PREVENTIONOFSIGNIFICANTDETERIORATIONPERMITFORGREENHOUSEGASEMISSIONSISSUEDPURSUANTTO1fHEREQUIREMENTSAT40CFR§52.21U.S.ENVIRONMENTALPROTECTIONAGENCY,REGION6PSDPERMITNUMBER:PSD-TX-1290-GHGPERl\1liTTEE:ElPasoElectricCompany100NorthStantonElPaso,TX79901FACILITYNAME:MontanaPowerStationFACILITYLOCATION:Section25,Block79,Township2Dln..,,_,.TV"700'lQLl1(l;)V,I..fl..I77JOPursuanttotheprovisionsoftheCleanAirAct(CAA),SubchapterI,PartC(42U.S.C.Section7470,et.Seq.),andtheCodeofFederalRegulations(CFR)Title40,Section52.21,andtheFederalImplementationPlanat40CFR§52.2305(effectiveMay1,2011andpublishedat76FR25178),theU.S.EnvironmentalProtectionAgency,Region6isissuingaPreventionofSignificantDeterioration(PSD)permittoElPasoElectricCompanyforGreenhouseGas(GHG)emissionsfromitsproposedMontanaPowerStatiion.ThePermitappliestotheadditionoffournaturalgasfiredsimplecyclecombustionturbines,firewaterpumpengine,circuitbreakersandassociatednaturalgaspipingatitsnewfacilitylocatedinElPasoCounty,Texas.ElPasoElectricCompanyisauthorizedtoconstructtheMontanaPowerStation,includingfournewnaturalgas-firedsimplecyclecombustionturbines,firewaterpumpengine,circuitbreakersandnaturalgaspipingasdescribedher,ein,inaccordancewiththepermitapplication(andplanssubmittedwiththepermitapplication),thefederalPSDregulationsat40CFR§52.21,andothertermsandconditionssetforthinthisPSDpermitinconjunctionwiththecorrespondingTexasCorrunissiononEnvironmentalQuality(TCEQ)permitNo.PSDTX1290and102294.FailuretocomplywithanyconditionortermsetforthinthisPSDPermitmayresultinenforcementactionpursuanttoSection113oftheCleanAirAct(CAA).ThisPSDPermitdoesnotrelieveElPasoElectricCompanyoftheresponsibilitytocomplywithanyotherapplicableprovisionsoftheCAA(includingapplicableimplementingregulationsin40CFRParts51,52,60,61,72through75,and98)orotherfederalandstaterequirements(includingthestatePSDprogramthatremainsunderapprovalat40CFR§52.2303).Inaccordancewith40CFR§124.15(b),thisPSDPermitbecomeseffective30daysaftertheserviceofnoticeofthisfinaldecisiontmlessreviewisrequestedonthepermitpursuantto40CFR§124.19.g'za/rwrrnStengDatef!'-MultimediaPlanningandPermittingDivision

### Montana Power Station (PSD-TX-1290-GHG) Prevention

of Significant Deterioration Permit For Greenhouse Gas Emissions Permit Conditions PROJECT
DE S CRIPTION The Montana

P o wer Station

is a proposed 400 MW

e l ectric generating station located
in El Paso County

, Texas

, using four (4 ) GE 

### LMSlOO simple cycle combustion turbines

. In addition, the project also inc

l udes the installation

of ancillary equipment that may emit GHG

, including

a firewater pump engine, circuit breakers and associated natural gas piping. The primary object of the proposed project

is to meet peak and intermediate load requirements. 

### EQUIPMENT LIST The following

d ev ices are subject
to this GHG PSD permit. 

### FIN EPN Description GT-1 GT-1 GT-2 GT-2 Four 100 MW (each

, nominal gross) Natural Gas Fired-Simple Cycle Turbines GT-3 GT-3
(GE Model LMS

I 00). GT-4 GT-4 Diesel fire pump engine (design output not to exceed 327 hp). ln addition

to FWP-1

F WP-1 emergency frre suppression activities, the unit is limited

to 1 hr per week; 52 hrs per 12-mon

ll h rolling basi

s of ope

r ation for maintenance
and testing. CTBR-SF-6 CTBR-SF-6

SF
6 Circuit Breaker Emissions FUG-1

F UG-1 Natural Gas

. Piping Components 

### I. GENERAL PERMIT CONDtiTIONS A. PERMIT EXPIRATION As provided

in 40 CFR §52.21(r)

, this PSD Permit shall become invalid
if construction: I. is not commenced

(as defined
.in 40 CFR §52.21(b)(9)) within
18 months after the approva

l takes effect; or 2.

i s discontinued

for
a per

i od of 18 months
or more; or 3. is not completed within

a reasonable time. Pursuant

to 40 CFR §52.21(r)

, EPA may extend the

1 8-month period upon

a written satisfactory showing that an extension

is justified.



### 2B
. PERMIT NOTIFICATION UEQUIREMENTS Permit

t ee shall notify EPA Region

6 in writing
or by electronic mail of the: 1. date construction

is commenced, postmarked within 30 days of such date; 2. actual date of initial startup,
as defined
in 40 CFR

§ 60.2, postmarked within
15 days of such da
t e; and 3. date upon which initial perfom1ance tests will commence,

in accordance with the provisions

of Section
V, postmarked
not les
s than 30 days prior to such date. Notification may be provided with the submitta

l of the performance
test protocol required pursuant

to Condition V.B. C. FACILITY OPERATION At nll t;.....,
.. s :n,.l .. tt: ... n ........ ;,.,.,t
.. nf' co+<:n+nn

.. 1-. .. ttlnu'" onA rna;nt

.. noni"P

P .. rrn1tt .... ch<>ll tn thP rl.L. a11 I.U.!!'\,1

) .111VJ.UUlllf)

**}'~ J..J.V\.1-**  VJ.. .:1"'"-'

.. '"" .}J' .:.J.u,.u

. uvv,u,

U.

. UU

. U

. J. U .U

. '-' (..U..a.'-'"")

A ""A.&.u

. &'-"'""'"" to.J.4.a.""u'

• '-'
.. . u

, ....., extent practicable, maintain and opera1te the facility including associated
air pollution control equipment

in a manner consistent with good air pollution contro

l practice for minimizing emiss

i ons. 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

r esults, review of operating maintenance procedures and inspection

of the facility. D. MALFUNCTION REPORTING 1. Permittee sha ll 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
10 days of the discovery

of any GHG em

i ssions above the
a llo wable emission limits resulting from malfunctions

as described

in I.D.l., Permittee shall provide

a written 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 fa ilur e, the estima

t ed resultant emissions

in excess of those allowed

in Section

II and III, 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 viol

l ation of this permit
or any law
o r regulation such malfunction may cause. E. RIGHT OF ENTRY EPA authorized representatives, upon the presentation

of credentials,
sha ll be permitted: 3

## 1. to enter th e premises where the facility

is located
or where any records are required

to be kept und er the terms and condiltions

of this PSD Permit

; 2. during norm al busine
ss hours

, to have access
to and to copy any records required

to be kept un de r the terms and condi

t ion
s of this PSD Permit

; 

# 3. to inspec

t any eq uipm ent, operation

, or m eth od subject
to requirement

s in this PSD Permit;
an d, 

# 4. to sample materials and emissions from the

s our ce(s). 

# F. TRANSFER

OF OWNERSHIP In the event of any changes

in control

m 

## own ership of
t he facilities

to be constructed

, this PSD Permit sha ll be bi ndin
g on all subsequent owners
an d operators. Permittee

s h all notify the succeedi

n g owner and operator
of th e ex

i stence of the P SD Permit and its condit

i ons by

l etter

; a co py of th e letter shail be forwarded



# to • EPA Region



# 6 within
th
i rty days 

# of the

l etter signatlll'e. G. SEVERABILITY The provisions

o f this PSD Permit are severable, and,

i f any provision
of the PSD Permit
is h e l d invalid

, the remainder

of this PSD Permit

s h a ll not be affected

. 

# H. ADHERENCE

TO APPLICATION
AND COMPLIANCE WITH OTHER ENVIRONMENTAL LAWS Permittee shall

c onstruct this project
in compliance

w i th thi s PSD Permit, the app li cat ion on wh ich this perm

i t i s b ased and

a ll other app licable federal, state, and local air quality regul at i ons. This PSD perm it does not re
l ease the Permittee from the obligation

to obtain

a PSD permit for other pollutants

e mitted in signific ant

; amount

s or from any liability for compliance with other applicable fede

r al, state and local environmental laws and regulations, including the Clean Air Act.



# 4I.ACRONYMSANDABBRE'VIATIONSAVOBACTCAAccsCEMSCFRCH4C02C02edscfEFEPNFINFRGCVGHGgrGWPHHVhrlbMMBtuMSSN20NSPSPSDQA/QCSCFHSCRSF6TACTCEQTPYu.s.c.Auditory,Visual,andOlfactoryBestAvailableControlTechnologyCleanAirActCarbonCaptureandSequestrationContinuousEmissionsMonitoringSystemCodeofFederalRegulationsMethaneCarbonDioxideCarbonDioxideEquivalentDryStandlardCubicFootEmissionFactorEmissionPointNumberFacilityIdentificationNumberFederalRegisterGrossCalorificValueGreenhouseGasGrainsr.lnh<>lW<>nninoPntAnti<>l"-J.&VVWI.YJ'\4&a&&..I.&C).,1.V"'"".I&\.,U.....HighHea1tingValueHourPoundMillionBritishThermalUnitsMaintenance,Start-upandShutdownNitrousOxidesNewSourcePerformanceStandardsPreventio111ofSignificantDeteriorationQualityAssuranceand/orQualityControlStandardCubicFeetperHourSelectiveCatalyticReductionSulfurhexafluorideTexasAdministrativeCodeTexasCo1mmissiononEnvironmentalQualityTonsperYear·UnitedStatesCode5

# II. Annual Emission Limits and BACT 

# Requirements FIN 

# EPN Description 

# GHG Mass Basis TPY BACT Requirements TPY

1 

# COzet,1,4 C02 262

, 036

. 50

3 

# -BACT limit ofl,IOO

lb COJMW-hr (gross). GT-1
GT-

1 Natural Ga
s CH4
5.34

3



# -No

t to excee

d 5,000 G T -2 GT-2

F ired-Simple

262,305

. 79

3 

# hours of operation
on a GT-3

G T -3 Cycle

12-month rolling basis per GT

- 4 GT-4

T ur bine, eac h NzO

0 .46

3 

# turbine. -See permit condition Ill .A.2 and 4. C 0 2 8.66

- Not to exceed 52 hours No

of non-emergency CH 4 Numerica

l operation

on a 12-month Firewater

Limit

ro llin g basis 

# FWP-i FWP -i Established

5

Q 

# .0::0 

# Pump Engine

b.U7



# - Use of Good No Combustion Practices. N 2 0

N

u merica

l

See permit cond

i tion L i mit

lll .B. Established

5 

# Fugitive

S F 6 Circuit

SF6

0

. 015 342.00 Work

Practices

. See CTBR-SF-6 CTBR

- SF-6

B reaker

permit condition lJJ.C. 

# Emissions Components
Implementation

of AVO Fugitive FUG-1 FUG-1 Leak

CH4

0.
1 5 3.75 Program. See permit Emissions

condition

lll .D. C02

I ,048,154.66 **CH~** 

# 21.50 Totals

6



# 1,049,577.60 N20

1.82 SF6

0

. 02



# .. I . The TPY

e m tss
t o n lt mtts

s p ecified
m
t h t:s tab

l e ar e not to b e exceede

d for thts

f a c tlt ty a n d mclude

e m tsstons from the facil

i ty during all operations and include MSS activities.

A ll emissions

a r e exp re ssed in terms of short tons. 2. Global Warm

i ng Potentials (GWP): C0

2 

# . = I , **C~** 

# = 25, N 2 

# 0 = 

# 298, SF 6 = 22,800 3. The GHG Mass
B as
i s TPY

l i m i t and

t h e C02e TP Y li mi
t f o r th e nat ural gas fi r e d simp

l e c yc
l e t u r bin es app li es to each turbine and is not
a combine

d limit. 4
. Annual C0

2 

# e emissions,

in tons pe r year (TPY) are based on 365-day rolli
n g basis

. 5. A ll val u es indicate

d as "No N u merica

l Limit Esta
b lished"
ar e less

t h an 0.0

I T P Y with ap p ropriate

r ounding. The emission limi

t will be a design/work practice sta n dard as specifie

d in the p e rmit. 6. Total emissions include the PTE for fugitive emissions. Totals are give
n for informationa

l purposes
on

l y and do not constitute
em

i ssion limits.



# 6

### III. SPEOAL PERMIT CONDITIONS A. Requirements

for the Natural Gas Fired-Simple Cycle Turbines (EPNs GT-1, GT-2, GT -3 and GT -4) 1. Fuel Specifications:

The fuel for each turbine shall be pipeline quality natural gas. 

### 2 . Turbine BACT Requirements: a. T he limit of

1 ,10 0 lbs ofC02/MW-hr gross output

is based on each turbine's daily average
of C0
2 emissions measured using

a Continuous Emissions M onitoring System (C:EMS) and divided by each turbines measured gross electrical output. The

. Permittee shall calculate each day
a combustion turbine operates, C0 2 emissions over the rolling 5,000 hours of operation basis divided by gross electrical output over the same period for comparison

to the limit for eac h combustion turbine. 

### b. The permittee shall calculate,
on a daily basis, the amount of C0
2 

### e emitted from ea ch turbine
in tons per year on a 365-day rolling ba s i s based on the measureme

nt of the C02 CEMS and the procedures
and Global Warming Pote ntial

s (GWP) contained

in the Greenhouse Gas Regulations,

40 CFR Part 98, Su bpart A, Table A-I, as published

on November 29,2013 (78 FR 71948) for CH4 and N20

. Compliance shall be based on a 365-day rolling basis. c . The annual quantity of fuel used by each turbine (EPNs GT-1

, GT-2, GT-3 and GT-4) shall not exceed 4,136,000 MMBtu (HHV). The permittee shall calculate, eac h day

a comb ustion turbine operates, the quan tity of fuel
u sed by each turbine ov er the trailing 365-day rolling basis by multiplying
the gross calorific value

o f the fuel combusted

by volume of fuel metered for comparison

to the annual fuel limit for each combustion turbine

. d. E ach turbine (EPNs GT-1, GT-2, GT-3 and GT-4)

is limited

to 5,000 operational hours on a 12-month wiling basis which shall include periods of startup and s hutd

o wn. 3. Turbine Work Practice and Operational Requirements

: a. The pennittee

s hall measure the pounds of C0
2 emitted hourly from each turbine from the procedure pro v ided in 40 CFR 75.1 O(a)(3)(i)
(di re ct emission measuremen

t using CEMS).

T h e CEMS required
by this permit shall be in stalled

, calibrated, operated

, audited, tested and maintained

in accordance with t he manufacturer's recommendations

and the appropriate perfonnance standards and quality assurance :requirements

in the appendices

of either 40 CFR Part 60 or 40 CFR Part 75. b. F or each turbine,

a C02 CEMS and volumetric stack gas flow monitoring system wit h an automated data acquisition and handling system for measuring and reco rding 

### C<h emissions discharged

to the atmosphere shall be

i nstalled and o perated for all operating hours

, including start up and shutdown. The measurement

fro m each turbine's C02 CEMS shall be used to show compliance with the emission limit in Table

I. 

### 7

## c. T he permittee shall ensure that

a ll required C02 monitoring system/equipment are in stalled and all cettification tests are completed

on or before the earlier of 90 unit operating days or 180 calendar days after the date the unit commences o peration

. d. 

## T he permitee sha ll maintain

th e following records for at
l east five years from the date or origin: i. 

## One-hour measured C02 emission averages. 

## ii. The results of all calibration and lin earity checks. iii. 

## RAT A test plar

t s and reports of test results. 

# e . The permittee shall ensure compliance with the specifications
and test p rocedure

s fo r C02 emission monitoring system
at stationary sou rces, 40 CFR Part 75,
o r 40 CFR Patt 60, Appendix

B, Performance Specification numbers

1 t hrough
9, as applica
bl e. f. 

## The permittee shall calculate the pounds of CH
4 

## and N 

## 2 0 emitted each ca le ndar day by using the default **C~** 

## and N 2 

## 0 

## emiss

i on factors contained

in Table C-2 of 40 CFR 98

, as in effect
as of the date of permit

i ssuance

, and the measured actual 

# ho urly heat input (HHV). g . For each turbine, fuel metering shall includ

e: i. 

## Measurement
and recording
of th e natural gas flow rate using an operational non- resettable elapsed flow meter insta

ll ed at each turbine inlet. ii. 

## Recording
the tota

l amount of fuel com busted for each turbine on a h ourly basis. 

## iii. The fuel

g ro ss •ca
l orific va lu e (GCV) [high heat value (HHV)], carbon content and, if applicable,

se mi-annu

a ll y by

t he procedures contained

i n 40 CFR Part 98.34(b)

(3 ) . Rec ord
s of the fuel GCV shall be maintained for
a minimum period of five years. Upon request, permittee shall prov id e a sarnp

l e an d/or analysis
of the fuel that is fired in any unit covered
by this permi

t at the

t im e of the request,

or shall allow

a sample t o be taken by IE P A for analysis. h. 

## Permitee sha ll calibrat·e and perfo rm prev

e nt ative maintenance check of
t he f u e l gas flow meters and document ann uall y. 1 . 

## The gross

e nergy output [MWh (gross)] for each turbine sha ll be measured and reco

r ded on an h o u rly basis

. j. 

## Pe rmittee shall subst

i tute data per th e Missing Data

S u bstitution Proced

u res specified under

4 0 C F R Part 75, Su bpart D. 4. Startup and Shutdown Requirements

for Turbines: 

## a. Per mittee sha ll minimize emissions during startup and sh u tdown activ

i ties by o perating and maintai
ni ng the fac ili ty and associated

a i r pollution control eq uipm ent in accordance with good air pollution control practices, safe operatin

g prac tic es, and protect ion of the fac ility. i. 

## A startup of each turbine

is defined
as the per iod that begins whe
n there i s measureable

fue

l flow to the

t u rb in e and ends when the turbine load reaches 50 percent.

A startup time
is limited
to 10 minutes. ii. 

## A shutdown

o f each turbine

is defined

as the period that begins when the 

# 8turbineloadfalllsbelow50percentandendswhenthereisnolongermeasureablefu1elflowtotheturbine.Ashutdownislimitedto10minutes.b.Emissionsduringeachstartupandshutdownactivityaswellasannualstartupandshutdownactivitiesshallbeminimizedbylimitingthedurationofoperationinstartupandshutdownmodeasfollows:i.Startupsandshutdownsarelimitedtonomorethan10minutesperevent.ii.Nomorethan832startupandshutdowneventsperturbineona12-monthrollingbasis.B.RequirementsfortheFirewateJrPumpEngine(EPN:1.FuelSpecification:Thefuel£orthefirewaterpumpislimitedtoNo.2fueloil.2.FirewaterPumpWorkPractiiceandOperationalRequirements:a;Thefirewaterpu..tnpshallnotexceed52hoursofnon-emergencyoperationona12-monthrollingbasis.andshallbeoperatedandmaintainedinaccordancewiththemanufacturer'srecommendations.b.Thepermiteeshallins1tallandmaintainanoperationalnon-resettableruntimemeterforthefirewaterpump.c.Thepermitteeshallinstallandmaintainanon-resettableelapsedflueflowmeterforthefirewaterpump.d.Theengineshallmeettheapplicablemonitoringandrecordkeepingrequirementsasrequiredin40CFRPart60SubpartIIII,StandardsofPerformanceforStationaryCompressietnIgnitionInternalCombustionEngines.C.RequirementsforMinimizingF'ugitiveEmissionsfromSF6CircuitBreaker(EPN:CTBR-SF6)FugitiveSF6CircuitBreakerWork.PracticeandOperationalRequirements:a.ForEPNCTBR-SF6,SF6emissionsshalJbecalculatedannually(calendaryear)inaccordancewiththemassbalanceapproachprovidedinequationDD-1oftheMandatoryGreenhouseGasReportingRuleforElectricalTransmissionandDistributionEquipmentUse,40CFRPart98,SubpartDO.ThetotalSF6inventoryofthecircuitbreakersshallnotexceed6,180lbwithleakdetection.b.Thecircuitbreakersshallbeequippedwithalowpressurealarmandlowpressurelockout.D.RequirementsforMinimizingFugitiveLeaksfromNaturalGasComponents(EPN:FUG-1)ComponentsFugitiveLeaksWork.PracticeandOperationalRequirements:a.Thepermitteeshallimpllementanauditory/visual/olfactory(AVO)monitoringprogramfordetectingleakinginrecoveredprocessfuelgasandnaturalgaspiping9

# components, including valves and flanges

. c. AVO monitoring shall b1e perfonned daily. d. Any component found to be leaking during AVO monitoring shall be repaired within
15 days. e. Records
of the daily AVO monitoring results must be maintained

on site. 

# IV. Recordkeeping

and Reporting A. Records 1. In or der to demonstrate compliance with the GHG emission limits in Table



# 1 , the permittee will monitor the following parameters and summarize

t he data as spe cified
in Special Conditions
III. A, B, C and D. a. Operating hour

s 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 n.ni time meter and fuel flow met e r measurements

fer the fire pu...'Tip engme; d. The fueJ usage for all turbines, and engine, using continuous fuel flow monitors

(a group of equipment can utilize

a common fuel flow meter,
as long as actual fuel usage
is allocated

to the individual equipment based upon actual operating hours and maximum firing rate) A computer tha

t collects, sums, and stores electronic data from continuous fuel flow meters

is an acceptable totalizer; e. Semi-annual
fuel sampling for natural gas or other frequencies

as allowed by 40 CFR Part 98 Subpart

C §98.34(b)(3). 2. Permittee shall maintain records of the following for the Equipment List: all final records or reports pertaining

to significant maintenance performed; duration
of startup, shutdown; the initi al startup period for the emission units

; malfunctions
that couJd affect the Equipment

's ability
to meet the limits in this permit; all records relating

to performance tests, calibrations, checks, and monitoring

of combustion equipment required by this permit; 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 form suitable fi::>r inspection. These records may be maintained

in electronic databases. The rec01rds must be retained for not less than five years following the date of their creation. 3. Permittee shall maintain records of all GHG emission units and C0

2 

# emis

s ion certification tests and monitoring and compliance information required by this permit. 4. Permittee shall maintain reports and documents pertaining

to
t he maintenance performed and comp

l iance with the Monitoring
and Quality Assurance and Quality Control (QA/QC) procedures outlined
in 40 CFR 98.304 for SF6 circuit breakers. 5. Permitt ee shall maintain records and submit

a written report of all excess emissions

to EPA sem i-annually

, except when: more frequent reporting

is specifically required by an applicable subpart;

or the Administrator

or authorized representative,

on a case-by-case basis, determines that more fwquent 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 semi-annual period and shall include the following: 10a.Timeintervals,dateandmagnitudeoftheexcessemissions,thenatureandcause(ifknown),correctiveactionstakenandpreventivemeasuresadopted;b.Timeanddateofeachperiodduringwhichthemonitoringequipmentwasinoperative(monitoringdown-time);c.Iftherehasbeennoexce:ssemissionsormonitoringdowntimeduringthereportingperiod,astatementtothateffect;d.Anyfailuretoconductanyrequiredsourcetesting,monitoring,orothercomplianceactivities;ande.Anyviolationoflimitationsonoperation,includingbutnotlimitedtorestriCtionsonhoursofoperationoftheemergencygeneratororfirepump.6.Excessemissionsshallbedefinedasanyperiodinwhichthefacilityemissionsexceedamaximumemissionlimitsetforthinthispermit,amalfunctionoccursofanemissionunitlistedintheEquipmentListthatresultsinexcessGHGemissions,oranyotherunauthorizedGHGemissionsoccur.7.ExcessemissionsindicatedbyGHGemissionsourcecertificationtestingorcomp!ia.11cemonitoringshallbeconsideredviolationsoftheapplicableemissionlimitforthepurposeofthispermit.8.AllrecordsrequiredbythisPSDPermitshallberetainedfornotlessthan5yearsfollowingthedateofsuchmeasurements,maintenance,andreporting.V.InitialPerformanceTesting]R-equirements:A.ThePermitteeshaHperformstacksamplingandothertestingtoestablishtheactualpatternandquantitiesofC02emissionsbdngemittedintotheatmospherefromthefourturbines(EPNGT-1,GT-2,GT-3andGT-4)andtodeterminetheinitialcompliancewiththeC02emissionlimitsestablishedinthispermit.Samplingshallbeconductedinaccordancewith40CFR§60.8andEPAMethod3Aor3BfortheconcentrationofC02.Thestacktestshallconsistofthre:eseparaterunsatorabove90%ofmaximumloadoperationsandthreeseparaterunsbelow70%butabove50%loadoperation.Stackgasflowratemeasurements,aswellatsmoisturemeasurements(ifneeded),shallbemadeduringeachtestrun.Theelectricalgeneration(grossmegawatts)duringeachtestrunshallalsoberecorded.TheC02emiss:ionrateshallbecalculatedasdefinedbelowandrecordedforeachtestruninlbC02/MWh{gross)andlbC02/hr.Thearithmeticmeanforthethreetestrunsatorabove90%ofmaximumloadoperationandthearithmeticmeanforthethreetestrunsbelow70%butaboveSCI%loadoperationshallalsobecalculatedandrecorded.1.TheC02hourlyaverageemissionratedeterminedbythethreerunsatorabove90%ofmaximumloadby5,000hours.2.IftheabovecalculatedC02emissiontotaldoesnotexceedthe(TPY)specifiedonTable1,nocompliancest:Jrategyneedstobedeveloped.3.IftheabovecalculatedC02emissiontotalexceedsthe(TPY)specifiedinTable1,thefacilityshall;a.Documenttheexce:edanceinthetestreport;and11

# b. Explain wit hin the

r eport how the facility will assure co mplian ce wi th 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 180 days after initial startu

p of the facility, performance tests(s) must be conducted and

a w1ritten report of the performance testing results furn

i shed to the EPA. Additional sampling may

b e 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 allow review of the test plan and to arrange for an observer

to be present

at the test. The performance
test shall be conducted



# in accordance with the submitted protocol, and any changes requ ired by EPA. 

# D. Performance tests must be conduct

1 ed under such conditions

to ensure representative performance

of the affected facility. The owner or operator must make available

to the EPA such record

s as may be necessary

to determine the conditions

of the performance tests. E. The owner or operator must provide the EPA at least 30 days' prior notice of any performance
test

, except
as specified under other subparts,

to afford the EPA the opportunity to have an observer present and/or
to attend

a pre-test meeting.



# If there


# is a deiay in the original test date

, the facility must provide

at least



# 7 da ys prior notice of the rescheduled date of the performance
test unless EPA approves

an earlier reschedu

l ed date due to unfores een events,

s uch as delays that are caused by weather. F. The owner or operator shall provide,
or cause to be provided

, performance

te sting facilities

as follows

: 1. Sampling ports adequate 

# for test methods applicable

to this facility, 2. Safe sampling platform(s), 3. Safe access
to sampling pl.atform(s),
and 4. Utilities for sampling and testing equipment. 

# G. To verify continued performance

a t permitted emission

li mits

, the permittee sha ll conduct
its initial and annual C02 CEMS relative accuracy test audit (RAT A), in accordance with 40 CFR Part 60

, Appendix

F, Procedure

1, and 40 CFR 75, Appendix

B, Section 2.3

. l to evaluate compliance

of each turbine with the emission standards
on a continuous basis. The initial C02 CEMS RAT A shall be on or before the earlier of 90 unit days or 180 calendar days after the date the unit commences operation

. 

# VI. Agency

N otifications Permittee sha ll s ubmit GHG permit applications, permit amendments

, and other applicable permit informa

ti on to: Multimedia Planning and Pem1itting Division EPA Region

6 1445 R os s Avenue (6PD -R) Dallas, TX 75202 Email: Group R6AirPermits@EP A.gov Permittee shall su bmi

t a copy of a ll comp

li ance and enforcement correspondence

as required
by 12thi
s A ppro

v al to C on
s truct to: Comp

l iance As
s urance and Enforcement Division EPA Region

6 1 4 4 5 R o ss Avenue (6EN) Da ll as, TX 75202

13