PERMITTEE: 

FACILITY NAME: 

FACILITY LOCATION: 

Golden Spread Electric Cooperative, Inc. 

P.O. Box 9898 

Amarillo, TX 79105 

Antelope Elk Energy Center 

1454 CR 315 

Abematl}y, TX 793 1! 

Pursuant to the provisions of the Clean Air Act (CAA), Subchapter I, Part C (42 U.S.C. § 7470, 

et seq.), and the Code of Federal Regulations (CFR) Title 40, Section 52.21, and the Federal 

Implementation Plan at 40 CFR § 52.2305 (effective May 1, 201 l and published at 76 FR 

25 178), the U.S. Environmental Protection Agency, Region 6 is issuing a Prevention of 

Significant Deterioration (PSD) permi1t to Golden Spread Electric Cooperative, Inc. for 

Greenhouse Gas (GHG) emissions from its proposed Antelope Elk Energy Center. The permit 

applies to the addition of one natural gas-fired simple-cycle combustion turbine, a diesel-fired 

emergency generator, a natural gas-fired fuel gas heater, circuit breakers and fugitive emissions 

at an existing facility located near Abernathy, Texas. 

Golden Spread Electric Cooperative is authorized to construct one new natural gas-fired simple 

cycle combustion turbine, a diesel-fired emergency generator, a natural gas-fired fuel gas heater, 

circuit breakers and fugitive emissions as described herein, in accordance with the permit 

application (and plans submitted with the permit application), the federal PSD regulations at 40 

CFR § 52.21, and other terms and conditions set forth in this PSD permit in conjunction with the 

corresponding Texas Commission on Enviromnental Quality (TCEQ) permit No. PSDTX1358. 

Failure to comply with any condition or term set forth in this PSD permit may result in 

enforcement action pursuant to Section 113 of the CAA. This PSD permit does not relieve 

Golden Spread Electric Cooperative of the responsibility to comply with any other applicable 

provisions of the CAA (including applicable implementing regulations in 40 CFR Parts 51 , 52, 

60, 61, 72 through 7 5, and 98) or other federal and state requirements (including the state PSD 

program that remains under approval at 40 CFR § 52.2303). 
Golden Spread Electric Cooperative, Inc. (GSEC) is proposing to add one new natural gas-fired 

simple cycle combustion turbine with 202 MW gross electric generating capability (maximum 

production capacity) to its existing 168 MW electric generating station, Antelope Elk Energy 

Center. In addition to the turbine, the ]project also includes the installation of an emergency 

diesel-fired generator, a gas-fired fuel gas heater, circuit breakers and fugitive emissions 

associated with the proposed project to meet peak and intermediate load requirements. 

EQUIPMENT LIST 

The following devices are subject to this GHG PSD permit: 

FIN EPN Description 

TURBl TURB1 One 202 (maximum gross) MW natural gas-fired simple cycle 

GE 7F 5-Series Combustion Turbine Generator. 

One diesel-fired generator (not to exceed 1,656 kW). In 

EMERGEN EMEGEN addition to emergency operations, the unit is limited to 100 hrs 

per 12-month rolling basis for non-emergency operations. 

NGHEATR-2 NGHEATR-2 One natural gas-fired fuel gas heater (5.5 million BTU (HHV)/hr fired capacity). 

SF6-FUG SF6-FUG Fugitive SF6 circuit breaker emissions. 

NG-FUG NG-FUG Fugitive emissions from various natural gas piping components. 

I. GENERAL PERMIT CONDIITIONS 

A. PERMIT EXPIRATION 

As provided in 40 CFR § 52.21 (r), this PSD permit shall become invalid if construction: 

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. 

Pursuant to 40 CFR § 52.2l(r), EPA may extend the 18-month period upon a written 

satisfactory showing that an extension is justified. 
3. date upon which initial performance tests will commence, in accordance 

with the provisions of Section V, postmarked not less than 30 days prior to 

such date. Notifi.cation may be provided with the submittal of the 

performance tesll protocol required pursuant to Condition V.B. 

C. FACILITY OPERATUON 

At all times, including periods of startup, shutdown, and maintenance, Permittee 

shall, to the extent practicable, maintain and operate the facility including 

associated air pollution control equipment in a manner consistent with good air 

pollution control practice for minimizing emissions. Determination of whether 

acceptable operating and maintenance procedures are being used will be based on 

information available to EPA, which may include, but is not limited to, 

monitoring results, revic::w of operating maintenance procedures and inspection of 

the facility. 

D. MALFUNCTION REJPORTING 

1. Permittee shall notify EPA by mail, or other means identified by EPA, 

within 48 hours 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 GHG emissions above the 

allowable emission limits stated in Section II and III of this permit. 

2. Within 1 0 days of the discovery of any GH G emissions above the 

allowable emission limits resulting from malfunctions as described in 

I. D .1., shall provide a writ1en supplement to the initial 

notification that includes 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 

Section II and HI, and the methods utilized to mitigate emissions and 

restore normal c1perations. 

3. Compliance with this malfunction notification provision shall not excuse 

or otherwise constitute a defense to any violation of this permit or any Jaw 

or regulation such malfunction may cause. 

E. RIGHT OF ENTRY EPA authorized representatives, upon the presentation of credentials, shall be permitted: 
4. to sample materiials and emissions from the source(s). 

F. TRANSFER OF OWNERSHIP 

In the event of any changes in control or ownership of the facilities to be constructed, this 

PSD permit shall be binding on all subsequent owners and operators. Permittee shall 

notify the succeeding owner and operator of the existence of the PSD permit and its 

conditions by letter; a copy of the letter shall be forwarded to EPA Region 6 within 30 

days of the letter signature. · 

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 

Permittee shall construct 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 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. 
CEMS 

CFR 

CH4 

C02 

C02e 

dscf 

EF 

EPN 

FfN 

FR 

GCV 

GHG 

gr 

GWP 

HHV 

hr 

lb 

LDAR 

MMBtu 

MSS 

N20 

NSPS 

PSD 

QA/QC 

SCFH 

SCR 

SF6 

TAC 

TCEQ 

TPY 

usc 

Continuous Emissions Monitoring System 

Code of Federal Regulations 

Methane 

Carbon Dioxide 

Carbon Dioxide Equivalent 

Dry Standard Cubic Foot 

Emission Factor 

Emission Point Number 

Facility Identification Number 

Federal Register 

Gross Calorific Value 

Greenhouse Gas 

Grains 

Global Warming Potential 

High Heating Value 

Hour 

Pound 

Leak Detection and Repair 

Million British Thermal Units 

Maintenance, Start-up and Shutdown 

Nitrous Oxides 

New Source Performance Standards 

Prevention of Significant Deterioration 

Quality Assurance and/or Quality Control 

Standard Cubic Feet per Hour 

Selective Catalytic Reduction 

Sulfur hexafluoride 

Texas Administrative Code 

Texas Commission on Environmental Quality 

Tons per Year 

United States Code 
COvMW

hr (gross) on a 

CH4 125.00 4,572 rolling operational 

Natural Gas 

hour average basis. 

TURS I TURSI Fired-Simple 539,094 -Not to exceed 4,572 hours 

Cycle Turbine 

of operation (including 

N20 13.30 startups and shutdowns) on a 12-month rolling total basis. 

-See permit condition lll.A.2 

and 4. 

C02 128.00 - Not to exceed 100 hours of 

non-emergency operation 

on 

Emergency CH4 0.01 a I 2-month rolling total basis 

EMERGEN EMERGEN Diesel 128 -Use of Good Combustion 

Generator No Numerical Practices. See permit 

1'.:0 Limit condition lll.B. 

Established1 

C02 1479.00 - Not to exceed 4,572 

hours 

Natural Gas 

of operation on a 12-month 

NG

HEATR-2 NGHEATR-2 Fired Fuel Gas 

C

H4 O.oJ 1488 rolling total basis 

Heater - Use of Good Combustion 

N20 0.03 Practices. See permit condition lli.C. 

Fugitive SF6 No Numerical No Numerical Work Practices. See permit 

SF6-FUG SF6-FUG 

Circuit SF6 Limit Limit condition Ili.D. Breaker Established4 Established4 Emissions 

Components No Numerical No Num~t rical Implementation of AVO 

NG-FUG NG-FUG Fugitive Lea.k CH4 Limit Limit Program. See permit 

Emissions Established4 Established4 condition HI.E. 

C02 533,614.00 

CH4 129.10 

Totals5 540,978 

N20 13.33 

SF6 0.01 

. . 

.. I. fhe TPY emtss1on lil111ts spectfied m th1s table are not to be exceeded for th1s fact.hty and mclude emtsstons from the facthty 

during all operations and include MSS activitit:s. 

2. Global Warming Potentials (GW

P): COz=l, CH4 = 25, N20 = 298, SF6

=22,800 

3. No numerical limit established because emissions are 0.01 tons/yr or less. 

4. Fugitive Jea.k emissions from SF6-FUG and NG··FUG are estimated to be 0.0073 TPY SF6 and 166.44 TPY C02e from SF6-

FUG, ru1d 0.079 TPY C02, 4.07 TPY 

CH4, and 101 .83 TPY C02e from NG-PUG. In lieu of an emission limit, the emissions 

will be limited by implementing a design/work practice standard a~ specitled in the permit. 

5. Total emissions include the 

PTE for fugitive emissions. Totals are given for informational purposes only and do not constitute 

emission limits. 
2. Turbine BACT Requirements: 

a. The BACT limit of 1,3041bs ofC02/MW-hr gross output is based on a 4,572 

rolling operational hour average basis, calculated daily using equations for 

C02 provided in 40 CFR Part 75, Appendix G, Procedure 2.3 or the C02 

emissions CEMS data 40 CFR Part 75, Appendix F. The Permittee shall 

calculate each day a combustion turbine operates, C02 emissions over the 

rolling 4,572 hours of operation basis divided by gross electrical output over 

the same period fo1r compa_rison to the limit for the combustion turbine. 

b. The Permittee shall calculate, on a daily basis, the amount of C02e emitted 

from the turbine in tons per year based on the calculation of the C02 and the 

procedures and Global Warming Potentials (GWP) contained in the 

Greenhouse Gas Regulations, 40 CFR Part 98, Subpart A, Table A-1 for CH4 

and N20. Compliance shall be based on a 12-month rolling total basis. 

c. The total quantity of fuel used by the turbine sba11 not exceed 8,873,053 MM 

Btu (HHV) in any 12-month rolling total basis, including fuel used during 

startup and shutdo,..vn. For each day the combustion turbine operates, the 

Permittee shall cah::ulate the quantity of fuel used over the trailing 12-month 

rolling basis by multiplying the gross calorific value (GCV) ofthe fuel 

combusted by volUime of fuel metered for comparison to the annual fuel limit. 

d. The turbine is limited to 4,572 operational hours on a 12-month rolling total 

basis. 

3. Turbine Work Practke and Operational Requirements: 

a. The Permittee shall determine the pounds of C02 emitted hourly from the 

turbine using equation G-4 of 40 CFR Part 75, Appendix G and the hourly 

average heat rate using on the heat input calculation procedures contained 

in 40 CFR Part 75, Appendix F, equation F-20. The C02 emission factor 

used in the Appendix G calculation procedure may be the generic factor 

provided in equation G-4 or a factor based on fuel composition and GCV 

measurements according to 40 CFR Part 75, Appendix F, equation F-7b. 

b. The Permittee shall install, calibrate, and operate a fuel flow meter that is 

provjding fuel t1::> the combustion turbine. Permittee shall perform monthly 

fuel sampling and analysis to determine GCV. Permittee shall meet all 

applicable requirements, including certification testing as specified in 40 

CFR Part 75, AJppendix D and 40 CFR Part 60 to be used in conjunction 

with the Fe factor based on the procedures to calculate the C02 emission 

rate in 40 CPR Part 75, Appendix F. 
systems/equipment are installed and all certification tests are completed on 

or before the earlier of 90 unit operating days or 180 calendar days after 

the date the unit commences operation. 

e. The Pennitee sh.aU maintain the following records for at least five years 

from the date of origin: 

1. One-·hour C02 emission averages. 

ii. The results of all calibration and linearity checks, as applicable. 

111. Relative Accuracy Test Audit (RAT A) test plans and reports of 

test results, as applicable. 

f. The Permittee slhall ensure compliance with the applicable specifications 

and test procedures for a C02 emission measur

ement system at stationary 

sources in 40 CFR Part 75. 

g. The Permittee slhall calculate the pounds of C& and N20 emitted each 

calendar day by using either the emission factors used in the permit 

application or the 

default CH4 and N20 emission factors contained in 

Table C-2 of 40 CFR Part 98 and the measured actual hourly heat input 

(HHV). These daily emission determinations shall be rolled into 4,572 

rolling operational hour average totals to determine compliance with the 

limits in Table II and 2. 

h. For the turbine, fuel metering shall include: 

1. Measurement and recording of the natural gas flow rate using an 

operational non-resettable elapsed flow meter installed at the 

turbine inlet. 

11. Recording the total amount of fuel combusted for the turbine on 

an hourly basis. 

111. 

The fuel GCV, high heat value (HHV), carbon content, and, if 

applicable, molecular weight of the fuels shall be detennined 

monthly according to the procedures contained in 40 CFR 

§ 98..34(b)(3). Records of the fuel GCV shall be maintained for 

a minimum period of five years. Upon request, the Permittee 

shall provide a sample and/or analysis of the fuel that is ftred at 

the time of the request, or shall allow a sample to be taken by 

EPA for analysis. 

1. Permittee shall calibrate and perform preventative maintenance checks of 

the fuel gas flow meters and document annually. 

J. The gross energy output (MWh, gross) for the turbine shall be measured 

and recorded on an hourly basis. 

k. Permittee shall substitute data per the Missing Data Substitution 

Procedures specified under 40 CFR Part 75, Subpart D. 
i. A startup of the turbine is defined as the period that begins when 

fuel flow is initiated in the combustion turbine as indicated by 

flame detection and ends when the normal operating low-NOx 

combustion mode is achieved. A startup time is limited to a 

maximum of 30 minutes. 

11. A shutdown of the turbine is defined as the time period that begins 

when tht! combustion turbine drops out of the normal operating 

combustion mode following an instruction to shut down, 

and ends when a flame is no longer detected in the combustion 

turbine combustor. A shutdown event wili also end if the 

combustion turbine is instructed to return to normal operating lowNOx combustion operating mode and subsequently achieves 

normal operating low-NOx combustion mode. A shutdown is 

limited to a maximum of24 minutes. 

b. Emissions during each startup and shutdown activity as well as annual 

startup and shutdown activities shall be minimized by limiting the duration 

of operation in startup and shutdown mode as fo1lows: 

1. Startups and shutdowns are limited to no more than the limits 

stated in paragraph a. 

ii. No more: than 635 startup events and 635 shutdown events on a 12-

month rolling total basis. 

B. Requirements for the Emerg1ency Diesel Generator (EPN: EMERGEN) 

1. Fuel Specification: The fuel for the emergency generator is limited to ultra-low 

sulfur diesel (ULSD) fuel. 

2. Emergency Diesel Generator Work Practice and Operational Requirements: 

a. The emergency diesel generator shall not exceed 100 hours of nonemergency operation on a 12-month rolling basis and shall be operated 

and maintained in accordance with the manufacturer's recommendations. 

b . The Permittee shall install and maintain an operational non-resettable 

elapse time met·er for the emergency diesel generator. 

c. The Permittee s.hall install and maintain a non-resettable elapsed fuel flow 

meter for the emergency diesel generator. 

d. The emergency diesel generator shall meet the applicable requirements of 

40 CFR Part 60, Subpart IIII, Standards of Performance for Stationary 

Compression Ignition Combustion Engines. 
C. Requirements for the Natural! Gas-Fired Fuel Gas Heater (EPN: NGHEATR-2) 

1. Fuel Specification: The fuel for the fuel gas heater shall be pipeline quality 

natural gas. 

2. Fuel Gas Heater Work Practice and Operational Requirements: 

a. The fuel gas heater shall not exceed 4,572 hours of operation on a 12-

month ro!!ing basis and shall be operated and maintained in accordance 

with the manufacturer's recommendations. 

b. The Permittee shall install and maintain an operational non-resettable 

elapse time meter for the fuel gas heater. 

c. The Permittee shall install and maintain a non-resettable elapsed fuel flow 

meter for the fuel gas heater. 

d. The Permittee shall calculate annual C02, CH4, and N20 emissions using 

the emission factors used in the permit application on a calendar year 

basis. These emissions data and the GWP contained in the Greenhouse 

Gas Regulations, 40 CFR Part 98, Subpart A, Table A-1 for CH4 and N20 

shall be used to calculate C02e emissions on a calendar year basis. 

D. Requirements for the SF6 Cir·cuit Breaker Fugitive Emissions (EPN: SF6-FUG) 

Fugitive SF6 Circuit Breaker Work Practice and Operation Requirements: 

1. For EPN SF6-FUG, SF 6 emissions shall be calculated annually (calendar year) in 

accordance with the mass balance approach provided in equation 00-1 of the 

Mandatory Greenhouse: Gas Reporting Rule for Electrical Transmission and 

Distribution Equipmen1t Use, 40 CFR Part 98, Subpart DD. The total SF6 

inventory of the circuit breakers shall not exceed 2,920 lb with leak detection. 

2. The circuit breakers shall be equipped with a low pressure alarm and low pressure 

lockout. 

3. Permittee shall maintain a file of all records, data measurements, reports and 

docwnents related to the fugitive emission sources including, but not limited to, 

the following: all records or reports pertaining to maintenance performed, all 

records relating to compliance with the Monitoring and Quality Assurance and 

Quality Control (QA/QC) procedures outlined in 40 CFR § 98 .. 304. 
and flanges. 

2. AVO monitoring shall be performed weekly. 

3. Any component found to be leaking shall he tagged and repaired within 15 days, 

if possible. 

4. Records ofthe weekly AVO monitoring results and tagging and repair of leaking 

components shall be maintained on site. 

IV. RECORDKEEPING AND REPORTING 

A. Records 

1. In order to demonstrate compliance with the GHG emission limits in Table 1, the 

permittee shall monitor the following parameters and summarize the data as 

specified in Special Conditions III. A, B, C, D, and E. 

a. Operating hours for all air emission sources authorized by this permit; 

b. Records of the fuel consumed by each source authorized by this permit; 

c. Records of run time meter and fuel flow meter measurements for the 

emergency diesd generator and fuel gas heater. A computer that collects, 

sums, and stores electronic data from ·continuous fuel flow meters is an 

acceptable totaliizer; and 

d. Semi-armual fuel sampling for natural gas or other frequencies as allowed 

by 40 CFR § 98.34(b)(3). 

2. Permittee shall maintain records of the following for GHG emissions from the 

Equipment List: all records or reports pertaining to significant maintenance 

performed; duration of startups and shutdowns; the initial startup period for the 

emission units; malfunctions; all records relating to performance tests, 

calibrations, checks, and monitoring of combustion equipment; duration of an 

inoperative monitoring device and emission units with the required corresponding 

emission data; and all other information required by this permit recorded in a 

permanent fonn suitable for inspection. These records may be maintained in 

electronic databases. The records shall be retained for not less than five years 

following the date of sULch measurements, maintenance, reports, and/or records. 

3. Permittee shall maintain records of all GHG emission units and C02 emission . 

tests and monitoring and compliance information required by this permit. 

4. Permittee shall maintain reports and documents pertaining to the maintenance 

performed and compliance with the Monitoring and Quality Assurance and Quality 

Control (QNQC) procedures outlined in 40 CPR§ 98.304 for SF6 circuit breakers. 

5. Permittee shall maintain records and submit a written report of all excess 

emissions to EPA semi-annually except when more frequent reporting is 

specifically required by an applicable subpart or the Administrator or authorized 
inoperative (monitoring down-time); 

c. lfthere has been no excess emissions or monitoring downtime during the 

reporting period, a statement to that effect; 

d. Any failure to conduct any required source testing, monitoring, or other 

compliance activities; and 

e. Any violation of limitations on operation, including but not limited to1 

restrictions on hours of operation of the emergency generator or natural gas 

heater. 

6. Excess emissions shall be defined as any period in which the facility emissions 

exceed a maximum emiission iimit set forth in this permit, a malfunction occms at 

an emission unit listed in the Equipment List that results in excess GHG 

emissions, or any other unauthorized GHG emissions occur. 

7. Excess emissions indicated by GHG emission source certification testing or 

compliance monitoring shall be considered violations of the applicable emission 

I imit for the purpose of this permit unless it is shown that the testing or 

compliance monitoring data is not accurate. 

8. Instruments and monitoring systems required by this PSD permit shall have a 

95% on-stream time on an annual basis. 

9. All records required by this PSD permit shall be retained for not less than 5 years 

following the date of such measurements, maintenance, and reporting. 

V. INITIAL PERFORMANCE TESTING REQUIREMENTS: 

A. The Permittee shall perform stack sampling and other testing to establish the actual 

pattern and quantities of air contaminants being emitted into the atmosphere from the 

turbine (EPN TURB I) and to determine the initial compliance with the C02 emission 

limits established in this permit. Sampling shall be conducted in accordance with 40 CFR 

§ 60.8 and EPA Method 3a or 3b for the concentration of C02. 

The stack test shall consist of three separate runs at or above 90% of maximum load 

operations and three separate runs below 70% but above 50% load operation. Stack gas 

tlow rate measurements, as we:ll as moisture measurements (if needed), shall be made 

during each test run. The e)ectdcal generation (gross megawatts) during each test run 

shall also be recorded. The C02 emission rate shall be calculated as defined below and 

recorded for each test run in Ib C02/MWh (gross) and Ib COVhr. The arithmetic mean for 

the three test runs at or above 90% of maximum load operation and the arithmetic mean 

for the three test runs below 70% but above 50% load operation shall also be calculated 

and recorded. 
b. Explain within the report how the facility will assure compliance with the 

C02 emission limit listed in Table 1. 

B. Within 60 days after achieving the maximum production rate at which the affected 

facility will be operated, but not later than 1 80 days after initial startup of the facility, 

performance test(s) sha11 be conducted and a written report of the perfom1ance testing 

results furnished to EPA. Additional sampling may be required by TCEQ or EPA. 

C. Permittee shall submit a performance test protocol to EPA no later than 30 days prior to 

the test to ali ow review of the test plan and to arrange for an observer to be present at the 

test. The performance test shalll be conducted in accordance with the submitted protocol, 

and any changes required by E:P A. 

D. Performance tests shall be conducted under such conditions to ensure representative 

performance of the affected facility. The Permittee shall make available to EPA such 

records as may be necessary to determine the conditions of the performance tests. 

E. The Permittee shall provide EPA at least 30 days' prior notice of any performance test, 

except as specified under other subparts, to afford EPA the opportunity to have an 

observer present and/or to attend a pre-test meeting. If there is a delay in the original test 

date, the facility must provide at least 7 days prior notice of the rescheduled date of the 

performance test unless EPA aJpproves an earlier rescheduled date due to unforeseen 

events, such as delays that are caused by weather. 

F. The Permittee shall provide, or cause to be provided, performance testing facilities as 

follows: 

l. Sampling ports adequate for test methods applicable to this facility, 

2. Safe sampling platform(s), 

3. Safe access to sampling platform(s), and 

4. Utilities for sampling and testing equipment. 

G. Emission testing for the turbine shall be performed every five years, plus or minus 6 

months, from when the previous performance test was performed to verify continued 

performance at permitted emission limits. 
EPA Region 6 

1445 Ross Avenue (6 PD-R) 

Dallas, TX 75202 

Email: Group R6AirPermits@EP A.gov 

Permittee shall submit a copy of all compliance and enforcement correspondence as 

required by this Approval to Construct to: 

Compliance Assurance and Enforcement Division 

EPA Region 6 

1445 Ross Avenue (6EN) 

Dallas, TX 75202