State of Montana 

Department of Environmental Quality 

Helena, Montana 59620 

AIR QUALITY OPERATING PERMIT NUMBER OP2650-01 

Renewal Application Received: May 31, 2006

Application Deemed Administratively Complete: June 30, 2006

Application Deemed Technically Complete: July 31, 2006

AFS Number: 030-111-0023A 

Draft Issue Date: July 30, 2007

Proposed Issue Date: August 31, 2007

End of EPA 45-day Review: October 19, 2007

Date of Decision: October 24, 2007

Effective Date: November 24, 2007

Expiration Date: November 24, 2012

In accordance with the Montana Code Annotated (MCA) Sections 75-2-217 and 218, and the 

Administrative Rules of Montana (ARM) Title 17, Chapter 8, Subchapter 12, Operating Permit Program, 

ARM 17.8.1201, et seq., 

Yellowstone Energy Limited Partnership 

NE 1⁄4 of Section 25, Township 1 North, Range 26 East in Yellowstone County 

2215 N. Frontage Road 

Billings, MT 59101 

hereinafter, referred to as "YELP", is authorized to operate a stationary source of air contaminants 

consisting of the emission units described in this permit. Until this permit expires or is modified or 

revoked, YELP is allowed to discharge air pollutants in accordance with the conditions of this permit. All 

conditions in this permit are federally and state enforceable unless otherwise specified. Requirements 

which are state only enforceable are identified as such in the permit. A copy of this permit must be kept 

on site at the above named facility. 

Issued by the Department of Environmental Quality 

 Signature Date 

Permit Issuance and Appeal Process: In accordance with ARM 17.8.1210(j), the Department of 

Environmental Quality’s (Department) decision regarding issuance of an operating permit is not effective 

until 30 days have elapsed from the date of the decision issued October 24, 2007. The decision may be 

appealed to the Board of Environmental Review by filing a request for a hearing within 30 days after the 

date of decision. If no appealed is filed then the Department will send notification and a final permit 

cover page to be attached to this document stating that the permit is final. In addition, ARM 17.8.1233 

allows for any person to petition the Environmental Protection Agency (EPA) within 60 days after the 

expiration of EPA’s 45-day review period to object to issuance of this operating permit. If EPA objects to 

the operating permit as a result of a petition prior to the Department’s notification of a final permit, YELP 

and all affected parties will be informed of the stay of a final permit. If the Department has already 

notified YELP and all affected parties, the Department shall issue a revised permit according to ARM 

17.8.1231. Questions regarding the final issuance date and status of appeals should be directed to the 

Department at (406) 444-3490. 

OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

i
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

ii

Montana Air Quality Operating Permit 

Department of Environmental Quality 

SECTION I. GENERAL INFORMATION ......................................................................................1 

SECTION II. SUMMARY OF EMISSION UNITS...........................................................................2 

SECTION III. PERMIT CONDITIONS ..............................................................................................3 

A. FACILITY-WIDE...............................................................................................................3 

B. EU01 – CIRCULATING FLUIDIZED BED COMBUSTION (CFBC) BOILERS (2) ..................6 

C. EU02 – LIMESTONE UNLOADING, HANDLING, AND CRUSHING AND EU03 LIMESTONE 

STORAGE .......................................................................................................................15 

D. EU04, EU05, EU06, AND EU07 OUTDOOR COKE LOADING, HANDLING AND STORAGE

.......................................................................................................................................17 

E. EU08 COKE UNLOADING/CRUSHING/PROCESSING FACILITY AND EU09 COKE BARN 19 

F. EU10 AND EU11 ASH UNLOADING, HANDLING AND STORAGE...................................21 

G. EU12 FUGITIVE EMISSIONS: VEHICLE TRAFFIC...........................................................22 

H. EU13 CAT SLURRY OIL TANK ......................................................................................24 

SECTION IV. NON-APPLICABLE REQUIREMENTS .................................................................26 

A. FACILITY-WIDE.............................................................................................................26 

B. EMISSION UNITS............................................................................................................26 

SECTION V. GENERAL PERMIT CONDITIONS .......................................................................27 

A. COMPLIANCE REQUIREMENTS.......................................................................................27 

B. CERTIFICATION REQUIREMENTS ...................................................................................27 

C. PERMIT SHIELD..............................................................................................................28 

D. MONITORING, RECORDKEEPING, AND REPORTING REQUIREMENTS.............................29 

E. PROMPT DEVIATION REPORTING ..................................................................................30 

F. EMERGENCY PROVISIONS..............................................................................................30 

G. INSPECTION AND ENTRY ...............................................................................................31 

H. FEE PAYMENT ...............................................................................................................31 

I. MINOR PERMIT MODIFICATIONS...................................................................................31 

J. CHANGES NOT REQUIRING PERMIT REVISION..............................................................32 

K. SIGNIFICANT PERMIT MODIFICATIONS .........................................................................33 

L. REOPENING FOR CAUSE.................................................................................................33 

M. PERMIT EXPIRATION AND RENEWAL ............................................................................33 

N. SEVERABILITY CLAUSE.................................................................................................34 

O. TRANSFER OR ASSIGNMENT OF OWNERSHIP.................................................................34 

P. EMISSIONS TRADING, MARKETABLE PERMITS, ECONOMIC INCENTIVES .....................34 

Q. NO PROPERTY RIGHTS CONVEYED ...............................................................................34 

R. TESTING REQUIREMENTS ..............................................................................................35 

S. SOURCE TESTING PROTOCOL ........................................................................................35 

T. MALFUNCTIONS ............................................................................................................35 

U. CIRCUMVENTION...........................................................................................................35 

V. MOTOR VEHICLES .........................................................................................................35 

W. ANNUAL EMISSIONS INVENTORY..................................................................................35 

X. OPEN BURNING .............................................................................................................35 

Y. MONTANA AIR QUALITY PERMITS................................................................................35 

Z. NATIONAL EMISSION STANDARD FOR ASBESTOS.........................................................36 

AA. ASBESTOS......................................................................................................................36 

BB. STRATOSPHERIC OZONE PROTECTION – SERVICING OF MOTOR VEHICLE AIR 

CONDITIONERS ..............................................................................................................36 

CC. STRATOSPHERIC OZONE PROTECTION – RECYCLING AND EMISSION REDUCTIONS .....37 

DD. EMERGENCY EPISODE PLAN..........................................................................................37 

EE. DEFINITIONS..................................................................................................................37 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

iii

APPENDIX A INSIGNIFICANT EMISSION UNITS.................................................................A-1 

APPENDIX B DEFINITIONS AND ABBREVIATIONS ........................................................... B-1 

APPENDIX C NOTIFICATION ADDRESSES ...........................................................................C-1 

APPENDIX D AIR QUALITY INSPECTOR INFORMATION ................................................D-1 

APPENDIX E JUNE 12, 1998 AND MARCH 17, 2000 BOARD ORDERS ADOPTING AN SO2

CONTROL PLAN.................................................................................................. E-1 

APPENDIX F AMBIENT MONITORING PLAN ...................................................................... F-1 

APPENDIX G FUEL OIL FLOWMETERING............................................................................G-1 

APPENDIX H CAM PLAN - PM10 CONTROL FROM CIRCULATING BED 

BOILERS (2) ..........................................................................................................H-1 

APPENDIX I CAM PLAN – SO2 CONTROL FROM CIRCULATING BED 

BOILERS (2) ........................................................................................................... I-1 

 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

1

Terms not otherwise defined in this permit or in the Definitions and Abbreviations Appendix of this 

permit have the meaning assigned to them in the referenced regulations. 

SECTION I. GENERAL INFORMATION 

The following general information is provided pursuant to ARM 17.8.1210(1). 

Company Name: Yellowstone Energy Limited Partnership

Mailing Address: 1087 West River Street

City: Boise State: Idaho Zip: 83702 

Plant Location: 2215 N. Frontage Road, Billings, Montana 59101-7303 

Responsible Official: Owen Orndorff Phone: (208) 344-3570

Facility Contact Person: Bob Young Phone: (406) 256-5296

Primary SIC Code: 4911

Nature of Business: External Combustion Boilers – Electric Generation

Description of Process: 

The primary operation of the YELP complex is the production of energy in the form of steam. The plant, 

a 65-Megawatt electric generating facility uses both petroleum coke and coker gas as the primary fuels to 

fire two circulating fluidized bed combustion (CFBC) boilers. These boilers in turn produce steam of 

which a portion is provided to the Exxon Refinery and the remainder is used to generate electricity 

through a steam turbine. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

2

SECTION II. SUMMARY OF EMISSION UNITS 

The emission units regulated by this permit are the following (ARM 17.8.1211): 

Emissions 

Unit ID 

Description Pollution Control Device/Practice 

EU01 Circulating Fluidized Bed Combustion (CFBC) 

Boilers (2) 

Particulate emissions are controlled by baghouse; 

sulfur is controlled by injection of lime into the 

boiler, NO2, VOC and CO emissions are 

controlled by lower operating temperature and a 

recirculation of fuel and ash particles through the 

combustion boiler. 

EU02 Limestone Unloading, Handling, and Crushing The unloading of limestone to the hopper takes 

place in an enclosed area and the limestone is 

transferred via an enclosed conveyor, controlling 

fugitive emission. The crushing activity is 

enclosed and the air is exhausted through a 

baghouse. 

EU03 Limestone Storage Particulate emission from the filling of the 

limestone storage silo are controlled by a 

baghouse. 

EU04 Coke Storage and Handling at Exxon Particulate emission from the use of the coke 

storage silo at Exxon are controlled by a 

baghouse. 

EU05 Coke Loading to Stockpile None 

EU06 Loading Coke from Stockpile to Hopper None 

EU07 Coke Storage and Handling From the hopper, the coke is pneumatically fed to 

a surge bin, which is also fed from the fluid coker 

process at Exxon. The surge bin contains a bag 

filter for exhausted displacement air. 

EU08 Coke Unloading/Crushing/Processing Facility This building houses a crusher system, which 

includes a scalper (screen), a crusher, and a belt 

delivery system to existing coke silos. The 

particulate emissions are controlled by a 

baghouse. 

EU09 Coke Barn This building stores coke. 

EU10 Ash Handling and Storage Ash generated by the boilers is removed from the 

boiler as bottom ash and from the baghouse as fly 

ash by a pneumatic system and conveyed to a 

temporary storage silo. A bag filter on the silo 

controls particulate emissions. 

EU11 Ash Unload to Trucks None 

EU12 Fugitive Emissions: Paved Roads None 

EU13 Cat Slurry Oil Tank Tank equipped with an internal floating roof. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

3

SECTION III. PERMIT CONDITIONS 

The following requirements and conditions are applicable to the facility or to specific emission units 

located at the facility (ARM 17.8.1211, 1212, and 1213). 

A. Facility-Wide 

Conditions Rule Citation Rule Description Pollutant/Parameter Limit 

A.1 ARM 17.8.105 Testing Requirements Testing Requirements ------- 

A.2 ARM 17.8.304(1) Visible Air Contaminants Opacity 40% 

A.3 ARM 17.8.304(2) Visible Air Contaminants Opacity 20% 

A.4 ARM 17.8.308(1) Particulate Matter, Airborne Fugitive Opacity 20% 

A.5 ARM 17.8.308(2) Particulate Matter, Airborne Reasonable Precautions ------- 

A.6 ARM 17.8.308 Particulate Matter, Airborne Reasonable Precaution, 

Construction 

20% 

A.7 ARM 17.8.309 Particulate Matter, Fuel Burning 

Equipment 

Particulate Matter E= 0.882 * H-0.1664 Or 

E= 1.026 * H-0.233

A.8 ARM 17.8.310 Particulate Matter, Industrial 

Processes 

Particulate Matter E= 4.10 * P0.67 or 

E= 55 * P0.11- 40 

A.9 ARM 17.8.322(4) Sulfur Oxide Emissions, Sulfur 

in Fuel 

Sulfur in Fuel (liquid or 

solid fuels) 

1 lb/MMBtu fired 

A.10 ARM 17.8.322(5) Sulfur Oxide Emissions, Sulfur 

in Fuel 

Sulfur in Fuel (gaseous) 50 gr/100 CF 

A.11 ARM 17.8.324(3) Hydrocarbon Emissions, 

Petroleum Products 

Gasoline Storage Tanks ------- 

A.12 ARM 17.8.324 Hydrocarbon Emissions, 

Petroleum Products 

65,000 Gallon Capacity ------- 

A.13 ARM 17.8.324 Hydrocarbon Emissions, 

Petroleum Products 

Oil-effluent Water 

Separator 

------- 

A.14 ARM 17.8.342 NESHAPs General Provisions SSM Plans Submittal 

A.15 ARM 17.8.1212 Reporting Requirements Compliance Monitoring ------- 

A.16 ARM 17.8.1207 Reporting Requirements Annual Certification ------- 

Conditions

A.1. Pursuant to ARM 17.8.105, any person or persons responsible for the emission of any air 

contaminant into the outdoor atmosphere shall, upon written request of the Department, provide 

the facilities and necessary equipment (including instruments and sensing devices) and shall 

conduct test, emission or ambient, for such periods of time as may be necessary using methods 

approved by the Department. 

Compliance demonstration frequencies that list “as required by the Department” refer to ARM 

17.8.105. In addition, for such sources, compliance with limits and conditions listing “as required 

by the Department” as the frequency, is verified annually using emission factors and engineering 

calculations by the Department’s compliance inspectors during the annual emission inventory 

review; in the case of Method 9 tests, compliance is monitored during the regular inspection by the 

compliance inspector. 

A.2. Pursuant to ARM 17.8.304(1), YELP shall not cause or authorize emissions to be discharged into 

the outdoor atmosphere from any source installed on or before November 23, 1968, that exhibit an 

opacity of 40% or greater averaged over 6 consecutive minutes, unless otherwise specified by rule 

or in this permit. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

4

A.3. Pursuant to ARM 17.8.304(2), YELP shall not cause or authorize emissions to be discharged into 

the outdoor atmosphere from any source installed after November 23, 1968, that exhibit an opacity 

of 20% or greater averaged over 6 consecutive minutes, unless otherwise specified by rule or in 

this permit. 

A.4. Pursuant to ARM 17.8.308(1), YELP shall not cause or authorize the production, handling, 

transportation, or storage of any material unless reasonable precautions to control emissions of 

particulate matter are taken. Such emissions of airborne particulate matter from any stationary 

source shall not exhibit an opacity of 20% or greater averaged over 6 consecutive minutes, unless 

otherwise specified by rule or in this permit. 

A.5. Pursuant to ARM 17.8.308(2), YELP shall not cause or authorize the use of any street, road or 

parking lot without taking reasonable precautions to control emissions of airborne particulate 

matter, unless otherwise specified by rule or in this permit. 

A.6. Pursuant to ARM 17.8.308, YELP shall not operate a construction site or demolition project 

unless reasonable precautions are taken to control emissions of airborne particulate matter. Such 

emissions of airborne particulate matter from any stationary source shall not exhibit an opacity of 

20% or greater averaged over 6 consecutive minutes, unless otherwise specified by rule or in this 

permit. 

A.7. Pursuant to ARM 17.8.309, unless otherwise specified by rule or in this permit, YELP shall not 

cause or authorize particulate matter caused by the combustion of fuel to be discharged from any 

stack or chimney into the outdoor atmosphere in excess of the maximum allowable emissions of 

particulate matter for existing fuel burning equipment and new fuel burning equipment calculated 

using the following equations: 

For existing fuel burning equipment (installed before November 23, 1968): 

E =0.882 * H-0.1664

For new fuel burning equipment (installed on or after November 23, 1968): 

E =1.026 * H-0.233

Where H is the heat input capacity in million BTU (MMBtu) per hour and E is the maximum 

allowable particulate emissions rate in pounds per MMBtu. 

A.8. Pursuant to ARM 17.8.310, unless otherwise specified by rule or in this permit, YELP shall not 

cause or authorize particulate matter to be discharged from any operation, process, or activity into 

the outdoor atmosphere in excess of the maximum hourly allowable emissions of particulate 

matter calculated using the following equations: 

For process weight rates up to 30 tons per hour: E = 4.10 * P0.67

For process weight rates in excess of 30 tons per hour: E = 55.0 * P0.11 – 40 

Where E = rate of emissions in pounds per hour and p = process weight rate in tons per hour. 

A.9. Pursuant to ARM 17.8.322(4), YELP shall not burn liquid or solid fuels containing sulfur in 

excess of 1 pound per million BTU fired, unless otherwise specified by rule or in this permit. 

A.10. Pursuant to ARM 17.8.322(5), YELP shall not burn any gaseous fuel containing sulfur compounds 

in excess of 50 grains per 100 cubic feet of gaseous fuel, calculated as hydrogen sulfide at 

standard conditions, unless otherwise specified by rule or in this permit. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

5

A.11. Pursuant to ARM 17.8.324(3), YELP shall not load or permit the loading of gasoline into any 

stationary tank with a capacity of 250 gallons or more from any tank truck or trailer, except 

through a permanent submerged fill pipe, unless such tank is equipped with a vapor loss control 

device or is a pressure tank as described in ARM 17.8.324(1), unless otherwise specified by rule 

or in this permit. 

A.12. Pursuant to ARM 17.8.324, unless otherwise specified by rule or in this permit, YELP shall not 

place, store or hold in any stationary tank, reservoir or other container of more than 65,000 gallon 

capacity any crude oil, gasoline or petroleum distillate having a vapor pressure of 2.5 pounds per 

square inch absolute or greater under actual storage conditions, unless such tank, reservoir or other 

container is a pressure tank maintaining working pressure sufficient at all times to prevent 

hydrocarbon vapor or gas loss to the atmosphere, or is designed and equipped with a vapor loss 

control device, properly installed, in good working order and in operation. 

A.13. Pursuant to ARM 17.8.324, unless otherwise specified by rule or in this permit, YELP shall not 

use any compartment of any single or multiple-compartment oil-effluent water separator, which 

compartment receives effluent water containing 200 gallons a day or more of any petroleum 

product from any equipment processing, refining, treating, storing or handling kerosene or other 

petroleum product of equal or greater volatility than kerosene, unless such compartment is 

equipped with a vapor loss control device, constructed so as to prevent emission of hydrocarbon 

vapors to the atmosphere, properly installed, in good working order and in operation. 

A.14. Pursuant to ARM 17.8.342 and 40 CFR 63.6, YELP shall submit to the Department a copy of any 

startup, shutdown, and malfunction (SSM) plan required under 40 CFR 63.6(e)(3) within 30 days 

of the effective date of this operating permit (if not previously submitted), within 30 days of the 

compliance date of any new National Emission Standard for Hazardous Air Pollutants 

(NESHAPs) or Maximum Achievable Control Technology (MACT) standard, and within 30 days 

of the revision of any such SSM plan, when applicable. The Department requests submittal of 

such plans in electronic form, when possible. 

A.15. On or before February 15 and August 15 of each year, YELP shall submit to the Department the 

compliance monitoring reports required by Section V.D. These reports must contain all 

information required by Section V.D, as well as the information required by each individual 

emissions unit. For the reports due by February 15 of each year, YELP may submit a single 

report, provided that it contains all the information required by Section V.B & V.D. Per ARM 

17.8.1207, 

any application form, report, or compliance certification submitted 

pursuant to ARM Title 17, Chapter 8, Subchapter 12 (including 

semiannual monitoring reports), shall contain certification by a 

responsible official of truth, accuracy and completeness. This 

certification and any other certification required under ARM Title 

17, Chapter 8, Subchapter 12, shall state that, “based on 

information and belief formed after reasonable inquiry, the 

statements and information in the document are true, accurate 

and complete.” 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

6

A.16. By February 15 of each year, YELP shall submit to the Department the compliance certification 

required by Section V.B. The annual certification required by Section V.B must include a 

statement of compliance based on the information available which identifies any observed, 

documented or otherwise known instance of noncompliance for each applicable requirement. Per 

ARM 17.8.1207, 

any application form, report, or compliance certification submitted 

pursuant to ARM Title 17, Chapter 8, Subchapter 12 (including 

annual certifications), shall contain certification by a responsible 

official of truth, accuracy and completeness. This certification and 

any other certification required under ARM Title 17, Chapter 8, 

Subchapter 12, shall state that, “based on information and belief 

formed after reasonable inquiry, the statements and information 

in the document are true, accurate and complete.” 

B. EU01 – Circulating Fluidized Bed Combustion (CFBC) Boilers (2) 

Main Stack Emissions 

Condition(s) Pollutant/ 

Parameter 

Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

B.1, B.17, 

B.21, B.22, 

B.23, B.25, 

B.30, B.34 

B.35, B.336 

B.38, B.39 

Opacity 20% CEMS 

 and 

Method 9

Ongoing 

and 

As required by 

the 

Department 

and Section 

III.A.1 

Quarterly 

and 

Semiannual

18.26 lb/hr Method 5 Annual Semiannual 

438.4 lb/day 

80.0 ton/yr 

Excess 

Emissions 

Reports 

As Necessary Quarterly 

B.2, B.3, B.24 

B.30, B.34, 

B.35, B.37, 

B.38, 

Particulate 

Matter 

0.03 lb/MMBtu heat input; 

99% reduction for solid fuel; 

and 

70% reduction for liquid 

Method 19 and 

Method 5 as 

specified in 40 

CFR 60, Subpart 

Da 

Annual Semiannual 

B.4, B.17, 

B.22, B.23, 

B.24, B.30, 

B.35, B.36, 

B.39 

SO2 Offsets 0.96 lb/MMBtu 

238 ton/yr 

720 bbl/day 

CEMS 

and 

Record-keeping 

Ongoing 

and 

As Necessary 

Quarterly 

B.5, B.6, B.17, 

B.22, B.23, 

B.24, B.30, 

B.32, B.33, 

B.36, B.39 

SO2 620.0 lb/hr – avg 

680.0 lb/hr – max 

8.160 ton/day 

2476.0 ton/yr 

B.5, B.7, B.9, 

B.17, B.22, 

B.23, B.24, 

B.30, B.32, 

B.33, B.35, 

B.36, B.39 

SO2 

(YELP is not 

receiving Exxon 

Coker flue gas) 

2040.0 lb/3-hr 

114.2 lb/3-hr 

10,543.0 lb/day 

3,848,049.0 lb/day 

CEMS 

and 

Method 6/6c 

Ongoing 

and 

Annual 

Quarterly 

and 

Semiannual 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

7

Main Stack Emissions 

Condition(s) Pollutant/ 

Parameter 

Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

B.5, B.8, B.9, 

B.17, B.22, 

B.23, B.24, 

B.30, B.34, 

B.35, 

B.37, B.38, 

B.39 

SO2 

(YELP is 

receiving Exxon 

Coker flue gas) 

2040.0 lb/3-hr 

16,320.0 lb/day 

5,956,800.0 lb/yr 

B.5, B.10, 

B.17, B.22, 

B.23.B.24, 

B.34, B.35, 

B.38, B.39 

SO2 92% reduction 

CEMS 

and 

Method 6/6c 

Ongoing 

and 

Annual 

Quarterly 

and 

Semiannual 

B.5, B.11, 

B.17, B.22, 

B.23, B.24, 

B.30, B.34, 

B.35, B.36, 

B.38, B.39

SO2 1.20 lb/MMBtu heat input and 

90% reduction or 70% 

reduction with <0.60 

lb/MMBtu 

CEMS 

and 

Method 6/6C 

Ongoing 

and 

As required by 

the 

Department 

and Section 

III.A.1 

Quarterly 

and 

Semiannual 

B.5, B.6, B.11, 

B.12, B.35, 

B.36, B.38, 

B.39

SO2 / Sulfur in 

fuel 

 0.777 lb/MMBtu heat input 

1.20 lb/MMBtu heat input and 

90% reduction or 70% 

reduction with <0.60 

lb/MMBtu; 

92% reduction 

Analyze weight 

percent Sulfur 

and heating 

value (Btu/lb) of 

petroleum Coke; 

analyze coker 

gas stream when 

boilers are 

operating 

Monthly Semiannual 

B.13, B.17, 

B.22, B.23, 

B.24, B.34, 

B.35, B.37, 

B.38 

CO 120.6 lb/hr 

2898.6 lb/day 

529.0 ton/yr 

CEMS 

and 

Method 3/3B 

Ongoing 

and 

Annual 

Quarterly 

and 

Semiannual 

B.14, B.17, 

B.22, B.23, 

B.24, B.34, 

B.35, B.38, 

B.39

NOx 319.0 lb/hr –avg 

1,396.0 ton/yr 

0.400 lb/MMBtu 

CEMS 

and 

Method 7/7E 

Ongoing 

and 

Annual 

Quarterly 

and 

Semiannual 

B.15, B.17, 

B.22, B.23, 

B.24, B.34, 

B.35, B.36, 

B.37, B.38, 

B.39 

NOx 0.20 lb/MMBtu heat input for 

gaseous fuels and 75% 

reduction; 

0.30 lb/MMBtu heat input for 

liquid fuels and 70% percent 

reduction 

CEMS 

and 

Method 7/7E 

Ongoing 

and 

Annual 

Quarterly 

and 

Semiannual 

B.16, B.25, 

B.26, B.35, 

B.38, B.39 

Emission 

Control 

Requirement 

Petroleum coke fuel, Cat 

Slurry Oil, and all of the 

Exxon process gas to be 

combusted in the YELP boilers 

Reporting As required by 

the 

Department 

and Section 

III.A.1 

As necessary but 

at least Quarterly 

B.17, B.27, 

B.35, B.38, 

B.39 

Emission 

Control 

Requirement 

Install, operate, and maintain a 

Fuel Oil Flowmeter as required 

Calculate fuel oil 

density and mass 

flow 

As required by 

the 

Department 

and Section 

III.A.1 

Quarterly 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

8

Main Stack Emissions 

Condition(s) Pollutant/ 

Parameter 

Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

B.18, B.28, 

B.38, B.39 

Cat Slurry Oil Not to be fired at >1400F Record-keeping As required by 

the 

Department 

and Section 

III.A.1 

Semiannual 

B.19, B.28, 

B.32, B.38, 

B.39 

PM10 CAM Plan ARM 17.8.1506 Provisions from 

CAM Plan, 

Appendix H 

Ongoing Semiannual 

B.20, B.29, 

B.33, B.38, 

B.39 

SO2 CAM Plan AEM 17.8.1506 Provisions from 

CAM Plan, 

Appendix I 

Ongoing Semiannual 

Conditions

B.1. YELP shall not cause to be discharged into the atmosphere from any affected facility any gases 

that exhibit greater than 20% opacity (6 minute average) except for one 6-minute period per hour 

of not more than 27% opacity (ARM 17.8.340 and 40 CFR 60.42a(b)). 

 B.2. Particulate Matter emission from the Main Stack shall not exceed the following (ARM 17.8.752): 

a. 18.26 lb/hr (0.023 lb/MMBtu); 

b. 438.4 lb/day; and 

 c. 80.0 ton/yr. 

B.3. Per 40 CFR 60.42a, YELP shall not cause to be discharged into the atmosphere from any affected 

facility any gases that contain particulate matter in excess of: 

a. 0.03 lb/MMBtu heat input derived from the combustion of solid, liquid, or gaseous fuel (40 

CFR 60.42a (a)(1)); 

b. 1% of the potential combustion concentration (99% reduction) when combusting solid fuel 

(40 CFR 60.42a(a)(2)); and 

c. 30% of the potential combustion concentration (70% reduction) when combusting liquid fuel 

(40 CFR 60.42a (a)(3)). 

 B.4. The construction and operation of the YELP facility required external offsets from the adjacent 

Exxon refinery. The sulfur dioxide emission reduction from the Exxon coker process gas shall be 

at least 238 tons per calendar year. The offsets are provided by the combustion and treatment of 

the Exxon coker process gas stream, by both an hourly limit on sulfur-in-fuel burned at the 

refinery on a refinery-wide basis of 0.96 pounds of sulfur-in-fuel per million BTUs fired and a 

daily limit on the number of barrels of fuel oil that may be burned at the refinery by all 

combustion units of 720 barrels per calendar day. The short term hourly offset shall be 

guaranteed for the YELP facility according to the following operating conditions: 

 a. At any time that YELP is notified by Exxon that Exxon has exceeded either the hourly sulfurin-fuel limitation or the daily limit on the number of barrels of fuel oil fired, YELP shall 

operate its facility in such manner as to ensure that the ratio of SO2 in the Exxon coker 

process gas stream to the SO2 emitted from the YELP main stack shall be equal to or greater 

than 1:1. During times that the SO2 CEM, that measures the inlet coker process gas from 

Exxon, is not operating, the minimum operating value recorded during the past 12-months 

shall be used. During the times that YELP's main stack SO2 CEM is not operating, the 

maximum operating value recorded during the past 12-months shall be used. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

9

b. If the initial notification from Exxon indicates that Exxon has exceeded the hourly sulfur-infuel limit, then YELP shall continue to comply with the ratio requirement described above in 

Section III.B.4.a until such time as YELP is notified by Exxon that the Exxon refinery has 

met the hourly sulfur-in-fuel limitation for 3 consecutive hourly periods. 

c. If the initial notification from Exxon indicates that Exxon has exceeded the daily limit on the 

number of barrels of fuel oil fired, then YELP shall continue to comply with the ratio 

requirement described above in Section III.B.4.a until such time as YELP is notified by 

Exxon that the Exxon refinery is in compliance with the daily limit on fuel oil firing. 

YELP shall report to the Department each time that it receives initial notification by Exxon as 

referenced above in Section III.B.4 (a). Such report shall be submitted with the emission 

report to the Department required in Section III, B.29 of this permit, and shall include both 

the date and time YELP received initial notification by Exxon as referenced above in Section 

III.B.4 (a), and the date and time YELP received subsequent notification by Exxon as 

referenced above in either Section III.B.4.b or III.B.4.c, as appropriate. The report shall also 

describe in detail the operating measures were taken by YELP to meet the requirements in 

Section III.B.4 (a) through B.4 (c) (ARM17.8.749). 

 B.5. YELP shall conform to the most stringent SO2 emission limits (hourly, daily, and annual) as 

listed in this operating permit (Billings/Laurel SO2 Emission Control Plan, approved into the SIP 

by EPA on May 2, 2002, and May 22, 2003). 

 B.6. SO2 emission from the Main Stack shall not exceed the following (ARM 17.8.752): 

a. 620.0 lb/hr computed on a rolling 30-day average (0.777 lb/MMBtu) 

b. 680.0 maximum lb/hr; 

c. 8.160 ton/day; and 

d. 2476.0 ton/yr computed as a 12 month total at the end of each calendar month. 

B.7. YELP Boiler stack SO2 emission shall be limited as follows during periods when the Exxon 

Coker Unit is operating and YELP is not receiving Exxon Coker flue gas (Billings/Laurel SO2

Emission Control Plan, approved into the SIP by EPA on May 2, 2002, and May 22, 2003). 

a. Three Hour Emissions of SO2 from the YELP boiler stack shall not exceed: 

i. 2,040 pounds per 3-hour period during that portion of each calendar-day beginning at 

6:00 a.m. and ending at 9:00 p.m.; and 

ii. 114.2 pounds per 3-hour period during that portion of each calendar-day beginning at 

9:00 p.m. and ending at 6:00 a.m. 

b. Daily Emissions of SO2 from the YELP boiler stack shall not exceed 10,543.0 pounds per 

calendar day; and 

 c. Annual Emissions of SO2 from the YELP boiler stack shall not exceed 3,848,049.0 pounds 

per calendar year. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

10

 

B.8. YELP Boiler stack SO2 emissions shall be limited as follows during periods when either the 

Exxon Coker Unit is not operating or the Exxon Coker Unit is operating and YELP is receiving 

the Exxon Coker flue gas (Billings/Laurel SO2 Emission Control Plan, approved into the SIP by 

EPA on May 2, 2002, and May 22, 2003): 

a. Three-Hour Emissions of SO2 from the YELP boiler stack shall not exceed 2040.0 pounds 

per 3-hour period; 

b. Daily Emissions of SO2 from the YELP boiler stack shall not exceed 16,320.0 pounds per 

calendar day; and 

c. Annual Emissions of SO2 from the YELP boiler stack shall not exceed 5,956,800.0 pounds 

per calendar year. 

B.9. If, for any 3-hour period during the course of a calendar day, the conditions for Section III.B.7 

and Section III.B.8 both apply, then the resulting 3-hour emission limitation for the YELP Boiler 

stack shall be determined by prorating, on an hourly basis, the emission limits contained in 

Section III.B.7 and Section III.B.8. The prorated 3-hour emission limitation shall be calculated as 

the sum of the 1-hour values determined in accordance with the requirements below 

(Billings/Laurel SO2 Emission Control Plan, approved into the SIP by EPA on May 2, 2002, and 

May 22, 2003): 

a. Each Clock Hour during any part of that the conditions for Section III.B.7 apply shall be 

assigned a 1-hour value equal to the emission limitation contained in Section III.B.7 (a)(ii) 

divided by 3; and 

b. All other Clock Hours in the subject 3-hour period shall be assigned a 1-hour value equal to 

the 3-hour emission limitation contained in Section III.B.8 (a) divided by 3. 

B.10. YELP shall achieve a minimum of 92% SO2 control for all boilers operating hours1

. Percent 

control of SO2 shall be determined according to the provision in 40 CFR 60, Subpart Da, Section 

60.48a, except that the percent control is required for all boiler operating hours instead of the 

boiler operating days as identified in the 40 CFR 60 (ARM 17.8.752). 

B.11. YELP shall not cause to be discharged into the atmosphere from any affected facility any gases 

that contain SO2 in excess of: 

a. 1.2 lb/MMBtu heat input and 10% of the potential combustion concentration (90 percent 

reduction) when combusting solid fuel or solid-derived fuel per 40 CFR 60.43a (a)(1); 

b. 30% of the potential combustion concentration (70% reduction) when emissions are less than 

0.60 lb/MMBtu heat input from the combustion of solid fuel or solid-derived fuel per 40 CFR 

60.43a(a)(2); 

c. 0.80 lb/MMBtu heat input and 10% of the potential combustion concentration (90 percent 

reduction) from the combustion of liquid or gaseous per 40 CFR 60.43a(b)(1); and 

d. 100% of the potential combustion concentration (zero percent reduction) when emissions are 

less than 0.20 lb/MMBtu of heat input when combusting liquid or gaseous fuels per 40 CFR 

60.43a(b)(2). 

 1 "Boiler operating hour" means any time during a 60-minute clock hour in which a boiler operates. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

11

 B.12. YELP shall analyze the weight percent sulfur and heating value (BTU/lb) of the petroleum coke 

fuel on a monthly basis when the boilers are operating. Twice per month YELP shall analyze the 

coker gas stream to facilitate F-Factor determination when the boilers are operating. Analysis 

procedures and methods shall follow 40 CFR 60.48a, including Reference Method 19 (ARM 

17.8.749; 40 CFR 60, Subpart Da; 40 CFR 60, Appendix A). 

B.13. CO emissions from the Main Stack shall not exceed the following (ARM 17.8.752): 

a. 529.0 ton/yr; 

b. 2898.6 lb/day; and 

c. 120.6 lb/hr. 

B.14. NOx emissions from the Main Stack shall not exceed the following (ARM 17.8.752): 

a. 1,396.0 ton/yr; and 

 b. 319.0 lb/hr computed on a rolling 30-day average (0.400 lb/MMBtu). 

B.15. YELP shall not cause to be discharged into the atmosphere from any affected facility any gases, 

based on a 30-day rolling average, that contain NOx emissions in excess of: 

a. 0.20 lb/MMBtu heat input derived from the combustion of gaseous fuels per 40 CFR 60.44a 

(a)(1); 

b. 25% of the potential combustion concentration (75% reduction) when combusting gaseous 

fuels per 40 CFR 60.44a (a)(1); 

c. 0.30 lb/MMBtu heat input derived from the combustion of liquid fuels per 40 CFR 60.44a 

(a)(1); and 

d. 30% of the potential combustion concentration (70% reduction) when combusting liquid fuels 

per 40 CFR 60.44a (a)(2); 

B.16. The facility shall burn, in conjunction with petroleum coke fuel and Cat Slurry Oil, all of the 

Exxon process gas in the YELP boilers. For purposes of ARM 17.8.340, 40 CFR 60.40a, and this 

permit, the Cat Slurry Oil shall be considered a liquid fuel. YELP is authorized to burn 

petroleum coke (solid fuel), coker gas (gas fuel), and Cat Slurry Oil (liquid fuel) (ARM 

17.8.749). 

B.17. YELP shall install, operate, and maintain the following Continuous Emission Monitors/ 

Continuous Emission Rate Monitors (CEMs/CERMs) (ARM 17.8.340 and ARM 17.8.749): 

a. Main Stack

i. Opacity 

ii. Sulfur Dioxide 

iii. Nitrogen Oxides 

iv. Oxygen 

v. Carbon Monoxide 

vi. Volumetric Flow Rate 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

12

b. Coker Process Gas Flue

i. Sulfur Dioxide 

ii. Volumetric Flow Rate 

c. The monitors shall comply with all applicable provisions of 40 CFR, Parts 60.5 through 

60.13, Subparts Da 60.46a through 60.49a and Appendix B, (Performance Specifications 1, 2, 

3, and 4) and Appendix F (Quality Assurance/Quality Control) provisions. Volumetric flow 

rate monitors shall comply with the requirements of Attachment 1 of the Stipulation 

(Appendix E of this permit), including Methods A-1 and B-1. Fuel oil flowmeters and fuel 

oil sulfur analysis shall comply with the requirements of Methods C-1 (Appendix H of this 

permit) (ARM 17.8.749). 

 B.18. Cat Slurry Oil shall not be fired in the boilers until the average combustor temperature reaches 

1400 oF (ARM17.8.749). 

B.19. YELP shall provide a reasonable assurance of compliance with emission limitations or standards 

for the anticipated range of operations at the Circulating Fluidized Bed Boiler for PM10 (ARM 

17.8.1504). 

B.20. YELP shall provide a reasonable assurance of compliance with emission limitations or standards 

for the anticipated range of operations at the Circulating Fluidized Bed Boiler for SO2 (ARM 

17.8.1504). 

 Compliance Demonstration 

B.21. A Method 9 test shall be performed, as required by, the Department and Section III.A.1 to 

monitor compliance with the opacity limit in Section III.B.1. The test methods and procedures 

shall be conducted in accordance with the Montana Source Test Protocol and Procedures Manual 

(ARM 17.8.106). 

B.22. Compliance with emission limits in Section III.B. shall be monitored by utilizing data taken from 

the CEMs listed in Section III.B.17 above, as required by, 40 CFR 60, Subpart Da, and in 

accordance with the Stipulation (Appendix E). Although the CEMS data is the method of 

monitoring compliance on a continuous basis, the data from annual reference method tests shall 

also be used to monitor compliance. All CEMS shall be operated pursuant to any and all 

requirements of Attachment 1 of Exhibit A of the Stipulation. The above does not relieve YELP 

from meeting any applicable requirements of 40 CFR 60, Appendices A and B, any requirement 

identified in the June 12, 1998, Stipulation, or other stack testing that will be required by the 

Department (Billings/Laurel SO2 Emission Control Plan, approved into the SIP by EPA on May 

2, 2002, and May 22, 2003). 

B.23. All gaseous continuous emission monitors shall be required to comply with quality 

assurance/quality control procedures in 40 CFR Part 60, Appendix F and the CEM availability 

requirements in 40 CFR 60.47a. CEM systems are to be in operation at all times when the 

emission units are operating except for quality assurance and control checks, breakdowns and 

repairs. In the event the primary CEM system is unable to meet minimum availability 

requirements, YELP shall provide a back-up or alternative monitoring system and plan such that 

continuous compliance can be monitored. YELP shall submit the alternative monitoring plan for 

Department approval within 60 days after achieving the maximum production rate for the facility 

and not later than 180 days after initial startup (ARM 17.8.105, and ARM 17.8.106, ARM 

17.8.749, and ARM 17.8.340). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

13

 

B.24. Compliance testing and continuous monitor certification shall be as specified in 40 CFR Part 60, 

Appendices A and B. The Department shall require annual compliance stack testing at the YELP 

main stack. Testing shall include: Methods 1-4 and 6/6C for sulfur dioxide (SO2), Method 7/7E 

for nitrogen oxides (NOx), Method 3/3B for carbon monoxide (CO), and Method 5 for particulate 

matter (PM, PM-10) or equivalent methods as approved by the Department and EPA, and in 

accordance with the Montana Source Test Protocol and Procedures Manual. Upon request, the 

Department may require stack testing for other pollutants. Test methods and procedures, where 

there is more than one option for any given pollutant, shall be approved by the Department prior 

to commencement of testing. Certification of all CEMS/CERMS shall be conducted annually. 

The annual monitor certification can coincide with the required compliance stack testing (ARM 

17.8.106 and ARM 17.8.749). The annual Relative Accuracy Test Audits (RATAs) required by 

Sections 6(C) and (D) of the Stipulation (Appendix E) may substitute for the annual source test 

provided that the flow rate RATA and the concentration RATA are performed simultaneously 

and additional calculations are made to determine and report the data in pounds per hour sulfur 

dioxide (Billings/Laurel SO2 Emission Control Plan, approved into the SIP by EPA on May 2, 

2002, and May 22, 2003). 

 B.25. YELP shall verify the sulfur dioxide emission rate, utilizing CEMS, on an hourly basis on both 

the YELP stack and from the Exxon coker process gas received by the YELP facility. The results 

shall be reported to the Department along with other emissions data within 30 days of the end of 

each reporting period. The report shall contain all necessary data from the coker process gas 

stream, fuel petroleum coke sulfur content, Cat Slurry Oil sulfur content, and the YELP main 

stack continuous emission monitoring system such that the sulfur dioxide emission reduction is 

quantifiable on an hourly basis (ARM 17.8.749). 

 B.26. YELP shall report to the Department, within 24-hours, any time in which the Exxon coker 

process gas is diverted away from the fluidized bed boiler facility (YELP). Said report shall 

include the period of diversion, estimate of process gas diverted, and circumstances explaining 

the diversion of this stream. Said report shall discuss what corrective actions will be taken to 

prevent recurrences of the situation and what caused the diversion (ARM 17.8.749). 

B.27. YELP shall install, operate, and maintain a continuous fuel oil flowmeter. YELP shall comply 

with the following fuel oil2

 flowmetering and analysis specifications: 

 

a. Conduct daily fuel oil sampling in accordance with Method C-1 of Appendix G. 

b. Analyze all fuel oil samples collected, for sulfur content in accordance with Method C-1 of 

Appendix G. 

c. Each fuel oil flowmeter shall demonstrate a flowmeter accuracy of 2.0 percent of the upper 

range value (i.e., maximum calibrated oil flow rate) as measured under laboratory conditions 

by the manufacturer or by the owner or operator, and pursuant to the calibration procedures 

as specified by Method C-1 of Appendix G. 

B.28. YELP shall monitor compliance by following the Compliance Assurance Monitoring (CAM) 

Plan for PM10 (Appendix H). The CAM Plan, written by YELP in accordance with ARM 

17.8.1504 is summarized in Appendix H and is available in full upon request by the Department 

or the facility (ARM 17.8.1503 and ARM 17.8.1213). 

 2 "Fuel Oil" means Cat Slurry Oil from the Exxon fluid catalytic cracking (FCC) unit. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

14

B.29. YELP shall monitor compliance by following the CAM Plan for SO2 (Appendix I). The CAM 

Plan, written by YELP in accordance with ARM 17.8.1504 is summarized in Appendix I and is 

available in full upon request by the Department or the facility (ARM 17.8.1503 and ARM 

17.8.1213). 

Recordkeeping 

B.30. YELP shall maintain all records necessary to verify compliance with the required SO2 offsets, all 

requirements identified in 40 CFR 60, Subpart Da, and all requirements identified in the June 12, 

1998, and March 17, 2000, stipulation. The records shall be made available to the Department 

upon request (Billings/Laurel SO2 Emission Control Plan, approved into the SIP by EPA on May 

2, 2002, and May 22, 2003). 

B.31. YELP shall maintain a log to record the combustor temperature before firing any Cat Slurry oil in 

the boilers. The log shall record the date, time, temperature of the combustor, and include the 

operators’ initials. The log shall be made available to the Department upon request 

(Billings/Laurel SO2 Emission Control Plan, approved into the SIP by EPA on May 2, 2002, and 

May 22, 2003). 

B.32. YELP shall be prepared and data kept in accordance with 40 CFR Part 64 and the CAM Plan for 

PM10, Appendix F of this permit (ARM 17.8.1212 and 40 CFR Part 64). 

B.33. YELP shall be prepared and data kept in accordance with 40 CFR Part 64 and the CAM Plan for 

SO2, Appendix G of this permit (ARM 17.8.1212 and 40 CFR Part 64). 

 

Reporting 

B.34. Any required source test report(s) shall be submitted in accordance with the Montana Source Test 

Protocol and Procedures Manual (ARM 17.8.106 and ARM 17.8.1212). 

B.35. YELP shall submit quarterly emission reports. Emission reporting for sulfur dioxide from the 

main stack and Exxon coker process gas shall consist of hourly and 24-hour calendar-day totals 

for each calendar month. The reports that are due 30 days after the end of each period shall also 

include the following (ARM 17.8.749 and 17.8.1212): 

a. Source or unit operating time during the reporting period and daily petroleum coke fuel, daily 

Cat Slurry Oil, and limestone consumption. 

b. Monitoring down time that occurred during the reporting period. 

c. A summary of excess emissions for each pollutant and averaging period identified in Section 

III.B for PM, SO2, CO, and NOx. 

d. Emission estimates for sulfur oxides and reduced sulfides from material balance, engineering 

calculation data, and any emission testing. Report of sulfur and BTU content from petroleum 

coke fuel analysis on a daily basis. Report of sulfur and BTU content from the Cat Slurry Oil 

analysis on a daily basis. 

e. Reasons for any excess emissions specifically allowed in Section III.B with mitigative 

measures utilized and corrective actions taken to prevent a recurrence of the upset situation. 

B.36. YELP shall submit quarterly emission reports that meet all of the requirements of 40 CFR 60.49a 

(Appendix I and ARM 17.8.1212). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

15

B.37. In accordance with Section 7 of the Stipulation (Appendix F), YELP shall submit quarterly 

reports on a calendar-year basis. The quarterly reports shall be submitted within 30 days of the 

end of each calendar quarter. The quarterly reports shall be submitted to the Department's 

Permitting and Compliance Division office in Helena and the Billings Regional Office. The 

quarterly report format shall consist of both a comprehensive electronic-magnetic report and a 

written or hard copy data summary report ((Billings/Laurel SO2 Emission Control Plan, approved 

into the SIP by EPA on May 2, 2002, and May 22, 2003 and ARM 17.8.1212). 

B.38. The annual compliance report required by Section V.B must contain a certification statement for 

the above applicable requirements (ARM 17.8.1212). 

B.39. The semiannual compliance monitoring report shall include the following (ARM 17.8.1212): 

a. Provide a summary of the results of any required reference method tests performed during the 

reporting period. The actual test report should be submitted as specified by the Montana 

Source Test Protocol and Procedures Manual, 

b. Certification that all CEMS were operated and maintained in accordance with Section III. 

B.17.c and the June 12, 1998, stipulation (Appendix E), 

c. Certification that quarterly reports were submitted as specified by Section III.B.29- 31, 

d. Certification that the log to record the combustor temperature was as specified by Section 

III.B.27, 

e. Certification of compliance with 40 CFR Part 64 (CAM), Appendix F; and 

f. Certification of compliance with 40 CFR Part 64 (CAM), Appendix G. 

C. EU02 – Limestone Unloading, Handling, and Crushing and EU03 Limestone Storage 

Limestone Unloading, Handling, Crushing, and Storage 

Condition(s) Pollutant/Parameter Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

Use of enclosed 

structure and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

C.1, C.2, C.5, Semiannual 

C.6, C.8, C.9, 

C.10, C.11 

Opacity 7% 

Method 9 As required by 

the Department 

and Section 

III.A.1 

As required by 

the Protocol 

Use of enclosed 

structure and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

C.2, C.3, C.5, Semiannual 

C.7, C.8, C.9, 

C.10, C.11 

Particulate Emissions 0.01 gr/dscf 

Method 5 Every 4-years As required by 

the Protocol 

Use of enclosed 

structure and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

C.2, C.4, C.5, Semiannual 

C.6, C.7, C.8, 

C.9, C.11 

Particulate Emissions .05 g/dscm (0.02 

gr/dscf) 

Method 5 Every 4-years As required by 

the Protocol 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

16

Conditions 

C.1. YELP shall not cause or authorize emissions to be discharged into the atmosphere from any 

transfer point on belt conveyors or from any other affected facility any stack emissions that 

exhibit greater than 7% opacity averaged over 6 consecutive minutes (ARM 17.8.340 and 40 CFR 

60.672(a)(2)). 

C.2. All storage silos, surge bins, hoppers, limestone crushing and conveyor systems shall utilize 

baghouses (bag filters) for particulate emission control (ARM 17.8.752). 

C.3. The limestone load-in hopper (used to load-in limestone and coke) shall be enclosed and 

particulate emissions shall be controlled by a baghouse. Particulate emissions from the baghouse 

shall not exceed 0.01 gr/dscf (ARM 17.8.749). 

C.4. YELP shall not cause or authorize emissions to be discharged into the atmosphere from any 

transfer point on belt conveyors or from any other affected facility any stack emissions that 

contain particulate matter in excess of .05 g/dscm (0.02 gr/dscf) (40 CFR 60.672(a)(1)). 

Compliance Demonstration

C.5. YELP shall use and maintain a baghouse for monitoring pertaining to the 7% opacity limit in 

Section III.C.1.and the particulate limit in Section III.C.3 and Section III.C.4 (ARM 17.8.1213) 

C.6. A Method 9 test shall be performed as required by the Department and Section III.A.1. The test 

methods and procedures shall be conducted in accordance with the Montana Source Test Protocol 

and Procedures Manual (ARM 17.8.106 and ARM 17.8.1213). 

C.7. A Method 5 test or other Department approved test shall be performed every 4 years. The test 

methods and procedures shall be conducted in accordance with the Montana Source Test Protocol 

and Procedures Manual (ARM 17.8.106 and ARM 17.8.1213). 

Recordkeeping

C.8. YELP shall maintain a log of corrective actions and all repair and maintenance activity performed 

on the baghouse. The log shall include, but is not limited to, the identification information for the 

baghouse, the date of the maintenance and/or corrective action, the name(s) of repair personnel, 

description of the maintenance activity and the item(s) repaired or replaced. The log shall be 

available to the Department for inspection and must be submitted to the Department upon request 

(ARM 17.8.1212). 

Reporting

C.9. The Method 9 test and Method 5 test or other Department approved test reports shall be submitted 

in accordance with the Montana Source Test Protocol and Procedures Manual (ARM 17.8.106 

and ARM 17.8.1212). 

C.10. The annual compliance report required by Section V.B must contain a certification statement for 

the above applicable requirements (ARM 17.8.1212). 

C.11. The semiannual compliance monitoring reports shall include the following (ARM 17.8.1212): 

a. Certification that the baghouse was operated and maintained during the operation of 

equipment; 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

17

b. Certification that the log required in Section III.C.8 was maintained and provide a summary 

of maintenance performed and corrective actions taken during the period as required; and 

c. A summary of the results of any reference method test performed during the reporting period. 

The actual test report should be submitted as specified by the Montana Source Test Protocol 

and Procedures Manual.

D. EU04, EU05, EU06, and EU07 Outdoor Coke Loading, Handling and Storage 

EU04 Coke Storage and Handling at Exxon 

EU05 Coke Loading to Stockpile, 

EU06 Loading Coke from Stockpile to Hopper 

EU07 Coke Storage and Handling 

Coke Loading, Handling and Storage 

Condition(s) Pollutant/Parameter Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

Use of enclosed 

structure and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

Semiannual 

Method 9 As required by 

the Department 

and Section 

III.A.1 

Semiannual 

D.1, D.2, D.3, 

D.6, D.7, D.9, 

D.10, D.11, 

D.12,x D.13, 

D.14 

Opacity 20% 

Visual Surveys Daily or when 

coke piles 

disturbed 

Semiannual 

Use of enclosed 

structure and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

D.3, D.4, D.6, Semiannual 

D.8, D.11, 

D.12, D.14 

Particulate Emissions 0.01 gr/dscf 

Method 5 Every 4-years Semiannual 

Normal 

Operations 

D.3, D.5, D.6, Ongoing Semiannual 

D.9, D.10, 

D.11, D.13, 

D.14 

Particulate Matter 18.1 ton/yr 

Visual Surveys Daily or when 

coke piles 

disturbed 

Semiannual 

Conditions 

D.1. YELP shall not cause or authorize emissions to be discharged into the outdoor atmosphere from any 

source that exhibits an opacity of 20% or greater averaged over 6 consecutive minutes (ARM 

17.8.304). 

D.2. YELP shall not cause or authorize the production, handling, transportation, or storage of any material 

unless reasonable precautions to control emissions of particulate matter are taken. Such emissions of 

airborne particulate matter from any stationary source shall not exhibit an opacity of 20% or greater 

averaged over 6 consecutive minutes unless otherwise specified by rule or in this permit (ARM 

17.8.308). 

D.3. All storage silos, surge bins, hoppers, and pneumatic coke truck unloading shall utilize baghouses 

(bag filters) for particulate emission control (ARM 17.8.749). 

D.4. The limestone load-in hopper (used to load-in limestone and coke) shall be enclosed and 

particulate emissions shall be controlled by a baghouse. Particulate emissions from the baghouse 

shall not exceed 0.01 gr/dscf (ARM 17.8.752). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

18

D.5. Particulate matter emissions from the coke storage facility and loading areas are limited to 18.1 

ton/yr (ARM 17.8.752). 

Compliance Demonstration 

D.6. YELP shall use and maintain a baghouse for monitoring pertaining to the 20% opacity limit in 

Section III.D.1 and the particulate emission limit and emission control requirements in Section 

III.D.3-5 (ARM 17.8.1213). 

D.7. A Method 9 test shall be performed as required by the Department and Section III.A.1. The test 

methods and procedures shall be conducted in accordance with the Montana Source Test Protocol 

and Procedures Manual (ARM 17.8.106 and ARM 17.8.1213). 

D.8. A Method 5 test or other Department approved test shall be performed every 4 years on the 

baghouse. The test methods and procedures shall be conducted in accordance with the Montana 

Source Test Protocol and Procedures Manual (ARM 17.8.106 and ARM 17.8.1213). 

D.9. At least daily or when coke piles are disturbed, during daylight hours, YELP shall visually survey 

all outside Coke handling areas and stockpiles to ensure compliance with Section III.D.2 and 

Section III.D.5. The person(s) conducting this survey does not have to be EPA Method 9 

certified. However, the observer must be trained and know how the visibility of emissions are 

affected by background contrast, ambient lighting, observer position relative to lighting, and 

wind. If a source or sources of excessive fugitive emissions are identified, YELP shall use water 

and/or chemical dust suppressant to minimize the fugitive emissions unless weather conditions 

would make this activity result in hazardous conditions. The person(s) conducting the survey 

shall record the results of the survey in a log (ARM 17.8.1213). 

Recordkeeping

D.10. YELP shall maintain a daily log recording the results of the visual surveys. The log shall include, 

but is not limited to, the date, time, observer(s), observer(s)’ s location, the area being surveyed, 

and the results of the visual survey(s). If any preventative or corrective action is required, the 

time, date, and a description of the action taken must be included in the log. The log shall be 

available to the Department for inspection and must be submitted to the Department upon request 

(ARM 17.8.1212). 

D.11. YELP shall maintain a log of corrective actions and all repair and maintenance activity performed 

on the baghouse. The log shall include, but is not limited to, the identification information for the 

baghouse, the date of the maintenance and/or corrective action, the name(s) of repair personnel, 

description of the maintenance activity and the item(s) repaired or replaced. The log shall be 

available to the Department for inspection and must be submitted to the Department upon request 

(ARM 17.8.1212). 

Reporting

D.12. The Method 9 test and Method 5 test or other Department approved test reports shall be submitted 

in accordance with the Montana Source Test Protocol and Procedures Manual (ARM 17.8.106 

and ARM 17.8.1212). 

D.13. The annual compliance report required by Section V.B must contain a certification statement for 

the above applicable requirements (ARM 17.8.1212). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

19

D.14. The semiannual compliance monitoring reports shall include the following (ARM 17.8.1212): 

a. Certification that the baghouse was operated and maintained during the operation of 

equipment; 

b. Certification that the visual surveys were performed and recorded as specified by Section 

III.D.9; 

c. Certification that the log required in Section III.D.10 was maintained and provide a summary 

of maintenance performed and corrective actions taken during the period; 

d. Identification of any instances of excessive fugitive emissions and provide a summary of any 

corrective action taken; and 

e. A summary of the results of any reference method test performed during the reporting period. 

The actual test report should be submitted as specified by the Montana Source Test Protocol 

and Procedures Manual. 

E. EU08 Coke Unloading/Crushing/Processing Facility and EU09 Coke Barn 

Coke Unloading/Crushing Processing Facility and Coke Barn

Condition(s) Pollutant/Parameter Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

Use of enclosed 

structure and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

E.1, E.2, Semiannual 

E.4, E.5, 

E.7, E.8, E.9, 

E.13, E.14 

Opacity 20% 

Method 9 As required by 

the Department 

and Section 

III.A.1 

Semiannual 

Use of enclosed 

structure and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

E.3, E.4, E.5, Semiannual 

E.7, E.9, E.11, 

E.13, E.14 

Particulate Emissions 0.01 gr/dscf 

Method 5 Every 4-years Semiannual 

E.6, E.10, 

E.12, E.14 

Emission Control 

Requirement 

Coke storage and 

processing not to 

exceed 

240,900 tons 

during any rolling 

12-month period. 

Record-keeping As necessary Semiannual 

Conditions 

E.1. YELP shall not cause or authorize emissions to be discharged into the outdoor atmosphere from 

any source that exhibit an opacity of 20% or greater averaged over 6 consecutive minutes (ARM 

17.8.304). 

E.2. YELP shall not cause or authorize the production, handling, transportation, or storage of any 

material unless reasonable precautions to control emissions of particulate matter are taken. Such 

emissions of airborne particulate matter from any stationary source shall not exhibit an opacity of 

20% or greater averaged over 6 consecutive minutes unless otherwise specified by rule or in this 

permit (ARM 17.8.308). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

20

E.3. Baghouse filter emission from the Coke Unloading/Crushing/Processing Facility shall not exceed 

0.01 gr/dscf (ARM 17.8.752). 

E.4. The coke unloading/crushing/processing plant shall be completely enclosed and utilize a 

baghouse to control emissions from the crusher, screen, and associated conveyors (ARM 

17.8.752). 

E.5. The Coke Barn shall be enclosed. In addition, the conveyor system linking the coke 

unloading/crushing/processing plant to the coke barn shall be enclosed (ARM 17.8.752).

E.6. The total amount of petroleum coke processed and stored shall not exceed 240,900 tons during 

any rolling 12 month period (ARM 17.8.752). 

Compliance Demonstration

E.7. YELP shall use and maintain a baghouse for monitoring pertaining to the 20% opacity limit in 

Section III.E.1 and the particulate emission limit requirement in Section III.E.3 (ARM 

17.8.1213). 

E.8. A Method 9 test shall be performed as required by the Department and Section III.A.1. The test 

methods and procedures shall be conducted in accordance with the Montana Source Test Protocol 

and Procedures Manual (ARM 17.8.106 and ARM 17.8.1213). 

E.9. A Method 5 test or other Department approved test shall be performed on the coke 

unloading/crushing/processing facility baghouse every 4 years. The test methods and procedures 

shall be conducted in accordance with the Montana Source Test Protocol and Procedures Manual 

(ARM 17.8.106 and ARM 17.8.1213). 

E.10. YELP shall perform recordkeeping to monitor compliance with Section III.E.6 (ARM 17.8.1213). 

Recordkeeping

E.11. YELP shall maintain a log of corrective actions and all repair and maintenance activity performed 

on the Coke Unloading/Crushing/Processing Facility Baghouse. The log shall include, but is not 

limited to, the identification information for the baghouse, the date of the maintenance and/or 

corrective action, the name(s) repair personnel, description of the maintenance activity and the 

item(s) repaired or replaced. The log shall be available to the Department for inspection and must 

be submitted to the Department upon request (ARM 17.8.1212). 

E.12. Once the Coke Unloading/Crushing/Processing Facility becomes operational, YELP shall 

document, by month, the amount of petroleum coke received. By the 25th day of each month, 

YELP shall total the amount of coke received for the previous month. The monthly information 

will be used to verify compliance with the rolling 12-month limitation in Section III.E.6. The 

information for each of the previous months shall be submitted along with the annual emission 

inventory 

Reporting

E.13. The Method 9 test and Method 5 test or other Department approved test reports shall be submitted 

in accordance with the Montana Source Test Protocol and Procedures Manual (ARM 17.8.106 

and ARM 17.8.1212). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

21

E.14. The annual compliance report required by Section V.B must contain a certification statement for 

the above applicable requirements (ARM 17.8.1212). 

E.15. The semiannual compliance monitoring reports shall include the following (ARM 17.8.1212): 

a. Certification that the baghouse was operated and maintained during the operation of 

equipment; 

b. Certification that the log required in Section III.E.11 was maintained and provide a summary 

of maintenance performed and corrective actions taken during the period; 

c. Certification that coke processed and stored was is in accordance with Section III.E.12 and 

provide the amount of coke processed and stored during the period and the amounts stored 

and processed from the previous 12 months; 

d. A summary of the results of any reference method test performed during the reporting period. 

The actual test report should be submitted as specified by the Montana Source Test Protocol 

and Procedures Manual. 

F. EU10 and EU11 Ash Unloading, Handling and Storage 

EU10 Ash Handling and Storage 

EU11 Ash Unload to Trucks 

Ash Unloading, Handling and Storage 

Condition(s) Pollutant/Parameter Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

Use and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

F.1, F.2, F.4, Semiannual 

F.5, F.7, F.8, 

F.9, F.10 

Opacity 20% 

Method 9 As required by 

the Department 

and Section 

III.A.1 

Semiannual 

Use and 

maintenance of a 

baghouse 

Whenever 

process 

equipment is 

operating 

F.3, F.4, F.6, Semiannual 

F.7, F.8, F.9, 

F.10 

Particulate Emissions 0.01 gr/dscf 

Method 5 Every 4-years Semiannual 

Conditions 

F.1. YELP shall not cause or authorize emissions to be discharged into the outdoor atmosphere from 

any source that exhibits an opacity of 20% or greater averaged over 6 consecutive minutes (ARM 

17.8.304). 

F.2. YELP shall not cause or authorize the production, handling, transportation, or storage of any 

material unless reasonable precautions to control emissions of particulate matter are taken. Such 

emissions of airborne particulate matter from any stationary source shall not exhibit an opacity of 

20% or greater averaged over 6 consecutive minutes unless otherwise specified by rule or in this 

permit (ARM 17.8.308). 

F.3. Baghouse filter emission from Ash Storage and Unloading shall not exceed 0.01 gr/dscf (ARM 

17.8.752). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

22

Compliance Demonstration 

F.4. YELP shall use and maintain a baghouse for monitoring pertaining to the 20% opacity limit in 

Section III.F.1 and the particulate emission limit requirement in Section III.F.3 (ARM 17.8.1213). 

F.5. A Method 9 test shall be performed as required by the Department and Section III.A.1. The test 

methods and procedures shall be conducted in accordance with the Montana Source Test Protocol 

and Procedures Manual (ARM 17.8.106 and ARM 17.8.1213). 

F.6. A Method 5 test or other Department approved test shall be performed every 4 years. The test 

methods and procedures shall be conducted in accordance with the Montana Source Test Protocol 

and Procedures Manual (ARM 17.8.106 and ARM 17.8.1213). 

Recordkeeping

F.7. YELP shall maintain a log of corrective actions and all repair and maintenance activity performed 

on the baghouse. The log shall include, but is not limited to, the identification information for the 

baghouse, the date of the maintenance and/or corrective action, the name(s) of repair personnel, 

description of the maintenance activity and the item(s) repaired or replaced. The log shall be 

available to the Department for inspection and must be submitted to the Department upon request 

(ARM 17.8.1212). 

Reporting

F.8. The Method 9 test and Method 5 test or other Department approved test reports shall be submitted 

in accordance with the Montana Source Test Protocol and Procedures Manual (ARM 17.8.106 

and ARM 17.8.1212). 

F.9. The annual compliance report required by Section V.B must contain a certification statement for 

the above applicable requirements (ARM 17.8.1212). 

F.10. The semiannual compliance monitoring reports shall include the following (ARM 17.8.1212): 

a. Certification that the baghouse was maintained and in place during operation of equipment; 

b. Certification that the log required in Section III.F.7 was maintained and provide a summary 

of maintenance performed and corrective actions taken during the period; and 

c. A summary of the results of any reference method test performed during the reporting period. 

The actual test report should be submitted as specified by the Montana Source Test Protocol 

and Procedures Manual. 

G. EU12 Fugitive Emissions: Paved Roads 

Fugitive Emissions: Vehicle Traffic

Condition(s) Pollutant/Parameter Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

G.1,G.2, G.3, 

G.5, G.6, G.7 

Opacity 20% Method 9 As required by 

the Department 

and Section 

III.A.1 

Semiannual 

G.1, G.2, G.3, 

G.4, G.5, G.6, 

G.7 

Opacity --------- Reasonable 

Precautions 

As necessary Semiannual 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

23

Conditions 

G.1. YELP shall not cause or authorize the production, handling, transportation, or storage of any 

material unless reasonable precautions to control emissions of particulate matter are taken. Such 

emissions of airborne particulate from any stationary source shall not exhibit an opacity of 20% 

or greater averaged over 6-consecutive minutes (ARM 17.8.308(1)). 

G.2. YELP shall not cause or authorize the use of any access roads, parking lots, or the general plant 

area without taking reasonable precautions to control emissions of airborne particulate matter 

(ARM 17.8.308(2)). 

Compliance Demonstration

G.3. As required by the Department and Section III.A.1, YELP shall perform a Method 9 test in 

accordance with Montana Source Protocol and Procedures Manual (ARM 17.8.106). Each 

observation period shall be a minimum of 6 minutes unless any one reading is 20% or greater, 

then the observation period shall be a minimum of 20 minutes or until a violation of the standard 

has been documented, whichever is a shorter period of time (ARM 17.8.1213). 

G.4. YELP shall treat all unpaved portions of the access roads, parking lots, and general plant area 

with fresh water and/or chemical dust suppressant as necessary to maintain compliance with the 

reasonable precaution requirement (ARM 17.8.1213). 

Recordkeeping

G.5. Method 9 test reports must be maintained onsite and must be submitted to the Department upon 

request (ARM 17.8.1212). 

Reporting 

G.6. The annual compliance report required by Section V.B must contain a certification statement for 

the above applicable requirements (ARM 17.8.1212). 

G.7. The semiannual compliance monitoring reports shall include the following (ARM 17.8.1212): 

a. Provide the results of the Method 9 tests as required by the Department, the actual test 

report must be submitted to the Department only upon request specified by Section 

III.G.5; and 

b. Certify annually whether the fugitive emissions from Vehicle Traffic are in compliance 

with ARM 17.8.304 and 17.8.308. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

24

H. EU13 Cat Slurry Oil Tank 

Cat Slurry Oil Tank 

Condition(s) Pollutant/Parameter Permit Limit Compliance Demonstration 

Method Frequency 

Reporting 

Requirements 

H.1, H.4, H.7, 

H.8, H.9 

Opacity 20% Method 9 As required by 

the Department 

and Section 

III.A.1 

Semiannual 

H.2, H.4, H.8, 

H.9 

Emission Control 

Requirement 

30,000 gallons 

heated tank 

Normal 

Operations 

As necessary Semiannual 

H.3, H.5, H.6, 

H.8, H.9 

40 CFR 60, subpart Kb All Applicable 

Provisions of 

Subpart Kb 

Record-keeping As necessary Semiannual 

Conditions 

H.1. YELP shall not cause or authorize emissions to be discharged into the outdoor atmosphere from 

any source that exhibit an opacity of 20% or greater averaged over 6 consecutive minutes (ARM 

17.8.304). 

H.2. YELP shall install and operate a storage tank for Cat Slurry Oil of no greater than 30,000 gallons. 

The tank shall be heated using steam from the YELP (ARM 17.8.749). 

H.3. YELP shall be subject to, at a minimum, all applicable NSPS provisions, as appropriate, of 40 

CFR 60, Subpart Kb 60.110b through 60.117b (Standards of Performance for Volatile Organic 

Liquid Storage Vessels, including: Petroleum Liquid Storage Vessels) for which construction, 

reconstruction, or modification commenced after July 23, 1984 (ARM 17.8.340). 

Compliance Demonstration

H.4. As required by the Department and Section III.A.1, YELP shall perform a Method 9 test in 

accordance with Montana Source Protocol and Procedures Manual (ARM 17.8.106). Each 

observation period shall be a minimum of 6 minutes unless any one reading is 20% or greater, 

then the observation period shall be a minimum of 20 minutes or until a violation of the standard 

has been documented, whichever is a shorter period of time (ARM 17.8.1213). 

H.5. YELP shall monitor operations of the CAT slurry oil tank in accordance 40 CFR 60, Subpart Kb 

60.116b (ARM 17.8.1213). 

Recordkeeping 

H.6. YELP shall keep all records in accordance with 60.116b (ARM 17.8.340 and 40 CFR 60, Subpart 

Kb). 

H.7. All compliance source test recordkeeping shall be performed in accordance with the test method 

used and the Montana Source Test Protocol and Procedures Manual, and shall be maintained on 

site (ARM 17.8.106 and ARM 17.8.1212). 

Reporting

H.8. The annual compliance report required by Section V.B must contain a certification statement for 

the above applicable requirements (ARM 17.8.1212). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

25

H.9. The semiannual compliance monitoring reports shall include the following (ARM 17.8.1212): 

a. Any source test performed during the semiannual period; and 

b. Certification that 40 CFR 60, Subpart Kb monitoring was followed and complied with as 

applicable. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

26

SECTION IV. NON-APPLICABLE REQUIREMENTS 

Air Quality Administrative Rules of Montana (ARM) and Federal Regulations identified as not applicable 

to the facility or to a specific emissions unit at the time of the permit issuance are listed below (ARM 

17.8.1214). The following list does not preclude the need to comply with any new requirements that may 

become applicable during the permit term. 

A. Facility-Wide 

The following table contains non-applicable requirements which are administrated by the Air Resources 

Management Bureau of the Department of Environmental Quality. 

Rule Citation Reason 

40 CFR 60, Subparts C, Ca, Cb, Cc, Cd, Db, 

Dc, E, F, G, H, I, J, K, 

Ka, L-X, Z, AA-EE, 

GG-HH, KK-NN, PPXX, AAA-BBB, DDD, 

FFF-LLL, NNN, PPPQQQ, RRR-WWW 

40 CFR 61 (Except subpart A, subpart M and 

appendices); 

40 CFR 63 (Except subpart A and appendices); 

40 CFR 68; 

40 CFR 82 (Except subparts B&F).

These requirements are not applicable because this 

facility is not an “affected facility” under these 

regulations.

40 CFR 72 through 78 These requirements are not applicable because the 

facility is not an affected source as defined by the 

acid rain regulations. 

ARM 17.8.316 

ARM 178.320 

ARM 17.8.321, 

ARM 17.8.323, 

ARM 17.8 331, 

ARM 17.8.332, 

ARM 17.8.333, 

ARM 17.8.334, and 

ARM 17.8.610.

These rules are not applicable because the facility is 

not listed in the source category cited in the rules.

B. Emission Units 

The permit application identified applicable requirements as well as non-applicable requirements. The 

Department has listed all non-applicable requirements in Section IV.A. These requirements relate to each 

specific unit as well as facility wide. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

27

SECTION V. GENERAL PERMIT CONDITIONS 

A. Compliance Requirements 

ARM 17.8, Subchapter 12, Operating Permit Program §1210(2)(a)-(c)&(e), §1206(6)(c)&(b)

1. The permittee must comply with all conditions of the permit. Any noncompliance with the 

terms or conditions of the permit constitutes a violation of the Montana Clean Air Act, and may 

result in enforcement action, permit modification, revocation and reissuance, or termination, or 

denial of a permit renewal application under ARM Title 17, Chapter 8, Subchapter 12. 

2. The filing of a request by the permittee for a permit modification, revocation and reissuance, or 

termination, or of a notification of planned changes or anticipated noncompliance does not stay 

any permit condition. 

3. It shall not be a defense for a permittee in an enforcement action that it would have been 

necessary to halt or reduce the permitted activity in order to maintain compliance with the 

conditions of the permit. If appropriate, this factor may be considered as a mitigating factor in 

assessing a penalty for noncompliance with an applicable requirement if the source 

demonstrates that both the health, safety or environmental impacts of halting or reducing 

operations would be more serious than the impacts of continuing operations, and that such 

health, safety or environmental impacts were unforeseeable and could not have otherwise been 

avoided. 

4. The permittee shall furnish to the Department, within a reasonable time set by the Department 

(not to be less than 15 days), any information that the Department may request in writing to 

determine whether cause exists for modifying, revoking and reissuing, or terminating the 

permit, or to determine compliance with the permit. Upon request, the permittee shall also 

furnish to the Department copies of those records that are required to be kept pursuant to the 

terms of the permit. This subsection does not impair or otherwise limit the right of the 

permittee to assert the confidentiality of the information requested by the Department, as 

provided in 75-2-105, MCA. 

5. Any schedule of compliance for applicable requirements with which the source is not in 

compliance with at the time of permit issuance shall be supplemental to, and shall not sanction 

noncompliance with, the applicable requirements on which it was based. 

6. For applicable requirements that will become effective during the permit term, the source shall 

meet such requirements on a timely basis unless a more detailed plan or schedule is required by 

the applicable requirement or the Department. 

B. Certification Requirements 

ARM 17.8, Subchapter 12, Operating Permit Program §1207 and §1213(7)(a)&(c)-(d)

1. Any application form, report, or compliance certification submitted pursuant to ARM Title 17, 

Chapter 8, Subchapter 12, shall contain certification by a responsible official of truth, accuracy 

and completeness. This certification and any other certification required under ARM Title 17, 

Chapter 8, Subchapter 12, shall state that, based on information and belief formed after 

reasonable inquiry, the statements and information in the document are true, accurate and 

complete. 

2. Compliance certifications shall be submitted by February 15 of each year, or more frequently if 

otherwise specified in an applicable requirement or elsewhere in the permit. Each certification 

must include the required information for the previous calendar year (i.e., January 1 – 

December 31). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

28

3. Compliance certifications shall include the following: 

a. The identification of each term or condition of the permit that is the basis of the 

certification; 

b. The identification of the method(s) or other means used by the owner or operator for 

determining the status of compliance with each term and condition during the certification 

period, consistent with ARM 17.8.1212; 

c. The status of compliance with each term and condition for the period covered by the 

certification, including whether compliance during the period was continuous or 

intermittent (based on the method or means identified in ARM 17.8.1213(7)(c)(ii), as 

described above); and 

d. Such other facts as the Department may require to determine the compliance status of the 

source. 

4. All compliance certifications must be submitted to the Environmental Protection Agency, as 

well as to the Department, at the addresses listed in the Notification Addresses Appendix of this 

permit. 

C. Permit Shield 

ARM 17.8, Subchapter 12, Operating Permit Program §1214(1)-(4)

1. The applicable requirements and non-federally enforceable requirements are included and 

specifically identified in this permit and the permit includes a precise summary of the 

requirements not applicable to the source. Compliance with the conditions of the permit shall 

be deemed compliance with any applicable requirements and any non-federally enforceable 

requirements as of the date of permit issuance. 

2. The permit shield described in 1 above shall remain in effect during the appeal of any permit 

action (renewal, revision, reopening, or revocation and reissuance) to the Board of 

Environmental Review (Board), until such time as the Board renders its final decision. 

3. Nothing in this permit alters or affects the following: 

a. The provisions of Sec. 7603 of the FCAA, including the authority of the administrator 

under that section; 

b. The liability of an owner or operator of a source for any violation of applicable 

requirements prior to or at the time of permit issuance; 

c. The applicable requirements of the Acid Rain Program, consistent with Sec. 7651g(a) of 

the FCAA; 

d. The ability of the administrator to obtain information from a source pursuant to Sec. 7414 

of the FCAA; 

e. The ability of the Department to obtain information from a source pursuant to the Montana 

Clean Air Act, Title 75, Chapter 2, MCA; 

f. The emergency powers of the Department under the Montana Clean Air Act, Title 75, 

Chapter 2, MCA; and 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

29

g. The ability of the Department to establish or revise requirements for the use of Reasonably 

Available Control Technology (RACT) as defined in ARM Title 17, Chapter 8. However, 

if the inclusion of a RACT into the permit pursuant to ARM Title 17, Chapter 8, 

Subchapter 12, is appealed to the Board, the permit shield, as it applies to the source’s 

existing permit, shall remain in effect until such time as the Board has rendered its final 

decision. 

4. Nothing in this permit alters or affects the ability of the Department to take enforcement action 

for a violation of an applicable requirement or permit term demonstrated pursuant to ARM 

17.8.106, Source Testing Protocol. 

5. Pursuant to ARM 17.8.132, for the purpose of submitting a compliance certification, nothing in 

these rules shall preclude the use, including the exclusive use, of any credible evidence or 

information relevant to whether a source would have been in compliance. However, when 

compliance or noncompliance is demonstrated by a test or procedure provided by permit or 

other applicable requirements, the source shall then be presumed to be in compliance or 

noncompliance unless that presumption is overcome by other relevant credible evidence. 

6. The permit shield will not extend to minor permit modifications or changes not requiring a 

permit revision (see Sections I & J). 

7. The permit shield will extend to significant permit modifications and transfer or assignment of 

ownership (see Sections K & N). 

D. Monitoring, Recordkeeping, and Reporting Requirements 

ARM 17.8, Subchapter 12, Operating Permit Program §1212(2)&(3)

1. Unless otherwise provided in this permit, the permittee shall maintain compliance monitoring 

records that include the following information: 

a. The date, place as defined in the permit, and time of sampling or measurement; 

b. The date(s) analyses were performed; 

c. The company or entity that performed the analyses; 

d. The analytical techniques or methods used; 

e. The results of such analyses; and 

f. The operating conditions at the time of sampling or measurement. 

2. The permittee shall retain records of all required monitoring data and support information for a 

period of at least 5 years from the date of the monitoring sample, measurement, report, or 

application. Support information includes all calibration and maintenance records and all 

original strip-chart recordings for continuous monitoring instrumentation, and copies of all 

reports required by the permit. All monitoring data, support information, and required reports 

and summaries may be maintained in computerized form at the plant site if the information is 

made available to Department personnel upon request, which may be for either hard copies or 

computerized format. Strip-charts must be maintained in their original form at the plant site 

and shall be made available to Department personnel upon request. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

30

3. The permittee shall submit to the Department, at the addresses located in the Notification 

Addresses Appendix of this permit, reports of any required monitoring by February 15 and 

August 15 of each year, or more frequently if otherwise specified in an applicable requirement 

or elsewhere in the permit. The monitoring report submitted on February 15 of each year must 

include the required monitoring information for the period of July 1 through December 31 of 

the previous year. The monitoring report submitted on August 15 of each year must include the 

required monitoring information for the period of January 1 through June 30 of the current year. 

All instances of deviations from the permit requirements must be clearly identified in such 

reports. All required reports must be certified by a responsible official, consistent with ARM 

17.8.1207. 

E. Prompt Deviation Reporting 

ARM 17.8, Subchapter 12, Operating Permit Program §1212(3)(c)

The permittee shall promptly report deviations from permit requirements, including those attributable 

to upset conditions as defined in the permit, the probable cause of such deviations, and any corrective 

actions or preventive measures taken. To be considered prompt, deviations shall be reported as part 

of the routine reporting requirements under ARM 17.8.1212(3)(b) and, if applicable, in accordance 

with the malfunction reporting requirements under ARM 17.8.110, unless otherwise specified in an 

applicable requirement. 

F. Emergency Provisions 

ARM 17.8, Subchapter 12, Operating Permit Program §1201(13) and §1214(5), (6)&(8)

1. An “emergency” means any situation arising from sudden and reasonably unforeseeable events 

beyond the control of the source, including acts of God, which situation requires immediate 

corrective action to restore normal operation and causes the source to exceed a technologybased emission limitation under this permit due to the unavoidable increases in emissions 

attributable to the emergency. An emergency shall not include noncompliance to the extent 

caused by improperly designed equipment, lack of reasonable preventive maintenance, careless 

or improper operation, or operator error. 

2. An emergency constitutes an affirmative defense to an action brought for noncompliance with a 

technology-based emission limitation if the permittee demonstrates through properly signed, 

contemporaneous logs, or other relevant evidence, that: 

a. An emergency occurred and the permittee can identify the cause(s) of the emergency; 

b. The permitted facility was at the time being properly operated; 

c. During the period of the emergency the permittee took all reasonable steps to minimize 

levels of emissions that exceeded the emission standards or other requirements in the 

permit; and 

d. The permittee submitted notice of the emergency to the Department within 2 working days 

of the time when emission limitations were exceeded due to the emergency. This notice 

fulfills the requirements of ARM 17.8.1212(3)(c). This notice must contain a description 

of the emergency, any steps taken to mitigate emissions, and corrective actions taken. 

3. These emergency provisions are in addition to any emergency, malfunction or upset provision 

contained in any applicable requirement. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

31

G. Inspection and Entry 

ARM 17.8, Subchapter 12, Operating Permit Program §1213(3)&(4)

1. Upon presentation of credentials and other requirements as may be required by law, the 

permittee shall allow the Department, the administrator, or an authorized representative 

(including an authorized contractor acting as a representative of the Department or the 

administrator) to perform the following: 

a. Enter the premises where a source required to obtain a permit is located or emissionsrelated activity is conducted, or where records must be kept under the conditions of the 

permit; 

b. Have access to and copy, at reasonable times, any records that must be kept under the 

conditions of the permit; 

c. Inspect at reasonable times any facilities, emission units, equipment (including monitoring 

and air pollution control equipment), practices, or operations regulated or required under 

the permit; and 

d. As authorized by the Montana Clean Air Act and rules promulgated thereunder, sample or 

monitor, at reasonable times, any substances or parameters at any location for the purpose 

of assuring compliance with the permit or applicable requirements. 

2. The permittee shall inform the inspector of all workplace safety rules or requirements at the 

time of inspection. This section shall not limit in any manner the Department’s statutory right 

of entry and inspection as provided for in 75-2-403, MCA. 

H. Fee Payment 

ARM 17.8, Subchapter 12, Operating Permit Program §1210(2)(f) and ARM 17.8, Subchapter 5, Air 

Quality Permit Application, Operation, and Open Burning Fees §505(3)-(5) (STATE ONLY)

1. The permittee must pay application and operating fees, pursuant to ARM Title 17, Chapter 8, 

Subchapter 5. 

2. Annually, the Department shall provide the permittee with written notice of the amount of the 

fee and the basis for the fee assessment. The air quality operation fee is due 30 days after 

receipt of the notice, unless the fee assessment is appealed pursuant to ARM 17.8.511. If any 

portion of the fee is not appealed, that portion of the fee that is not appealed is due 30 days after 

receipt of the notice. Any remaining fee, which may be due after the completion of an appeal, 

is due immediately upon issuance of the Board’s decision or upon completion of any judicial 

review of the Board’s decision. 

3. If the permittee fails to pay the required fee (or any required portion of an appealed fee) within 

90 days of the due date of the fee, the Department may impose an additional assessment of 15% 

of the fee (or any required portion of an appealed fee) or $100, whichever is greater, plus 

interest on the fee (or any required portion of an appealed fee), computed at the interest rate 

established under 15-31-510(3), MCA. 

I. Minor Permit Modifications 

ARM 17.8, Subchapter 12, Operating Permit Program §1226(3)&(11)

1. An application for a minor permit modification need only address in detail those portions of the 

permit application that require revision, updating, supplementation, or deletion, and may 

reference any required information that has been previously submitted. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

32

2. The permit shield under ARM 17.8.1214 will not extend to any minor modifications processed 

pursuant to ARM 17.8.1226. 

J. Changes Not Requiring Permit Revision 

ARM 17.8, Subchapter 12, Operating Permit Program §1224(1)-(3), (5)&(6)

1. The permittee is authorized to make changes within the facility as described below, provided 

the following conditions are met: 

a. The proposed changes do not require the permittee to obtain an air quality preconstruction 

permit under ARM Title 17, Chapter 8, Subchapter 7; 

b. The proposed changes are not modifications under Title I of the FCAA, or as defined in 

ARM Title 17, Chapter 8, Subchapters 8, 9, or 10; 

c. The emissions resulting from the proposed changes do not exceed the emissions allowable 

under this permit, whether expressed as a rate of emissions or in total emissions; 

d. The proposed changes do not alter permit terms that are necessary to enforce applicable 

emission limitations on emission units covered by the permit; and 

e. The facility provides the administrator and the Department with written notification at least 

7 days prior to making the proposed changes. 

2. The permittee and the Department shall attach each notice provided pursuant to 1.e above to 

their respective copies of this permit. 

3. Pursuant to the conditions above, the permittee is authorized to make Section 502(b)(10) 

changes, as defined in ARM 17.8.1201(30), without a permit revision. For each such change, 

the written notification required under 1.e above shall include a description of the change 

within the source, the date on which the change will occur, any change in emissions, and any 

permit term or condition that is no longer applicable as a result of the change. 

4. The permittee may make a change not specifically addressed or prohibited by the permit terms 

and conditions without requiring a permit revision, provided the following conditions are met: 

a. Each proposed change does not weaken the enforceability of any existing permit 

conditions; 

b. The Department has not objected to such change; 

c. Each proposed change meets all applicable requirements and does not violate any existing 

permit term or condition; and 

d. The permittee provides contemporaneous written notice to the Department and the 

administrator of each change that is above the level for insignificant emission units as 

defined in ARM 17.8.1201(22) and 17.8.1206(3), and the written notice describes each 

such change, including the date of the change, any change in emissions, pollutants emitted, 

and any applicable requirement that would apply as a result of the change. 

5. The permit shield authorized by ARM 17.8.1214 shall not apply to changes made pursuant to 

ARM 17.8.1224(3) and (5), but is applicable to terms and conditions that allow for increases 

and decreases in emissions pursuant to ARM 17.8.1224(4). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

33

K. Significant Permit Modifications 

ARM 17.8, Subchapter 12, Operating Permit Program §1227(1), (3)&(4)

1. The modification procedures set forth in 2 below must be used for any application requesting a 

significant modification of this permit. Significant modifications include the following: 

a. Any permit modification that does not qualify as either a minor modification or as an 

administrative permit amendment; 

b. Every significant change in existing permit monitoring terms or conditions; 

c. Every relaxation of permit reporting or recordkeeping terms or conditions that limit the 

Department’s ability to determine compliance with any applicable rule, consistent with the 

requirements of the rule; or 

d. Any other change determined by the Department to be significant. 

2. Significant modifications shall meet all requirements of ARM Title 17, Chapter 8, including 

those for applications, public participation, and review by affected states and the administrator, 

as they apply to permit issuance and renewal, except that an application for a significant permit 

modification need only address in detail those portions of the permit application that require 

revision, updating, supplementation or deletion. 

3. The permit shield provided for in ARM 17.8.1214 shall extend to significant modifications. 

L. Reopening for Cause 

ARM 17.8, Subchapter 12, Operating Permit Program §1228(1)&(2)

This permit may be reopened and revised under the following circumstances: 

1. Additional applicable requirements under the FCAA become applicable to the facility when the 

permit has a remaining term of 3 or more years. Reopening and revision of the permit shall be 

completed not later than 18 months after promulgation of the applicable requirement. No 

reopening is required under ARM 17.8.1228(1)(a) if the effective date of the applicable 

requirement is later than the date on which the permit is due to expire, unless the original 

permit or any of its terms or conditions have been extended pursuant to ARM 17.8.1220(12) or 

17.8.1221(2); 

2. Additional requirements (including excess emission requirements) become applicable to an 

affected source under the Acid Rain Program. Upon approval by the administrator, excess 

emission offset plans shall be deemed incorporated into the permit; 

3. The Department or the administrator determines that the permit contains a material mistake or 

that inaccurate statements were made in establishing the emission standards or other terms or 

conditions of the permit; or 

4. The administrator or the Department determines that the permit must be revised or revoked and 

reissued to ensure compliance with the applicable requirements. 

M. Permit Expiration and Renewal 

ARM 17.8, Subchapter 12, Operating Permit Program §1210(2)(g), §1220(11)&(12), and §1205(2)(d)

1. This permit is issued for a fixed term of 5 years. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

34

2. Renewal of this permit is subject to the same procedural requirements that apply to permit 

issuance, including those for application, content, public participation, and affected state and 

administrator review. 

3. Expiration of this permit terminates the permittee’s right to operate unless a timely and 

administratively complete renewal application has been submitted consistent with ARM 

17.8.1221 and 17.8.1205(2)(d). If a timely and administratively complete application has been 

submitted, all terms and conditions of the permit, including the application shield, remain in 

effect after the permit expires until the permit renewal has been issued or denied. 

4. For renewal, the permittee shall submit a complete air quality operating permit application to 

the Department not later than 6 months prior to the expiration of this permit, unless otherwise 

specified. If necessary to ensure that the terms of the existing permit will not lapse before 

renewal, the Department may specify, in writing to the permittee, a longer time period for 

submission of the renewal application. Such written notification must be provided at least 1 

year before the renewal application due date established in the existing permit. 

N. Severability Clause 

ARM 17.8, Subchapter 12, Operating Permit Program §1210(2)(i)&(l)

1. The administrative appeal or subsequent judicial review of the issuance by the Department of 

an initial permit under this subchapter shall not impair in any manner the underlying 

applicability of all applicable requirements, and such requirements continue to apply as if a 

final permit decision had not been reached by the Department. 

2. If any provision of a permit is found to be invalid, all valid parts that are severable from the 

invalid part remain in effect. If a provision of a permit is invalid in one or more of its 

applications, the provision remains in effect in all valid applications that are severable from the 

invalid applications. 

O. Transfer or Assignment of Ownership 

ARM 17.8, Subchapter 12, Operating Permit Program §1225(2)&(4)

1. If an administrative permit amendment involves a change in ownership or operational control, 

the applicant must include in its request to the Department a written agreement containing a 

specific date for the transfer of permit responsibility, coverage and liability between the current 

and new permittee. 

2. The permit shield provided for in ARM17.8.1214 shall not extend to administrative permit 

amendments. 

P. Emissions Trading, Marketable Permits, Economic Incentives 

ARM 17.8, Subchapter 12, Operating Permit Program §1226(2)

Notwithstanding ARM 17.8.1226(1) and (7), minor air quality operating permit modification 

procedures may be used for permit modifications involving the use of economic incentives, 

marketable permits, emissions trading, and other similar approaches, to the extent that such minor 

permit modification procedures are explicitly provided for in the Montana State Implementation Plan 

or in applicable requirements promulgated by the administrator. 

Q. No Property Rights Conveyed 

ARM 17.8, Subchapter 12, Operating Permit Program §1210(2)(d)

This permit does not convey any property rights of any sort, or any exclusive privilege. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

35

R. Testing Requirements 

ARM 17.8, Subchapter 1, General Provisions §105

The permittee shall comply with ARM 17.8.105. 

S. Source Testing Protocol 

ARM 17.8, Subchapter 1, General Provisions §106

The permittee shall comply with ARM 17.8.106. 

T. Malfunctions 

ARM 17.8, Subchapter 1, General Provisions §110

The permittee shall comply with ARM 17.8.110. 

U. Circumvention 

ARM 17.8, Subchapter 1, General Provisions §111

The permittee shall comply with ARM 17.8.111. 

V. Motor Vehicles 

ARM 17.8, Subchapter 3, Emission Standards §325

The permittee shall comply with ARM 17.8.325. 

W. Annual Emissions Inventory 

ARM 17.8, Subchapter 5, Air Quality Permit Application, Operation and Open Burning Fees §505 

(STATE ONLY)

The permittee shall supply the Department with annual production and other information for all 

emission units necessary to calculate actual or estimated actual amount of air pollutants emitted 

during each calendar year. Information shall be gathered on a calendar-year basis and submitted to 

the Department by the date required in the emission inventory request, unless otherwise specified in 

this permit. Information shall be in the units required by the Department. 

X. Open Burning 

ARM 17.8, Subchapter 6, Open Burning §604, 605 and 606

The permittee shall comply with ARM 17.8.604, 605 and 606. 

Y. Montana Air Quality Permits 

ARM 17.8, Subchapter 7, Permit, Construction and Operation of Air Contaminant Sources §745 and 

764 (ARM 17.8.745(1) and 764(1)(b) are STATE ENFORCEABLE ONLY until approval by the 

EPA as part of the SIP) 

1. Except as specified, no person shall construct, install, alter or use any air contaminant source or 

stack associated with any source without first obtaining a permit from the Department or Board. 

A permit is not required for those sources or stacks as specified by ARM 17.8.744(1)(a)-(k). 

2. The permittee shall comply with ARM 17.8.743, 744, 745, 748, and 764. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

36

3. ARM 17.8.745(1) specifies de minimis changes as construction or changed conditions of 

operation at a facility holding an air quality preconstruction permit issued under Chapter 8 that 

does not increase the facility’s potential to emit by more than 15 tons per year of any pollutant, 

except (STATE ENFORCEABLE ONLY until approved by the EPA as part of the SIP): 

a. Any construction or changed condition that would violate any condition in the facility’s 

existing air quality preconstruction permit or any applicable rule contained in Chapter 8 is 

prohibited, except as provided in ARM 17.8.745(2); 

b. Any construction or changed conditions of operation that would qualify as a major 

modification under Subchapters 8, 9 or 10 of Chapter 8; 

c. Any construction or changed condition of operation that would affect the plume rise or 

dispersion characteristic of emissions that would cause or contribute to a violation of an 

ambient air quality standard or ambient air increment as defined in ARM 17.8.804; 

d. Any construction or improvement project with a potential to emit more than 15 tons per 

year may not be artificially split into smaller projects to avoid air quality preconstruction 

permitting; or 

e. Emission reductions obtained through offsetting within a facility are not included when 

determining the potential emission increase from construction or changed conditions of 

operation, unless such reductions are made federally enforceable. 

4. Any facility making a de minimis change pursuant to ARM 17.8.745(1) shall notify the 

Department if the change would include a change in control equipment, stack height, stack 

diameter, stack gas temperature, source location or fuel specifications, or would result in an 

increase in source capacity above its permitted operation or the addition of a new emission unit. 

The notice must be submitted, in writing, 10 days prior to start up or use of the proposed de 

minimis change, or as soon as reasonably practicable in the event of an unanticipated 

circumstance causing the de minimis change, and must include the information requested in 

ARM 17.8.745(1) (STATE ENFORCEABLE ONLY until approval by the EPA as part of the 

SIP). 

Z. National Emission Standard for Asbestos 

40 CFR, Part 61, Subpart M

The permittee shall not conduct any asbestos abatement activities except in accordance with 40 CFR 

61, Subpart M (National Emission Standard for Hazardous Air Pollutants for Asbestos). 

AA. Asbestos 

ARM 17.74, Subchapter 3, General Provisions and Subchapter 4, Fees

The permittee shall comply with ARM 17.74.301, et seq., and ARM 17.74.401, et seq. (State only) 

BB. Stratospheric Ozone Protection – Servicing of Motor Vehicle Air Conditioners 

40 CFR, Part 82, Subpart B

If the permittee performs a service on motor vehicles and this service involves ozone-depleting 

substance/refrigerant in the motor vehicle air conditioner (MVAC), the permittee is subject to all the 

applicable requirements as specified in 40 CFR 82, Subpart B. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

37

CC. Stratospheric Ozone Protection – Recycling and Emission Reductions 

40 CFR, Part 82, Subpart F

The permittee shall comply with the standards for recycling and emission reductions in 40 CFR 82, 

Subpart F, except as provided for MVACs in Subpart B: 

1. Persons opening appliances for maintenance, service, repair, or disposal must comply with the 

required practices pursuant to §82.156; 

2. Equipment used during the maintenance, service, repair or disposal of appliances must comply 

with the standards for recycling and recovery equipment pursuant to §82.158; 

3. Persons performing maintenance, service, repair or disposal of appliances must be certified by 

an approved technical certification program pursuant to §82.161; 

4. Persons disposing of small appliances, MVACs and MVAC-like (as defined at §82.152) 

appliances must comply with recordkeeping requirements pursuant to §82.166; 

5. Persons owning commercial or industrial process refrigeration equipment must comply with the 

leak repair requirements pursuant to §82.156; and 

6. Owners/operators of appliances normally containing 50 or more pounds of refrigerant must 

keep records of refrigerant purchased and added to such appliances pursuant to §82.166. 

DD. Emergency Episode Plan 

The permittee shall comply with the requirements contained in Chapter 9.7 of the State of Montana 

Air Quality Control Implementation Plan. 

Each major source emitting 100 tons per year located in a Priority I Air Quality Control Region, shall 

submit to the Department a legally enforceable Emergency Episode Action Plan (EEAP) that details 

how the source will curtail emissions during an air pollutant emergency episode. The industrial 

EEAP shall be in accordance with the Department’s EEAP and shall be submitted according to a 

timetable developed by the Department, following Priority I reclassification. 

EE. Definitions 

Terms not otherwise defined in this permit or in the Definitions and Abbreviations Appendix of this 

permit, shall have the meaning assigned to them in the referenced regulations. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

A-1

Appendix A INSIGNIFICANT EMISSION UNITS 

Disclaimer: The information in this appendix is not State or Federally enforceable, but is presented to 

assist YELP, the permitting authority, inspectors, and the public. 

Pursuant to ARM 17.8.1201(22)(a), an insignificant emission unit means any activity or emission unit 

located within a source that: (i) has a potential to emit less than 5 tons per year of any regulated pollutant; 

(ii) has a potential to emit less than 500 pounds per year of lead; (iii) has a potential to emit less than 500 

pounds per year of hazardous air pollutants listed pursuant to Section 7412 (b) of the FCAA; and (iv) is 

not regulated by an applicable requirement, other than a generally applicable requirement that applies to 

all emission units subject to Subchapter 12. 

List of Insignificant Activities:

The following table of insignificant sources and/or activities was provided by YELP. Because there are 

no requirements to update such a list, the emission units and/or activities may change from those specified 

in the table. 

Emissions 

Unit ID 

Description 

IEU01 Fuel Usage:Diesel Fuel 

IEU02 Emergency Generators 

IEU03 Repair and Maintenance Activities 

IEU04 Welding 

IEU05 Fuel Storage Tanks 

IEU06 Space Heating 

IEU07 Wind Erosion of Stockpile 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

B-1

Appendix B DEFINITIONS and ABBREVIATIONS 

"Act" means the Clean Air Act, as amended, 42 U.S. 7401, et seq. 

"Administrative permit amendment" means an air quality operating permit revision that: 

(a) Corrects typographical errors; 

(b) Identifies a change in the name, address or phone number of any person identified in the air 

quality operating permit, or identifies a similar minor administrative change at the source; 

(c) Requires more frequent monitoring or reporting by YELP; 

(d) Requires changes in monitoring or reporting requirements that the Department deems to be 

no less stringent than current monitoring or reporting requirements; 

(e) Allows for a change in ownership or operational control of a source if the Department has 

determined that no other change in the air quality operating permit is necessary, consistent 

with ARM 17.8.1225; or 

(f) Incorporates any other type of change that the Department has determined to be similar to 

those revisions set forth in (a)-(e), above. 

"Applicable requirement" means all of the following as they apply to emission units in a source 

requiring an air quality operating permit (including requirements that have been promulgated or approved 

by the Department or the administrator through rule making at the time of issuance of the air quality 

operating permit, but have future-effective compliance dates; provided that such requirements apply to 

sources covered under the operating permit): 

(a) Any standard, rule, or other requirement, including any requirement contained in a consent 

decree or judicial or administrative order entered into or issued by the Department, that is 

contained in the Montana state implementation plan approved or promulgated by the 

administrator through rule making under Title I of the FCAA; 

(b) Any federally enforceable term, condition or other requirement of any air quality 

preconstruction permit issued by the Department under Subchapters 7, 8, 9 and 10 of this 

chapter, or pursuant to regulations approved or promulgated through rule making under Title 

I of the FCAA, including parts C and D; 

(c) Any standard or other requirement under Section 7411 of the FCAA, including Section 

7411(d); 

(d) Any standard or other requirement under Section 7412 of the FCAA, including any 

requirement concerning accident prevention under Section 7412(r)(7), but excluding the 

contents of any risk management plan required under Section 7412(r); 

(e) Any standard or other requirement of the acid rain program under Title IV of the FCAA or 

regulations promulgated thereunder; 

(f) Any requirements established pursuant to Section 7661c(b) or Section 7414(a)(3) of the 

FCAA; 

(g) Any standard or other requirement governing solid waste incineration, under Section 7429 of 

the FCAA; 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

B-2

(h) Any standard or other requirement for consumer and commercial products, under Section 

7511b(e) of the FCAA; 

(i) Any standard or other requirement for tank vessels, under Section 7511b(f) of the FCAA; 

(j) Any standard or other requirement of the regulations promulgated to protect stratospheric 

ozone under Title VI of the FCAA, unless the administrator determines that such 

requirements need not be contained in an air quality operating permit; 

(k) Any national ambient air quality standard or increment or visibility requirement under part C 

of Title I of the FCAA, but only as it would apply to temporary sources permitted pursuant to 

Section 7661c(e) of the FCAA; or 

(l) Any federally enforceable term or condition of any air quality open burning permit issued by 

the Department under Subchapter 6. 

"Department" means the Montana Department of Environmental Quality. 

"Emission unit" means any part or activity of a stationary source that emits or has the potential to emit 

any regulated air pollutant or any pollutant listed under Section 7412(b) of the FCAA. This term is not 

meant to alter or affect the definition of the term "unit" for purposes of Title IV of the FCAA. 

"FCAA" means the Federal Clean Air Act, as amended. 

"Federally enforceable" means all limitations and conditions that are enforceable by the administrator, 

including those requirements developed pursuant to 40 CFR Parts 60 and 61, requirements within the 

Montana state implementation plan, and any permit requirement established pursuant to 40 CFR 52.21,or 

under regulations approved pursuant to 40 CFR Part 51, Subpart I, including operating permits issued 

under an EPA approved program that is incorporated into the Montana state implementation plan and 

expressly requires adherence to any permit issued under such program. 

"Fugitive emissions" means those emissions that could not reasonably pass through a stack, chimney, 

vent, or other functionally equivalent opening. 

"General air quality operating permit" or "general permit" means an air quality operating permit that 

meets the requirements of ARM 17.8.1222, covers multiple sources in a source category, and is issued in 

lieu of individual permits being issued to each source. 

"Hazardous air pollutant" means any air pollutant listed as a hazardous air pollutant pursuant to 

Section 112(b) of the FCAA. 

"Non-federally enforceable requirement" means the following as they apply to emission units in a 

source requiring an air quality operating permit: 

(a) Any standard, rule, or other requirement, including any requirement contained in a consent 

decree, or judicial or administrative order entered into or issued by the Department, that is not 

contained in the Montana state implementation plan approved or promulgated by the 

administrator through rule making under Title I of the FCAA; 

(b) Any term, condition or other requirement contained in any air quality preconstruction permit 

issued by the Department under Subchapters 7, 8, 9 and 10 of this chapter that is not federally 

enforceable; 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

B-3

(c) Does not include any Montana ambient air quality standard contained in Subchapter 2 of this 

chapter. 

"Permittee" means the owner or operator of any source subject to the permitting requirements of this 

subchapter, as provided in ARM 17.8.1204, that holds a valid air quality operating permit or has 

submitted a timely and complete permit application for issuance, renewal, amendment, or modification 

pursuant to this subchapter. 

"Regulated air pollutant" means the following: 

(a) Nitrogen oxides or any volatile organic compounds; 

(b) Any pollutant for which a national ambient air quality standard has been promulgated; 

(c) Any pollutant that is subject to any standard promulgated under Section 7411 of the FCAA; 

(d) Any Class I or II substance subject to a standard promulgated under or established by Title VI 

of the FCAA; or 

(e) Any pollutant subject to a standard or other requirement established or promulgated under 

Section 7412 of the FCAA, including, but not limited to the following: 

(i) Any pollutant subject to requirements under Section 7412(j) of the FCAA. If the 

administrator fails to promulgate a standard by the date established in Section 7412(e) of 

the FCAA, any pollutant for which a subject source would be major shall be considered 

to be regulated on the date 18 months after the applicable date established in Section 

7412(e) of the FCAA; 

(ii) Any pollutant for which the requirements of Section 7412(g)(2) of the FCAA have been 

met, but only with respect to the individual source subject to Section 7412(g)(2) 

requirement. 

"Responsible official" means one of the following: 

(a) For a corporation: a president, secretary, treasurer, or vice-president of the corporation in 

charge of a principal business function, or any other person who performs similar policy or 

decision-making functions for the corporation, or a duly authorized representative of such 

person if the representative is responsible for the overall operation of one or more 

manufacturing, production, or operating facilities applying for or subject to a permit and 

either: 

(i) The facilities employ more than 250 persons or have gross annual sales or expenditures 

exceeding $25 million (in second quarter 1980 dollars); or 

(ii) The delegation of authority to such representative is approved in advance by the 

Department. 

(b) For a partnership or sole proprietorship: a general partner or the proprietor, respectively. 

(c) For a municipality, state, federal, or other public agency: either a principal executive officer 

or ranking elected official. For the purposes of this part, a principal executive officer of a 

federal agency includes the chief executive officer having responsibility for the overall 

operations of a principal geographic unit of the agency (e.g., a regional administrator of the 

environmental protection agency). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

B-4

(d) For affected sources: the designated representative in so far as actions, standards, 

requirements, or prohibitions under Title IV of the FCAA or the regulations promulgated 

thereunder are concerned, and the designated representative for any other purposes under this 

subchapter. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

B-5

Abbreviations:

ARM Administrative Rules of Montana 

ASTM American Society of Testing Materials 

BACT Best Available Control Technology 

bbl barrels 

Btu British Thermal Unit 

CAT Fluid Catalytic Cracking 

CFBC Circulating Fluidized Bed Combustion 

CFR Code of Federal Regulations 

CO carbon monoxide 

DEQ Department of Environmental Quality 

dscf dry standard cubic foot 

dscfm dry standard cubic foot per minute 

EPA U.S. Environmental Protection Agency 

EPA Method Test methods contained in 40 CFR 60, Appendix A 

EU emission unit 

FCAA Federal Clean Air Act 

gr grains 

HAP hazardous air pollutant 

IEU insignificant emission unit 

Mbdft thousand board feet 

Method 5 40 CFR 60, Appendix A, Method 5 

Method 9 40 CFR 60, Appendix A, Method 9 

MMBtu million British Thermal Units 

NOx oxides of nitrogen 

NO2 nitrogen dioxide 

O2 oxygen 

Pb lead 

PM particulate matter 

PM10 particulate matter less than 10 microns in size 

psi pounds per square inch 

scf standard cubic feet 

SIC Source Industrial Classification 

SO2 sulfur dioxide 

SOx oxides of sulfur 

TPY tons per year 

U.S.C. United States Code 

VE visible emissions 

VOC volatile organic compound 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

C-1

Appendix C NOTIFICATION ADDRESSES 

Compliance Notifications: 

Montana Department of Environmental Quality 

Permitting and Compliance Division 

Air Resources Management Bureau 

P.O. Box 200901 

Helena, MT 59620-0901 

United States EPA 

Air Program Coordinator 

Region VIII, Montana Office 

10 W. 15th Street, Suite 3200 

Helena, MT 59626 

Permit Modifications: 

Montana Department of Environmental Quality 

Permitting and Compliance Division 

Air Resources Management Bureau 

P.O. Box 200901 

Helena, MT 59620-0901 

Office of Partnerships and Regulatory Assistance 

Air and Radiation Program 

US EPA Region VIII 8P-AR 

1595 Wynkoop Street 

Denver, CO 80202-1129 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

D-1

Appendix D AIR QUALITY INSPECTOR INFORMATION 

Disclaimer: The information in this appendix is not State or Federally enforceable but is presented to 

assist YELP, permitting authority, inspectors, and the public. 

1. Directions to Plant: 

YELP is located three miles northeast of Billings adjacent to the Exxon Refinery at 2215 N. Frontage 

Road. 

2. Safety Equipment Required:

Representatives of the State of Montana, Department of Environmental Quality, who wish to enter 

YELP’s premises for the purpose of conducting an inspection of the facility, as per 75-2-403, MCA, 

shall at a minimum, have in possession and utilize the following personnel protective equipment 

(PPE): 

1. Hard Hat 

2. Safety Glasses 

3. Hearing Protection 

In addition to the above mentioned items, and at the direction of a Representative of YELP, additional 

PPE may be required, including, but not limited to Nomex ® clothing, respirators, etc. 

At all times that a Department Representative is present upon the premises, the Representative shall 

follow all directions of a YELP Representative that are meant to protect the health and safety of the 

State Representative and facility employees. 

3. Facility Plot Plan:

A facility plot plan was submitted on June 12, 1996, as part of the Title V Operating Permit 

Application. 

.
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

E-1

Appendix E June 12, 1998 and March 17, 2000 Board Orders Adopting an SO2 Control Plan 

 

Although the hard copy of Appendix E has been removed from the permit, the contents of Appendix E, 

June 12, 1998, and March 17, 2000, Board Orders Adopting an SO2 Control Plan remain as applicable 

requirements as stated in the Title V Operating Permit #OP2650-01. To receive a hard copy of this 

appendix, please contact one of the following: 

Montana Department of Environmental Quality 

Permitting and Compliance Division 

Air Resources Management Bureau 

1520 E. Sixth Ave. 

P.O. Box 200901 

Helena, Montana 59620-0901 

Bureau Phone #: (406) 444-3490 

OR 

Yellowstone Energy Limited Partnership 

2215 North Frontage Road 

Billings, MT 59101 

Phone (406) 256-5296 

The EPA SIP-approval of the SO2 Emission Control Plan, dated May 2, 2002, and May 22, 2003, can be 

supplied by the Department, or can be obtained via the web at the following website: 

http://www.epa.gov/fedrgstr/
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

F-1

Appendix F AMBIENT MONITORING PLAN 

AMBIENT MONITORING PLAN 

YELLOWSTONE ENERGY LIMITED PARTNERSHIP 

Permit #2650-07 

1. This ambient air monitoring plan is required by air quality Permit #2650-07 that applies to the 

petroleum coke-fired power generation facility adjacent to the Exxon petroleum refinery in 

Billings, Montana. This monitoring plan may be changed from time to time by the Department, 

but all current requirements of this plan are also considered conditions of the permit. 

2. YELP shall operate and maintain two air monitoring sites in the vicinity of their power generation 

facility. The exact locations of the monitoring sites must be approved by the Department and 

meet all the requirements contained in the Montana Quality Assurance Manual, including 

revisions; the EPA Quality Assurance Manual, including revisions; the EPA Ambient Monitoring 

Guidelines for Prevention of Significant Deterioration (PSD), including revisions (EPA-450/4-87-

007); Parts 53 and 58 of the Code of Federal Regulations; and any other requirements specified 

by the Department. 

3. YELP shall continue air monitoring for a minimum of 2 years after maximum production has 

been achieved. At that time, the air monitoring data will be reviewed by the Department and the 

Department will determine if continued monitoring or additional monitoring is warranted. The 

Department may require continued air monitoring to track long-term impacts of emissions from 

the facility or require additional ambient air monitoring if any changes take place in regard to 

quality and/or quantity of emissions or the area of impact from the emissions. 

4. YELP shall monitor the following parameters at the sites and frequencies described below: 

AIRS 

Number 

 Site 

Name 

UTM 

Coordinates 

(All Zone 12) 

 Parameter Frequency 

30-111-2006 Johnson 

Lane 

E 701010 

N 5076000 

SO2

1

, Wind Speed and 

Direction, Temperature, Sigma 

Theta2

Continuous 

30-111-2007 Pine 

Hills 

E 703670 

N 5078600 

SO2, Wind Speed and 

Direction, Temperature, Sigma 

Theta 

Continuous 

1

 SO2 = sulfur dioxide 2 Sigma Theta = Standard Deviation of Horizontal Wind Direction 

5. Data recovery for all parameters shall be at least 80 percent computed on a quarterly and annual 

basis. The Department may require continued monitoring if this condition is not met. 

6. Any ambient air monitoring changes proposed by YELP must be approved in writing by the 

Department. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

F-2

7. YELP shall utilize air monitoring and quality assurance procedures which are equal to or exceed 

the requirements described in the Montana Quality Assurance Manual, including revisions; the 

EPA Quality Assurance Manual, including revisions; the EPA Ambient Monitoring Guidelines 

for Prevention of Significant Deterioration (PSD), including revisions (EPA-450/4-87-007); 40 

CFR Parts 53 and 58 of the Code of Federal Regulations; and any other requirements specified by 

the Department. 

8. YELP shall submit quarterly data reports within 45 days after the end of the calendar quarter and 

an annual data report within 90 days after the end of the calendar year. The annual report may be 

substituted for the fourth quarterly report if all information in 9. below is included in the annual 

report. 

9. The quarterly report shall consist of a narrative data summary and a data submittal of all data 

points in AIRS format. This data must be submitted in ASCII files on 3" or 5" high or lowdensity floppy disks, in IBM-compatible format, or on AIRS data entry forms. The narrative data 

summary shall include: 

a. A topographic map of appropriate scale, with UTM coordinates and a true north arrow, 

showing the air monitoring site locations in relation to the YELP facility and the general 

Billings area; 

b. A hard copy of the individual data points; 

c. The quarterly and monthly means for SO2, wind speed and direction; 

d. The first and second highest hourly concentrations for SO2; 

e. The first and second highest, rolling three-hour concentrations for SO2; 

f. The first and second highest, rolling 24-hour concentrations for SO2; 

g. The quarterly and monthly wind roses; 

h. A summary of the data collection efficiency; 

i. A summary of the reasons for missing data; 

j. A precision and accuracy (audit) summary; 

k. A summary of any ambient air standard or PSD increment exceedances; and 

l. Calibration information. 

10. The annual data report shall consist of a narrative data summary containing: 

a. A topographic map of appropriate scale, with UTM coordinates and a true north arrow, 

showing the air monitoring site locations in relation to the YELP facility and the general 

Billings area; 

b. A pollution trend analysis; 

c. The annual means for SO2, wind speed and direction; 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

F-3

d. The first and second highest hourly concentrations for SO2; 

e. The first and second highest, rolling three-hour concentrations for SO2; 

f. The first and second highest, rolling 24-hour concentrations for SO2; 

g. The annual wind rose; 

h. An annual summary of data collection efficiency; 

i. An annual summary of precision and accuracy (audit) data, including the results from 

EPA's National Performance Audit for SO2; 

j. An annual summary of any ambient standard or PSD increment exceedance; and 

k. Recommendations for future monitoring. 

The Department may audit, or may require YELP to contract with an independent firm to audit the air 

monitoring network, the laboratory performing associated analyses, and any data handling procedures at 

unspecified times. On the basis of the audits and subsequent reports, the Department may recommend or 

require changes in the air monitoring network and associated activities in order to improve precision, 

accuracy and data completeness.
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

G-1

Appendix G FUEL OIL FLOWMETERING 

METHOD C-1 

FUEL OIL FLOWMETERING AND ANALYSIS SPECIFICATIONS 

1.0 FLOWMETER SPECIFICATIONS 

YELP shall measure and record the fuel oil consumption rate within the fuel oil loop on an hourly basis. 

YELP shall measure the flow of fuel oil with in-line fuel oil flowmeters, as required by Section III.C. of 

this permit. 

1.1 Initial Calibration and Certification 

Design and equip each fuel oil flowmeter used to demonstrate a flowmeter accuracy of 2.0 percent of the 

upper range value (i.e., maximum calibrated oil flow rate) as measured under laboratory conditions by the 

manufacturer or by the owner or operator. Use the procedures in the following ASME codes for flow 

measurement for use in the laboratory, as appropriate to the type of flowmeter: ASME MFC-3M-1989 

with September 1990 Errata (Measurement of Fluid Flow in Pipes Using Orifice, Nozzle, and Venturi), 

ASME MFC-5M-1985 (Measurement of Liquid Flow in Closed Conduits Using Transit-Time Ultrasonic 

Flowmeters), ASME MFC-6M-1987 with June 1987 Errata (Measurement of Fluid Flow in Pipes Using 

Vortex Flow Meters), or ASME MFC-9M-1988 with December 1989 Errata (Measurement of Liquid 

Flow in Closed Conduits by Weighing Method) for all other flowmeter types. More current ASME or 

NIST (National Institute of Standards and Technology) procedures or other ASME or NIST procedures 

that are appropriate to flowmeter construction may, upon Department approval, be substituted. If the 

flowmeter accuracy exceeds two percent of the upper range value, the flowmeter does not qualify for 

certification. 

1. Annual Calibration 

Recalibrate each fuel oil flowmeter to a flowmeter accuracy of 2.0 percent of the upper range value at 

least annually, or more frequently if required by manufacturer specifications, using the same ASME 

procedures required for initial calibration and certification. 

1.2.1 Alternative Annual Calibration Method 

Alternatively, the fuel oil flowmeter may be recalibrated to a flowmeter accuracy of 2.0 percent of the 

upper range value at least annually by comparing the measured flow of a flowmeter to the measured flow 

from another flowmeter which has been calibrated or recalibrated during the previous 365 days using the 

procedures in ASME MFC-9M-1988 with December 1989 Errata, "Measurement of Liquid Flow in 

Closed Conduits by Weighing Method", or which has been recalibrated by the manufacturer. Perform the 

comparison over a period of no more than 7 consecutive facility operating days. Compare the average of 

three fuel oil flow readings for each meter at three different flow levels: (1) a frequently used low 

operating level selected within the range between the minimum safe and stable operating level and 50% 

of maximum operating level; (2) a frequently used high operating level selected within the range between 

80% of maximum operating level and maximum operating level; and (3) normal operating level. 

Calculate the flowmeter accuracy using the following equation: 

ξ R – A ξ 

 ACC = URV x 100 (Eq. C-1) 

Where: 

ACC = Flow meter accuracy as a percentage of the upper range value. 

R = Average of the three low-, mid-, or high-level flow measurements of the reference 

flowmeter. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

G-2

A = Average of the three measurements of the flowmeter being tested. 

URV = Upper range value of fuel flowmeter being tested (i.e. maximum measurable 

flow). 

If the flowmeter accuracy exceeds 2% of the upper range value, either recalibrate the flowmeter until the 

accuracy is within the performance specification, or replace the flowmeter with another one that is within 

the performance specification. 

2.0 FUEL OIL SAMPLING AND ANALYSIS 

YELP shall perform sampling and analysis of as-fired fuel oil from the fuel oil loop to determine the 

percentage of sulfur by weight in the fuel oil. 

2.1 Sampling Frequency and Methods 

YELP shall perform daily fuel oil sampling using either the flow proportional method described in 

Section 2.2 or the daily manual method described in Section 2.3. 

2.2 Flow Proportional Sampling Method 

YELP shall conduct flow proportional fuel oil sampling or continuous drip fuel oil sampling in 

accordance with ASTM D4177-82 (Reapproved 1990), "Standard Practice for Automatic Sampling of 

Petroleum and Petroleum Products", every day the facility is combusting fuel oil within the fuel oil loop. 

Extract fuel oil at least once every hour and blend into a daily composite sample. The sample 

compositing period may not exceed 24 hours. 

2.3 Daily Manual Sampling Method 

Representative as fired fuel oil samples may be taken manually every 24 hours according to ASTM 

D4057-88, "Standard Practice for Manual Sampling of Petroleum and Petroleum Products", provided that 

the highest fuel oil sulfur content recorded at that facility from the most recent 30-daily samples is used 

for the purposes of calculating SO2 emissions. 

2.4 Sample Archiving 

Split and label each daily fuel oil sample. Maintain a portion (at least 200 cc) of each daily sample for not 

less than 150 calendar days after the submittal to the Department of the quarterly data report for the 

calendar quarter during which the sample was collected. Analyze fuel oil samples for percent sulfur 

content by weight in accordance with ASTM D129-91, "Standard Test Method for Sulfur in Petroleum 

Products (General Bomb Method)," ASTM D1552-90, "Standard Test Method for Sulfur in Petroleum 

Products (High Temperature Method)," ASTM D2622-92, "Standard Test Method for Sulfur in Petroleum 

Products by X-Ray Spectrometry," or ASTM D4294-90, "Standard Test Method for Sulfur in Petroleum 

Products by Energy-Dispersive X-Ray Fluorescence Spectroscopy". 

3.0 VOLUMETRIC FLOW MEASUREMENT 

3.1 Fuel Oil Density 

Where the flowmeter records volumetric flow rather than mass flow, analyze daily fuel oil samples to 

determine the density or specific gravity of the fuel oil (not required where the flowmeter records mass 

flow). Determine the density or specific gravity of the fuel oil sample in accordance with ASTM D941-

88, "Standard Test Method for Density and Relative Density (Specific Gravity) of Liquids by Lipkin 

Bicapillary Pycnometer," ASTM D1217-91, "Standard Test Method for Density and Relative Density 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

G-3

(Specific Gravity) of Liquids by Bingham Pycnometer;" ASTM D1481-91, "Standard Test Method for 

Density and Relative Density (Specific Gravity) of Viscous Materials by Lipkin Bicapillary;" ASTM 

D1480-91, "Standard Test Method for Density and Relative Density (Specific Gravity) of Viscous 

Materials by Bingham Pycnometer;" ASTM D1298-85 (Re-approved 1990), "Standard Practice for 

Density, Relative Density (Specific Gravity) or API Gravity of Crude Petroleum and Liquid Petroleum 

Products by Hydrometer Method;" or ASTM D4052-91, "Standard Test Method for Density and Relative 

Density of Liquids by Digital Density Meter". 

3.2 Calculation of Mass Flow from Volumetric Flow 

Where the flowmeter records volumetric flow rather than mass flow, calculate and record the fuel oil 

mass for each hourly period using hourly fuel oil flow measurements and the density or specific gravity of 

the daily oil sample. 

Convert density, specific gravity, or API gravity of the fuel oil sample to density of the fuel oil sample at 

the sampling location's temperature using ASTM D1250-80 (Re-approved 1990), "Standard Guide for 

Petroleum Measurement Tables". 

Where density of the fuel oil is determined by the applicable ASTM procedures from Section 3.1 of 

Department Method C-1, use the following equation to calculate the mass of fuel oil consumed (in lb/hr). 

Moil = Voil x Doil (Eq. C-2) 

Where: 

Moil = Mass of oil consumed per hr, lb/hr. 

Voil = Volume of oil consumed per hr, measured in scf, gal, barrels, or m3

. 

Doil = Density of oil, measured in lb/scf, lb/gal, lb/barrel, or lb/m3

. 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

H-1

Appendix H CAM Plan - PM10 Control from Circulating Bed Boilers (2) 

Monitoring Approach -- ESP 

I. Indicator Triboelectric Signal (Baghouse Leak Detector) 

II. Measurement Approach A triboelectric monitor will be used at the baghouse exhaust 

stack. An alarm will sound when the signal stays over a preset level for more than 30 seconds. This is an indication of a 

broken bag. 

III. Indicator Value An excursion is defined as an event in which the 

triboelectric signal exceeds a yet to be determined 

percentage of full scale for 30 seconds. The indicator value 

will be established during a source test (see Stack Test 

below). An excursion triggers an inspection and, if 

necessary, corrective action. 

The probe is placed inside the baghouse exhaust stack. The 

triboelectric output signal is a function of the amount of 

particulate in the stack. The function is linear provided 

particle size and velocity remain relatively constant. This is 

a reasonable assumption for this unit. 

The baghouse leak detector will be monitored by the control 

room operators daily. 

Calibration of the unit is automatically done via internal 

electronics. The unit itself will be inspected once a month. 

The unit monitors particulate on a continuous basis. 

There is no on-going data collection. The unit contains an 

alarm. When the alarm sounds as described above, action 

will be taken. 

None 

IV. Performance Criteria 

A. Data Representativeness 

 B. Verification of Operational Status 

 C. QA/QC Practices and Criteria 

 D. Monitoring Frequency 

 E. Data Collection Procedures 

F. Averaging period 

G. Stack Test 

 

After Department approval of the CAM Plan, YELP will 

schedule and conduct testing to establish a suitable indicator 

value. The indicator value shall be established as 

expeditiously as practicable after Department approval 

(Department Decision on OP 2650-01) but in no case shall 

the establishment of the indicator value prevent monitoring 

from beginning within 180 days after Department approval 

(ARM 17.8.1508(4)). 
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

H-2

Although the complete hard copy of Appendix G is not included in the permit, the contents of Appendix F, 

YELP’s CAM plan remain as applicable requirements as stated in the Title V Operating Permit #OP2650-01. 

To receive a hard copy of this appendix, please contact one of the following: 

The Department of Environmental Quality 

Permitting and Compliance Division 

Air Resources Management Bureau 

1520 E. Sixth Ave. 

P.O. Box 200901 

Helena, Montana 59620-0901 

Bureau Phone (406) 444-3490 

OR 

Yellowstone Energy Limited Partnership 

2215 North Frontage Road 

Billings, MT 59101 

Phone (406) 256-5296
OP2650-01 Date of Decision: 10/24/07 

Effective Date: 11/24/07

I-1

Appendix I CAM Plan – SO2 Control from Circulating Bed Boilers (2) 

Monitoring Approach -- ESP 

I. Indicator Exit stream SO2 concentration. 

II. Measurement Approach A CEMS on the boiler exit stream includes continuous SO2

concentration readings which are used to control the amount 

of limestone that is added. 

III. Indicator Value The exit stream concentration is maintained at 0.59 lbs 

SO2/MMBtu heat input. 

Same direct SO2 measurement as used to meet emission 

limits. 

CEMS data is monitored by operators. 

As required by 40 CFR 60 Subpart Da, Appendix B and 

Appendix F, operation of the SO2 CEMS is regulated by a 

daily calibration drift check of CEMS, a quarterly cylinder 

gas audit and an annual RATA on system. 

Continuous. 

CEMS automatically records exit stream SO2

concentrations. 

IV. Performance Criteria 

 A. Data Representativeness 

 B. Verification of Operational Status 

 C. QA/QC Practices and Criteria 

 D. Monitoring Frequency 

 E. Data Collection Procedures 

 F. Averaging period 

 1 hour. 

Although the complete hard copy of Appendix H is not included in the permit, the contents of Appendix F, 

YELP’s CAM plan remain as applicable requirements as stated in the Title V Operating Permit #OP2650-01. 

To receive a hard copy of this appendix, please contact one of the following: 

The Department of Environmental Quality 

Permitting and Compliance Division 

Air Resources Management Bureau 

1520 E. Sixth Ave. 

P.O. Box 200901 

Helena, Montana 59620-0901 

Bureau Phone (406) 444-3490 

OR 

Yellowstone Energy Limited Partnership 

2215 North Frontage Road 

Billings, MT 59101 

Phone (406) 256-5296