product,
EMact(i)
Eact(i)
x Pi/2000
2)
Allowable emissions must
be determined as follows:
When emission limits are prescribed
in lb/mmBtu,
EMall(i)
—
Eall(i)
x Hi/2000When emission limits are
prescribed in lb/ton of processed product,
EMa11(i)
Eall(i)
x Pi/2000
Where:
EMact(i)
=
Total mass of actual NOx emissions in tons for a unit.
EMall(i)
-—-—Total
mass of
allowable
NOx emissions in tons for a unit.
Eact
—
Actual NOx emission rate (lbs/mmBtu or lbs/ton of product) as determined
by
a performance test,
acontinuous
emissions monitoring system, or an
alternative method
approved
by the Agency.
Eall
=
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, of thiz Part. For an affected industrial boiler
subject
to
Subpart
of this Part, or process heater subject to Subpart
BE
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 of thia Part,2l7.l04.
or an
uncontrolled NOx emission rate as determined by an alternative method
approved
by the
Agency will be used.
H
H
—
Heat input (mmBtu/ozone season or mmBtu/year) calculated
from
fuel flow meter and the heating value of the fuel used.
P
Eaweight
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)
or
(B)
that is complying through an emissions averaging plan
under this
Section
must comply with the applicable provisions
for determining
actual and
allowable
emissions under Section 217.390 of Subpart
Q
of this
Part,2l7.390.
the testing and monitoring requirements
under Section
217.394 of
Subpart
Q
of thic
Part,2l7.394, and the recordkeeping
and reporting requirements
under Section
217.396 of
Subpart
Q
of thic Part.2l7.396.
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 NOx 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
hatialocated
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 NOx pollution control equipment, if any,
continues
to
operate on all other emission units operating during the
maintenance
period.-—
(Source:
Added at 33 Ill. Reg.
, effective
SUBPART
PE:
INDUSTRIAL
BOILERS
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 of thig Part,217.l50, except as provided in subsections
(b)
and
Cc)
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, and cogeneration units,
as
that
term is defined in Soction
225.130
of Part 225,35 Ill. Adm. Code 225.130,
if such boilers or cogeneration
units are subject to the
CAIR NOx Trading Programs
under
35 Ill. Adm. Code
225Subpart
P or E
of Part 225.
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
NOx
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 NOx
emissions from such boiler to less than 15 tons
per year and less
than five tons
per ozone season.
(Source: Added at 33 Iii.
Reg.
effective
Section 217.164
Emissions Limitations
On and
after January 1,
2012, no person shall cause or allow emissions
of NOx
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.
Emissions
EmissionFuelEmission Unit Type and
Limitation
Fuol
Rated Heat Input
Capacity
(mmBtu/hr)
cmcnt
a
(mmBtu/hr)Nox Emissions Limitation
(lb/mmBtu)
or
Reauirementa)
Natural Gas
-)-
Industrial boilcr
0.08
or Other Gaseous
Fuelsl)
Industrial boiler greater than 100
Fucls
21000.082)
Industrial boiler
Combustion LuLLng
less
than or equal
to
100
—bCombustion
tuninab)
Distillate Fuel Oil
1)
Industrial boiler
0.10
greater than 100
21000.102)
Industrial boiler
Combustion tuninc
less than or equal to 100
—eCombustion
tuninac)
Other Liquid
Fuelsl) Industrial boiler
0.15
Fucls
greater
than 100
1000.15
2)
Industrial boiler
Combustui uiI
less than or equal to
100
—dCombustion
tuninad)
Solid Fuel
1)
Industrial
boiler
0.12
greater than 100,
circulating fluidized bed
combustor
2Q122)
Industrial
boiler
0.18
greater than -5-G
32500.183)
Industrial boiler
0.25
greater
than 100 but
less than or equal
to -6-G
42500.254)
Industrial boiler
Combustion tuning
than or equal to
100 Combustion tuning
e)
For
an industrial
boiler combusting a combination of natural gas, coke
oven gas,
and blast
furnace
gas,
the NOx emissions
limitation shall
be
calculated
using the
following equation:
NOx
omissions limitation for pcriod
in lb/MrEtu=
(NOxNC
ETUNG I NOxCOC
ETUCOC
NOxBFC
BTUBFG)
/
(BTtThTC
ETUCOG I BTUBF
NOx emissions
limitation for period in lb/mmBtu =
Whcrc:
NGNG—-——O.O84
lb/MMEtummBtu
for natural
gas
ETUNC = the
heat
inputinou
of natural
gas in PrTWBiU over that period
NOxCOC - O.l44
lb/MMEtummtu
for coke oven
gas
ETUCOC
- the heat input
of
coke oven
gas
in
Bt
over that period
NOxEFC
= O.O288 lb/MM-mmBtu
for blast
furnace gas
ETUEFO
- the heat input of blast furnace
gas in RTTJBtu over
that period
(Source:
Added at 33 Ill. Reg.
effective
Section 217.165 Combination of Fuels
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 of
this
Subpart.2l7.164.
(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 of this Subpart
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:
l)
The date the combustion tuning was performed;
b)
The name, title, and affiliation of the person who performed the
combustion tuning;
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;
4d)
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
&)
Operating parameters recorded
at
the start
and at conclusion of combustion
tuning.
(Source: Added at 33 Ill. Reg.
effective
SUBPART
BE:
PROCESS HEATERS
Section
217.180 Applicability
The
provisions of Subpart G of this Part and this
Subpart apply to all process
heaters
located at sources subject to this Subpart pursuant
to Section
217.150
of
this
Part.2l7.l50.
(Source:
Added at 33 Ill. Reg.
, effective
Section 217.182
Exemptions
Notwithstanding
Section 217.180 of this
Subpart,217.180. the provisions of this
Subpart do not
apply
to a
process heater
operating under a federally enforceable
limit of
NOx 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
On and aftcr January 1,
2012,
no person shall cause or allow emissions of NOx
into the On and after January 1, 2012, no person shall
cause
or allow emissions
of NOx 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.
Emissions
Limitation
Fuel
FuelEmission Unit Tvoe and Rated Heat
Input Capacity
(mmBtu/hr)
Nox Emissions Limitation (lb/mmBtu)
or Requirement
a)
Natural Gas
Proccss neater
0.09
or
Other Gaseous
Fuelsl)
Process heater
greater than 100
Fuc 1 s
20.082)
Process heater
Combustion tuning
less than or equal to 100
—bCombustion
tunincb)
Residual
Fuel Oil
1)
Process heater
0.10
greater than 100,
natural draft
20.102)
Process heater
0.15
greater than 100,
mechanical draft
30.153)
Process heater
Combustion tuning
less than or equal to 100--
eCombustion
tuninac)
Other Liquid
Fuelsi)
Process heater
0.05
Fuels
greater than 100,
natural draft
20.052)
Process heater
0.09
greater
than 100,
mechanical
draftQ9
3)
Process heater
Combustion tuning
less
than or
equal to
lOOCombustion
tunina
(Source:
Added at 33
Ill. Reg.
effective
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 of this
Subpart
.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
of thic Subpart
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:
1)
The date the
combustion
tuning was performed;
h)
The name,
title, and affiliation
of the person who
performed
the
combustion tuning;
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;
4d)
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
-)
Operating
parameters recorded
at the start
and at conclusion
of combustion
tuning.
(Source:
Added
at
33 Ill. Reg.
effective
SUBPART
:
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
of
thic Part.217.lSO.
(Source:
Added at
33 Ill. Reg.
, effective
Section 217.202
Exemptions
Notwithstanding
Section
217.200 of thic
Subpart,2l7.200.
the provisions
of this
Subpart
do
not apply
to a
glass
melting
furnace operating
under
a federally
enforceable
limit of NOx 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
NOx
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.
ProductEmission
Unit TvoeNox
Emissions
Limitation
(lb/ton glass
Product
It1juuiofl uiii
produced)
1)
Container Class
ClassGlassGlass
melting
furnace
5.0
—2-5.02)
Flat Class
ClassGlassGlass
melting furnace
Other Class
Class.QIasGIa.aa
melting furnace
11.
0
b)
The
emissions limitations under
this Section do not apply during glass
melting
furnace startup
(not
to exceed 70
days) or idling (operation at less
than 35
of furnace capacity) . For the purposes of
demonstrating seasonal and
annual compliance, the emissions limitation during
such
periods shall
be
calculated
as
follows:
NOx omissions limitation (lb,’day)
=
UNL)
,‘
L’L’)
Whcrc:
2’NL = The applicable
NOx emissions limitation (lb/day) =
(ANL)
/
(PPC)
Where:
ANL=The atxlicable
NOx emissions limitation
under this
Section in pounds per ton
of glass
produccdPPC
producedPPC=
Permitted
production capacity in tons of glass
produced per day
(Source:
Added
at 33
Ill. Reg.
effective
SUBPART
GH:
CEMENT AND LIME KILNS
Section 217.220 Applicability
a)
Notwithstanding Subpart T of this Part, the provisions of Subpart
OD
of
this Part and this Subpart apply to all cement kilns located at sources
subject
to
this Subpart pursuant to Section 217.150 of this
Part.21l15
b)
The
provisions
of Subpart
12
of this Part and this Subpart apply
to
all lime kilns located at
sources
subject to this Subpart pursuant to Section
217.150 of this
Part.2l7.150.
(Source: Added at 33 Ill. Reg.
effective
Section
217.222 Exemptions
Notwithstanding Section 217.220 of this
Subpart,2l7.220.
the provisions of
this
Subpart
do
not apply to a cement kiln or lime kiln operating under a federally
enforceable limit of NOx 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
NOx 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 TvoeNox
Emissions
Limitation
(lb/ton
clinker
Unit
Trn
produced)
1)
Long dry
kiln
5.1
—2-5.12)
Short
dry
kiln
—3-5.13)
Preheater
kiln
3.8
43.84)
Preheater/precalciner
kiln
2.8
b)
On
and
after
January
1, 2012,
no
person
shall
cause
or
allow emissions
of
NOx
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.
FuelEmission
Unit
TvoeNox
Emissions
Limitation
(lb/ton
lime
Fuol
Emiozion
Unit
Typo
produced)
Ga-s
Rotary
kiln
2-)-
Coal
Rotary2J
GasRotarv
kiln2.22)
CoalRotarv
kiln
2.5
(Source:
Added
at 33
Ill.
Reg.
,
effective
SUBPART
WI:
IRON
AND
STEEL
AND
ALUMINUM
MANUFACTURING
Section
217.240
Applicability
a)
The
provisions
of Subpart
G
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
of this
Part.2l7.lSO.
b)
The
provisions
of Subpart
GD
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
of
this
Part
.2j7j.5Q
(Source:
Added
at
33
Ill. Reg.
effective
Section
217.242
Exemptions
Notwithstanding
Section
217.240
of
this
Subpart,
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
NOx 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
NOx 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.
NOc
Emission Unit TvoeNox
Emissions
Limitation
UJi1L
iy•pC
(lb/mmBtu)
1)
Reheat furnace,
regenerative
0.13
—0.182)
Reheat furnace, recuperative,
combusting natural
gas—30.093)
Reheat
furnace, recuperative,
0.142
combusting
a
combination of
natural gas and coke oven
gas
4-)-
Rchcat furnacc, 0.1424)Reheat
furance, cold—a
air
0.03
—5-0.035)
Annealing furnace. recTenerativeo.386)Anneal±ncT
furnace. recuoerativeo . l67)Annealina
furance, cold-airO . 078)Galvanizina
furnace,
regenerative
0.39
Anncalingo
.469)Ga1vanizinc
furnace,
recuperative
0.16
Anncalingo.lGlO)Galvanizina
furnace, cold—
air
0.07
aIvan1z1ng
rurnace, rcacncrativc
Galvanizing
furnacc, rccupcrativc
0.1C
Galvanizing
furnacc, cold air
0.06
b)
On and after January 1, 2012, no person shall
cause or allow
emissions of NOx 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 TvoeNox
Emissions
Limitation
Emiccion Unit Typc
(lb/mmBtu)
1)
Reverberatory
furnace
0.09
—5J.2)
Crucible
furnace
0.lC1
(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 fuel-fired
stationary
boiler serving
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 of thic
Part.217 .150.
(Source: Added
at 33 Ill.
Reg.
effective
Section
217.342
Exemptions
a)
Notwithstanding
Section
2l7.30 of
thic
Subpart,2l7.340.
the
provisions
of thic Subpart
and this
Subpart
do
not
apply to
a fossil fuel-fired
stationary
boiler operating
under a
federally enforceable
limit
of NOx emissions
from such boiler
to less than
15
tons per
year and less
than five tons
per ozone
season.
b)
Notwithstanding
Section
2l7.30
of thic
SuJDpart,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
thePart
225
35 Ill. Adm. Code
225.Subpart
B through the
multi-pollutant
standard under
Scction35
Ill. Adm.
Code
225.233
of Part 225 or
the combined
pollutant standards
under
35 Ill. Adm. Code
225.Subpart
F of Part 225.
(Source:
Added
at 33 111. Beg.
effective
Section 217.344
Emissions Limitations
On and
after January
1, 2012,
no person shall
cause or allow
emissions of
NOx
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.
NOx
EuelEmission
Unit
Tvoe Nox
Emissions
Limitation
Fuel
uLiit
(lb/mmEtu)
a-)-
Solid
Boiler
(lb/mmBtu)a)
SolidBoilero.12
b)
Natural
aa
Boiler
easBoilerO
. 06
c)
Liquid
1)
Boiler
that commenced
0.10
operation before
January 1, 2008
220080.102)
Boiler
that commenced
0.08
operation on or
after January 1,
200820080.08
(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
of thic
Subpart.217.344.
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WT
JCAR3
NOTICE
502 17-090692
VERSION.
irO
1
1
TITLE 35:
ENVIRONMENTAL PROTECTION
2
SUBTITLE B:
AIR POLLUTION
3
CHAPTER I: POLLUTION CONTROL BOARD
4
SUBCHAPTER
C: EMISSION
STANDARDS AND LIMITATIONS
5
FOR STATIONARY
SOURCES
6
7
PART217
8
NITROGEN
OXIDES EMISSIONS
9
10
SUBPART A: GENERAL PROVISIONS
11
12
Section
13
217.100
Scope and Organization
14
217.101
Measurement Methods
15
2 17.102
Abbreviations and Units
16
217.103
Definitions
17
217.104
Incorporations by Reference
18
19
SUBPART B: NEW FUEL COMBUSTION EMISSION
SOURCES
20
21
Section
22
2 17.121
New
Emission Sources (Repealed)
23
24
SUBPART
C: EXISTING FUEL COMBUSTION EMISSION UNITSSOTJRCES
25
26
Section
27
2 17.141
Existing Emission Sources in Major Metropolitan Areas
28
29
SUBPART D:
NO
GENERAL
REQUIREMENTS
30
31
Section
32
217.150
Applicability
33
217.152
Compliance Date
34
217.154
Performance Testing
35
217.155
Initial Compliance Certification
36
217.156
Recordkeeping and Reporting
37
217.157
Testing
and Monitoring
38
217.158
Emissions Averaging Plans
39
40
SUBPART
E:
INDUSTRIAL
BOILERS
41
42
Section
43
217.160
Applicability
444
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Applicability
88
217.342
Exemptions
89
2 17.344
Emissions Limitations
90
217.345
Combination of Fuels
91
92
SUBPART 0: CHEMICAL MANUFACTURE
93
94
Section
95
217.381
Nitric
Acid Manufacturing Processes
96
97
SUBPART Q: STATIONARY
RECIPROCATING
98
INTERNAL COMBUSTION ENGINES AND TURBINES
99
100
Section
101
217.386
Applicability
102
217.388
Control and
Maintenance
Requirements
103
2 17.390
Emissions Averaging Plans
104
217.392
Compliance
105
2 17.394
Testing
and Monitoring
106
2 17.396
Recordkeeping and Reporting
107
108
SUBPART T: CEMENT KILNS
109
110
Section
111
217.400
Applicability
112
2
17.402
Control Requirements
113
217.404
Testing
114
217.406
Monitoring
115
217.408
Reporting
116
217.410
Recordkeeping
117
118
SUBPART U:
NO
CONTROL AND
TRADING PROGRAM FOR
119
SPECIFIED
NO
GENERATING UThfITS
120
Section
121
217.450
Purpose
122
217.452
Severability
123
217.454
Applicability
124
2
17.456
Compliance
Requirements
125
217.458
Permitting Requirements
126
2 17.460
Subpart U
NO
Trading Budget
127
2
17.462
Methodology for Obtaining
NO
Allocations
128
2
17.464
Methodology for Determining
NO
Allowances from the New Source Set-Aside
129
2
17.466
NO
Allocations Procedure for Subpart U Budget
Units
JCAR35O21
7-0906921r01
130
2 17.468
New
Source
Set-Asides
for
“New”
Budget
Units
131
217.470
Early Reduction Credits
(ERCs) for Budget
Units
132
2 17.472
Low-Emitter
Requirements
133
217.474
Opt-In Units
134
2 17.476
Opt-In Process
135
2 17.478
Opt-In Budget
Units: Withdrawal
from
NO
Trading
Program
136
2 17.480
Opt-Tn
Units: Change in Regulatory
Status
137
2 17.482
Allowance
Allocations
to
Opt-Tn
Budget Units
138
139
SUBPART V: ELECTRIC
POWER GENERATION
140
141
Section
142
217.521
Lake of
Egypt Power Plant
143
217.700
Purpose
144
217.702
Severability
145
217.704
Applicability
146
2 17.706
Emission
Limitations
147
217.708
NO
Averaging
148
217.710
Monitoring
149
217.712
Reporting
and Recordkeeping
150
151
SUBPART W:
NO
TRADING
PROGRAM FOR
152
ELECTRICAL
GENERATING
UNITS
153
154
Section
155
217.750
Purpose
156
217.752
Severability
157
217.754
Applicability
158
217.756
Compliance
Requirements
159
217.758
Pennitting
Requirements
160
217.760
NO
Trading
Budget
161
2 17.762
Methodology
for
Calculating
NO
Allocations for
Budget Electrical Generating
162
Units (EGU5)
163
217.764
NO
Allocations
for Budget EGUs
164
217.768
New Source
Set-Asides for “New”
Budget EGUs
165
217.770
Early Reduction
Credits for Budget
EGUs
166
217.774
Opt-Tn
Units
167
2 17.776
Opt-Tn
Process
168
217.778
Budget
Opt-Tn Units: Withdrawal
from
NO
Trading Program
169
2 17.780
Opt-Tn
Units: Change in Regulatory
Status
170
2 17.782
Allowance
Allocations to
Budget
Opt-Tn
Units
171
172
SUBPART X: VOLUNTARY
NO
EMISSIONS
REDUCTION
PROGRAM
JCAR35O2 1 7-0906921r01
173
174
175
176
177
178
179
180
181
182
183
184
185
186
187
188
189
190
191
192
193
194
195
196
197
198
199
200
201
202
203
204
205
206
207
208
209
210
211
212
213
214
Section
217.800
217.805
217.8 10
217.8 15
217.820
217.825
217.830
217.835
217.840
217.845
217.850
217.855
217.860
217.865
Purpose
Emission Unit Eligibility
Participation
Requirements
NO
Emission Reductions and the
Subpart X
NO
Trading Budget
Baseline Emissions Determination
Calculation of Creditable
NO
Emission Reductions
Limitations on
NO
Emission Reductions
NO
Emission Reduction Proposal
Agency Action
Emissions Determination Methods
Emissions
Monitoring
Reporting
Recordkeeping
Enforcement
Rule into Section Table
Section into Rule Table
Compliance Dates
Non-Electrical Generating Units
Large Non-Electrical Generating Units
Allowances for Electrical
Generating Units
Existing Reciprocating Internal Combustion Engines Affected by the
NO
SIP Call
Compliance Dates for Certain Emissions Units at
Petroleum Refineries
217.APPENDIX A
217.APPENDIX B
217.APPENDIX C
217.APPENDIX D
217.APPENDIX
E
217.APPENDIX F
217.APPENDIX
G
217.APPENDIX H
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 ROl-li at
25 Ill. Reg. 4597, effective March 15,
2001;
amended
in R01-16
and R01-17 at 25 Iii. Reg. 5914, effective April 17, 2001; amended in R07-
18
at 31111. Reg.
14271, effective September 25, 2007;
amended in R08-19
at 33
Ill. Reg.
effective
SUBPART A: GENERAL PROVISIONS
Section 217.100
Scope and Organization
215
a)
This
Part sets standards and limitations for emission of oxides of nitrogen from
JCAR35O21 7-0906921r01
216
stationary sources.
217
218
b)
Permits for sources subject
to
this Part
may be
required pursuant to
35
Ill.
Adm.
219
Code 201 or Section 39.5 of the Act.
220
221
c)
Notwithstanding
the provisions of this Part the air quality standards contained in
222
35 Ill. Adm. Code 243 may not
be
violated.
223
224
d)
These rules
have
been grouped for convenience of the public; the scope of each is
225
determined by its language and history.
226
227
(Source: Amended at 33 Ill. Reg.
effective
228
229
Section 217.104 Incorporations by Reference
230
231
The
following materials are incorporated by reference. These incorporations do not include any
232
later amendments or
editions.
233
234
a)
The
phenol
disulfonic acid procedures, as published in 40 CFR 60, Appendix A,
235
Method
7
(2000);
236
237
b)
40 CFR 96, subparts B, D,
G,
and H (1999);
238
239
c)
40 CFR 96.1 through 96.3, 96.5
through
96.7, 96.50 through
96.54,
96.55(a) &
240
(b),
96.56 and 96.57 (1999);
241
242
d)
40 CFR 60,
72,
75 & 76
(2006);
243
244
e)
Alternative Control
Techniques
Document
— NO
Emissions from Cement
245
Manufacturing, EPA-453!R94-004,
U.S.
Environmental Protection Agency-
246
Office
of Air Quality Planning and Standards,
Research
Triangle Park,
N.C.
247
27711, March 1994;
248
249
f)
Section 11.6, Portland Cement Manufacturing, AP-42 Compilation of Air
250
Emission Factors, Volume 1: Stationary Point and Area Sources,
U.S.
251
Environmental Protection Agency-Office of Air Quality Planning and Standards,
252
Research
Triangle Park,
N.C.
27711, revised
January 1995;
253
254
g)
40 CFR6O.13 (2001);
255
256
h)
40 CFR 60,
Appendix
A,
Methods
3A, 7, 7A, 7C, 7D, 7E, 19, and
20 (2000);
257
JCAR3
502 17-090692
irOl
258
i)
ASTM
D6522-00,
Standard Test
Method for
Determination
of Nitrogen
Oxides,
259
Carbon
Monoxide,
and Oxygen
Concentrations in
Emissions from Natural
Gas-
260
Fired Reciprocating
Engines, Combustion
Turbines,
Boilers, and Process
Heaters
261
Using
Portable
Analyzers (2000);
262
263
jk)
Standards
of Perfonnance
for
Stationary
Combustion Turbines,
40 CFR
60,
264
Subpart
KKKK,
60.4400
(2006); a4
265
266
14)
Compilation
of Air Pollutant
Emission Factors:
AP-42, Volume
I:
Stationary
267
Point
and Area
Sources
(2000), USEPA
268
269
II
40 CFR 60,
Appendix A,
Methods 1, 2, 3, and
4
(2007);
270
271
Alternative
Control
Techniques
Document
— NO
Emissions
from
272
Industrial/Commercial/Institutional
(ICI)
Boilers,
EPA-453/R-94-022,
U.S.
273
Environmental
Protection
Agency, Office of Air
and Radiation,
Office of Air
274
Ouality
Planning and Standards,
Research
Triangle Park, N.C.
27711, March
275
1994;
276
277
Alternative
Control Techniques
Document
— NO
Emissions
from Process
278
Heaters
(Revised),
EPA-453/R-93-034,
U.S.
Environmental Protection
Agency,
279
Office of Air and
Radiation, Office
of Air
Quality
Planning and Standards,
280
Research
Triangle
Park,
N.C.
27711,
September 1993;
281
282
Alternative
Control Techniques
Document
— NO
Emissions from Glass
283
Manufacturing,
EPA-453/R-94-037,
U.S.
Environmental
Protection Agency,
284
Office of
Air and Radiation,
Office of
Air
Ouality
Planning
and
Standards,
285
Research
Triangle Park, N.C.
27711, June
1994;
and
286
287
p
Alternative
Control
Techniques Document
— NO
Emissions
from Iron and
Steel
288
Mills,
EPA-453/R-94-065,
U.S.
Environmental
Protection
Agency, Office
of Air
289
and
Radiation,
Office
of Air
Quality
Planning
and Standards,
Research
Triangle
290
Park, N.C.
27711, September
1994.
291
292
(Source:
Amended at 33 Ill. Reg.
effective
293
294
SUBPART
B: NEW FUEL
COMBUSTION
EMISSION SOURCES
295
296
Section
217.121 New
Emission
Sources (Repealed)
297
298
No
person shall
cause or
allow
the emission of nitrogen
oxides
into the
atmosphere in any
299
one
hour period
from
any new
fuel combustion emission
source with
an actual
heat input equal
300
to or
greater
than 73.2
MW (250
btu/l
to exceed
the
following
standards and
limitations:
1Ii.
I
:
JCAR35O21 7-0906921r01
318
319
(Source:
Repealed at 33 Ill. Reg.
effective
320
321
SUBPART C: EXISTING
FUEL
COMBUSTION EMISSION UNITSSOIJRCES
322
323
Section 217.141 Existing Emission UnitsSourccs in
Major Metropolitan Areas
324
325
No person shall cause or
allow the emission
of nitrogen oxides into the atmosphere in any
one
326
hour period from any
existing fuel combustion emission
jtsource with an actual heat input
327
equal to or greater than 73.2 MW (250 mmbtu!hr), located in the Chicago or St. Louis (Illinois)
328
major
metropolitan areas to exceed the following
limitations:
329
330
a)
For gaseous and/or liquid fossil
fuel firing, 0.46 kg/MW-hr (0.3 lbs/mmbtu) of
331
actual heat input;
332
333
b)
For solid fossil
fuel
firing, 1.39 kg/MW-hr (0.9 lbs/mmbtu) of actual heat input;
334
335
c)
For fuel combustion emission unitssources burning simultaneously any
336
combination of solid, liquid
and gaseous fuel, the allowable emission rate shall be
337
determined by the following equation:
338
339
E=(AG+BL+CS)Q
340
341
Where:
342
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
343
Metric
English
E
Kg/hr
lls/hr
Q
MW
Mmbtu/hr
A
0.023
0.003
JCAR35O21
7-0906921r01
B
0.023
0.003
C
0.068
0.009
344
345
d)
Exceptions:
This
Sectionle
shall not apply
to the
following:
346
347
fl
Existingexisting
fuel combustion
sources thatwhich
are either cyclone
348
fired boilers
burning solid or liquid
fuel,
or horizontally
opposed fired
349
boilers burning solid
fuel
350
351
Emission units that
are
subject
to the emissions limitations
of
Subpart
E,
352
F,
G,
H,
I, M,
or
Q
of this Part.
353
354
(Source: Amended
at
33
Ill.
Reg.
effective
355
356
SUBPART
D: INDUSTRIAL
BOILERS
357
358
Section
217.150
Applicability
359
360
Applicability
361
362
D
The
provisions of this Subpart
and Subparts
E, F, G, H, I, and
M of this
363
Part apply
to the following:
364
365
All sources that
are located
in either one of the following
areas
and
366
that emit
or have the potential
to emit
NO
in
an amount equal to
367
or greater than
100 tons
per
year:
368
369
The area
composed
of the Chicago area counties
of
Cook,
370
DuPage,
Kane, Lake, McHenry,
and
Will, the Townships
371
of Aux
Sable and
Goose
Lake in Grundy
County,
and
the
372
Township
of Oswego in
Kendall County;
or
373
374
jj
The area
composed of the
Metro East
area counties of
375
Jersey,
Madison,
Monroe,
and St. Clair,
and the Township
376
of
Baldwin in
Randolph
County; and
377
378
Any industrial
boiler,
process heater, glass melting
furnace,
cement
379
kiln,
lime kiln, iron and steel
reheat,
annealing,
or galvanizing
380
furnace,
aluminum reverberatory
or
crucible furnace, or fossil
fuel
381
fired
stationary
boiler
at such sources
described in subsection
382
(a)(1)(A)
of this Section
that emits
NOjn an amount
equal to or
JCAR35O21 7-0906921r01
383
greater than
15 tons per year and equal to or greater than five
tons
384
per ozone season.
385
386
For purposes of this Section,
“potential to emit” means the quantity
of
387
NQ
that potentially could be
emitted by a
stationary
source before add-on
388
controls
based on the design capacity
or
maximum production
capacity of
389
the source and
8,760 hours per year or the quantity of
NO
that potentially
390
could be emitted
by
a
stationary source as established in a federally
391
enforceable permit.
392
393
If a source ceases to fulfill the emissions criteria
of
subsection
(a)
of this Section,
394
the requirements of this
Subpart and Subpart E, F,
G,
H, I, or M of this Part
395
continue to apply to any emission unit that was ever subject to the provisions
of
396
any of those Subparts.
397
398
c)
The provisions of this Subpart do
not apply to afterburners, flares, and
399
incinerators.
400
401
Where a construction permit, for which the application was submitted to
the
402
Agency prior to the
adoption of this Subpart, is issued that relies on decreases
in
403
emissions of
NO
from existing
emission units for purposes of netting or emission
404
offsets, such
NO
decreases remain creditable
notwithstanding any requirements
405
that may apply to the existing emission units pursuant to this
Subpart and
Subpart
406
E, F, G, H, I, or M of this Part.
407
408
The owner or operator of an emission unit that is subject
to this Subpart and
409
Subpart
E,
F, G, H, I, or M of this Part must operate such unit in a manner
410
consistent with good air
pollution
control practice to minimize
NO
emissions.
411
412
(Source:
Added at 33 Ill. Reg.
effective
413
414
Section
217.152 Compliance Date
415
416
Compliance with the requirements of Subparts E, F,
G,
H, I and
M by an owner or
417
operator of an emission unit
that is
subject
to any of those Subparts is required
418
beginning January 1, 2012.
419
420
Notwithstanding subsection
(a) of
this
Section, compliance with the requirements
421
of
Subpart
G
of this Part
by
an owner or
operator of an emission unit
subject
to
422
Subpart G of this Part shall be extended until December
31,
2014,
if such units are
423
required to
meet emissions limitations for
NON,
as measured using
a continuous
424
emissions monitoring
system, and included within a legally enforceable order
on
JCAR35O21
7-0906921r01
425
or before
December
31, 2009,
whereby
such emissions
limitations
are
less than
30
426
percent
of the emissions
limitations
set
forth under
Section
2 17.204.
427
428
ci
Notwithstanding
subsection
(a)
of this
Section,
the owner
or
operator
of
emission
429
units
subject to
Subpart
E or F
of this
Part and
located
at a
petroleum
refinery
430
must
comply
with the
requirements
of this Subpart
and
Subpart E
or F of this
Part,
431
as applicable,
for those
emission
units beginning
January
1,
2012,
except that
the
432
owner
or operator
of emission
units
listed
in Appendix
H
must comply
with
the
433
requirements
of this
Subpart,
including
the
option
of
demonstrating
compliance
434
with
the
applicable
Subpart through
an emissions
averaging
plan
under Section
435
2
17.158 and
Subpart
E or F
of
this
Part, as
applicable,
for
the listed
emission
units
436
beginning
on the dates
set forth
in
Appendix
H. With
Agency
approval,
the
437
owner
or
operator of
emission units
listed
in Appendix
H
may elect
to comply
438
with
the requirements
of this
Subpart and
Subpart E
or F
of this Part,
as
439
applicable,
by reducing
the emissions
of emission
units
other than
those listed
in
440
Appendix
H,
provided
that the
emissions
limitations
of
such other
emission
units
441
are
equal
to or more
stringent than
the applicable
emissions
limitations
set
forth
in
442
Subpart
E or
F of this
Part, as
applicable,
by the dates
set
forth in Appendix
H.
443
444
(Source:
Added
at 33 Ill.
Reg.
effective
445
446
Section
217.154
Performance
Testing
447
448
Performance
testing
of
NO
emissions
for emission
units
constructed
on or
before
449
July 1,
2011,
and
subject
to
Subpart
E, F,
G,
H, or I of this
Part
must
be conducted
450
in
accordance
with Section
217.157.
This
subsection
does
not apply
to owners
451
and
operators
of emission
units demonstrating
compliance
through
a continuous
452
emissions
monitoring
system.
453
454
Performance
testing
of
NO
emissions
for
emission units
for which construction
455
or
modification
occurs
after July
1,
2011,
and
that are subject
to Subpart
B, F,
G,
456
H,
or I
of this
Part
must
be
conducted
within
60 days
after
achieving
maximum
457
operating
rate
but no later
than 180
days after
initial startup
of the new
or
458
modified
emission
unit, in
accordance
with Section
2 17.157.
This subsection
459
does
not apply
to owners
and
operators
of emission
units
demonstrating
460
compliance
through
a
continuous
emissions
monitoring
system.
461
462
ci
Notification
of the initial
startup
of
an
emission
unit
subject
to
subsection
(b)
of
463
this Section
must be
provided
to
the
Agency
no later
than
30
days
after initial
464
startup.
465
JCAR35O21 7-0906921r01
466
c)
The owner or operator of an emission unit subject
to subsection
(a)
or (b) of this
467
Section must notify the Agency
of the scheduled date for the
performance
testing
468
in writing at least 30 days before such
date
and
five days before such date.
469
470
If demonstrating compliance
through an emissions averaging plan,
at least 30
471
days before changing the method
of compliance, the owner or
operator
of an
472
emission unit must submit a written notification
to the Agency describing the
new
473
method of compliance,
the reason for the change in the
method of compliance,
474
and the scheduled date for performance
testing, if
required.
Upon changing
the
475
method of compliance, the owner or operator
of an emission unit must submit
to
476
the Agency a revised compliance
certification that meets the requirements
of
477
Section
217.155.
478
479
(Source: Added at 33 Ill. Reg.
effective
480
481
Section 217.155
Initial Compliance
Certification
482
483
By the applicable compliance date set forth under Section 217.152,
an owner or
484
operator of an emission
unit
subject
to Subpart E, F,
G,
H, or I of this Part
who is
485
not demonstrating compliance through
the use of a continuous emissions
486
monitoring system must certify to the Agency that
the emission unit will be in
487
compliance with the applicable emissions limitation of
Subpart
E, F,
G,
H, or I
of
488
this Part
beginning
on such applicable compliance date. The performance
testing
489
certification must include
the results of the performance testing
performed
in
490
accordance with Section
217.154(a)
and
(b)
and the calculations necessary to
491
demonstrate that the subject emission unit will be in initial
compliance.
492
493
j)
By the applicable compliance date set forth under Section 2
17.152, an owner
or
494
operator of an emission
unit
subject
to Subpart E, F,
G,
H, I, or M of this
Part who
495
is demonstrating compliance through the use of a continuous
emissions
496
monitoring system must
certify to the Agency that the affected emission units
will
497
be in
compliance
with the applicable emissions limitation of Subpart
E, F,
G, H, I,
498
or M
of this Part beginning on such applicable
compliance date. The compliance
499
certification must include a certification of the installation and
operation
of a
500
continuous emissions monitoring
system
required
under Section 217.157 and
the
501
monitoring data necessary to demonstrate that the subject emission
unit will
be in
502
initial
compliance.
503
504
(Source: Added at 33 Ill. Reg.
effective
505
506
Section 217.156
Recordkeeping
and Reporting
507
JCAR35O2
17-090692
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508
The
owner
or operator
of an emission
unit subject
to
Subpart
E, F,
G,
H, I, or
M
509
of
this Part must
keep
and
maintain
all
records
used to
demonstrate
initial
510
compliance
and
ongoing
compliance
with the
requirements
of those
Subparts.
511
512
D
Except
as otherwise
provided
under
this Subpart
or Subpart
E, F,
G,
H, I,
513
or
M of this Part,
copies
of such
records must
be
submitted
by the
owner
514
or
operator
of the
source
to the Agency
within
30
days
after receipt
of a
515
written
request
by
the
Agency.
516
517
)
Such records
must
be
kept at the
source
and
maintained
for at least
five
518
years and
must be
available
for
immediate
inspection
and
copying
by the
519
Agency.
520
521
)
The owner
or operator
of an
emission
unit subject
to Subpart
E, F,
G,
H,
I, or
M
522
of this
Part
must maintain
records
that demonstrate
compliance
with the
523
requirements
of
those Subparts,
as applicable,
that
include
the
following:
524
525
]j
Identification,
type
(e.g.,
gas-fired),
and location
of
each unit.
526
527
)
Calendar
date of the
record.
528
529
Monthly,
seasonal,
and
annual
operating
hours.
530
531
4)
Type
and quantity
of
each
fuel used
monthly,
seasonally,
and
annually.
532
533
)
Product
and
material throughput,
as applicable.
534
535
)
Reports for
all applicable
emissions
tests for
NO
conducted
on the
unit,
536
including
results.
537
538
7)
The
date, time,
and
duration
of any
startup, shutdown,
or
malfunction
in
539
the
operation
of any
emission
unit
subject
to
Subpart E,
F,
G,
H, I,
or
M
of
540
this
Part or any
emissions
monitoring
equipment.
The records
must
541
include
a description
of
the
malfunction
and
corrective
maintenance
542
activity.
543
544
)
A
log
of
all maintenance
and inspections
related to
the unit
Ts
air
pollution
545
control equipment
for
NO that is
performed
on
the unit.
546
547
)
A log
for
the
NO
monitoring
device, if
present, including
periods
when
548
not in service
and
maintenance
and inspection
activities
that
are performed
549
on the
device.
550
JCAR35O21
7-090692
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551
Identification
of time periods for which operating conditions and
pollutant
552
data were not obtained by the continuous
emissions monitoring system,
553
including the reasons for not obtaining
sufficient
data and
a description of
554
corrective
actions taken.
555
556
ii)
If complying with the emissions
averaging plan provisions of Section
557
217.158,
copies of the calculations used
to
demonstrate compliance
with
558
the ozone season
and annual control period limitations, noncompliance
559
reports for the ozone season,
and ozone and annual control period
560
compliance reports submitted to the Agency.
561
562
c).
The
owner
or operator of an industrial boiler subject to Subpart E of this Part
563
must maintain records in order to demonstrate
compliance with the combustion
564
tuning requirements
under Section 217.166.
565
566
The owner or operator
of a process heater
subject
to Subpart F of this Part must
567
maintain records in order to demonstrate compliance with the
combustion tuning
568
requirements under
Section 217.186.
569
570
The owner or operator of an emission unit subject to Subpart E, F,
G, H, I, or M
571
of this Part must maintain records in order to demonstrate compliance with
the
572
testing
and monitoring requirements
under Section 217.157.
573
574
The owner or operator of an emission unit subject
to Subpart E, F, G, H, or I of
575
this Part must provide the following information with
respect
to performance
576
testing
pursuant
to Section 2 17.157:
577
578
D
Submit a testing protocol to the Agency at least 60 days prior to testing;
579
580
j
Notify the Agency at least 30 days in writing prior to conducting
581
performance testing for
NO
emissions and five days
prior to such testing;
582
583
Not later than 60 days afier the completion of the test, submit the
results of
584
the test to the Agency;
and
585
586
4
If,
after the
30-days’ notice for an initially scheduled test is sent, there
is a
587
delay (e.g., due to operational
problems)
in conducting
the test as
588
scheduled, the owner or operator of the unit must notify the Agency
as
589
soon as practicable of the delay in the original test date, either
by
590
providing at least
seven days’ prior
notice
of the rescheduled date of the
591
test or
by
arranging a new test date with the
Agency by mutual aeement.
592
JCAR3 50217-090692
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593
g
The owner or operator of
an emission unit
subject
to Subpart
B, F, G, H, I,
or
M
594
of this Part
must notify the Agency
of
any exceedances
of an applicable emissions
595
limitation of Subpart
E, F,
G,
H, I, or M of this Part
by
sending
the applicable
596
report with an explanation
of the causes of such exceedances to the
Agency
597
within 30 days following the end
of the applicable compliance period in which the
598
emissions
limitation was not met.
599
600
Within 30 days after the
receipt of a written request by the Agency, the owner
or
601
operator of an emission unit that is
exempt from the requirements of Subpart E, F,
602
G,
H, I, or M of this
Part must submit records that document
that the emission
603
unit is exempt from those requirements
to the Agency.
604
605
If demonstrating compliance through
an emissions
averaging
plan, by March 1
606
following the applicable
calendar year, the owner or
operator
must submit to
the
607
Agency a report that demonstrates the following:
608
609
D
For all units that are part of the emissions averaging
plan, the total mass of
610
allowable
NO
emissions for the ozone season and for the annual
control
611
period;
612
613
)
The total
mass of actual
NO
emissions for the ozone season
and
annual
614
control period
for each unit included in the averaging plan;
615
616
The calculations that demonstrate
that the total mass of actual
NO
617
emissions are less than the total mass
of
allowable
NO
emissions using
618
equations in
Section
217.158(f);
and
619
620
4
The infonnation required to determine the total mass of actual
NO
621
emissions.
622
623
The owner or
operator
of an emission unit
subject
to the requirements of Section
624
217.157
and demonstrating compliance
through the use of a continuous emissions
625
monitoring system must submit to the Agency
a report within 30 days after the
626
end
of each calendar quarter. This
report must include the following:
627
628
3
Information
identifying and explaining the times and dates when
629
continuous emissions monitoring
for
NO
was not in operation, other
than
630
for purposes of calibrating or performing
quality assurance or quality
631
control activities for the monitoring equipment;
and
632
633
An excess emissions and monitoring
systems performance
report
in
634
accordance with the requirements
of
40
CFR
60.7(c)
and
(d)
and 60.13,
or
JCAR35O21
7-0906921r01
635
40 CFR 75, or an
alternate
procedure
approved
by
the
Agency
and
636
USEPA.
637
638
The owner or operator
of an emission
unit
subject
to
Subpart
M of this
Part must
639
comply with the
compliance certification
and recordkeeping
and reporting
640
requirements
in
accordance
with
40 CFR
96,
or an alternate procedure
approved
641
by
the Agency
and USEPA.
642
643
(Source: Added
at 33 Ill. Reg.
effective
644
645
Section 2 17.157
Testing and Monitoring
646
647
Industrial
Boilers and Process
Heaters
648
649
D
The owner
or operator
of an industrial boiler
subject
to
Subpart E of this
650
Part
with a rated heat input
capacity greater
than 250 mmBtulhr
must
651
install,
calibrate, maintain,
and operate
a
continuous
emissions
monitoring
652
system
on the emission
unit for the measurement
of
NO
emissions
653
discharged into the atmosphere
in
accordance with
40
CFR
75, as
654
incorporated
by
reference in Section 217.104.
655
656
)
The owner or operator
of an industrial
boiler
subject
to Subpart E
of this
657
Part with a rated
heat input
capacity greater than
100 mmBtulhr but less
658
than or
equal to 250 mmBtu/hr
must install,
calibrate, maintain,
and
659
operate a
continuous emissions
monitoring system
on such
emission
unit
660
for the measurement
of
NO
emissions discharged
into the atmosphere
in
661
accordance
with 40 CFR
60,
subpart A and
appendix B, Performance
662
Specifications
2
and
3, and appendix F, Quality
Assurance Procedures,
as
663
incorporated
by reference
in Section 217.104.
664
665
The
owner or operator of
a process heater
subject
to Subpart
F of this
Part
666
with a rated
heat input capacity
greater than
100 mmBtu/hr must
install,
667
calibrate,
maintain, and operate
a continuous emissions
monitoring
system
668
on the emission
unit for the
measurement of
NO
emissions discharged
669
into the
atmosphere in accordance
with 40 CFR
60, subpart
A and
670
appendix
B, Performance
Specifications 2
and 3, and appendix F,
Quality
671
Assurance
Procedures, as
incorporated
by
reference
in Section
2 17.104.
672
673
4)
If demonstrating
compliance through an
emissions averaging
plan, the
674
owner or
operator
of
an industrial
boiler
subject
to Subpart
E of this
Part,
675
or a process heater
subject to
Subpart
F
of this Part,
with a rated heat
input
676
capacity
less
than or equal to 100
mmBtu/hr and
not demonstrating
677
compliance through
a continuous
emissions monitoring
system must
have
JCAR350217-0906921r01
678
an initial
performance
test conducted pursuant to subsection (a)(4)(B) of
679
this Section and Section 217.154.
680
681
An
owner or operator of an industrial boiler or process heater must
682
have subsequent performance
tests conducted pursuant to
683
subsection
(a)(4)(B)
of this Section
at
least once every five years.
684
When, in the opinion of the Agency or USEPA, it is necessary to
685
conduct
testing to demonstrate compliance with Section
217.164
or
686
217.184, as applicable, the owner
or
operator
of
an industrial
boiler
687
or process heater must, at his or her own expense, have such test
688
conducted in accordance
with the
applicable test methods and
689
procedures specified in this Section within 90 days after receipt of
690
a notice to test from the Agency or USEPA.
691
692
The owner or operator of an industrial boiler or process heater
693
must have
a
performance
test conducted using
40
CFR 60, subpart
694
A and appendix A, Method 1, 2, 3, 4, 7E, or 19, as incorporated
by
695
reference
in Section
217.104,
or other alternative USEPA methods
696
approved by the Agency. Each
performance
test must consist
of
697
three separate runs, each lasting a minimum of 60 minutes.
NO
698
emissions
must be measured while the industrial boiler is operating
699
at maximum operating
capacity or
while the process heater is
700
operating at normal maximum load. If the industrial boiler or
701
process heater has combusted more than one type of fuel in the
702
prior year, a separate performance test is required for each fuel.
If
703
a
combination of fuels is typically
used, a
performance test
maybe
704
conducted, with Agency approval, on such combination of fuels
705
typically used.
Except
as provided under subsection
(e)
of this
706
Section, this subsection (a)(4)(B) does not apply if such owner
or
707
operator is demonstrating
compliance with an emissions
limitation
708
through a continuous emissions monitoring system under
709
subsection
(a)(1), (a)(2), (a)(3),
or
(a)(5)
of
this Section.
710
711
Instead of complying with the requirements of subsections (a)(4),
712
(a)(4)(A), and (a)(4)(B) of this Section, an owner or operator of an
713
industrial boiler
subject
to
Subpart
E
of
this Part,
or a
process
heater
714
subject
to Subpart F of this Part, with a rated heat
input
capacity less
than
715
or equal to 100 mmBtu/hr may install and operate a continuous emissions
716
monitoring
system on such emission
unit in accordance with the
717
applicable requirements of 40 CFR
60,
subpart
A
and appendix B,
718
Performance Specifications 2 and 3, and appendix F, Quality Assurance
719
Procedures, as incorporated by reference in Section 2 17.104. The
720
continuous emissions
monitoring system must be used to demonstrate
JCAR35O21 7-0906921r01
721
compliance with the applicable
emissions limitation or emissions
722
averaging
plan on an ozone season and annual
basis.
723
724
)
Notwithstanding subsection
(a)(2)
of this Section, the owner or
operator of
725
an auxiliary boiler
subject
to Subpart
B of this Part with a rated heat input
726
capacity
less than or equal to 250 mmBtu/hr
and a capacity factor of less
727
than or equal to
20%
is
not required to install, calibrate, maintain,
and
728
operate a continuous emissions
monitoring system on such boiler for
the
729
measurement
of
NO
emissions discharged
into the atmosphere, but must
730
comply with the performance
test requirements under subsections
(a)(4),
731
(a)(4)(A), and
(a)(4)(B)
of this Section.
732
733
j
Glass
Melting
Furnaces; Cement Kilns; Lime Kilns;
Iron and Steel Reheat,
734
Annealing, and Galvanizing Furnaces;
and Aluminum
Reverberatory
and
735
Crucible Furnaces
736
737
D
An owner
or operator of a glass melting furnace subject
to Subpart
G
of
738
this Part, cement kiln or lime
kiln
subject
to Subpart H of this Part, iron
739
and steel reheat, annealing, or galvanizing furnace
subject
to Subpart I
of
740
this Part, or aluminum
reverberatory or crucible furnace subject
to Subpart
741
I of this Part that has
the potential to emit
NO
in an amount equal
to or
742
greater than one ton per day
must install, calibrate, maintain, and operate
a
743
continuous emissions monitoring
system on such emission unit for the
744
measurement of
NO
emissions discharged into the
atmosphere in
745
accordance with 40
CFR 60, subpart A and appendix B, Performance
746
Specifications 2 and
3,
and
appendix F, Quality Assurance Procedures,
as
747
incorporated by reference in Section 217.104.
748
749
An owner or operator of a glass melting furnace
subject to Subpart
G
of
750
this Part, cement kiln
or lime kiln
subject
to Subpart H of this Part, iron
751
and steel reheat, annealing, or galvanizing furnace subject
to Subpart I
of
752
this Part, or aluminum reverberatory
or crucible furnace
subject
to Subpart
753
I of
this Part
that has the potential to emit
NO
in an amount less
than one
754
ton per day must have an initial performance
test conducted pursuant
to
755
subsection
(b)(4) of this Section and Section 217.154.
756
757
An owner or operator of a glass melting furnace subject
to Subpart
G of
758
this Part,
cement
kiln or lime kiln
subject
to Subpart H of this Part,
iron
759
and steel reheat,
annealing, or galvanizing furnace subject to Subpart
I of
760
this Part, or aluminum reverberatory
or crucible furnace
subject
to
Subpart
761
I of this Part that has the potential to emit
NO
in an amount less than
one
762
ton per day must have
subsequent
performance tests
conducted pursuant
to
763
subsection
(b)(4) of this Section as follows:
JCAR3502
17-090692
1r01
764
765
)
For
all glass melting
furnaces subject
to Subpart
G
of
this Part,
766
cement
kilns
or lime kilns
subject
to Subpart
H
of this
Part, iron
767
and steel reheat,
annealing,
or galvanizing
furnace subject
to
768
Subpart
I of this Part,
or aluminum
reverberatory
or
crucible
769
furnaces
subject
to Subpart
I of this Part,
including
all such
units
770
included
in
an
emissions
averaging
plan, at
least
once every
five
771
years;
and
772
773
)
When,
in the opinion
of the
Agency
or USEPA,
it
is
necessary
to
774
conduct
testing
to demonstrate
compliance
with
Section 217.204,
775
2 17.224,
or 2 17.244
of this
Part, as
applicable,
the
owner
or
776
operator
of a glass
melting
furnace,
cement kiln,
lime kiln,
iron
and
777
steel reheat,
annealing,
or galvanizing
furnace, or
aluminum
778
reverberatory
or
crucible
furnace must,
at
his
or
her own expense,
779
have
such test conducted
in
accordance
with the
applicable
test
780
methods
and
procedures
specified in
this Section
within 90
days
781
after receipt
of a
notice to test
from
the
Agency or
USEPA.
782
783
4)
The
owner or
operator
of
a glass
melting
furnace,
cement
kiln,
or lime kiln
784
must have
a performance
test conducted
using
40 CFR
60,
subpart
A and
785
appendix
A, Methods
1,
2,
3, 4,
and 7E, as
incorporated
by
reference
in
786
Section
217.104 of
this Part,
or other alternative
USEPA
methods
787
approved
by the
Agency.
The
owner
or operator
of an iron
and steel
788
reheat,
annealing,
or
galvanizing
furnace,
or
aluminum
reverberatory
or
789
crucible
furnace
must have
a performance
test conducted
using
40
CFR
790
60,
subpart A
and
appendix
A,
Method
1, 2, 3,
4,
7E,
or
19, as
791
incorporated
by
reference
in Section
217.104
of
this Part, or
other
792
alternative
USEPA
methods
approved
by
the
Agency.
Each
performance
793
test must
consist
of three
separate
runs,
each
lasting
a minimum
of
60
794
minutes.
NO
emissions
must
be
measured
while
the glass
melting
795
furnace,
cement
kiln, lime
kiln, iron and
steel reheat,
annealing,
or
796
galvanizing
furnace,
or
aluminum
reverberatory
or
crucible
furnace
is
797
operating
at maximum
operating
capacity.
If the
glass melting
furnace,
798
cement
kiln, lime
kiln,
iron and
steel reheat,
annealing,
or
galvanizing
799
furnace,
or aluminum
reverberatory
or
crucible
furnace has
combusted
800
more
than one
type of
fuel in
the
prior
year, a
separate performance
test
is
801
required
for
each
fuel.
Except
as provided
under
subsection
(e) of
this
802
Section,
this
subsection
(b)(4) does
not apply
if
such owner
or operator
is
803
demonstrating
compliance
with an
emissions
limitation
through a
804
continuous
emissions
monitoring
system
under subsection
(b)(1)
or
(b)(5)
805
of this Section.
806
JCAR3
50217-090692
irOl
807
Instead of complying with the
requirements
of subsections (b)(2), (b)(3),
808
and
(b)(4) of this Section, an owner or operator of a glass melting
furnace
809
subject to Subpart
G
of this Part,
cement kiln or lime kiln
subject
to
810
Subpart H of this Part, iron and steel reheat,
annealing, or galvanizing
811
furnace
subject
to Subpart I of this Part,
or
aluminum reverberatory
or
812
crucible
furnace subject to Subpart I of this Part that has the potential
to
813
emit
NO
in an amount less than
one ton per day may install and operate a
814
continuous emissions monitoring system
on such
emission unit in
815
accordance
with the applicable requirements of 40 CFR 60,
subpart
A
and
816
appendix B, Performance Specifications
2 and 3, and appendix F, Quality
817
Assurance Procedures, as incorporated
by
reference in Section 2 17.104
of
818
this Part. The continuous emissions
monitoring system must be used to
819
demonstrate
compliance with the applicable emissions limitation or
820
emissions averaging plan on an ozone season
and
annual basis.
821
822
Fossil Fuel-Fired Stationary Boilers. The owner or operator of a fossil fuel-fired
823
stationary
boiler subject
to Subpart M of this Part must install, calibrate, maintain,
824
and operate a continuous emissions monitoring system on such emission
unit for
825
the measurement of
NO
emissions discharged into the atmosphere in accordance
826
with 40 CFR
96,
subpart H.
827
828
Common Stacks. If two or more emission units
subject
to Subpart E, F,
G, H, I,
829
M, or
Q
of this Part are
served
by a common stack and the owner or
operator
of
830
such emission units is operating a continuous emissions monitoring system, the
831
owner
or operator may, with written
approval
from the
Agency,
utilize a single
832
continuous emissions monitoring system for the combination of emission units
833
subject
to Subpart E, F, G, H, I, M, or
Q
of this Part that share the common stack,
834
provided such emission units are
subject
to an emissions averaging plan under
this
835
Part.
836
837
Compliance
with
the continuous
emissions
monitoring system
(CEMS)
838
requirements
by an owner or operator of an emission unit who is
required
to
839
install,
calibrate, maintain, and operate a CEMS on
the
emission
unit under
840
subsection
(a)(1),
(a)(2), (a)(3), or
(b)(1)
of this Section, or who has elected
to
841
comply
with the CEMS requirements under subsection
(a)(5) or
(b)(5)
of this
842
Section,
or who has elected to comply with the predictive emission monitoring
843
system
(PEMS)
requirements under subsection
(f)
of this Section, is required
by
844
the
following dates:
845
846
For the owner or operator of an emission unit that is subject to a
847
compliance date in calendar year 2012 under Section 2 17.152,
compliance
848
with the
CEMS or PEMS
requirements,
as applicable, under this Section
849
for such emission unit is
required
by
December 31, 2012, provided
that,
JCAR35O2
1 7-0906921r01
850
during the
time
between
the
compliance
date and
December
31,
2012,
the
851
owner or
operator must
comply
with the applicable
performance
test
852
requirements
under
this Section
and the
applicable
recordkeeping
and
853
reporting
requirements
under
this Subpart.
For
the
owner
or
operator
of
854
an emission
unit that
is
in
compliance
with
the CEMS
or PEMS
855
requirements,
as
applicable,
under this
Section on
January
1, 2012, such
856
owner
or operator
is not
required to
comply with
the
performance
test
857
requirements
under this
Section.
858
859
For the owner
or
operator
of an emission
unit
that
is subject
to
a
860
compliance
date
in
a
calendar
year
other than
calendar year
2012 under
861
Section
2 17.152
of this
Subpart,
compliance
with
the CEMS
or
PEMS
862
requirements,
as applicable,
under
this Section
for such emission
unit
is
863
required
by
the
applicable
compliance
date,
and
such owner
or operator
is
864
not
required to
comply with
the performance
test requirements
under
this
865
Section.
866
867
fi
As
an
alternative
to
complying
with
the requirements
of
this Section,
other
than
868
the
requirements
under
subsections
(a)(1)
and
(c)
of this
Section,
the owner
or
869
operator
of an emission
unit
who
is not otherwise
required
by
any
other statute,
870
regulation,
or enforceable
order
to install,
calibrate,
maintain,
and
operate
a
871
CEMS
on
the emission
unit
may
comply
with
the
specifications
and test
872
procedures
for
a
predictive
emission monitoring
system (PEMS)
on the
emission
873
unit
for the measurement
of
NO
emissions
discharged
into
the atmosphere
in
874
accordance
with the requirements
of 40 CFR
60, subpart
A
and appendix
B,
875
Performance
Specification
16.
The
PEMS
must be used
to
demonstrate
876
compliance
with the applicable
emissions
limitation
or
emissions averaging
plan
877
on an
ozone
season and
annual
basis.
878
879
(Source:
Added at
33 Ill. Reg.
effective
880
881
Section
217.158
Emissions
Averagin2
Plans
882
883
Notwithstanding
any
other
emissions
averaging
plan provisions
under
this Part,
an
884
owner
or operator
of a
source with
certain emission
units
subject
to
Subpart E,
F,
885
G,
H,
I,
or
M of this
Part, or
subject
to Subpart
Q
of this
Part
that are
located
in
886
either
one of
the areas
set
forth
under
Section
217.150(a)(1)(A)
or
(B),
may
887
demonstrate
compliance
with the
applicable
Subpart
through
an
emissions
888
averaging
plan. An
emissions
averaging
plan can only
address
emission
units that
889
are
located
at one
source
and
each
unit may
only
be
covered
by
one emissions
890
averaging
plan.
Such
emission
units at the
source are
affected
units and
are
891
subject
to the requirements
of this Section.
892
JCAR35O21
7-0906921r01
893
1)
The following
units may
be included
in
an
emissions averaging
plan:
894
895
A)
Units that
commenced
operation
on or
before January
1, 2002.
896
897
Units that
the
owner
or operator
may claim
as exempt
pursuant to
898
Section
217.162,
217.182,
217.202,
217.222,
217.242, or
217.342
899
of this
Part, as
applicable,
but
does not
claim
exempt.
For as long
900
as such
a unit is included
in an
emissions
averaging
plan, it will
be
901
treated
as an
affected
unit and
subject
to the
applicable
emissions
902
limitations,
and
testing,
monitoring,
recordkeeping
and reporting
903
requirements.
904
905
c)
Units
that
commence
operation
after
January
1, 2002,
if the
unit
906
replaces
a
unit that
commenced
operation
on
or before
January
1,
907
2002,
or it
replaces a
unit
that
replaced
a
unit
that commenced
908
operation
on or
before
January
1, 2002.
The
new unit
must be
909
used
for the same
purpose
and
have
substantially
equivalent
or less
910
process
capacity or
be permitted
for less
NO
emissions
on an
911
annual
basis than
the
actual
NO
emissions
of the unit
or units
that
912
are
replaced.
Within
90
days
after permanently
shutting
down
a
913
unit that
is replaced,
the owner
or operator
of such
unit must
914
submit
a written
request to
withdraw
or
amend the
applicable
915
permit
to reflect
that
the
unit is no
longer in
service
before
the
916
replacement
unit
may
be included
in an
emissions
averaging
plan.
917
918
)
The following
types
of units
may not be
included
in
an
emissions
919
averaging
plan:
920
921
A)
Units that
commence
operation
after
January
1, 2002, except
as
922
provided
by
subsection
(a)(l)(C)
of this Section.
923
924
])
Units that
the owner
or operator
is claiming
are
exempt
pursuant
to
925
Section
217.162,
217.182,
217.202,
217.222,
217.242,
or
217.342
926
of this Part,
as applicable.
927
928
)
Units that
are required
to meet emission
limits
or
control
929
requirements
for
NO,as
provided
for in
an
enforceable
order,
930
unless
such order
allows
for emissions
averaging
931
932
})
An
owner
or operator
must submit
an emissions
averaging
plan to the
Agency
by
933
January
1, 2012. The
plan must
include,
but is not
limited
to, the
following:
934
JCAR3
502
17-090692
irO
1
935
The
list
of
affected
units
included
in the
plan
by
unit identification
936
number;
and
937
938
)
A
sample calculation
demonstrating
compliance
using
the
methodology
939
provided in
subsection
(f)
of this
Section for
the
ozone
season (May
1
940
through
September
30)
and calendar
year
(January 1
through December
941
942
943
An
owner or operator
may
amend an
emissions
averaging
plan only
once per
944
calendar
year.
Such an
amended
plan must be
submitted
to
the Agency
by
945
January
1 of the
applicable
calendar
year. If an
amended
plan is not
received
by
946
the
Agency
by January
1 of the applicable
calendar
year,
the
previous
year’s
plan
947
will
be the applicable
emissions
averaging
plan.
948
949
Notwithstanding
subsection
(c) of this
Section:
950
951
1)
If a unit
that is listed
in an emissions
averaging
plan is
taken
out of
952
service,
the
owner
or
operator
must
submit
to the
Agency,
within
30
days
953
after such
occurrence,
an updated
emissions
averaging
plan;
or
954
955
)
If
a unit that
was
exempt
from
the
requirements
of
Subpart E,
F,
G,
H, I,
956
orM
of this
Part
pursuant
to Section
217.162, 217.182,
217.202,
217.222,
957
2 17.242,
or 217.342
of
this
Part, as
applicable,
no longer
qualifies for
an
958
exemption,
the owner
or operator
may amend
its
existing
averaging
plan
959
to include
such unit
within
30
days after the
unit no
longer
qualifies
for the
960
exemption.
961
962
ç
An
owner or operator
must:
963
964
D
Demonstrate
compliance
for the
ozone season
(May
1
through September
965
30) and the
calendar
year
(January
1 through
December
31)
by
using the
966
methodology
and
the
units listed
in the most
recent emissions
averaging
967
plan submitted
to the
Agency
pursuant
to
subsection
(b)
of this
Section,
968
the monitoring
data
or
test data determined
pursuant to
Section 217.157,
969
and the actual
hours
of
operation
for the applicable
averaging
plan
period;
970
971
972
Submit
to the Agency,
by
March
1 following
each
calendar
year,
a
973
compliance
report
containing
the
information
required
by Section
974
217.156(i).
975
976
fi
The
total
mass of actual
NO
emissions
from
the units
listed
in the
emissions
977
averaging
plan must
be equal
to
or
less
than
the total
mass
of allowable
NO
JCAR350217-0906921r01
978
emissions for those
units for
both the ozone season
and calendar year. The
979
following
equation must be used
to determine
compliance:
980
981
Nact
N
982
983
Where:
984
N
=
n
k
act
-
EM
act(i,j)
1=1 j=l
N
n
k
all
-
EM
all(i,j)
1=1 j=l
=
Total sum of the actual
NO
mass emissions
from
units
included
in the averaging
plan for each
fuel used
(tons
per
ozone season and
year).
Na
11
= Total
sum of the allowable
NO
mass emissions
from
units included
in the averaging
plan for each
fuel used
(tons
per ozone season
and
year).
EMaCt(i)
=
Total mass of actual
NO
emissions in tons
for a unit
as
determined
in subsection
(f)(1)
of this Section.
i
=
Subscript denoting
an
individual
unit.
j
Subscript denoting
the fuel type used.
k
= Number
of different
fuel
types.
Number
of different units in the
averaging plan.
EMall(i)
=
Total mass of
allowable
NO
emissions
in tons for
a unit
as
determined in
subsection
(f)(2)
of this Section.
985
986
987
For each unit in
the averaging plan, and
each fuel used by
such unit, determine
988
actual and allowable
NO
emissions using
the following
equations:
989
990
D
Actual emissions
must be determined
as follows:
991
992
When emission
limits are prescribed
in
lb/mmBtu,
993
EIVIact(i)
Eact(i)
X
I—I.
/ 2000
994
995
When emission limits
are
prescribed
in lb/ton
of processed product,
996
JCAR35O21
7-090692
lrOl
EMaCt(i)
x
F /2000
997
998
j
Allowable
emissions
must
be determined
as
follows:
999
1000
When emission
limits
are prescribed
in
lb/mrnBtu,
1001
EMall(•)
x
H
1
/ 2000
1002
1003
V/hen emission
limits
are prescribed
in lb/ton of
processed
product,
1004
EMaII(i)
E
11
i
x
F,
/
2000
1005
1006
Where:
1007
EMact(i)
= Total
mass
of
actual
NO
emissions
in
tons for
a unit.
EMaI
1
(j)
Total
mass of allowable
NO
emissions
in tons
for a unit.
Eact
=
Actual
NO
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.
Eaji
=
Allowable
NO
emission
rate
(lbs/mniBtu
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
NO
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
NO
emission
rate
from
USEPA’s AP-42,
as incorporated
by
reference in
Section 217.104,
or
an
uncontrolled
NO
emission
rate as determined
by
an alternative
method
approved
by the Agency,
will
be
used.
II
Heat
input
(mmBtu/ozone
season
or mrnBtu/year)
calculated
from
fuel flow
meter and
the heating
value
of
the
fuel used.
JCAR3 502 17-090692 lrOl
P
weight in tons of processed
product.
1008
1009
g
An owner or operator of an emission unit subject
to Subpart
0
of this Part that is
1010
located in either one of the areas set forth under Section 217.150(a)(1)(A)
or (B)
1011
that is
complying
through an emissions averaging plan under this Section must
1012
comply with the applicable provisions
for determining actual and allowable
1013
emissions under Section 217.390, the testing and
monitoring requirements under
1014
Section
2 17.394,
and the recordkeeping and reporting requirements under
Section
1015
217.396.
1016
1017
The
owner or operator
of an emission unit located at a petroleum refinery who is
1018
demonstrating compliance with an applicable Subpart through an
emissions
1019
averaging plan under this Section
may exclude from the calculation demonstrating
1020
compliance those time periods when an emission unit included in the emissions
1021
averaging
plan
is shut down for a maintenance
turnaround, provided that such
1022
owner or operator notify the Agency in writing at least 30 days in advance of
the
1023
shutdown of the emission unit for the maintenance
turnaround and the shutdown
1024
of the emission unit does not exceed 45 days per ozone season or calendar
year
1025
and
NO
pollution control equipment,
if any, continues to operate on all other
1026
emission units operating during the maintenance turnaround.
1027
1028
The owner or operator of an emission unit that combusts a combination of coke
1029
oven gas and other gaseous
fuels
and that is located at a source that manufactures
1030
iron
and steel who is demonstrating compliance
with an applicable Subpart
1031
through an emissions averaging plan under this Section may exclude
from the
1032
calculation demonstrating compliance those time periods when the coke oven
gas
1033
desulfurization unit included in the emissions averaging
plan is shut down for
1034
maintenance, provided that such owner or operator notify the Agency in writing
at
1035
least 30
days in advance of the shutdown
of
the
coke oven gas desulfurization unit
1036
for maintenance and such shutdown does not exceed 35 days per ozone season
or
1037
calendar year and
NO
pollution
control equipment, if
any,
continues
to operate
1038
on all other emission
units
operating during the maintenance period.
1039
1040
(Source: Added at 33 Ill. Reg.
effective
1041
1042
SUBPART E: INDUSTRIAL BOILERS
1043
1044
Section 217.160
Applicability
1045
1046
The provisions of
Subpart
D of this Part and this Subpart apply to all industrial
1047
boilers
located
at
sources subject
to
this
Subpart pursuant to Section
2
17.150,
1048
except
as provided in subsections
(b)
and
(c)
of this Section.
1049
JCAR35O2 17-0906921r01
1050
)
The provisions of this Subpart do
not apply to boilers serving a
generator that has
1051
a
nameplate capacity greater than
25 MWe
and produces
electricity
for
sale, and
1052
cogeneration units, as that term is
defined in 35 Ill. Adm.
Code
225.130,
if such
1053
boilers or cogeneration units are
subject
to the CAR
NO
Trading
Programs
1054
under 35 Ill. Adm. Code 225.Subpart
D or E.
1055
1056
ç).
The provisions of this Subpart
do not apply to fluidized
catalytic cracking units,
1057
their regenerator and associated
CO boiler or boilers and
CO
furnace
or furnaces
1058
where present,
if
such units are located
at a petroleum refinery and such
units are
1059
required to meet emission limits
or control requirements
for
NO
as provided
for
1060
in an enforceable order.
1061
1062
(Source: Added at 33 Ill. Reg.
effective
1063
1064
Section 217.162 Exemptions
1065
1066
Notwithstanding Section
217.160
of this Subpart, the provisions
of this Subpart do not apply
to
1067
an industrial boiler operating under a federally
enforceable limit of
NO
emissions
from such
1068
boiler to less than 15 tons per year and less than five
tons per ozone season.
1069
1070
(Source: Added at
33
Ill. Reg.
effective
1071
1072
Section 217.164 Emissions Limitations
1073
1074
On and after January 1, 2012, no person shall cause or allow
emissions of
NO
into the
1075
atmosphere
from any industrial boiler
to
exceed
the following limitations.
Compliance must
be
1076
demonstrated with the applicable emissions limitation
on an ozone season and armual
basis.
1077
Emission
Unit Type and
missions
Rated Heat Input Capacity
Limitation (lb/mmBtu)
Fuel
(mmBtu/hr)
or Requirement
Natural Gas or Other
D
Industrial boiler
greater
0 08
Gaseous
Fuels
than 100
)
Industrial boiler less than
Combustion
tuning
or equal to 100
Distillate Fuel Oil
D
Industrial boiler greater
0.10
than
100
j Industrial
boiler less than
.
Combustion
tuning
or equal to 100
JCAR3
5021
7-0906921r01
ç)
Other
Liquid
Fuels
fl
Industrial
boiler
greater
)
Industrial
boiler
less
than
Combustion tumng
or equal
to
100
,)
Solid Fuel
.
0.12
j)
Industnal
boiler
greater
than 100,
circulating
fluidized
bed combustor
)
Industrial
boiler
greater
0
18
than
250
Industrial
boiler
greater
0.25
than
100 but
less than
or
equal
to
250
4)
Industrial
boiler
less
than
Combustion
tuning
or
equal
to
100
1078
1079
ç
For an
industrial
boiler
combusting
a
combination
of
natural
gas, coke
oven
gas,
1080
and blast
furnace
gas,
the
NO
emissions
limitation
shall
be calculated
using
the
1081
following
equation:
1082
1083
NQ
emissions
limitation
for
period
in lb/mmBtu
=
(NOX
*
BtuNG
+
NO
*
Btu
+
NO
*
Btu
BFG
)
/(BtuNG
+
Btu
COG
+ Btu
1084
Where:
1085
NO
XNG
=
0.084 lb/mmBtu for
natural
gas
BtuNG
= 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
BFG
= 0.0288
lb/mmBtu for
blast
furnace
gas
BtuBFG
=
the
heat
input of
blast
furnace
gas
in Btu
over that
period
1086
JCAR35O21 7-0906921r01
1087
(Source: Added at 33 Ill. Reg.
effective
1088
1089
Section 217.165 Combination of Fuels
1090
1091
The owner
or operator of an industrial boiler
subject
to this Subpart and
operated with any
1092
combination
of fuels
must
comply with a heat input weighted
average emissions
limitation to
1093
demonstrate compliance with Section 2
17.164.
1094
1095
(Source: Added at 33 Ill. Reg.
effective
1096
1097
Section
217.166
Methods and Procedures for
Combustion Tuning
1098
1099
The owner or operator of an industrial boiler subject
to the combustion tuning
requirements of
1100
Section 217.164 must have combustion tuning
performed on the boiler
at least annually. The
1101
combustion
tuning must
be performed
by an employee
of the owner or operator or
a contractor
1102
who has successfully completed a training course
on the combustion tuning
of boilers firing
the
1103
fuel
or fuels
that
are fired in the boiler.
The owner or
operator must maintain the following
1104
records that must be made available to the
Agency upon request:
1105
1106
The
date the combustion
tuning was performed;
1107
1108
j
The name, title, and affiliation
of the person who
performed
the combustion
1109
tuning;
1110
1111
Documentation demonstrating
the provider of
the combustion tuning training
1112
course, the dates the training
course was taken, and
proof
of successful
1113
completion of the training course;
1114
1115
Tune-up procedure followed and checklist
of items
(such
as burners,
flame
1116
conditions, air supply, scaling
on heating surface,
etc.)
inspected
prior to the
1117
actual
tune-up; and
1118
1119
Operating parameters
recorded at the start and
at conclusion of combustion
1120
tuning.
1121
1122
(Source: Added at 33 Ill. Reg.
effective
1123
1124
SUBPART
F: PROCESS HEATERS
1125
1126
Section 217.180 Applicability
1127
1128
The provisions of
Subpart D
of
this
Part and this
Subpart
apply to all process heaters
located at
1129
sources
subject
to
this Subpart pursuant
to Section 217.150.
JCAR35O2
1 7-0906921r01
1130
1131
(Source:
Added
at 33 Ill.
Reg.
effective
1132
1133
Section
217.182
Exemptions
1134
1135
Notwithstanding
Section
217.180,
the provisions
of
this Subpart
do not
apply
to a process
heater
1136
operating
under
a federally
enforceable
limit of
NO
emissions
from such
heater
to less
than 15
1137
tons
per year
and less
than five
tons per
ozone season.
1138
1139
(Source:
Added
at
33
Ill.
Reg.
effective
1140
1141
Section 217.184
Emissions
Limitations
1142
1143
On
and after January
1, 2012,
no person
shall cause
or allow emissions
of
NO
into
the
1144
atmosphere
from any
process
heater to
exceed
the following
limitations.
Compliance
must
be
1145
demonstrated
with
the applicable
emissions
limitation
on an ozone
season
and
annual
basis.
1146
Emissions
Limitation
Emission
Unit
Type and
Rated
(lb/mmBtu)
or
Fuel
Heat
Input Capacity
(mmBtu!hr)
Requirement
)
Natural
Gas or
fl
Process
heater greater
0.08
Other
Gaseous
than
100
Fuels
)
Process
heater less
than
Combustion
tuning
or
equal to 100
j
Residual
Fuel Oil
j
Process
heater
greater
0.10
than
100, natural
draft
Process
heater
greater
0.15
than 100,
mechanical
draft
)
Process heater
less than
Combustion
tuning
or
equal to
100
ç
Other
Liquid
1)
Process
heater greater
0.05
Fuels
than
100, natural
draft
)
Process
heater
greater
than 100,
mechanical
draft
JCAR3 502 17-090692
irOl
)
Process heater
less
than
or
Combustion
tuning
equal to
100
1147
1148
(Source: Added at
33 Ill. Reg.
effective
1149
1150
Section 217.185
Combination
of Fuels
1151
1152
The owner or operator
of a process heater
subject
to
this Subpart and
operated with any
1153
combination of fuels
must comply
with a heat input weighted
average
emissions limitation
to
1154
demonstrate compliance
with Section 217.184.
1155
1156
(Source: Added
at 33 Ill. Reg.
effective
1157
1158
Section
217.186
Methods
and
Procedures for
Combustion Tuning
1159
1160
The owner or operator
of a process heater
subject
to
the combustion tuning
requirements
of
1161
Section 2 17.184 must
have combustion
tuning performed
on the
heater
at least annually. The
1162
combustion tuning
must be performed
by an
employee
of the owner or operator
or a contractor
1163
who has successfully
completed a
training course on the
combustion
tuning of heaters
firing the
1164
fuel
or
fuels
that
are fired in the heater.
The owner
or operator
must
maintain the following
1165
records
that
must
be made available
to the
Agency
upon request:
1166
1167
The date the
combustion tuning
was performed;
1168
1169
j)
The name,
title, and affiliation
of the person who
performed
the combustion
1170
tuning;
1171
1172
c
Documentation
demonstrating
the
provider
of the combustion tuning
training
1173
course,
the
dates the
training
course was taken,
and proof of
successful
1174
completion
of the training course;
1175
1176
Tune-up
procedure followed
and checklist
of items
(such
as burners,
flame
1177
conditions,
air supply, scaling
on heating surface,
etc.)
inspected
prior to the
1178
actual
tune-up; and
1179
1180
Operating
parameters
recorded
at the start and
at conclusion of
combustion
1181
tuning.
1182
1183
(Source:
Added at 33 Ill. Reg.
effective
1184
1185
SUBPART
G: GLASS MELTING
FURNACES
1186
1187
Section 217.200
Applicability
JCAR35O21
7-0906921r01
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.
1191
1192
(Source: Added
at 33 Ill. Reg.
effective
1193
1194
Section
217.202 Exemptions
1195
1196
1197
1198
1199
1200
1201
1202
1203
1204
1205
1206
1207
1208
1209
1210
1211
1212
1213
1214
1215
1216
1217
1218
1219
1188
1189
1190
Notwithstanding
Section 2 17.200,
the provisions
of this Subpart do not
apply to a glass melting
furnace operating
under a federally
enforceable limit
of
NO
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
)
On and after January
1, 2012, no person shall
cause or allow emissions
of
NO
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.
Emissions Limitation
Product
Emission
Unit Type
(lb/ton
glass produced)
j
Container
Glass
Glass
melting
furnace
5.0
Flat Glass
Glass
melting furnace
7.9
Other Glass
Glass melting furnace
The
emissions limitations
under this Section do
not apply during glass
melting
furnace
startup
(not
to
exceed
70
days)
or idling
(operation at less
than 35% of
furnace
capacity). For the
purposes of demonstrating
seasonal and annual
compliance,
the
emissions limitation
during such
periods shall be
calculated as
follows:
NQ
emissions
limitation
(lb/day) = (ANL)/(PPC)
Where:
ANL
The applicable
NO
emissions
limitation under this
Section
in pounds
per ton of glass
produced
JCAR3
50217-090692
irOl
PPC =
Permitted
production
capacity
in
tons
of glass
produced
per
4y
1220
1221
(Source:
Added
at 33 Iii.
Reg.
effective
1222
1223
SUBPART
H:
CEMENT
AND
LIME
KILNS
1224
1225
Section
217.220
Applicability
1226
1227
g
Notwithstanding
Subpart
T of
this
Part,
the provisions
of
Subpart
D
of this Part
1228
and
this
Subpart
apply
to all
cement kilns
located
at
sources
subject
to
this
1229
Subpart
pursuant
to Section
2 17.150.
1230
1231
The
provisions
of Subpart
D of
this Part
and this
Subpart
apply
to all lime
kilns
1232
located
at sources
subject
to
this Subpart
pursuant
to
Section
217.150.
1233
1234
(Source:
Added
at 33 Iii.
Reg.
effective
1235
1236
Section
217.222
Exemptions
1237
1238
Notwithstanding
Section
217.220,
the
provisions
of this Subpart
do not
apply
to
a
cement kiln
or
1239
lime kiln
operating
under
a federally
enforceable
limit
of
NO
emissions
from such
kiln
to
less
1240
than 15
tons per
year and
less than
five
tons
per
ozone
season.
1241
1242
(Source:
Added
at 33 Ill.
Reg.
effective
1243
1244
Section
217.224
Emissions
Limitations
1245
1246
On
and after
January
1,
2012,
no
person
shall
cause
or
allow emissions
of
NO
1247
into
the
atmosphere
from any
cement
kiln to exceed
the following
limitations.
1248
Compliance
must
be
demonstrated
with
the applicable
emissions
limitation
on an
1249
ozone
season and
annual basis.
1250
No
Emissions
Limitation
Emission
Unit
Type
(lb/ton
clinker produced)
Long
dry
kiln
Short
dry
kiln
5.1
Preheater kiln
3.8
Preheater/precalciner
kiln
2.8
1251
1252
On
and
after January
1. 2012,
no person
shall cause
or allow
emissions
of
NO
1253
into
the atmosphere
from
any lime
kiln to exceed
the
following
limitations.
JCAR3
502 17-090692
irO 1
1254
Compliance
must be demonstrated
with the
applicable
emissions
limitation on an
1255
ozone season and annual basis.
1256
Emissions Limitation
Fuel
Emission Unit Type
(lb/ton
lime
produced)
D
Gas
Rotary
kiln
2.2
Coal
Rotarykiln
2i
1257
1258
(Source: Added at 33 Ill. Reg.
effective
1259
1260
SUBPART I: IRON AND STEEL AND ALUMINUM MANUFACTURING
1261
1262
Section 217.240 Applicability
1263
1264
The
provisions
of
Subpart
D of this Part and this Subpart
apply
to
all reheat
1265
furnaces, annealing furnaces, and galvanizing furnaces used in iron and steel
1266
making located at sources
subject
to this Subpart pursuant to Section
217.150.
1267
1268
)
The provisions of Subpart D of this Part and this Subpart apply to all
1269
reverberatory furnaces and crucible furnaces used in aluminum melting located at
1270
sources
subject
to
this
Subpart pursuant to Section
2
17.150.
1271
1272
(Source:
Added at
33
Ill. Reg.
effective
1273
1274
Section
217.242 Exemptions
1275
1276
Notwithstanding Section 2 17.240, the
provisions
of this Subpart do not apply to an iron and steel
1277
reheat
furnace,
annealing furnace, or galvanizing furnace, or aluminum reverberatory furnace or
1278
crucible
furnace operating under a
federally enforceable
limit of
NO
emissions from such
1279
furnace to less
than 15 tons per year and less than five tons per ozone season.
1280
1281
(Source: Added at 33 Ill. Reg.
effective
1282
1283
Section
217.244 Emissions Limitations
1284
1285
On
and after January 1. 2012, no person shall cause or allow emissions of
NO
1286
into the atmosphere from any reheat furnace, annealing furnace, or galvanizing
1287
furnace used in iron and steel making to exceed the following limitations.
1288
Compliance
must be demonstrated with
the
applicable
emissions
limitation
on an
1289
ozone
season and annual basis.
1290
JCAR3
50217-090692
irOl
No
Emissions
Emission Unit Type
Limitation (lb/mmBtu)
fl
Reheat furnace, regenerative
0.18
Reheat furnace, recuperative, combusting
natural
gas
Reheat furnace,
recuperative, combusting a
0.142
combination of natural gas
and coke oven
Reheat furance, cold-air
0.03
Annealing furnace, regenerative
0.38
Annealing furnace, recuperative
0.16
D
Annealing
furance,
cold-air
0.07
Galvanizing furnace, regenerative
0.46
Galvanizing furnace, recuperative
0.16
Galvanizing
furnace, cold air
0M6
1291
1292
j)
On
and after January 1, 2012, no
person shall cause or allow emissions of
NO
1293
into the atmosphere from any reverberatory
furnace or crucible furnace used in
1294
aluminum melting to exceed the following limitations. Compliance
must be
1295
demonstrated with the applicable emissions limitation on an ozone season
and
1296
annual basis.
1297
ssions
Emission Unit
Type
Limitation (lb/mmBtu)
fl
Reverberatory furnace
5.1
Crucible furnace
5.1
1298
1299
(Source: Added at 33 Ill. Reg.
effective
1300
1301
SUBPART M: ELECTRICAL GENERATING
UNITS
1302
1303
Section 217.340
Applicability
1304
1305
Notwithstanding
Subpart V or W of this Part, the provisions
of Subpart D of this Part and this
1306
Subpart apply
to any
fuel-fired stationary
boiler
serving
a generator that has
a
nameplate
capacity
1307
greater than 25 MWe
and produces electricity
for sale, excluding any units listed in Appendix
D
1308
of
this Part, located
at sources
subject
to this Subpart
pursuant to Section 217.150.
1309
JCAR35O21 7-0906921r01
1310
(Source:
Added
at 33 Iii. Reg.
effective
1311
1312
Section 217.342 Exemptions
1313
1314
Notwithstanding Section 2 17.340, the
provisions of this Subpart do not apply to
a
1315
fossil fuel-fired stationary boiler operating
under a federally enforceable limit of
1316
NQ
emissions
from
such boiler to less than 15 tons per year and less
than five
1317
tons per ozone season.
1318
1319
Notwithstanding
Section 217.340,
the provisions of this Subpart do not apply
to a
1320
coal-fired
stationary
boiler that
commenced operation before January 1, 2008, that
1321
is complying
with
35 Ill. Adm. Code 225.Subpart B through the multi-pollutant
1322
standard under 35 Ill. Adm. Code 225.233
or the combined pollutant standards
1323
under
35
Ill. Adm. Code 225.Subpart
F.
1324
1325
(Source: Added at 33 Ill. Reg.
effective
1326
1327
Section
217.344 Emissions Limitations
1328
1329
On
and after January 1, 2012, no person shall cause or allow emissions
of
NO
into the
1330
atmosphere
from any fossil
fuel-fired
stationary boiler to exceed the following limitations.
1331
Compliance must be
demonstrated with
the applicable emissions limitation on an ozone season
1332
and annual
basis.
1333
No
Emissions
Fuel
Emission Unit Type
Limitation
(lb/mmBtu)
Solid
Boiler
0.12
])
Natural gas
Boiler
0.06
Liquid
1)
Boiler that commenced
0.10
operation before January 1,
2008
)
Boiler that commenced
0.08
operation
on or after January
1,2008
1334
1335
(Source: Added
at
33
Ill. Reg.
effective
1336
1337
Section
217.345 Combination of Fuels
1338
JCAR35O21
7-0906921r01
1339
The
owner
or
operator
of a fossil
fuel-fired
stationary
boiler subject
to this
Subpart
and
operated
1340
with any
combination
of fuels
must comply
with a heat
input weighted
average
emissions
1341
limitation
to demonstrate
compliance
with
Section 217.344.
1342
1343
(Source:
Added
at
33 Ill. Reg.
effective
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