### United States Environmental Protection Agency Region 8 Air Program 1 595 Wynkoop Street Denver, Colorado 80202-1129 September 27, 2012

Final Air Pollution Control Prevention of Significant Deterioration (PSD) Permit to Construct PSD-WY-00000 1 -2011.001 Permittee: Owner: Cheyenne Light, Fuel & Power 

### I Black Hills Power, Inc. Operator: B lack Hills Service Company P
.O. Box 1400 625 Ninth Street Rapid City, South Dakota 57709 Permitted Facility: Cheyenne Prairie Generating Station Laramie County, Wyoming

## Table of Contents I. INTRODUCTION
...................................................................................... 1 II. GENERAL PERMIT CONDITIONS
. . .. . . . ... . ..... . .. . ............................... . .. . .. .. .. .. l A. PERMIT EFFECTIVE DATE AND EXPIRATION
........................................... l 

### B. PERMIT NOTIFICATION REQUIREMENTS
............... . ................................2 C. FACILITY OPERATION
............................................................................. 2 D. MALFUNCTION REPORTING
.................................................................... 2 E. RIGHT OF ENTRY
.................................................................................... 3 F. TRANSFER OF OWNERSHIP
............ . ..... . .......... .. .... .... ............. .. . .. ..... . .......3 G. SEVERABILITY
......... . ............. . .. . ..... . .. . .. . ....... . ..... . .................................. 3 H. ADHERENCE TO APPLICATION AND COMPLIANCE WITH OTHER ENVIRONMENTAL LAWS
..................... ..........3 I
. BINDING APPLICATION
. ....... . .. . .. . .. . ..... . .. . . . .. . .. . . . .. . ................................... 4 

### J. ENFORCEABILITY OF PERMIT
................................................................. 4 K. TREATMENT OF EMISSIONS
.......................... . ...... .... .... .. .................. .. ......4 III. SPECIAL PERMIT CONDITIONS
........................ . ................. .. .......... ... .......5 A. POINT SOURCE EMISSION LIMITS
.............. . ..... . ..... . .... . . . ........ . ......... . .. .. . .. 5 B. REQUIREMENTS FOR COMBUSTION TURBINES
.... ......................................6 1. 

### COMPLIANCE WITH COMBUSTION TURBINE (CT) BACT EMISSION LIMITS
........................................................... 6 2. C02 EMISSION MONITOR OR C02 CEMS
..........................................7 3. 

### COMBUSTION TURBINE WORK PRACTICE AND OPERATIONAL REQUIREMENTS
.....................................................7 C. REQUIREMENTS FOR AUXILIARY COMBUSTION EQUIPMENT
. . .. .. . .. .. . .. . .. .8 D. FUGITIVE EMISSION SOURCES
...................... ............... .. ..... . .....................8 1. 

### FUGITIVE EMISSION SOURCES EMISSION LIMITS
.............................8 2. FUGITIVE EMISSION SOURCES WORK PRACTICE AND OPERATIONAL REQUIREMENTS
..............................8 IV. RECORDKEEPING REQUIREMENTS ······· : ··················· · ·····························9 V. STACK TESTING AND FUEL SAMPLING REQUIREMENTS
.....................................................................................

### lO VI
. AGENCY NOTIFICATIONS
........................... .. ........................................... 12

### BACT bhp Btulhr Cat Ox CEMS CFR CGS 

## Cf4 CLF&P 

## co C02 C02e dscf EP FIP FR FTIR GC-FID GE GHG gr HHV hr HRSG kWh lb lbpy MMBtu/hr 

### MW MWh N20 NSPS 

### NOx PSD PTE 

### QAJQC RATA Scflhr SCR SF6 tpy 

## voc % 

## Table of Acronym s Best Available Control Technology Brake Ilorse Power British Thennal Units per Hour Catalytic Oxidation Continuous Emission Monitoring System Code ofFederal Regulations Cheyenne Generating Station Methane Cheyenne Light, Fuel & Power Carbon Monoxide Carbon Dioxide Carbon Dioxide Equivalent Dry Standard Cubic Foot Emission Point Federal Implementation Plan Federal Register Fourier Transfonn Infra-Red Spectroscopy Gas Chromatogra ph-Flame Ionization Detector General Electric Greenhouse Gas 

### Grains High Heating Value I 

### lour Heat Recovery Steam Generator Killowatt-Hour Pound Pounds Per Year Million British Thermal Units per Hour Megawatt Megawatt-Hour Nitrous Oxide New Source Performance Standards Nitrogen Oxides Prevention of Significant Deterioration Potential to Emit Quality Assurance and/or Quality Control Relative Accuracy Test Audit Standard Cubic Feet per Hour Selective Catalytic Reduction Sulfur Hexafluoride Tons Per Year Volatile Organic Compounds Percent

### I. INTRODUCTION This Federal PSD permit is being issued under authority of 40 CFR 52.21 (PSD) and 52.37 (FIP to issue permits under the PSD requirements to sources that emit GHG). Cheyenne Light, Fuel & Power and Black Hills Power, Inc., (hereinafter the "Permittee") proposes to construct a new nominal 220 MW gross simple and combined cycle natural gas -tired combustion turbine power plant in Laramie County, Wyoming. The plant, the Cheyenne Prairie Generating Station, will be located five miles southeast of downtown Cheyenne along Interstate 80. Cheyenne Light, Fuel and Power, as well as Black Hills Power, Inc
. , are wholly owned subsidiaries ofBlack Hills Corporation. Cheyenne Light, Fuel and Power was acquired from Xcel Energy in 2005. Cheyenne Light, Fuel and Power Company provides electric utility service to Laramie County, Wyoming. The Cheyenne Prairie Generating Station will be operated by Black Hills Service Company and will include three simple cycle General Electric LM6000 PF SPRINT natural gas turbines , and two General Electric LM6000 PF SPRINT turbines operated in a 2-on-1 combined cycle configuration (each turbine exhausts to its own heat recovery steam generator (HRSG) and that steam is routed to a single steam turbine electric generator). In addition to the turbines the facility will include one wet cooling tower for the combined cycle steam turbine; three electric chiller units, each with cooling towers, for inlet air cooling for the turbine inlet ai r; six natural gas-fired inlet air heaters to heat the turbine inlet air, two natural gas-fired fuel gas heaters, one diesel emergency generator, and one diesel fire pump. 

### TI. GENERAL PERMIT CONDITIONS On the basis offindings set forth in Section III Special Permit Condition s, ofthis permit, and pursuant to the author it

y (as delegated by the Administrator) of52.2l(u) , EPA hereby conditionally aut horizes Black Hills Corporation to construct the Cheyenne Prairie Generating Station. The authorization is expressly conditioned as follows: 

### A. PERMIT EFFECTIVE DATE AND EXPIRATION As provided in 40 CFR 124.15 (b ), this PSD permit shall become effective 30 days after the service of notice ofthe p ermit decision, unless: 1. A later effective date is specified in the decision; 2. Review is requested on the permit under§ 124.19; or 

### 3. No comments requested a change in the draft permit, in which case the permit shall become effective immediately upon issuance. As provided in 40 CFR 52.2l(r), this PSD Permit shall become invalid ifconstruction: 

### 1

### 1. Is not commenced (as defined in 40 CFR §52.21(b)(9)) within 18 months after the approval takes effect; or 2. Is discontinued for a period of 18 months or more; or 3. Is not completed within a reasonable time; and 4. EPA may extend the 18 month period upon a satisfactory showing that an extension isjustified. 

### B. PERMIT NOTIFICATION REQUIREMENTS The Permittee shall notify EPA in writing of: 

### 1. The date construction is commenced, postmarked within 30 days ofsuch date; 2. The actual date ofinitial startup, postmarked within 15 days ofsuch date. Startup means the setting in operation ofan affected facility for any purpose; 3. The date upon which initial performance tests will commence, postmarked not less than 30 days prior to such date
. Notification may be provided with the submittal ofthe performance test protocol required pursuant to Condition V
.B
. ; and 4. The date upon which certification tests ofthe C02 and flow rate CEMS will commence, in accordance with 40 CFR 75.61(a)(l)(i) and 40 CFR Part 60, Appendix B, Performance Specification 3 (ifthe Permittee elects to use CEMS to demonstrate compliance with the lb C02eiMWh emission limit). Additionally, the initial certification or recertification application shall be submitted for the C02 CEMS (ifused) as required by 40 CFR 75.63. 

### C. FACILITY OPERATION At all times , including periods of startup, shutdown, and malfunction, Permittee shall maintain and operate the facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing GHG emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the EPA, which may include, but is not limited to, monitoring results , review ofoperating maintenance procedures and inspection of the facility. 

### D. MALFUNCTION REPORTING 1. The Permittee shall notify EPA by mail within two working days following the discovery of any failure of air pollution control equipment, process equipment, or ofa process to operate in a normal manner, which results in an increase in C02 e emissions above the allowable emission limits stated in Condition liLA., ofthis permit. 

### 22. In addition, the Permittee shall notify EPA in writing within 15 days of any such failure described under Section IV Recordkeeping Requirements
. This notification shall include a description ofthe malfunctioning equipment or abnormal operation, the date of the initial malfunction, the period of time over which emissions were increased due to the failure, the cause ofthe failure, the estimated resultant emissions in excess of those allowed in Condition III.A., and the methods utilized to mitigate emissions and restore normal operations. 3. Compliance with this malfunction notification provision shall not excuse or otherwise constitute a defense to any violation ofthis permit or any law or regulation such malfunction may cause. 

### E. RIGHT OF ENTRY EPA authorized representatives, upon the presentation ofcredent ials, shall be permitted: 1. To enter the premises where the facility is located or where any records are required to be kept under the terms and conditions ofthis PSD Permit; 2. During normal business hours, to have access to and to copy any records required to be kept under the terms and conditions ofthis PSD Permit; 3. To inspect any equipment, operation, or method subject to requirements 

### in this PSD Permit; and 4. To sample materials and emissions from the source(s). 

### F. TRANSFER OF OWNERSillP In the event ofany changes in control or ownership of the facilities to be constructed under this permit, this PSD Permit is binding on all subsequent owners and operators. The Permittee shall notify, by letter, the succeeding owner and operator ofthe existence of this PSD Permit and its conditions. A copy of the letter shall be provided to EPA within 

### 30 days ofthe letter sign ature. Permit transfers shall be made 

### in accordance with 40 CFR Part 122, Subpart D. 

### G. SEVERABILITY The provisions ofthis PSD Permit are severable, and, ifany provision ofthe PSD Permit is held invalid, the remainder ofthis PSD Permit shall not be affected. 

### H. ADHERENCE TO APPLICATION AND COMPLIANCE WITH OTHER ENVIRONMENTAL LAWS The Permittee shall construct and operate this project in compliance with this PSD Permit, the application on which this permit is based, and all other applicable federal, state, and local air quality regulations. This 

### 3PSD permit does not release the Permittee from any liability for compliance with other applicable federal, state and local environmental laws and regulations, including the Clean Air Act. I. BINDING APPLICATION This permit is issued in reliance upon the accuracy and completeness of the information set forth in the Permittee ' s application to EPA dated September 23, 2011, and subsequent information provided by the Permittee to EPA, as listed in the Administrative Record for issuance ofthis permit. The Permittee shall abide by all representations, statements of intent and agreements contained in the permit application and subsequent submittals as listed in the Administrative Record. EPA shall be notified no less than 10 d'ays in advance ofany significant deviation from the permit application as well as any plans, specifications or supporting data furnished. The issuance ofthis PSD Permit to Construct and Operate may be suspended or revoked ifEPA determines that a significant deviation from the permit application, specifications, and supporting data furnished has been, or is to be, made. 

### J. ENFORCEABILITY OF PERMIT On the effective date ofthis permit, the conditions herein become enforceable by EPA pursuant to any remedies it now has or may have in the future, under the Clean Air Act. K. TREATMENT OF EMISSIONS Emissions in excess of the limits specified in this permit shall constitute a violation.

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### III. SPECIAL PERMIT CONDITIONS A
. POINT SOURCE EMISSION LIMITS At all times , including during startup, shutdown and malfunction, the Permittee shall not allow the discharge ofGHG emissions from each unit into the atmosphere, in excess of the following: Table 1: E mission Limits Source 

### ID. Emission Point/Equipment Limitations lb/MWh limitations are based on rolling 365-day averages tpy limitations are b11sed on rolling 365-dlly totals all references to tons represent US short tons (20001b) EPOt

- EP02 CTOlA and CTOIB- 

## • 11 00 I b C02 c/MWh(gross) per turbine GE LM6000PF SPRI NT 

## • 187 ,3 1 8 tpy C02c per turbine Combined Cycle Combustion 

## • Fuel: pipeline quality natural gas Turbine (366 MMBtu/hr) with HRSG # 1, SCR and CatOx EP03- EP05 CT02A, CT02B , CT03A

- 

## • 1600 lb C02ciMWh(gross) per turbine GE LM6000PF SPRINT Simple 

## • 187,3 18 tpy per turbine Cycle Combustion Turbine (366 

# • Fuel: pipeline quality natural gas MMBtulhr) with SCR and Ca tOx EP06- EPII Natural Gas-Fired Inlet Air 

# • 4 , 117 tpy C02e per heater Heaters # 1

- #6 

## • Fuel: pipeline quality natural gas EP12- EP14 Inlet Air Chillers NIA EP15 Diesel Emergency /Standby 

## • 226 tpy C0 2e Genera tor 

## • Not to exceed 500 hours ofoperation per 12-month period 

## • EPA Tier 2 (or Better) Certified Engine 

## • Rated**at ~**  839 bhp 

## • Diesel fuel (#2 grade fuel oil) EP16 Diesel Fire Pump Engine 

# • 51 tpy C02 c 

## • Not to exceed 250 hours of operation per 12-month period 

## • EPA Tier 3 (or Better ) Certified Engine 

## • Rated at _:s 327 bhp 

## • Diesel fuel (#2 grade fuel oil) EPI7 Wet Cooling Tower N/A EP18- EP19 Natural Gas -Fired Fuel Gas 

## • 1 , 153 tpy C 0 2e per heater Heater # I and #2 

## • Fuel: pipeline quality natural gas

5B. REQUIREMENTS FOR COMBUSTION TURBINES 1. Compliance with Combustion 'fur bine (CT) BACT Emission Limits
a . The Permittee shall demonstrate compliance with the lb C02 e/MWh(gross) emission limits for each ofthe CT's (Units EPOl

- EP05) as follows
. 1. The Permittee shall calculate the pounds ofC02 emitted hourly using the procedure provided in 40 CFR 75.10(a)(3)(i) (direct emission measurement using CEMS) or using the procedure provided in 40 CFR 75.1 O(a)(3)(ii) (calculation ofC02 emissions using the equations from 40 CFR 75, Appendix G, using Fe factors updated monthly from fuel analysis) , and sum the hourly emissions for each calendar day. ii. The Permittee shall calculate the pounds ofCRt and N 2 0 emitted each calendar day by using the default CI-Lt and N20 emission factors contained in Table C-2 of40 CFR 98 and the measured actual hourly heat input (HHV). The Permittee shall then calculate the pounds of C02e (as Cfu and N20) based on the procedures contained in Greenhouse Gas Regulations, 40 CFR 98, Subpart A using the Global Warming Potentials (GWP) listed in Table A

- 1 of40 CFR 98, Subpart A. iii
.The Permittee shall sum the daily emissions from Condition III.B.l.a.i
. , and ii (in pounds ofC02e). iv. The Permittee shall also measure the hourly gross electrical output in terms ofMWh for each hour.
v . At the end ofeach calendar day the Permittee shall sum the pounds ofC02c emitted that day with the emissions from the previous 364 days, and sum th e hourly gross output during the same 365 day period. The average lb C02e/MWh result for the 365-day period is obtained by dividing the total pounds C02e emissions value by the total gross energy output (MWh(gross)) value. The result shall be expressed in lbs C02eiMWh(gross), on a 365-day rolling average. b. The Permittee shall demonstrate compliance with the tons per year (tpy) emission limits for each ofthe CT's (Units EPOl- EP05) as follows.
1. The Permittee shall calculate the pounds of C02eemitted each calendar day using the procedures in Condition III
.B
. l.a.i through iii above, and convert the result into tons. ii
. At the end ofeach calendar day, the Permittee shall sum the tons ofC02e emitted that day with the tons of C02 e emitted from the prev ious 364 days , and record the 365-day total.



### 62. C02 Emission Monitor or C02 CEMS
a. If the Permittee elects to follow the procedure from 40 CFR 75.10(a)(3)(i) , which involves installation, certification, operation and maintenance of a C02 CEMS and flow monitoring system, the Permittee shall meet the applicable CEMS requirements, including certification testing , of40 CFR Part 60, Appendix B , Performance Specification 3 , and 40 CFR Part 75. b. In accordance with 40 CFR 75.4(b)(2), the Permittee shall ensure that all required C02 monitoring system/equipment are installed, and all certification tests are completed, on or before 180 calendar days after the date the unit commences commercial operation (as defined in 40 CFR 72.2).
c. The Permittee shall comply with the specifications and test procedures for C02 CEMS at 40 CFR 75.13 and related requirements in Appendices A, B and G of40 CFR Part 75. 3. Combu stion Turbine Work Practice and O p erational Requirements
a. The Permittee shall determine the gross calorific value ofthe fuel monthly using the procedures contained in 40 CFR Part 75, Appendix F, § 5.5.2 , and shall maintain records ofthe monthly fuel gross calorific value for a period of five years. Upon request by EPA, the Permittee shall provide a sample and/or analysis ofthe fuel fired in the CT's , or shall allow a sample to be taken by EPA for analysis. b. The Permittee shall install, maintain and operate an elapsed flow meter, to measure the flow rate ofthe fuel combusted in emission units EP01-EP05.
c. The Permittee shall measure and record the gross energy output (MWh(gross)) on an hourly basis.

7

### C. REQUIREMENTS FOR AUXILIARY C OMBUSTION EQUIPMENT 1. The Permittee shall install, maintain and operate a non-resettable elapsed time meter for the Diesel Emergency/Standby Generator (EP15) and the Diesel Fire Pump Engine (EP16). Compliance with the hours of operation limitations, fuel grade limitation, and brake-horsepower limitations, listed i n Condition liLA. , Table 1, for Units EP15 and EP16 shall constitute compliance with the tpy C02e emission limitations also listed in Condition liLA., Table 1 for these units. 2. The Permittee shall maintain a file ofall records, data measurements, reports and documents related to the operation ofthe diesel fired engin es , EP 15 and EP 16, as necessary to show compliance with the limitations in Condition liLA
. This may include, but is not limited to, the following: all records or r eports pertaining to maintenance performed; hours ofoperation; and, for each diesel fuel oil delivery, documents from the fuel supplier certifying compliance with the limitation to burn diesel fuel in Condition liLA. , recorded in a permanent form suitable for inspection. The Permittee must retain the records for not less than five years following the date of such measurements, maintenance, reports , and/or records. 

### D. FUGITIVE EMISSION SOURCES 1. Fugitive Emission Sources Emission Limits At all times the Permittee shall not discharge from the source, or cause the discharge, of fugitive emissions from each unit into the atmosphere in excess ofthe following:
a e 

# . ugatlve IDISSIOn ources IDISSIOn a mats 

# . T bl 2 F E
.. S 

### E
.. L
.. Unit ID. No. Unit Description GHG Pollutants Mass Basis) GHG C02e Pollutant TPY TPY NG-FUG Fugitive natural gas emissions CH4 16 336 from valves, flanges and on site compressor SF6 -FUG t through 9 SF6circuit breakers SF6 0.0027 64.5 SF6 -FUG9 60 lbs SF 6 each breaker (5.4 lbpy) 1% SF6 1eak rate or bett er With leak detection 2
. Fugitive Emission Sources Work Practice and Operational Requirements
a. For CH4 emissions from sources NG-FUG, emissions shall be calculated by the Permittee annually (calendar year). Emissions shall be calculated based on the emission factors from Table W-lA of40 CFR Part 98, Subpart W , Petroleum and Natural Gas Systems. b. For SF6 emissions from sources SF6

-FUGI through SF6 -FUG9, emissions shall be calculated by the Permittee annually (calendar year) in accordance with the mass balance approach provided in equation DD-1 ofthe Mandatory Greenhouse Gas Reporting Rule for Electrical Transmission and Distribution Equipment Use, 40 CFR Part 98, Subpart DD. 

### 8c. The Permittee shall maintain a file of all records, data measurements, r eports and documents related to the fugitive emissions sources (NG

-FUG and SF6-FUG1 through SF6-FUG9) including, but not limited to , the following: all records or reports pertaining to maintenance performed, equipment replacement, and all records relating to compliance with the Monitoring and Quality Assu rance and Quality Control (QA/QC) procedures outlined in 40 CFR 98.304. 

### IV. RECORDKEEPING REQUIREMENTS A. ln addition to any recordkeeping requirements spec ified elsewhere in this permit, the Permittee s hall maintain a record of all data, measurements , calculations, reports , and documents related to the operation ofany systems or devices that could affect the ability ofthe Permittee to comply with the limitations in Condition liLA., Table 

### 1., including, but not limited to, the following: all records or reports pertaining to s ignificant maintenance performed on any s uch systems or devices, recorded in a permanent form suitable for inspection. The records must be retained for not less than five years following the date ofsuch measurements, maintenance, reports, and/or records. 

### B. The Permittee shall maintain the following records for at least five years, including:



# c. 1. The occurrence and duration of any startup, shutdown, malfunction; 2. Stack testing (including stack test results, and stack test reports) conducted under Condition V .A.; 3. CEMS emission measurements ifthe CEMS compliance option under 40 CFR 75.10(a)(3)(i) is u sed; 4. CEMS testing, maintenance, and calibration checks conducted to satisfy quality assurance requirements ifthe CEMS comp liance option under 40 CFR 75.10(a)(3)(i) is used; 5. The time and duration of any periods that monitoring devices are not operating; and 6. Any emission data required by this permit. The Permittee shall maintain records ofall GHG emission units and C02 emission CEMS certification tests and monitoring and compliance information required by this permit. 

### D. The Permittee shall maintain records of any exceedance of limitations in this permit and submit a written report of all exceedances to EPA semi-annually, except when: more frequent reporting is specifically required by an applicable subpart; or the Admini strator of authorized representative, on a case-by-case basis, determines that more frequent reporting is necessary to accurately assess the compliance status of the source. The report is due on the 30th day following the end of each semiannual period and shall include the following:



### 9 •1. Time intervals , data and magnitude ofthe cxceedance, the nature and cause (if known), corrective actions taken and preventative measures adopted; 2. Applicable time and date ofeach period during which the monitoring equipment was inoperative (monitoring down-time); 

### 3. If no exceedances of a permit limit occurred during the reporting period or the monitoring equipment has not been inoperative, repaired or adjusted, a statement that no exceedance ofthat limit occUTied, and/or that the monitoring equipment has not been inoperative, repaired or adjusted (as applicable), shall be submitted; 4. Any failure to conduct any requir , ed source testing, monitoring , or other compliance activities; and 5. Any violation of limitations on operation, including but not limited to restrictions on hours of operation of the emergency generator or fire pump. E. Exceedance shall be defined as any period in which the facility emissions or other parameter of operation exceed a maximum limit set forth in this permit. 

### F. Excess emissions indicated by GHG emission source certification testing or compliance monitoring shall be considered violations ofthe applicable emission limit for the purpose ofthis permit. G. All records required by this PSD Permit shall be retained for not less than five years following the date of such measurements, maintenance, and reports. 

### V. STACK TESTING AND FUEL SAMPLING REQUIREMENTS A. The Permittee shall conduct stack tests to establish the actual quantities of C02 being emitted into the atmosphere from one ofthe simple cycle CT's and from one ofthe combined cycle CT's. The testing shall be conducted by the deadline specified in Condition III.B.2.b
. Sampling shall be conducted in accordance with 40 CFR 60.8 and EPA Methods 3A or 3B for C02 concentration, Method 2, 2F or 2G (for stack gas volumetric flow rate), and Method 4 (for stack gas moisture content, ifneeded). The stack test shall consist ofthree separate runs. Each C02 test run shall be at least one hour in duration. Stack gas flow rate measurements, as well as moisture measurements (ifneeded), shall be made during each test run. The gross electrical load (megawatts) during each test run shall be recorded. The C02 emission rate shall be calculated and recorded for each test run in lb C02 /MWh(gross). The arithmetic mean for the three test runs shall also be calculated and recorded. The Permittee shall submit a stack test report within 60 days ofcompletion oftesting.



### 10B. The Permittee shall submit a stack test protocol to EPA no later than 30 days prior to the test to allow review ofthe test plan and to arrange for an observer to be present at the test. The stack test shall be conducted by the Permittee in accordance with the submitted protocol, and any changes required by EPA. C. Fuel sampling for emission units EPOI

-EPOS shall be conducted by the Permittee in accordance with 40 CFR Part 75 and Part 98. D. Each CT tested by the Permittee shall be at or above 90% ofmaximum load operations. Tested turbine load shall be identified by the Permittee in the stack test report. E. The Permittee shall conduct stack tests under conditions that are representative ofnormal operation ofthe affected facility. The Permittee shall make available to the EPA such records as may be necessary to determine the conditions ofthe stack tests. F. The Permittee shall provide the EPA at least 30 days prior notice of any stack test, to afford the EPA the opportunity to have an observer present. Ifthere is a delay in the original test date, the Permittee must provide at least 7 days prior notice ofthe rescheduled date of the stack test unless unavoidable circumstances (e.g. inclement weather, plant outage) result in cancellation ofthe test. G. The Permittee shall provide, or cause to be provided, stack testing facilities as follows: 1. Sampling ports adequate for test methods applicable to this facility; 2. Safe sampling platform(s); 

### 3. Safe access to sampling platfonn(s); and 4. Utilities for samp ling and testing equipment.



### 11VI. AGENCY NOTIFICATIONS The Permittee shall submit GHG permit applications , permit amendments , and other applicable permit information to: Air Program (8P-AR) US EPA Region 8 1595 Wynkoop St. Denver, CO 80202 The Permittee shall submit a copy ofall compliance and enforcement correspondence as required by this permit to: Air Technical Enforcement Program (8ENF-AT) US EPA Region 8 1595 Wynkoop St. Denver, CO 80202

Authorized By: United States Environmental Protection Agency, Region 8

Assistant Regional Admin istrator Office ofPartnerships and Regulatory Assistance



### 12