United States Environmental Protection Agency 

Region 8 

Air Program 

1595 Wynkoop Street 

Denver, Colorado 80202-1129 

September 27, 2012 

Final 

Air Pollution Control 

Prevention of Significant Deterioration (PSD) 

Permit to Construct 

PSD-WY-000001-2011.001 

Permittee: 

Owner: Cheyenne Light, Fuel & Power I Black Hills Power, Inc. 

Operator: Black 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 Acronyms 

Best Available Control Technology 

Brake I lorse Power 

British Thennal Units per Hour 

Catalytic Oxidation 

Continuous Emission Monitoring System 

Code of Federal 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 Chromatograph-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 of Black 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 air; 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 of findings set forth in Section III Special Permit Conditions, ofthis permit, and pursuant to the 

authority (as delegated by the Administrator) of52.2l(u), EPA hereby conditionally authorizes 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 

of the permit 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 if construction: 

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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 is justified. 

B. PERMIT NOTIFICATION REQUIREMENTS 

The Permittee shall notify EPA in writing of: 

1. The date construction is commenced, postmarked within 30 days of such date; 

2. The actual date of initial startup, postmarked within 15 days of such date. Startup means the setting 

in operation of an 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 of the performance test protocol 

required pursuant to Condition V.B.; and 

4. The date upon which certification tests of the 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 (if the 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 (if used) 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 of operating 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 of a process to operate in a normal 

manner, which results in an increase in C02e emissions above the allowable emission limits stated in 

Condition liLA., of this permit. 

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2. 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 of the 

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 of the 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 of this permit or any law or regulation such malfunction may cause. 

E. RIGHT OF ENTRY 

EPA authorized representatives, upon the presentation of credentials, 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 of this 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 of this 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 of any 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 of the existence of this PSD Permit and its conditions. A copy of the letter 

shall be provided to EPA within 30 days of the letter signature. Permit transfers shall be made in accordance 

with 40 CFR Part 122, Subpart D. 

G. SEVERABILITY 

The provisions of this PSD Permit are severable, and, if any provision of the PSD Permit is held invalid, the 

remainder of this 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 

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PSD 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 of this 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 of any significant deviation from the permit application as well as any plans, 

specifications or supporting data furnished. The issuance of this PSD Permit to Construct and Operate may 

be suspended or revoked if EPA 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 of this 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: Emission 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 C02c /MWh(gross) per turbine 

GE LM6000PF SPRINT • 187,3 18 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 • 187,318 tpy per turbine 

Cycle Combustion Turbine (366 • Fuel: pipeline quality natural gas 

MMBtulhr) with SCR and CatOx 

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 C02e 

Generator • Not to exceed 500 hours of operation 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 C02c 

• 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 C0 2e per heater 

Heater # I and #2 • Fuel: pipeline quality natural gas 

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B. REQUIREMENTS FOR COMBUSTION TURBINES 

1. Compliance with Combustion 'furbine (CT) BACT Emission Limits 

a. The Permittee shall demonstrate compliance with the lb C02e/MWh(gross) emission limits for 

each ofthe CT's (Units EPOl- EP05) as follows. 

1. The Permittee shall calculate the pounds of C02 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 of C02 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 of CRt and N20 emitted each calendar day by 

using the default CI-Lt and N20 emission factors contained in Table C-2 of 40 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 of 40 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 of each calendar day the Permittee shall sum the pounds of C02c emitted that 

day with the emissions from the previous 364 days, and sum the 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 

of the CT's (Units EPOl- EP05) as follows. 

1. The Permittee shall calculate the pounds of C02e emitted 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 of each calendar day, the Permittee shall sum the tons ofC02e emitted that day 

with the tons of C02e emitted from the previous 364 days, and record the 365-day total. 

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2. 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, of 40 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 of 40 CFR Part 75. 

3. Combustion Turbine Work Practice and Operational Requirements 

a. The Permittee shall determine the gross calorific value of the fuel monthly using the procedures 

contained in 40 CFR Part 75, Appendix F, § 5.5.2, and shall maintain records of the monthly fuel 

gross calorific value for a period of five years. Upon request by EPA, the Permittee shall provide 

a sample and/or analysis of the 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 

of the fuel combusted in emission units EP01-EP05. 

c. The Permittee shall measure and record the gross energy output (MWh(gross)) on an hourly 

basis. 

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C. REQUIREMENTS FOR AUXILIARY COMBUSTION 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 in 

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 of all records, data measurements, reports and documents related 

to the operation of the diesel fired engines, 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 reports pertaining to maintenance performed; hours of operation; 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 of the following: 

a e . T bl 2 F . ugatlve E IDISSIOn ources IDISSIOn a mats .. 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 SF6 circuit breakers SF6 0.0027 64.5 

SF6-FUG9 60 lbs SF6 each breaker (5.4 lbpy) 

1% SF61eak rate or better 

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 of 40 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 of the Mandatory Greenhouse Gas Reporting Rule for Electrical Transmission 

and Distribution Equipment Use, 40 CFR Part 98, Subpart DD. 

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c. The Permittee shall maintain a file of all records, data measurements, reports 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 Assurance and Quality Control (QA/QC) procedures outlined in 40 CFR 98.304. 

IV. RECORDKEEPING REQUIREMENTS 

A. ln addition to any recordkeeping requirements specified elsewhere in this permit, the Permittee shall 

maintain a record of all data, measurements, calculations, reports, and documents related to the 

operation of any systems or devices that could affect the ability of the Permittee to comply with the 

limitations in Condition liLA., Table 1., including, but not limited to, the following: all records or 

reports pertaining to significant maintenance performed on any such 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 of such 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 if the CEMS compliance option under 40 CFR 75.10(a)(3)(i) is used; 

4. CEMS testing, maintenance, and calibration checks conducted to satisfy quality assurance 

requirements if the CEMS compliance 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 of all 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 Administrator 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 of the cxceedance, the nature and cause (if known), corrective 

actions taken and preventative measures adopted; 

2. Applicable time and date of each 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 of that 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 of the applicable emission limit for the purpose of this 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 of the simple cycle CT's and from one of the 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, if needed). 

The stack test shall consist of three separate runs. Each C02 test run shall be at least one hour in 

duration. Stack gas flow rate measurements, as well as moisture measurements (if needed), 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 of completion oftesting. 

10 
B. The Permittee shall submit a stack test protocol to EPA no later than 30 days prior to the test to 

allow review of the 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% of maximum 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 of normal operation 

of the affected facility. The Permittee shall make available to the EPA such records as may be 

necessary to determine the conditions of the 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. If there is a delay in the original test date, the Permittee 

must provide at least 7 days prior notice of the rescheduled date of the stack test unless unavoidable 

circumstances (e.g. inclement weather, plant outage) result in cancellation of the 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 sampling and testing equipment. 

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VI. 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 of all 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 Administrator 

Office of Partnerships and Regulatory Assistance 

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