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 Annotat ed (MCA) Sections 75-2-217 and 218, and the Administrative Rules of Montana (ARM) Title 17, Chap ter 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 pe rmit. 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 en forceable 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 regardi ng issuance of an operating permit is not effective until 30 days have elapsed from the date of the deci sion issued October 24, 2007. The decision may be appealed to the Board of Environmental Review by fi ling a request for a hearing within 30 days after the date of decision. If no appealed is filed then th e 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 pe riod to object to issuance of this operating permit. If EPA objects to the operating permit as a result of a petition prior to th e 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 Depart ment 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 iOP2650-01 Date of Decision: 10/24/07

Effective Date: 11/24/07 ii Montana Air Quality Operating Permit Department of Environmental Quality

SECTION I. GENERA L INFORMATION ......................................................................................1
SECTION II. SUMMARY OF EMISSION UNITS...........................................................................2
SECTION III. PERMIT CONDITIONS ..............................................................................................3

A. F ACILITY -W IDE ...............................................................................................................3

B. EU01

– C IRCULATING F LUIDIZED B ED C OMBUSTION (CFBC) B OILERS (2) ..................6

C. EU02

– L IMESTONE U NLOADING

, H ANDLING

, AND C RUSHING AND EU03 L IMESTONE
S TORAGE .......................................................................................................................15 D. EU04, EU05, EU06, AND EU07 O UTDOOR C OKE L OADING

, H ANDLING AND S TORAGE

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

E. EU08 C OKE U NLOADING /C RUSHING /P ROCESSING F ACILITY AND EU09 C OKE B ARN 19

F. EU10 AND EU11 A SH U NLOADING

, H ANDLING AND S TORAGE ...................................21

G. EU12 F UGITIVE E MISSIONS : V EHICLE T RAFFIC ...........................................................22

H. EU13 C AT S LURRY O IL T ANK ......................................................................................24
SECTION IV. NON-APPLI CABLE REQUIREMENTS .................................................................26

A. F ACILITY -W IDE .............................................................................................................26

B. E MISSION U NITS ............................................................................................................26
SECTION V. GENERAL PE RMIT CONDITIONS .......................................................................27

A. C OMPLIANCE R EQUIREMENTS .......................................................................................27

B. C ERTIFICATION R EQUIREMENTS ...................................................................................27

C. P ERMIT S HIELD ..............................................................................................................28

D. M ONITORING

, R ECORDKEEPING

, AND R EPORTING R EQUIREMENTS .............................29

E. P ROMPT D EVIATION R EPORTING ..................................................................................30

F. E MERGENCY P ROVISIONS ..............................................................................................30

G. I NSPECTION AND E NTRY ...............................................................................................31

H. F EE P AYMENT ...............................................................................................................31

I. M INOR P ERMIT M ODIFICATIONS ...................................................................................31

J. C HANGES N OT R EQUIRING P ERMIT R EVISION ..............................................................32

K. S IGNIFICANT P ERMIT M ODIFICATIONS .........................................................................33

L. R EOPENING FOR C AUSE .................................................................................................33

M. P ERMIT E XPIRATION AND R ENEWAL ............................................................................33

N. S EVERABILITY C LAUSE .................................................................................................34

O. T RANSFER OR A SSIGNMENT OF O WNERSHIP .................................................................34

P. E MISSIONS T RADING

, M ARKETABLE P ERMITS

, E CONOMIC I NCENTIVES .....................34 Q. N O P ROPERTY R IGHTS C ONVEYED ...............................................................................34

R. T ESTING R EQUIREMENTS ..............................................................................................35

S. S OURCE T ESTING P ROTOCOL ........................................................................................35

T. M ALFUNCTIONS ............................................................................................................35

U. C IRCUMVENTION ...........................................................................................................35

V. M OTOR V EHICLES .........................................................................................................35

W. A NNUAL E MISSIONS I NVENTORY ..................................................................................35

X. O PEN B URNING .............................................................................................................35

Y. M ONTANA A IR Q UALITY P ERMITS ................................................................................35

Z. N ATIONAL E MISSION S TANDARD FOR A SBESTOS .........................................................36

AA. A SBESTOS ......................................................................................................................36

BB. S TRATOSPHERIC O ZONE P ROTECTION

– S ERVICING OF M OTOR V EHICLE A IR C ONDITIONERS ..............................................................................................................36

CC. S TRATOSPHERIC O ZONE P ROTECTION

– R ECYCLING AND E MISSION R EDUCTIONS .....37

DD. E MERGENCY E PISODE P LAN ..........................................................................................37

EE. D EFINITIONS ..................................................................................................................37OP2650-01 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 IN SPECTOR INFORMATION ................................................D-1

APPENDIX E JUNE 12, 1998 AND MARCH 17, 2000 BOARD ORDERS ADOPTING AN SO 2 CONTROL PLAN.................................................................................................. E-1

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

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

APPENDIX H CAM PLAN - PM 10 CONTROL FROM CIRCULATING BED BOILERS (2) ..........................................................................................................H-1

APPENDIX I CAM PLAN – SO 2 CONTROL FROM CIRCULATING BED BOILERS (2) ........................................................................................................... I-1OP2650-01 Date of Decision: 10/24/07

Effective Date: 11/24/07 1 Terms not otherwise defined in this permit or in the Definitions and Abbrev iations 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, B illings, 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 petr oleum 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 an d 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, NO 2 , 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 generate d 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 applicab le 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 Testi ng 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 * P 0.67 or E= 55 * P 0.11 - 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) Hy drocarbon 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 pers ons 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 pe riods 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, complia nce 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 in spectors 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 con secutive 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 af ter 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 operat e a construction site or demolition project unless reasonable precautions are taken to control emi ssions 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 th e 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 equi pment and new fuel burning equipment calculated using the following equations:

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

E =0.882 * H -0.1664

For new fuel burning equipment (insta lled 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 disch arged 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 * P 0.67
For process weight rates in excess of 30 tons per hour: E = 55.0 * P 0.11 – 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 AR M 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, reser voir or other container of more than 65,000 gallon capacity any crude oil, gasoline or petroleum di stillate having a vapor pr essure 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 worki ng 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-com partment 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, cons tructed 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 sh all submit to the Department a copy of any startup, shutdown, and malfunction (SSM) plan re quired 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 Emissi on Standard for Hazardous Air Pollutants (NESHAPs) or Maximum Achievable Control Tech nology (MACT) standard, and within 30 days of the revision of any such SSM plan, when a pplicable. 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 inform ation 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), s hall contain certification by a responsible official of truth, a ccuracy 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 certifica tion required by Section V.B must include a statement of compliance based on the informa tion available which identifies any observed, documented or otherwise known instance of noncomp liance 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 contai n certification by a responsible official of truth, accuracy and comp leteness. This certification and any other certification require d 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

Method 5 Annual Semiannual 18.26 lb/hr 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 SO 2 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 SO 2 620.0 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 SO 2 (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
SemiannualOP2650-01 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 SO 2 (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 SO 2 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 SO 2 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 SO 2 / 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 NO

x 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 NO

x 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 QuarterlyOP2650-01 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 PM 10 CAM Plan ARM 17.8.1506 Provisions from CAM Plan, Appendix H Ongoing Semiannual

B.20, B.29, B.33, B.38,
B.39 SO 2 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 th e atmosphere from any affected facility any gases that exhibit greater than 20% opacity (6 minut e 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 di scharged 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 f acility 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 da y. 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 SO 2 in the Exxon coker process gas stream to the SO 2 emitted from the YELP main stack shall be equal to or greater than 1:1. During times that the SO 2 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 SO 2 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 requireme nt 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 th at 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 recei ved 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 SO 2 emission limits (hourly, daily, and annual) as listed in this operating permit (Billings/Laurel SO 2 Emission Control Plan, approved into the SIP by EPA on May 2, 2002, and May 22, 2003).

B.6. SO 2 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 SO 2 emission shall be limited as follows during periods when the Exxon Coker Unit is operating and YELP is not recei ving Exxon Coker flue gas (Billings/Laurel SO 2 Emission Control Plan, approved into the SIP by EPA on May 2, 2002, and May 22, 2003).

a. Three Hour Emissions of SO 2 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 peri od during that portion of each calendar-day beginning at 9:00 p.m. and ending at 6:00 a.m.

b. Daily Emissions of SO 2 from the YELP boiler stack shall not exceed 10,543.0 pounds per calendar day; and

c. Annual Emissions of SO 2 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 SO 2 emissions shall be limited as follo ws 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 SO 2 Emission Control Plan, approved into the SIP by EPA on May 2, 2002, and May 22, 2003):

a. Three-Hour Emissions of SO 2 from the YELP boiler stack shall not exceed 2040.0 pounds per 3-hour period;

b. Daily Emissions of SO 2 from the YELP boiler stack shall not exceed 16,320.0 pounds per calendar day; and

c. Annual Emissions of SO 2 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 resu lting 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 SO 2 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 th e conditions for Section III.B.7 apply shall be assigned a 1-hour value equal to the emission lim itation contained in Section III.B.7 (a)(ii) divided by 3; and

b. All other Clock Hours in the subject 3-hour pe riod 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% SO 2 control for all boilers operating hours 1 . Percent
control of SO 2 shall be determined according to the pr ovision in 40 CFR 60, Subpart Da, Section 60.48a, except that the percent control is require d 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 th e atmosphere from any affected facility any gases
that contain SO 2 in excess of:

a. 1.2 lb/MMBtu heat input and 10% of the pot ential 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 ope rating. Twice per month YELP shall analyze the coker gas stream to facilitate F-Factor determin ation 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 sh all 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. NO

x 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 th e atmosphere from any affected facility any gases, based on a 30-day rolling average, that contain NO

x 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 concentrati on (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 petr oleum coke fuel and Cat Slurry Oil, all of the Exxon process gas in the YELP boilers. For pur poses 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 fu el), 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 RateOP2650-01 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 Appe ndix B, (Performance Specifications 1, 2, 3, and 4) and Appendix F (Quality Assurance/Qua lity 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 re quirements 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 PM 10 (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 SO 2 (ARM 17.8.1504).

Compliance Demonstration

B.21. A Method 9 test shall be performed, as requi red by, the Department and Section III.A.1 to monitor compliance with the opacity limit in S ection III.B.1. The test methods and procedures
shall be conducted in accordance with the Mont ana 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, th e data from annual reference method tests shall also be used to monitor compliance. All CE MS shall be operated pursuant to any and all requirements of Attachment 1 of Exhibit A of th e 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 SO 2 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 Pa rt 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 syst em 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 achie ving the maximum production rate for the facility and not later than 180 days after initial st artup (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 certif ication shall be as specified in 40 CFR Part 60, Appendices A and B. The Department shall requi re annual compliance stack testing at the YELP main stack. Testing shall include: Methods 1-4 and 6/6C for sulfur dioxide (SO 2 ), Method 7/7E for nitrogen oxides (NO

x ), Method 3/3B for carbon monoxide (C O), 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 po llutants. Test methods and procedures, where there is more than one option for any given pollu tant, 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 w ith 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 S tipulation (Appendix E) may substitu te for the annual source test provided that the flow rate RATA and the concentration RATA are performed simultaneously

and additional calculations are ma de to determine and report the data in pounds per hour sulfur dioxide (Billings/Laurel SO 2 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 ga s received by the YELP facility. The results shall be reported to the Department along with othe r emissions data within 30 days of the end of each reporting period. The report shall contai n 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, with in 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 pr ocess gas diverted, and circumstances explaining the diversion of this stream. Said report sha ll discuss what corrective actions will be taken to prevent recurrences of the situation and wh at caused the diversion (ARM 17.8.749).

B.27. YELP shall install, operate, and maintain a c ontinuous fuel oil flowmete r. YELP shall comply with the following fuel oil 2 flowmetering and analysis specifications:

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

b. Analyze all fuel oil samples collected, for sulf ur 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 follow ing the Compliance Assurance Monitoring (CAM)

Plan for PM 10 (Appendix H). The CAM Plan, written by YELP in accordance with ARM 17.8.1504 is summarized in Appendix H and is ava ilable 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 th e 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 SO 2 (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 Depart ment 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 SO 2 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 record s shall be made available to the Department upon request (Billings/Laurel SO 2 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 SO 2 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

PM 10 , 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

SO 2 , 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 (A RM 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 cons ist 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, SO 2 , CO, and NO

x .

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 th at 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 Stipul ation (Appendix F), YELP shall submit quarterly reports on a calendar-year basis. The quarterly re ports 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 Hele na 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 SO 2 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 requi red reference method tests performed during the reporting period. The actual test report shoul d be submitted as specified by the Montana Source Test Protocol and Procedures Manual,

b. Certification that all CEMS were operated a nd maintained in accordance with Section III. B.17.c and the June 12, 1998, stipulation (Appendix E),

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

d. Certification that the log to record the com bustor 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 Semiannual C.1, C.2, C.5, 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 Semiannual C.2, C.3, C.5, 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 Semiannual C.2, C.4, C.5, 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 ProtocolOP2650-01 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 ove r 6 consecutive minutes (ARM 17.8.340 and 40 CFR 60.672(a)(2)).

C.2. All storage silos, surge bins, hoppers, lim estone crushing and conveyor systems shall utilize baghouses (bag filters) for particulat e 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 m onitoring pertaining to the 7% opacity limit in Section III.C.1.and the particulate limit in Sec tion 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 acco rdance 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 acco rdance 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 main tenance activity performed on the baghouse. The log shall include, but is no t limited to, the identification information for the baghouse, the date of the maintenance and/or corr ective 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 Montan a 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 operate d 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 Secti on III.C.8 was maintained and provide a summary of maintenance performed and corrective acti ons taken during the period as required; and

c. A summary of the results of any reference met hod 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 Semiannual D.3, D.4, D.6, D.8, D.11, D.12, D.14 Particulate Emissions 0.01 gr/dscf

Method 5 Every 4-years Semiannual

Normal Operations Ongoing Semiannual D.3, D.5, D.6, 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, ha ndling, 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 sour ce 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 pne umatic coke truck unload ing shall utilize baghouses (bag filters) for particulate em ission 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 st orage 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 m onitoring 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 acco rdance 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 appr oved test shall be performed every 4 years on the baghouse. The test methods and procedures sha ll 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 trai ned 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 fugitiv e 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 c onditions. 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, tim e, observer(s), observer(s)’ s location, the area being surveyed, and the results of the visual survey(s). If a ny 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 main tenance activity performed on the baghouse. The log shall include, but is no t limited to, the identification information for the baghouse, the date of the maintenance and/or corr ective 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 Montan a 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 operate d and maintained during the operation of equipment;

b. Certification that the visual surveys were pe rformed 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 correctiv e actions taken during the period;

d. Identification of any instances of excessive f ugitive emissions and provide a summary of any corrective action taken; and

e. A summary of the results of any reference met hod 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 Semiannual E.1, E.2, 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 Semiannual E.3, E.4, E.5, 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 Unloadi ng/Crushing/Processing Facility shall not exceed 0.01 gr/dscf (ARM 17.8.752).

E.4. The coke unloading/crus hing/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 acco rdance 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 Mont ana 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 main tenance 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 av ailable 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/Processi ng 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 ro lling 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 Montan a 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 operate d 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 correc tive 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 met hod 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 Semiannual F.1, F.2, F.4, 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 Semiannual F.3, F.4, F.6, 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 re quirement 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 acco rdance 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 t est shall be performed every 4 years. The test methods and procedures shall be conducted in acco rdance 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 main tenance activity performed on the baghouse. The log shall include, but is no t limited to, the identification information for the baghouse, the date of the maintenance and/or corr ective 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 Montan a 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 maintain ed and in place during operation of equipment;

b. Certification that the log required in Secti on 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 met hod 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 SemiannualOP2650-01 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 an y access roads, parking lots, or the general plant area without taking reasonable precautions to contro l 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 a nd 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 suppressan t 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 submitte d 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 repor ts 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 emissi ons 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, a ll applicable NSPS provisions , as appropriate, of 40 CFR 60, Subpart Kb 60.110b through 60.117b (S tandards 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 Secti on III.A.1, YELP shall perform a Method 9 test in
accordance with Montana Source Protocol a nd 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 sl urry oil tank in accordance 40 CFR 60, Subpart Kb 60.116b (ARM 17.8.1213).

Recordkeeping

H.6. YELP shall keep all record s 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 Sec tion 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 repor ts 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) a nd Federal Regulations identified as not applicable to the facility or to a specific emissions unit at th e time of the permit issuance are listed below (ARM 17.8.1214). The following list does not preclude the n eed to comply with any new requirements that may become applicable during the permit term.

A. Facility-Wide

The following table contains non-applicable require ments 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 applicab le because the facility is not listed in the source category cited in the rules.

B. Emission Units

The permit application identified applicable require ments 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 pe rmit modification, revocation and reissuance, or termination, or of a notification of planned ch anges 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 impa cts of continuing operations, and that such health, safety or environmental impacts were unf oreseeable and could not have otherwise been
avoided.

4. The permittee shall furnish to the Department, w ithin 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 sh all be supplemental to, and shall not sanction noncompliance with, the applicable requirements on which it was based.

6. For applicable requirements that will become e ffective 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 Pe rmit Program §1207 a nd §1213(7)(a)&(c)-(d)

1. Any application form, report, or compliance cer tification submitted pursuant to ARM Title 17, Chapter 8, Subchapter 12, shall contain certifica tion by a responsible official of truth, accuracy and completeness. This certification and any other certification require d under ARM Title 17, Chapter 8, Subchapter 12, shall state that, based on information and belief formed after reasonable inquiry, the statements and inform ation 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 th e 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 a nd 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 liste d in the Notification Addresses Appendix of this permit.

C. Permit Shield ARM 17.8, Subchapter 12, Oper ating 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 re quirements and any non-federally enforceable requirements as of the date of permit issuance.

2. The permit shield described in 1 above shall rema in in effect during the appeal of any permit action (renewal, revision, reopening, or re vocation 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 in formation from a source pursuant to Sec. 7414 of the FCAA;

e. The ability of the Department to obtain info rmation from a source pursuant to the Montana Clean Air Act, Title 75, Chapter 2, MCA;

f. The emergency powers of the Department un der the Montana Clean Air Act, Title 75, Chapter 2, MCA; andOP2650-01 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 define d 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 s ubmitting 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 sha ll then be presumed to be in compliance or noncompliance unless that presumption is overcom e by other relevant credible evidence.

6. The permit shield will not extend to minor perm it modifications or changes not requiring a permit revision (see Sections I & J).

7. The permit shield will extend to significant perm it modifications and transfer or assignment of ownership (see Sections K & N).

D. Monitoring, Recordkeeping, and Reporting Requirements ARM 17.8, Subchapter 12, Oper ating 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 require d monitoring data and s upport information for a period of at least 5 years from the date of the monitoring sample, measurement, report, or application. Support information includes a ll 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 mainta ined 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 othe rwise 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 Ja nuary 1 through June 30 of the current year. All instances of deviations from the permit requi rements 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, Oper ating 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 pr obable 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 Perm it 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 emergenc y 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 pe rmittee demonstrates through properly signed, contemporaneous logs, or othe r 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 ex ceeded 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 mitiga te 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, Oper ating 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 admini strator, 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 record s 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, em ission 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, Opera ting 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 an y required portion of an appealed fee) within 90 days of the due date of the fee, the Depart ment may impose an additional assessment of 15% of the fee (or any required portion of an appeal ed 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, Opera ting 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, updatin g, supplementation, or deletion, and may reference any required in formation 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 w ithin 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 cha nges 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 term s that are necessary to enforce applicable
emission limitations on emission un its 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 wr itten 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, Operati ng 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. Signi ficant 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 pe rmit monitoring terms or conditions;

c. Every relaxation of permit reporting or recor dkeeping 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 require ments of ARM Title 17, Chapter 8, including those for applications, public participation, and re view by affected states and the administrator, as they apply to permit issuance and renewal, excep t that an application for a significant permit modification need only address in detail those porti ons of the permit application that require revision, updating, supplementation or deletion.

3. The permit shield provided for in ARM 17.8.1 214 shall extend to significant modifications.

L. Reopening for Cause ARM 17.8, Subchapter 12, Oper ating Permit Program §1228(1)&(2)

This permit may be reopened and revi sed 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 th e 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 th at the permit contains a material mistake or
that inaccurate statements were made in estab lishing 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 w ith the applicable requirements.

M. Permit Expiration and Renewal ARM 17.8, Subchapter 12, Operating Permit Pr ogram §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 applicati on 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 pe rmit renewal has been issued or denied.

4. For renewal, the permittee shall submit a comple te 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 wr iting 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, Opera ting 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 sha ll not impair in any manner the underlying applicability of all applicable requirements, a nd 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 i nvalid, 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, Oper ating 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 responsib ility, 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, Op erating Permit Program §1226(2)

Notwithstanding ARM 17.8.1226(1) and (7), mi nor air quality operating permit modification procedures may be used for permit modificati ons involving the use of economic incentives, marketable permits, emissions trading, and other si milar approaches, to the extent that such minor permit modification procedures are explicitly provide d 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, Oper ating 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 A pplication, 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 emi ssion 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 a nd 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, inst all, alter or use any air contaminant source or stack associated with any source without first obt aining 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 AR M 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 chang es as construction or changed conditions of operation at a facility holding an air quality pr econstruction 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 approv ed 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 c ondition of operation that would affect the plume rise or dispersion characteristic of emissions that w ould 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 smalle r projects to avoid air quality preconstruction permitting; or

e. Emission reductions obtained th rough offsetting within a facility are not included when determining the potential emission increase fro m construction or ch anged 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 opera tion 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 prac ticable 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 abat ement 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 – Servic ing 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, re pair or disposal of appliances must comply with the standards for recycling and r ecovery 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, M VACs and MVAC-like (as defined at §82.152) appliances must comply with recordkeep ing requirements pursuant to §82.166;

5. Persons owning commercial or industrial process re frigeration 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 adde d to such appliances pursuant to §82.166.

DD. Emergency Episode Plan

The permittee shall comply with the requirements c ontained 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 Em ergency Episode Action Plan (EEAP) that details how the source will curtail emissions during an ai r 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 Abbrev iations 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 Stat e 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 po llutants 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 un its 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 StockpileOP2650-01 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 pho ne 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 requi rements 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 qua lity 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 requi rements 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 entere d into or issued by the Department, that is contained in the Montana state implementa tion 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 regu lations approved or promulgated through rule making under Title I of the FCAA, including parts C and D;

(c) Any standard or other requirement under S ection 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 u nder 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 cons umer 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 regul ations 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 in crement or visibility requirement under part C of Title I of the FCAA, but only as it would ap ply 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 unde r Section 7412(b) of the FCAA. This term is not

meant to alter or affect the definition of the te rm "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 re quirement 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 functionall y 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 multip le 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 implementa tion 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 qualit y 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 st andard contained in Subchapter 2 of this chapter.

"Permittee" means the owner or operator of any source s ubject to the permitting requirements of this subchapter, as provided in ARM 17.8.1204, that hol ds a valid air quality operating permit or has submitted a timely and complete perm it 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 ai r 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 othe r 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 a ny 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 re presentative is approved in advance by the Department.

(b) For a partnership or sole proprietorship: a ge neral partner or the proprietor, respectively.

(c) For a municipality, state, federal, or other pub lic agency: either a pr incipal 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

NO 2 nitrogen dioxide

O 2 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

SO 2 sulfur dioxide
SOx oxides of sulfur TPY tons per year
U.S.C. United States Code
VE visible emissions VOC volatile organic compoundOP2650-01 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. 15 th 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 80202-1129OP2650-01 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 in spection of the facility, as per 75-2-403, MCA, shall at a minimum, have in possession and u tilize the following personnel protective equipment (PPE):

1. Hard Hat

2. Safety Glasses

3. Hearing Protection

In addition to the above mentione d 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 SO 2 Control Plan

Although the hard copy of Appendix E has been remo ved from the permit, the contents of Appendix E, June 12, 1998, and March 17, 2 000, Board Orders Adopting an SO 2 Control Plan remain as applicable requirements as stated in the Title V Operating Perm it #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 SO 2 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 gene ration 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 ar e 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 s ites 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 Deterior ation (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, th e air monitoring data will be reviewed by the Department and the Department will determine if continued monitori ng 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 monito ring 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 SO 2 1 , Wind Speed and Direction, Temperature, Sigma

Theta 2 Continuous

30-111-2007 Pine

Hills E 703670

N 5078600 SO 2 , Wind Speed and Direction, Temperature, Sigma
Theta Continuous

1 SO 2 = 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 assu rance procedures which are equal to or exceed the requirements described in th e Montana Quality Assurance Manual, including revisions; the EPA Quality Assurance Manual, including revisi ons; 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 Regul ations; 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 e nd 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 s ubmitted 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 SO 2 , wind speed and direction;

d. The first and second highest hourly concentrations for SO 2 ;

e. The first and second highest, rolling three-hour concentrations for SO 2 ;

f. The first and second highest, rolling 24-hour concentrations for SO 2 ;

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 SO 2 , 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 SO 2 ;

e. The first and second highest, rolling three-hour concentrations for SO 2 ;

f. The first and second highest, rolling 24-hour concentrations for SO 2 ;

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 SO 2 ;

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 c ontract with an independent firm to audit the air monitoring network, the laboratory performing associat ed analyses, and any data handling procedures at unspecified times. On the basis of the audits and subsequent reports, the De partment 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 appropria te 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 Erra ta (Measurement of Fluid Flow in Pipes Using Vortex Flow Meters), or ASME MFC-9M-1988 wi th December 1989 Errata (Measurement of Liquid Flow in Closed Conduits by Weighing Method) for a ll other flowmeter types. More current ASME or NIST (National Institute of Standards and Technol ogy) 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 uppe r 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 recalibra ted to a flowmeter accuracy of 2.0 percent of the upper range value at least annually by comparing the me asured 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 thr ee 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 ope rating level; and (3) nor mal 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 hi gh-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 re place 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 sampli ng 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 bl end 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 SO 2 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 DensityOP2650-01 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).

M oil = V oil x D oil (Eq. C-2)

Where:

M oil = Mass of oil consumed per hr, lb/hr.

V oil = Volume of oil consumed per hr, measured in scf, gal, barrels, or m 3

. D oil = Density of oil, measured in lb/scf, lb/gal, lb/barrel, or lb/m 3

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

Effective Date: 11/24/07 H-1 

### Appendix H CAM Plan - PM 10 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 auto matically 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) 256-5296OP2650-01 Date of Decision: 10/24/07

Effective Date: 11/24/07 I-1 

### Appendix I CAM Plan – SO 2 Control from Circulating Bed Boilers (2)

Monitoring Approach -- ESP

I. Indicator Exit stream SO 2 concentration.
II. Measurement Approach A CEMS on the boiler exit stream includes continuous SO 2 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

SO 2 /MMBtu heat input.

Same direct SO 2 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 SO 2 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 SO 2 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