appendix c: ract

west virginia department of environmental protection

Appendix C: RACT

Promoting a healthy environment.

PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-1

[This page intentionally left blank.]


WV DEP RACT Analysis



west virginia department of environmental protection

Division of AiT Quality 60 I 57"' Street SE Charleston, WV 25304

Earl Ray Tomblin, Governor Randy C. Huflinan, Cabinet Secretary

www.dep. wv.gov Phone (304) 926-0475 • FAX: (304) 926-0479

RACT ANALYSIS

FACILITY INFORMATION

Plant ID No.: Applicant: Facility Name: Location: SIC Code: Received Date: Engineer Assigned: UTM's: Description:

BACKGROUND

009-00002 Mountain State Carbon, LLC Follansbee Plant Brooke County 3312 May 5, 2015 Steven R. Pursley, PE Easting: 533.41 km Northing: 4,465.76 km Zone: 17 Reasonably Available Control Technology (RACT) Analysis in support of the West Virginia Department of Environmental Protection's (WVDEP) State Implementation Plan (SIP).

On June 2, 2010, the United States Environmental Protection Agency (USEPA) finalized a revision to the primary S02 National Ambient Air Quality Standards (NAAQS). The revised standard was set at 75 parts per billion (ppb). An area is deemed in attainment with that standard when the 3 year average of the 99th percentile of daily maximum 1 hour concentrations does not exceed 75 ppb.

On October4, 2013, USEPA, published a rule designating 29 areas in 16 states as not attaining that standard based on ambient air quality monitoring data for the years 2009-2011. One of those areas was the portion of Brooke County in West Virginia that is bounded by the Cross Creek tax district. Mountain State Carbon, LLC is an existing major source of S02 located in this area. ·

Any state contain.ing a nonattainment area for a NAAQS is required by the Clean Air Act (CAA) to develop a SIP meeting the requirements of Title I, part D, subparts 1 and 5 of the CAA. Section 172(c) of the CAA requires that the SIP contain provisions that shall provide for the implementation of all reasonably available control measures as expeditiously as practicable (including such reductions in emissions from existing sources in the area as may be obtained through the adoption, at a minimum, of reasonably available control technology) . .".". It also requires an attainment demonstration showing that the affected area will meet the standard by the statutory attainment date. 42 U.S. Code§ 7514a(a) specifies "Implementation plans required under section 7514(a) of this title shall provide for attainment of the relevant primary standard as expeditiously as practicable but no later than 5 years from the date of the nonattainment designation." For

Promoting a healthy environment.


the Cross Creek tax district, this means an attainment date of no later than October 2018. EPA guidance also clearly states that "EPA expects attainment plans to require sources to comply with the requirements of the attainment strategy at least 1 calendar year before the attainment date. Thus, for areas that were designated with an effective date of October 2013, with an attainment deadline that is as expeditiously as practicable, but no later than October 2018, the EPA would expect states to require sources to begin complying with the attainment strategy in the SIP no later than January 1, 2017." Accordingly, any control strategy determined to meet RACT must be installed and operating no later than January 1, 2017.

RACT DEFINITION

RACT is defined in 40 CFR part 51.100 (o) as "devices, systems, process modifications, or other apparatus or techniques that are reasonably.available taking into account:

(1) The necessity of imposing such controls in order to attain and maintain a national ambient air quality standard;

(2) The social, environmental, and economic impact of such controls"

Therefore, any control plan that is sufficient to attain and maintain the NAAQs meets this definition of RACT. Mountain State Carbon has proposed a suite of process conditions which they contend is sufficient to attain and maintain the NAAQS.

RACT PROPOSAL

COKE OVEN BATTERIES, EXCESS COG FLARE AND COG BOILERS

The main source of S02 from the facility is the combustion of coke oven gas (COG). Sulfur is introduced into the process in the coal supply. In the heated coke oven batteries the sulfur is released as part of the off gas as hydrogen sulfide. Because this off gas has such a high BTU content Mountain State Carbon uses it as a fuel source for their boilers and oven firing systems. This combustion of the H2S containing COG results in emissions of S02 from the boilers, coke oven batteries and the flare.

The amount of S02 emissions from these combustion sources are driven almost exclusively by the amount of H2S in the COG. Therefore, for the coke oven batteries and the COG fired boilers, Mountain State Carbon has proposed a RACT limit of 50 grains of H2S per 1 00 dry standard cubic feet of COG during normal operations. This reduced H2S concentration is achieved by the use of an existing desulfurization process at Mountain State Carbons by-product plant. The facility uses an ammonia wash technology for the dissolution of H2S with ammonia to reduce the sulfur content of the COG prior to combustion.

For up to 20 days each year, Mountain State Carbon has to take this desulfurization system off line to inspect and repair the system. During these outages, achieving a H2S concentration of 50 grains per dscf in the COG is not possible. Additionally, due to the

Page 2 of 4

RACT Analysis Mountain State Carbon, LLC

Follansbee, WV


nature of coke batteries, they cannot temporarily shut down. Therefore, during outages Mountain State Carbon has proposed a RACT limiting the sulfur content of the coal to no greater than 1.25% and reduce operations to 63 ovens per day.

MSC has also proposed merging Boiler 9 and Boiler 1 0 exhaust into the existing Boilers an stack in order to increase S02 dispersion.

ENGINES

Mountain State Carbon also employs two engines at the facility. One engine is a 600 hp emergency generator and the other is a 527 hp emergency air compressor. Both of these engines fire diesel fuel which contains sulfur. During combustion of diesel fuel the vast majority of this sulfur is emitted as S02• For these units Mountain State Carbon has proposed using ultra low sulfur diesel (15 ppm max) as fuel in order to meet the RACT requirements. This results in emissions of S02 of 0.1 pounds per hour from each engine.

NATURAL GAS COMBUSTION

Mountain State Carbon also utilizes one 85 mmbtu/hr natural gas fired boiler and several other natural gas combustion sources rated at Jess than 10 mmbtu/hr. The small amount of sulfur in natural gas is mostly converted to S02 during combustion. Pipeline quality natural gas is inherently very low in sulfur. Therefore, Mountain State Carbon has proposed that the exclusive use of pipeline quality natural gas in these units is RACT.

ATTAINMENT DEMONSTRATION

EPA guidance states "for attainment demonstrations for the 2010 S02 NAAQS, the air agency should demonstrate future attainment and maintenance of the NAAQS in the entire area designated as nonattainment (i.e., not just at the violating monitor) by using air quality dispersion modeling ... " In November2015, MSC submitted a report which included modeling results demonstrating that the NAAQS would be met by compliance with the proposed RACT. Jon McClung ofWVDAQs planning section has reviewed and approved said modeling. According to the report "As outlined in Sections 5.1 of this report the modeling analyses completed by MSC for the 1 hour S02 nonattainment SIP demonstrate compliance with the 1 hour S02 NAAQS".

Page 3 of 4


Follansbee, WV


RECOMMENDATION TO DIRECTOR

Mountain State Carbon's submitted proposal results in modeled compliance with the 2010 1 hour S0.2 NAAQS. Specifically, it appears that the proposed modifications will result in immed1ate (once implemented) compliance with the NAAQS during normal operations. Additionally, MSC has indicated that it would be mid 2018 before any additional add on controls could be added. So it appears that compliance with the NAAQS during outages will occur before any additional add on controls could be installed. Therefore, it is the recommendation of the writer that the submission be considered RACT.

Page 4 of 4

November 30, 2015


Follansbee, WV

2MSC SO RACT Proposal


Environmental solutions delivered uncommonly well

SO2 RACT PROPOSAL FOR COKE OVEN BATTERIES, BOILERS, AND ENGINES

Mountain State Carbon, LLC

Follansbee, WV

PreparedBy:

TRINITYCONSULTANTS4500BrooktreeRoad

Suite103Wexford,Pennsylvania15090

(724)935‐2611

May2015

Project153901.0009


Mountain State Carbon, LLC | SIP RACT Proposal Trinity Consultants

TABLE OF CONTENTS

1. REASONABLY AVAILABLE CONTROL TECHNOLOGY (RACT) REVIEW 3

1.1.Introduction 3

1.2.OverviewofCokemakingTechniques 4

1.3.RACTAssessmentMethodology 5

Step1–IdentifyAllControlTechnologies 5

Step2–EliminateTechnicallyInfeasibleOptions 5

Step3–RankRemainingControlTechnologiesbyControlEffectiveness 5

Step4–EvaluateMostEffectiveControlsandDocumentResults 5

Step5–SelectRACT 6

1.3.1.IdentificationofPotentialControlTechnologies 6

1.3.2.EconomicFeasibilityCalculationProcess 7

1.4.CokeOvenBatteryandCOGBoilerRACTEvaluation 8

1.4.1.SO2RACT 8

1.5.RACTEvaluationforOutagePeriods 12

1.5.1.SO2RACT 12

1.6.EngineRACTEvaluation 14

1.6.1.SO2RACT 14

1.7.NaturalGasCombustionSourceRACTEvaluation 17

APPENDIX A – RACT DOCUMENTATION


Mountain State Carbon, LLC | SIP RACT Proposal Trinity Consultants 3

1. REASONABLY AVAILABLE CONTROL TECHNOLOGY (RACT) REVIEW

1.1. INTRODUCTION

MountainStateCarbon,LLC(MSC)ownsandoperatesametallurgicalcokeproductionfacilityinFollansbee,WV(FollansbeePlant).OperationsattheFollansbeePlantincludefour(4)by‐productrecoverycokeproductionbatteries,four(4)boilersfiredwithcokeovengas(COG)generatedinthebatteries,one(1)boilerfiredwithnaturalgas,two(2)diesel‐firedstationaryinternalcombustionenginesdrivinggeneratorsduringemergencysituations,andothermiscellaneouscombustionsources.TheseandotheremissionunitsattheFollansbeePlantarepermittedunderTitleVoperatingPermitR30‐00900002‐2010issuedbytheWestVirginiaDepartmentofEnvironmentalProtection(WVDEP)onJanuary5,2010.TheFollansbeePlantislocatedintheCrossCreektaxdistrictofBrookeCountywhichhasbeendesignatednonattainmentwithrespecttothe1‐hourNationalAmbientAirQualityStandards(NAAQS)forsulfurdioxide(SO2).WVDEPisrequiredtosubmitaStateImplementationPlan(SIP)thatprovidesforattainmentoftheSO2standardbasedonSO2emissionreductionsfromcontrolmeasuresthatarepermanentandenforceable.Inthatregard,WVDEPisrequiredtoconsiderreasonablyavailablecontroltechnology(RACT)andreasonablyavailablecontrolmeasures(RACM)thatcanbeimplemented,inlightoftheattainmentneedsfortheaffectedarea.1U.S.EPAhasstatedthat“thedefinitionforRACTforSO2isthatcontroltechnologywhichisnecessarytoattainandmaintaintheNAAQS.Thetechnologymustalsobereasonablyavailableconsideringtechnologicalandeconomicfeasibility.Furthermore,RACTmustbethattechnologywhichwillprovidefortheachievementoftheNAAQSwithintheestablishedstatutorytimeframes.”2ThereisnoproscribedmethodofdeterminingRACT.Basedontheabovestandard,therequirementsforRACTareachievediftheareawillattainthestandardinthestatutorytimeframe.Forthemostrecentthreecalendaryearperiodof2012to2014,threeofthefourmostrelevantambientairmonitorshavedemonstratedattainmentwiththeNAAQS.ThefourthmonitoriswithinonemicrogrampercubicmeterofattainingtheNAAQSandisonatrajectorytoreachattainmentbytheendofthecalendaryear.Therefore,thecontrolsalreadyinplaceareconsideredRACT.Nonetheless,attherequestofWVDEP,MSChaspreparedthisreportwhichproposesRACTonthebasisoftechnicalandeconomicfeasibilityforthesourcesofSO2attheFollansbeePlant.MSChasalsofollowedthe“top‐down”approachattherequestofWVDEP.Table1‐1identifiesemissionunitsconsideredintheRACTproposalandtheirapproximatepotentialemissions(PTE)peryear.

1StephenD.Page,Director,U.S.EPA,Guidancefor1‐HourSO2NonattainmentAreaSIPSubmissions,April23,2014,page14.269Fed.Reg.24986(May5,2004)(regardingEPA’sapprovalofWestVirginia’sSIPinvolvingWheeling‐PittsburghSteel(now

MSC)).



Table1‐1.EmissionUnitsEvaluatedintheRACTProposal

SO2

EquipmentAllowablesLevel(tpy)

CokeOvenBatteries >100 Boilers >100 Engines <1 Misc.CombustionUnits ‐

MSCcontrolsemissionsofSO2fromtheFollansbeePlantusingapre‐combustiondesulfurizationsystemthatreducessulfurconcentrationsinthecokeovengaspriortocombustion.AmmonialiquorproducedattheFollansbeePlantabsorbshydrogensulfide(H2S)fromthecokeovengas,andMSCusesasteamdeacifiertoextractthesulfurouscompoundsforthepurposesofmanufacturingsulfuricacidandfertilizer.Themajorityofby‐productrecoverycokeproductionfacilitiesdonothavedesulfurizationsystemsimplementedtocontrolSO2andthusdonothavecontrolequipmentforSO2.3

1.2. OVERVIEW OF COKEMAKING TECHNIQUES

MSC’sFollansbeePlantisaby‐productrecoverycokeproductionfacility.Thedestructivedistillationofcoaltoproducemetallurgicalcokegeneratescokeovengas(COG)intheheadspaceofthecokeovensand,becausethisCOGisrichinvaluablecompounds,theby‐productplantincludesseveralchemicalrecoveryand/orproductgeneratingprocessesthatcouldproducethefollowingmarketableproducts:tar,lightoil,benzene,elementalsulfur,sulfuricacid,anhydrousammonia,andammoniumsulfatefromtheCOG.Incontrast,non‐recoverycokeproductionfacilitiescompletelycombusttheCOGinacommonbatterytunnelwithoutrecoveringanyofthesecompounds.Thedifferencesbetweenby‐productrecoveryandnon‐recoverycokemakingtechniqueslimitthetechnicalfeasibilityofcertaincontroltechniquesconsideredinthisRACTproposal.Nonrecoverycokeplant(NRCP)designiscompletelydifferentthanarecoverycokeplant.NRCParedesignedtoburnallCOGasgeneratedandgenerallydesignedforonecommonfluestackandFGDcontemplatedintheirdesign.RecoverycokeplantslikeMSCaredesignedtoremovesulfurfromthepre‐combustionCOGforthemanufactureofsulfuricacidandammoniumsulfate.Theyarenotdesignedtoremovepostcombustionsulfur,andtheretro‐fitofFGDisnotRACTasitisnottechnicallyandeconomicallyfeasible.Furthermore,becauseCOGfromtheby‐productrecoveryprocessiscombustedinmanydifferenton‐siteoperations(COGfiredboilers,severalbatteryunderfiringsystems,andexcessgasflare),theprocessinvolvesmultipleegresspoints.Applyingadd‐on,post‐combustioncontroldevicestomultipleegresspointsisnottechnicallyandeconomicallyfeasible.Forthereasonsdescribedabove,add‐on,postcombustioncontroldevicesarenottechnicallyandeconomicallyfeasibleforby‐productrecoveryoperationsevenifthesedevicesaretechnicallyandeconomicallyfeasibleforNRCP.

3AIST2015CokemakingByproductsRoundup–Iron&SteelTechnology–March2014–AIST.org.



1.3. RACT ASSESSMENT METHODOLOGY

ThefollowingsectionsdescribetheprocedureMSCusedtoselectRACTfortheemissionssourcesattheFollansbeePlant.ThecriteriaforRACTisthatitiscapableofreachingattainmentandthatitistechnicallyandeconomicallyfeasible.Thefirststepinthisapproachistodetermine,fortheemissionunitinquestion,themoststringentcontrolavailableforasimilaroridenticalsourceorsourcecategory.Ifitcanbeshownthatthislevelofcontrolistechnicallyoreconomicallyinfeasiblefortheunitinquestion,thenthenextmoststringentlevelofcontrolisdeterminedandsimilarlyevaluated.Thisprocesscontinuesuntilthecontrollevelunderconsiderationcannotbeeliminatedonthebasisoftechnicaloreconomicfeasibility.Presentedbelowarethefivebasicstepsofatop‐downcontroltechnologyreviewasidentifiedbytheU.S.EPA.4

Step 1 – Identify All Control Technologies

Availablecontroltechnologiesareidentifiedforeachemissionunitinquestion.Thefollowingmethodsareusedtoidentifypotentialtechnologies:1)researchingtheReasonablyAvailableControlTechnology(RACT)/BACT/LowestAchievableEmissionRate(LAER)Clearinghouse(RBLC)database,2)surveyingregulatoryagencies,3)drawingfrompreviousengineeringexperience,4)surveyingairpollutioncontrolequipmentvendors,and/or5)surveyingavailableliterature.

Step 2 – Eliminate Technically Infeasible Options

Aftertheidentificationofcontroloptions,ananalysisisconductedtoeliminatetechnicallyinfeasibleoptions.Acontroloptioniseliminatedfromconsiderationifthereareprocessspecificconditionsthatprohibittheimplementationofthecontroltechnologyorifthehighestcontrolefficiencyoftheoptionwouldresultinanemissionlevelthatishigherthananyapplicableregulatorylimits,suchasanNSPS.

Step 3 – Rank Remaining Control Technologies by Control Effectiveness

Oncetechnicallyinfeasibleoptionsareremovedfromconsideration,theremainingoptionsarerankedbasedontheircontroleffectiveness.Ifthereisonlyoneremainingoptionorifalloftheremainingtechnologiescouldachieveequivalentcontrolefficiencies,rankingbasedoncontrolefficiencyisnotrequired.

Step 4 – Evaluate Most Effective Controls and Document Results

Beginningwiththemostefficientcontroloptionintheranking,detailedeconomic,energy,andenvironmentalimpactevaluationsareperformed.Ifacontroloptionisdeterminedtobeeconomicallyfeasiblewithoutadverseenergyorenvironmentalimpacts,evaluatingtheremainingoptionswithlowercontrolefficienciesisnotnecessary.

4U.S.EPA.DraftNewSourceReviewWorkshopManual,ChapterB.ResearchTrianglePark,NorthCarolina.October,1990.



Theeconomicevaluationcentersonthecosteffectivenessofthecontroloption.CostsofinstallingandoperatingcontroltechnologiesareestimatedandannualizedfollowingthemethodologiesoutlinedintheEPA’sOAQPSControlCostManual(CCM)andotherindustryresources.5

Step 5 – Select RACT

Inthefinalstep,onepollutant‐specificcontroloptionisproposedasRACTforeachemissionunitunderreviewbasedonevaluationsfromthepreviousstep.Thetop‐downRACTanalysesareperformedforeachemissionunitandarelistedbelowinSections1.4through1.7.

1.3.1. Identification of Potential Control Technologies

PotentiallyapplicableemissioncontroltechnologieswereidentifiedbyresearchingtheU.S.EPAcontroltechnologydatabase,technicalliterature,controlequipmentvendorinformation,statepermittingauthorityFiles,and/orbyusingprocessknowledgeandengineeringexperience.TheRACT/BestAvailableControlTechnology(BACT)/LowestAchievableEmissionRate(LAER)Clearinghouse(RBLC),adatabasemadeavailabletothepublicthroughtheU.S.EPA’sOfficeofAirQualityPlanningandStandards(OAQPS)TechnologyTransferNetwork(TTN),liststechnologiesandcorrespondingemissionlimitsthathavebeenapprovedbyregulatoryagenciesinpermitactions.Thesetechnologiesaregroupedintocategoriesbyindustryandcanbereferencedindeterminingwhatemissionslevelswereproposedforsimilartypesofemissionsunits.TrinityperformedsearchesoftheRBLCdatabaseinApril2015toinitiallyidentifytheemissioncontroltechnologiesandemissionlevelsthatweredeterminedbypermittingauthoritiesasRACTforemissionsourcescomparabletothecokeovenbatteries,boilers,engines,andmiscellaneouscombustionunitsatthefacility.ThefollowingCokeOvenBatterycategorieswereselectedtoperformthesearchforthecokeovenbatteries:> Pushing(RBLCCode81.111),

> BatteryStack(RBLCCode81.112),

> Doors(RBLCCode81.113),

> Lids(RBLCCode81.114),

> Charging(RBLCCode81.115),and

> OtherCokeProcesses(RBLCCode81.190).

TheCommercialandInstitutional‐sizeBoilersandFurnacesfiredbyNaturalGas(RBLCCode13.310)categorywasselectedtoperformthesearchforthelessthan100MMBtu/hrnaturalgasfiredcombustionunits.TheCommercialandInstitutional‐sizeBoilersandFurnacesfiredbyOtherGaseous&GaseousFuelMixtures(RBLCCode13.390)categorywasselectedtoperformthesearchforthelessthan100MMBtu/hrcokeovengas(COG)firedboilers.TheLargeInternalCombustionEnginesfiredbyFuelOil(RBLCCode

5OfficeofAirQualityPlanningandStandards(OAQPS),EPAAirPollutionControlCostManual,SixthEdition,EPA452‐02‐001(http://www.epa.gov/ttn/catc/products.html#cccinfo),DanielC.Mussatti&WilliamM.Vatavuk,January2002.



17.110)categorywasselectedtoperformthesearchforthegreaterthan500horsepower(HP)dieselfiredengines.

AppendixApresentsasummarytableofrelevantRACTdeterminationsforcokeovenbatteries,boilersfiringothergaseousfuelsandmixtures,enginesfiringdiesel,andmiscellaneouscombustionunits.

1.3.2. Economic Feasibility Calculation Process

Economicanalyseswerepreformedtocomparetotalcosts(capitalandannual)forpotentialcontroltechnologies.Capitalcostsincludetheinitialcostofthecomponentsintrinsictothecompletecontrolsystem.Annualoperatingcostsincludethefinancialrequirementstooperatethecontrolsystemonannualbasisandincludeoverhead,maintenance,outages,rawmaterials,andutilities.Thecapitalcostestimatingtechniqueusedisbasedonafactoredmethodofdeterminingdirectandindirectinstallationcosts.Thatis,installationcostsareexpressedasafunctionofknownequipmentcosts.ThismethodisconsistentwiththelatestU.S.EPAOAQPSguidancemanualonestimatingcontroltechnologycosts.6Totalpurchasedequipmentcostrepresentsthedeliveredcostofthecontrolequipment,auxiliaryequipment,andinstrumentation.Auxiliaryequipmentconsistsofallthestructural,mechanical,andelectricalcomponentsrequiredfortheefficientoperationofthedevice.Auxiliaryequipmentcostsareestimatedasastraightpercentageoftheequipmentcost.Directinstallationcostsconsistofthedirectexpendituresformaterialsandlaborforsitepreparation,foundations,structuralsteel,erection,piping,electrical,painting,andfacilities.Indirectinstallationcostsincludeengineeringandsupervisionofcontractors,constructionandfieldexpenses,constructionfees,andcontingencies.Otherindirectcostsincludeequipmentstartup,performancetesting,workingcapital,andinterestduringconstruction.

Annualcostsarecomprisedofdirectandindirectoperatingcosts.Directannualcostsincludelabor,maintenance,replacementparts,rawmaterials,utilities,andwastedisposal.Indirectoperatingcostsincludeplantoverhead,taxes,insurance,generaladministration,andcapitalcharges.Replacementpartcostswereincludedwhereapplicable,whilerawmaterialcostswereestimatedbasedupontheunitcostandannualconsumption.Withtheexceptionofoverhead,indirectoperatingcostswerecalculatedasapercentageofthetotalcapitalcosts.Theindirectcapitalcostswerebasedonthecapitalrecoveryfactor(CRF)definedas:

1)1(

)1(

n

n

i

iiCRF

whereiistheannualinterestrateandnistheequipmentlifeinyears.Theequipmentlifeisbasedonthenormallifeofthecontrolequipmentandvariesonanequipmenttypebasis.Thesameinterestappliesto

6U.S.EPA,OAQPSControlCostManual,6thedition,EPA452/B‐02‐001,July2002.

http://www.epa.gov/ttn/catc/dir1/c_allchs.pdf



allcontrolequipmentcostcalculations.Forthisproposal,aninterestrateof7%wasusedbasedoninformationprovidedinthemostrecentOAQPSControlCostManual.7Notethatalleconomiccalculationsarebasedon2014dollars.DetailedcostanalysescalculationsarepresentedinAppendixA.

1.4. COKE OVEN BATTERY AND COG BOILER RACT EVALUATION

TheRACTevaluationforthecokeovenbatteriesandforthe90and98MMBtu/hrCOG‐firedboilersisprovidedinSection1.4.1.Asdiscussedabove,theRBLCwasusedinthisproposaltoidentifyemissioncontroltechnologiesandemissionlimitsdeterminedtobeRACTbythepermittingauthoritiesforemissionunitscomparabletothoseatthefacility.AppendixAprovidesasummaryofRBLCandpermitsearchresults.

1.4.1. SO2 RACT

1.4.1.1. Background on Pollutant Formation

ThemainsourceofSO2fromcokeovenprocessesisthecombustionofCOG.Sulfurentersthecokemakingprocessthroughtheinitialcoalsupplyandisreleasedashydrogensulfide(H2S)duringthenon‐destructivedistillationoccurringintheheatedcokeovenbatteries.BecausethecomponentsoftheCOGareavaluablesourceofthermalenergy,MSCusestheCOGasafuelsourceintheon‐siteboilersandintheunderfiringsystemsusedtoprovideheattotheovens.ThecombustionofresidualH2SintheCOGresultsinemissionsofSO2fromtheboilerstacks,batterystacks,andonsiteexcessCOGflarestack.Duringcombustionintheboilers,H2SfromthecokeovengasbecomesSO2,orlessdesirableSO3whentheO2contentishigh.8WhentheO2contentishighandthetemperatureislow,theSO3becomeshighlycorrosiveH2SO4.TheformationofSO2ispredominatelydeterminedbytheinitialsulfurcontentinthefuel,andnottheboilerparameters.

1.4.1.2. Analysis of RACT Alternatives

SO2reductionfromby‐productcokeovenbatteriescanbeaccomplishedbytwogeneralmethodologies:pre‐combustiondesulfurizationandrestrictionsoncoalsulfurcontent.Pre‐combustiondesulfurizationneutralizesorabsorbssulfurcompounds(e.g.,H2SorSO2)fromtheCOGbeforesubsequentcombustionwhilecoalsulfurrestrictionslimittheamountofsulfurenteringtheplant’svariouscombustionprocesses.Theprimarypre‐combustiondesulfurizationprocesscurrentlyexistingattheFollansbeeFacilityutilizesammoniawashtechnologyforthedissolutionofH2SwithNH4intheH2Swashertoensurethatsulfurconcentrationsinthecokeovengasarereducedpriortocombustion.Thesystemalsoincludesadeacifiercolumnandasulfuricacidplant.

7U.S.EPA,OAQPSControlCostManual,6thedition,Section2,Chapter1,page1‐52.http://www.epa.gov/ttn/catc/dir1/c_allchs.pdf

8Sridhar,K.,&Mohaideen,J.Abbas,InternationalJournalofEngineeringResearchandDevelopment,Volume1,Issue1,page42‐45.https://www.idc‐online.com/technical_references/pdfs/civil_engineering/Environmental%20Impact.pdf



UsingtheRBLCsearch,potentiallyapplicableSO2controltechnologiesforcokeovenbatteriesandforboilerswereidentifiedbasedontheprinciplesofcontroltechnologyandengineeringexperienceforgeneralcokeindustryprocessesandforgeneralcombustionunits.Table1‐3outlinesthetop‐downRACTproposalforSO2emissionsfromthecokeovenbatteries.

1.4.1.3. Selection of RACT

TheRBLCentriesforSO2controlsareprovidedwithinAppendixA.Mostoftheemissionlimitsestablishedforsulfuremissionsfromcokeovenbatteriesandforgaseousfuel‐firedboilersareeithermass‐based(i.e.,poundperhour)post‐combustionSO2limits,concentration‐based(i.e.,grainspercubicfoot)pre‐combustionH2Slimits,ornumericalrestrictionsoncoalsulfurcontent(e.g.,percentbyweight).Certainofthelimitsforboilersareevaluatedoveraveragingperiodsrangingfrom1hourto1year.BasedonareviewoftheemissionlimitsachievableandrecentRACTdeterminationsforsimilarfacilities,MSCisproposingSO2RACTfornormaloperationasalimitof50grains(gr)ofH2Sperevery100drystandardcubicfeet(dscf)ofCOG.Becausethispre‐combustiondesulfurizationrequirementreducesemissionsofSO2fromthebatterystacksandtheboilers,thisproposalconstitutesRACTforeachoftheaforementionedsources.Table1‐2summarizestheRACTdeterminationforthecokeovenbatteriesandfortheCOG‐firedboilers.TheRACTlimitsareapplicableduringnormaloperation(i.e.,excludesperiodsofstartupandshutdown).



Table1‐2.CokeOvenBatteryandCOGBoilerRACTSummary

Pollutant Limit Units ProposedRACTComplianceMethod

H2S 50 gr/100dscfPrimaryPre‐CombustionDesulfurization

H2SCEMS


Table1‐3.Top‐DownRACTProposalforCokeOvenBatteriesandCOGBoilers‐SO2Process Pollutant

ControlTechnology

Pre‐CombustionPrimaryDesulfurization

CoalSulfurContentRestrictions

ControlTechnologyDescription

UtilizesammoniawashtechnologyforthedissolutionofH2SwithNH4intheH2Swashertoensurethatsulfur

concentrationsinthecokeovengasarereducedpriortocombustion.The

systemalsoincludesadeacifiercolumnandasulfuricacidplant.a

UtilizescoalwithasulfurcontentlimittoreducetheformationofH2SandSO2.

TypicalWasteStreamInletFlowRate

63mmscfda N/A

TypicalWasteStreamInletPollutantConcentration

275grainsH2S/100scfcokeovengasb N/A

OtherConsiderationsDuringthebi‐annualoutageperiodsformaintenance,nodesulfurizationofthe

cokeovengasoccurs.

Theavailabilityoflow‐sulfurcoalmaybelimitedbythefluctuationsofregional

energymarkets.

RBLCDatabase

Information

NotincludedinRBLCforcontrolofSO2emissionsfromcokeovenbatteries.

IncludedinRBLCforthecontrolofSO2emissionsfromcokeovenbatteries.

Alsolistedforboilerslessthan100MMBtu/hr.

FeasibilityDiscussion

Feasible Feasible

Step3.RANKREMAINING

CONTROLTECHNOLOGIES

OverallControlEfficiency

BaseCase N/A‐InputRestriction

Step4.EVALUATEANDDOCUMENTMOST

EFFECTIVECONTROLS

CostEffectiveness($/ton)

Step5.

RACTLimit:50grainsH2S/100scf

cokeovengasc

a.Originaldesigncokeovengasgenerationrate.b.Condition5.1.17(2)ofR30‐00900002‐2010c.Condition3.1.26ofR30‐00900002‐2010

SELECTRACT

CokeOvenBatteriesandCOGBoilers

SO2

Step1. IDENTIFYAIRPOLLUTIONCONTROL

TECHNOLOGIES

Step2.

ELIMINATETECHNICALLYINFEASIBLEOPTIONS

Mountain State Carbon, LLC | SIP RACT ProposalTrinity Consultants

11PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-23


1.5. RACT EVALUATION FOR OUTAGE PERIODS

TheRACTevaluationforthecokeovenbatteriesandforthe90and98MMBtu/hrCOG‐firedboilersisprovidedinSection1.4.1.Asdiscussedabove,theRBLCwasusedinthisproposaltoidentifyemissioncontroltechnologiesandemissionlimitsdeterminedtobeRACTbythepermittingauthoritiesforemissionunitscomparabletothoseatthefacility.AppendixAprovidesasummaryofRBLCandpermitsearchresults.

1.5.1. SO2 RACT


Foratotalof20dayseachyear,MSCmusttemporarilyremovetheprimarydesulfurizationsystemfromservicetoconductinspectionsandimplementrepairsnecessarytomaintainthesystem(i.e.,outageperiods).Table1‐4inthissectionevaluatesRACTfortheseoutageperiods.ThemechanismsofSO2formationduringtheseoutageperiodsareconsistentwiththemechanismsdescribedinSection1.4.1.1;however,theRBLCdoesnotincluderecordsofanycontroltechnologydeterminationsspecificallyestablishedforoutageperiodsatbyproductrecoveryoperations.However,itshouldbenotedthatRBLCdoesprovidecleardocumentationthatoutagesofSO2controlsarepermittedforvariouscokeproductionoperationsasageneralmatter.


OneofthecontroltechniquesconsideredforoutageperiodsinvolvestheinstallationofaredundantdesulfurizationsystemcapableofmaintainingH2Sremovalduringplannedoutagesoftheexistingdesulfurizationsystem.Thiscontrolstrategyiseconomicallyinfeasibleandpresentssignificantoperationalchallengesgiventhatdesulfurizationsystemsarenotcapableofoperatingatlessthan30percentofthedesigncapacity.Asaresult,COGmustbedistributedbetweentheexistingandredundantdesulfurizationsystemsduringnormaloperation,andduringperiodsofdiminishedproduction,thecokeovenbatteriesmaynotgeneratesufficientCOGtosupplybothdesulfurizationsystems.Insuchascenario,operatorsofredundantsystemswouldberequiredtopurchase,store,andburnelementalsulfur(i.e.,intentionallygenerateSO2emissions)simplytomaintaintheoperationalintegrityofthedesulfurizationsystems.MSCconsideredtheseoperationalchallengeswhenevaluatingthetechnicalandeconomicalfeasibilityofthiscontroltechniqueinTable1‐4.


GiventhelimitednatureoftheseplannedoutageeventsandtheconclusionthatcurrentoperationsmeetRACT,weareproposingasulfurincoallimitationduringplannedoutagesastheRACTlimitation.Specifically,weproposethatcoalusedinthecokebatterieshaveanaverageblendedsulfurcontentofnogreaterthan1.25%.


Table1‐4.Top‐DownRACTProposalforDesulfurizationOutagePeriods‐SO2Process Pollutant

ControlTechnology

Pre‐CombustionRedundantDesulfurization

CoalSulfurContentRestrictions


UtilizesammoniawashtechnologyforthedissolutionofH2SwithNH4intheH2Swashertoensurethatsulfur

concentrationsinthecokeovengasarereducedpriortocombustion.The

systemalsoincludesadeacifiercolumnandacompactsulfuricacidplant.b

UtilizescoalwithasulfurcontentlimittoreducetheformationofH2SandSO2duringplannedoutagesoftheexisting

desulfurizationsystem.


63mmscfdb N/A


275grainsH2S/100scfcokeovengasc N/A

OtherConsiderations

Desulfurizationsystemistooperatecontinuouslyataminimum30%operationaldesigncapacity.Low

productionconditiondoesnotallowfortheoperationofboth(redundant)

desulfurizationplants.Theinstallationofadditionalequipmenttopurchase,storeandburnsulfur(createSO2)forthesolepurposeofoperatingtheacidplantwouldbenecessary.Necessaryrealestatefortheredundantplantdoes

notcurrentlyexist.

Theavailabilityoflow‐sulfurcoalmaybelimitedbythefluctuationsofregional

energymarkets.

RBLCDatabase

Information

NotincludedinRBLCforcontrolofSO2emissionsfromcokeovenbatteries.

IncludedinRBLCforthecontrolofSO2emissionsfromcokeovenbatteries.

Alsolistedforboilerslessthan100MMBtu/hr.


Feasible Feasible

Step3.RANKREMAINING

CONTROLTECHNOLOGIES


Similarcontrolefficiencyasexistingdesulfurizationfor20daysduringthebi‐

annualshutdownoftheprimarydesulfurizer

N/A‐InputRestriction


EFFECTIVECONTROLS

CostEffectiveness($/ton)

$7,981pertonofSO2removedbasedon20operatingdaysperyear.Thisis

beyondtherangeofcosteffectivenessforRACTforSO2.

a

Step5.

RACTLimits:1.25%sulfurcontentduringplannedoutagesoftheexisitng

desulfurizationsystem

a.DeterminedthroughacostestimatebyTrinityConsultantsdatedJanuary2015.b.Originaldesigncokeovengasgenerationrate.c.Condition5.1.17(2)ofR30‐00900002‐2010

SELECTRACT

CokeOvenBatteriesandCOGBoilersDuring

DesulfurizationOutagePeriods

SO2


TECHNOLOGIES

Step2.





1.6. ENGINE RACT EVALUATION

TheRACTevaluationforthe527and600horsepower(HP)dieselfiredenginesisprovidedinSection1.6.1.Asdiscussedabove,theRBLCwasusedinthisproposaltoidentifyemissioncontroltechnologiesandemissionlimitsdeterminedtobeRACTbythepermittingauthoritiesforemissionunitscomparabletothoseatthefacility.AppendixAprovidesasummaryofRBLCandpermitsearchresults.

1.6.1. SO2 RACT


ThemainsourceofSO2fromenginesisemittedthroughfluegasventing.TheenginesatMSC’sFollansbeeFacilityarefueledbydieselwhichcontainssulfur.Therefore,sulfurentersthecombustionprocessthroughthedieselfuel.DuringcombustionthesulfurinthedieselisoxidizedintoSOx,mostlySO2.TheformationofSO2ispredominatelydeterminedbytheinitialsulfurcontentinthediesel,andnottheengineparameters.Whendieseliscombusted,approximately95percentofthesulfurbecomesSO2,1to5percentbecomesSO3and1to3percentbecomessulfurparticulate9.Incombinationwithwatervapor,SO3quicklybecomesH2SO4,acorrosiveacid.


SO2reductionfromenginescanbeaccomplishedbythreegeneralmethodologies:fluegasdesulfurization,restrictionsonsulfurcontentoffuels,andgoodcombustionpractices.Fluegasdesulfurizationoxidizes,neutralizesorabsorbstheSO2fromthewastegasintoasolidcompoundwhilefuelrestrictionslimittheamountofsulfurinitiallyenteringtheprocess.Goodcombustionpracticesinvolvetheappropriateoperationandmaintenanceofequipmenttoensureproperfunctioningandnounintendedemissionincreases.UsingtheRBLCsearch,potentiallyapplicableSO2controltechnologiesfordieselfiredengineswereidentifiedbasedontheprinciplesofcontroltechnologyandengineeringexperienceforgeneralcombustionunits.Table1‐6outlinesthetop‐downRACTproposalforSO2emissionsfromtheengines.


TheRBLCentriesforSO2controlsareprovidedwithinAppendixA.Mostoftheemissionlimitsestablishedforsulfuremissionsfromdieselfiredenginesareeithermass‐based(e.g.,poundperhour)orconcentrationbased(e.g.,partspermillionbyvolume)exhaustlimitations.Certainoftheselimitsareevaluatedover3houraveragingperiods.MostofthefacilitiesidentifiedwiththemoststringentSO2emissionlimitsutilizedlowsulfurfuelforcontrolofSO2emissions.BasedonareviewoftheemissionlimitsachievableandrecentRACTdeterminationsforsimilarfacilities,SO2RACTfornormaloperationisalimitof0.1lbs/hrforEngineE1and0.1lbs/hrforEngineE5utilizinglowsulfurdieselandgoodcombustionpractices.Table1‐5summarizestheRACTdeterminationsfortheengines.TheseRACTlimitsareapplicableduringnormal(steady‐state)operation(i.e.,excludesperiodsofstartupandshutdown).

9U.S.EPA,CompilationofAirPollutantEmissionFactors,Chapter1,Section3.

http://www.epa.gov/ttnchie1/ap42/ch01/final/c01s03.pdf



Table1‐5.EngineRACTSummary

Pollutant

EngineEmissionUnitID Limit Units

AveragingPeriod ProposedRACT

ComplianceMethod

SO2 E1 0.1 lbs/hr N/AUseofLowSulfurDieselandGoodCombustionPractices

FuelUsageRecords

E5 0.1 lbs/hr 12‐mo.rolling

UseofLowSulfurDieselandGoodCombustionPractices

FuelUsageRecords


Table1‐6.Top‐DownRACTProposalforEngines‐SO2Process Pollutant

ControlTechnology

FlueGasDesulfurization FuelSulfurContentRestrictions GoodCombustionPractices


Injectsanalkalinereagentintothefluegasinaspraytowerordirectlyintotheductwhereitoxidizes,

neutralizes,and/orabsorbsSO2intoasolidcompound,eithercalciumor

sodiumsulfate.a

UtilizesfuelwithasulfurcontentlimittoreducetheformationofSO2during

combustion.

Operateandmaintaintheequipmentinaccordancewithgoodairpollutioncontrolpracticesandwithgoodcombustionpractices.

TypicalOperating

Temperature

300‐700°Fforwetscrubbers300‐1830°Ffordrysorbent

injectionaN/A N/A


15‐4300mmscfdb N/A N/A


Aslowas2000ppmvorlessa N/A N/A

OtherConsiderations

ChlorinecontentimprovesSO2removalbutincreasessalt

depositionintheequipment.Anadditionalfanmaybenecessarytokeeppressureconstantacrosstheabsorber.Inwetsystems,fluegasmayneedtobereheatedtopreventductcorrosionfromcondensation.Indrysystems,fluegasmayneedtobecooledpriortoenteringthe

system.a

N/A N/A

RBLCDatabase

Information

NotincludedinRBLCforthecontrolofSO2emissionsfromenginesgreaterthan500MMBtu/hr.

IncludedinRBLCforthecontrolofSO2emissionsfromenginesgreaterthan500

MMBtu/hr.

IncludedinRBLCforthecontrolofSO2emissionsfromenginesgreaterthan500

MMBtu/hr.


Technicallyinfeasible.Fluegasdesulfurizationistypicallyappliedtostationarycoal‐andoil‐firedcombustionunitsranginginsizebetween50and15,000MMBtu/hr.Theenginesatthisfacilityarefiredbydieselbutareratedatcapacitieswellbelowthelowerendoftheapplicablesizerange.Theenginesonlyoperateonanemergencybasis.

Feasible Feasible

Step3.RANKREMAINING

CONTROLTECHNOLOGIES


BaseCase BaseCase


EFFECTIVECONTROLS

CostEffectiveness

($/ton)

Step5.

RACTLimits:15ppmsulfurcontentindieselfuelc,0.1lbs/hrSO2forE1

d,

&0.1lbs/hrSO2forE5e

a.U.S.EPA,OfficeofAirQualityPlanningandStandards,"AirPollutionControlTechnologyFactSheet(FlueGasDesulfurization),"EPA‐452/F‐03‐034.b.DeterminedbasedonF‐factorsfromTable19‐2in40CFR60Method19andSourceA,EPA‐452/F‐03‐034.c.Condition6.1.12(f)(i)ofR30‐00900002‐2010d.ThepropsoedRACTforE1isbasedontheexistinglimitforasimilarsource(i.e.,E5).e.Condition9.1.4ofR30‐00900002‐2010

SELECTRACT

Engines SO2


TECHNOLOGIES

Step2.





1.7. NATURAL GAS COMBUSTION SOURCE RACT EVALUATION

TheFollansbeeFacilityincludesone(1)85MMBtu/hrnaturalgasfiredboilerandadditionalnaturalgasfiredcombustionsourcesratedlessthan10MMBtu/hrinsize.ThesesourcesproduceSO2throughfuelcombustionandcanbecontrolledthroughthesamemethodsoffluegasdesulfurization,fuelsulfurcontentrestrictions,andgoodcombustionpracticesdescribedabovefortheCOGboilersandengines.UsingtheRBLCsearch,potentiallyapplicableSO2controltechnologiesforthenaturalgascombustionsourceswereidentifiedbasedontheprinciplesofcontroltechnologyandengineeringexperienceforgeneralcombustionunits.Table1‐7outlinesthetop‐downRACTproposalforSO2emissionsfromtheengines.BasedonareviewoftheemissionlimitsachievableandrecentRACTdeterminationsforsimilarfacilities,SO2RACTfortheseunitsisgoodcombustionpractices.


Table1‐7.Top‐DownRACTProposalforNaturalGasCombustionUnits‐SO2Process Pollutant

ControlTechnology

FlueGasDesulfurization FuelSulfurContentRestrictions GoodCombustionPractices


Injectsanalkalinereagentintothefluegasinaspraytowerordirectlyintotheductwhereitoxidizes,neutralizes,and/orabsorbsSO2intoasolid

compound,eithercalciumorsodiumsulfate.a

UtilizesfuelwithlowsulfurcontenttoreducetheformationofSO2during

combustion.

Operateandmaintaintheequipmentinaccordancewithgoodairpollutioncontrolpracticesandwithgoodcombustionpractices.

TypicalOperating

Temperature

300‐700°Fforwetscrubbers300‐1830°Ffordrysorbent

injectionaN/A N/A


15‐4300mmscfdb N/A N/A


Aslowas2000ppmvorlessa N/A N/A

OtherConsiderations

ChlorinecontentimprovesSO2removalbutincreasessalt

depositionintheequipment.Anadditionalfanmaybenecessarytokeeppressureconstantacrosstheabsorber.Inwetsystems,fluegas

mayneedtobereheatedtopreventductcorrosionfrom

condensation.Indrysystems,fluegasmayneedtobecooledpriorto

enteringthesystem.a

N/A N/A

RBLCDatabase

Information

NotincludedinRBLCforthecontrolofSO2emissionsfromboilerslessthan100MMBtu/hr,therepresentativecategoryforthemiscellaneouscombustion

unitsonsite.

IncludedinRBLCforthecontrolofSO2emissionsfromboilerslessthan100MMBtu/hr,therepresentativecategoryforthemiscellaneouscombustionunits

onsite.

IncludedinRBLCforthecontrolofSO2emissionsfrom

boilerslessthan100MMBtu/hr,therepresentativecategoryforthemiscellaneouscombustionunitsonsite.


Technicallyinfeasible.Fluegasdesulfurizationistypicallyappliedtostationarycoal‐andoil‐firedcombustionunitsranginginsize

between50and15,000MMBtu/hr.Themiscellaneouscombustionunitsatthisfacilityaremuchsmallerthantheapplicablesizerange.

Feasible.Pipeline‐qualitynaturalgasisinherentlylowinsulfurcontent.

Feasible

Step3.RANKREMAINING

CONTROLTECHNOLOGIES


BaseCase


EFFECTIVECONTROLS

CostEffectiveness

($/ton)

Step5. RACT:UseofNaturalGas

RACT:GoodCombustion

Practices

a.U.S.EPA,OfficeofAirQualityPlanningandStandards,"AirPollutionControlTechnologyFactSheet(FlueGasDesulfurization),"EPA‐452/F‐03‐034.b.DeterminedbasedonF‐factorsfromTable19‐2in40CFR60Method19andSourceA,EPA‐452/F‐03‐034.

SELECTRACT

NaturalGasCombustionUnits

SO2


TECHNOLOGIES

Step2.




Mountain State Carbon, LLC | SIP RACT Proposal Trinity Consultants A-1

APPENDIX A

RACT Documentation


SO2‐FerrousMetals/Industry‐CokeProcesses‐CokeOvenBatteries‐Pushing

ID State CompanyCokemakingTechnique

PermitIssuanceDate Capacity Units Limit Units

AveragingPeriod ComplianceMethod ControlType Note(s)

LA‐0239 LAConsolidatedEnvironmentalManagementInc‐NucorSteelLouisiana

Non‐recovery 5/24/2010 126 tons/hr 21.22 lbs/hrOther‐40CFR60AppAMethod8

UnspecifiedorNone


Non‐recovery 5/24/2010 126 tons/hr 21.22 lbs/hrOther‐40CFR60AppAMethod8

UnspecifiedorNone

OH‐0272 OHSunCokeCompany‐HaverhillNorthCokeCompany

Non‐recovery 2/27/2001 4.3milliontons/yr

33.75 lbs/hr Unspecified None


Non‐recovery 12/11/2003 275,000 tons/yrcok 24 lbs/hr Unspecified Lowsulfurcoal<1%Additionallimitfornewbatteries:28.8lbsSO2perhourasa3‐houraverage.


Non‐recovery 12/11/2003 275,000 tons/yrcok 24 lbs/hr Unspecified Lowsulfurcoal<1%

OH‐0297 OHU.S.CokingGroup,L.L.C.‐FDSCoke


16.8 lbs/hr Unspecified UnspecifiedorNone

OH‐0332 OHSunCokeEnergy,Inc.‐MiddletownCokeCompany

Non‐recovery 2/9/2010 912,500 tons/yr 49 lbs/hr EPA/OARMethod6C None

MountainStateCarbonSO2RBLCReview A‐2


SO2‐FerrousMetals/Industry‐CokeProcesses‐CokeOvenBatteries‐Charging











Non‐recovery 12/11/2003 275,000 tons/yrcok 0.14 lbs/hr Unspecified Lowsulfurcoal<1%


Non‐recovery 12/11/2003 275,000 tons/yrcok 0.14 lbs/hr Unspecified Lowsulfurcoal<1%








Non‐recovery 2/9/2010 912,500 tons/yr 0.15 lbs/hr EPA/OARMethod6C NoneMethod6Conlyifrequired.Monthlycoalsamples.


Non‐recovery 2/9/2010 912,500 tons/yr 0.15 lbs/hr EPA/OARMethod6C NoneMethod6Conlyifrequired.Monthlycoalsamples.



SO2‐FerrousMetals/Industry‐CokeProcesses‐CokeOvenBatteries‐BatteryStack






243.3 lbs/hr UnspecifiedLimespraydryer,lowsulfurcoal,combustionoptimization

AdditionalLimit:0.99lbsSO2 pertonofwetcoalchargedwithcoalcontaininglessthan0.9wt.%sulfur;1.06lbsSO2/tonwithcoalcontaining0.9wt.%orgreatersulfur



243.3 lbs/hr UnspecifiedLimespraydryer,lowsulfurcoal,combustionoptimization

AdditionalLimit:0.99lbsSO2 pertonofwetcoalchargedwithcoalcontaininglessthan0.9wt.%sulfur;1.06lbsSO2/tonwithcoalcontaining0.9wt.%orgreatersulfur



0.1 lbs/hr Unspecified

IN‐0012 IN InlandSteelCo.‐InlandSteelCo.By‐productRecovery

9/22/1980 UnspecifiedUnderfirefuelislimitedtonaturalgas,desulfurizedcokeovengas,orblastfurnacegas.

WV‐0004 WVPennsylvaniaCokeTechnology,Inc.‐PennsylvaniaCokeTechnology,Inc.

By‐productRecovery

8/6/1981 210,000 tons/yr 161.1 lbs/hr UnspecifiedFuelSpec:Lowsulfurcoalfeed



SO2‐FerrousMetals/Industry‐CokeProcesses‐CokeOvenBatteries‐Coking




IN‐0012 IN InlandSteelCo.‐InlandSteelCo.By‐productRecovery

9/22/1980 0.35gr/100cfH2S

Unspecified LimitisLAER


Non‐recovery 5/24/2010 197 tons/hr 251.62 lbs/hr Other‐CEMS

Fluegasdesulfurization.Maximumcontentof1.25%sulfurinthecoal.Purchasenaturalgascontainingnomorethan2,000grainsofsulfurperMMscf

Sulfurdioxide>=90%captureefficiencywhenthe6monthrollingaverageconcentrationofsulfurintheblendedchargematerialislessthanorequalto1%.Sulfurdioxide>=91%captureefficiencywhenthe6monthrollingaverageconcentrationofsulfurintheblendedchargematerialisgreaterthan1%.PlannedmaintenancebypassofatowerwithintheCokeBattery1FGDsystemshallbelimitedtoamaximumof8dayswithinatwelvemonthrollingperiod.FluegasbypassinganFGDtowermustbedivertedtothebaghouseandmaynotbeventeddirectlytotheatmosphere.

MD‐0006 MDBethlehemSteelCorp.‐BethlehemSteelCorp.


8/6/1979 1.4milliontons/yrcoal

26 lbs/hr UnspecifiedFuelSpec:Sinfuellimitto1.0%bywt.

OH‐0040 OHRepublicSteelCorp.‐RepublicSteelCorp.


3/1/1983 32tons/hrcoke

35gr/100cfH2S

Unspecified Operating%mainten.proced.


Non‐recovery 2/27/2001 4 milliontons 265 lbs/hrAsa3‐houraverage

SO2CEMSDryscrubber,limespraydryer,andlowsulfurcoal:<4%sulfur

Nocostanalysissubmittedfortechnologyinstalled.Additionallimit:594lbs/hrand968.42tons/yr.


Non‐recovery 12/11/2003 275,000 tons/yrcok 192 lbs/hr SO2CEMSDryscrubberwithwetlimesprayinjectionandlowsulfur<1%coal


Non‐recovery 12/11/2003 275,000 tons/yrcok 192 lbs/hr SO2CEMSDryscrubberwithwetlimesprayinjectionandlowsulfur<1%coal


Non‐recovery 2/9/2010 2,300 tons/day 498.33 lbs/hr SO2CEMSBypassoneHRSGatatime,onestack

Estimated23.92lbsSO2/tonofcoal.Restrictedto960hoursbypassofHRSG/yr(tpylimit)andoneHRSGbypassedatatime.


Non‐recovery 2/9/2010 1,794 lbs/hr SO2CEMS

Duringthebypassofthespraydryerthechargesizeshallbereducedby28%orthesulfurincoalreducedby28%

Duringthebypassofthespraydryerthechargesizeshallbereducedby28%orthesulfurincoalreducedby28%.2491.7lbs/hrx72%=1794lbs/hrx120hoursx1ton/2000lbs=107.64T/YRfromspraydryer/baghousebypassfortheallowed120hours/YR.


Non‐recovery 2/9/2010 912,500 tons/yr 300 lbs/hrBasedon3‐hrblockaverage

SO2CEMS

Fabricfilter,commontunnelafterburnermaintainedat1,400degreesF,limespraydryer.

Otherlimit:192.0lbs/hrbasedona24‐hrblockaverage.IfrequiredMethod6C.Monthlycoalsamples.



SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐NaturalGas

ID State Company

PermitIssuanceDate FuelType Capacity Units Limit Units


AK‐0062 AK BadamiDevelopmentFacility 08/19/2005 NaturalGas 14.87 MMBtu/hr 250 ppmv H2SContentofNaturalGas

AK‐0062 AK BadamiDevelopmentFacility 08/19/2005 NaturalGas 1.34 MMBtu/hr 250 ppmv H2SContentofNaturalGas

AK‐0062 AK BadamiDevelopmentFacility 08/19/2005 NaturalGas 34 MMBtu/hr 250 ppmv H2SContentofNaturalGas

AL‐0230 ALThyssenkruppSteelandStainlessUSA,LLC

08/17/2007 NaturalGas 64.9 MMBtu/hr 0.0006 lb/MMBtu

AL‐0231 AL NucorDecaturLLC 06/12/2007 NaturalGas 95 MMBtu/hr 0.0006 lb/MMBtu

AR‐0090 AR NucorSteel,Arkansas 04/03/2006 NaturalGas 12.6 MMBtu/hr 0.1 lb/hr

AR‐0090 AR NucorSteel,Arkansas 04/03/2006 0.0006 lb/MMBtu

FL‐0286 FL FPLWestCountyEnergyCenter 01/10/2007 NaturalGas 99.8 MMBtu/hr 2 gr/100scf

FL‐0286 FL FPLWestCountyEnergyCenter 01/10/2007 NaturalGas 10 MMBtu/hr 2 gr/100scf

FL‐0335 FL SuwanneeMill 09/05/2012 NaturalGas 46 MMBtu/hr 2 gr/100scf GoodCombustionPractices

*IN‐0158 IN St.JosephEnergyCenter,LLC 12/03/2012 NaturalGas 80 MMBtu/hr 0.0022 lb/MMBtu 3hours FuelSpecifications

LA‐0192 LA CrescentCityPower 06/06/2005 19 MMBtu/hr 0.008 lb/hrHourlyMaximum

GoodCombustionPracticesandNaturalGasOnly

LA‐0203 LA OakdaleOSBPlant 06/13/2005 NaturalGas 66.5 MMBtu/hr 0.05 lb/hrHourlyMaximum

GoodCombustionPracticesandNaturalGasOnly

LA‐0231 LA LakeCharlesGasificationFacility 06/22/2009 NaturalGas 34.2 MMBtu/hr 0.02 lb/hrHourlyMaximum

NaturalGasorSNG

LA‐0231 LA LakeCharlesGasificationFacility 06/22/2009 NaturalGas 35 MMBtu/hr 0.02 lb/hrHourlyMaximum

NaturalGasorSNG

LA‐0231 LA LakeCharlesGasificationFacility 06/22/2009 NaturalGas 56.9 MMBtu/hr 0.03 lb/hrHourlyMaximum

NaturalGasorSNG

MD‐0040 MD CPVSt.Charles 11/12/2008 NaturalGas 1.7 MMBtu/hr 0

NJ‐0079 NJ WoodbridgeEnergyCenter 07/25/2012 NaturalGas 2000 hr/yr 0.162 lb/hrAvg.ofThreeTests

NaturalGasOnly

NJ‐0080 NJ HessNewarkEnergyCenter 11/01/2012 NaturalGas 51.9 mmcf/yr 0.08 lb/hr NaturalGasOnly

NV‐0044 NV Harrah'sOperatingCompany,Inc. 01/04/2007 NaturalGas 35.4 MMBtu/hr 0.001 lb/MMBtu NaturalGasOnly

NV‐0046 NV GoodspringsCompressorStation 05/16/2006 NaturalGas 3.85 MMBtu/hr 0.0026 lb/MMBtu NaturalGasOnly

NV‐0047 NV NellisAirForceBase 02/26/2008 NaturalGas 0.0015 lb/MMBtu NaturalGasOnly

NV‐0048 NV GoodspringsCompressorStation 05/16/2006 NaturalGas 3.85 MMBtu/hr 0.0015 lb/MMBtu NaturalGasOnly







NV‐0049 NV Harrah'sOperatingCompany,Inc. 08/20/2009 NaturalGas 24 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly



SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐NaturalGas

ID State Company




NV‐0050 NV MGMMirage 11/30/2009 NaturalGas 41.64 MMBtu/hr 0.0007 lb/MMBtu NaturalGasOnly


NV‐0050 NV MGMMirage 11/30/2009 NaturalGas 2 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly



NV‐0050 NV MGMMirage 11/30/2009 NaturalGas 2.1 MMBtu/hr 0.0048 lb/MMBtuGoodCombustionPracticesandNaturalGasOnly



NY‐0095 NY CaithnesBellportEnergyCenter 05/10/2006 NaturalGas 29.4 MMBtu/hr 0.0005 lb/MMBtu Low‐sulfurFuel

OH‐0309 OH ToledoSupplierPark‐PaintShop 05/03/2007 NaturalGas 20.4 MMBtu/hr 0.01 lb/hr

*OH‐0350 OH RepublicSteel 07/18/2012 NaturalGas 65 MMBtu/hr 0.037 lb/hr

OK‐0129 OK ChouteauPowerPlant 01/23/2009 NaturalGas 33.5 MMBtu/hr 0.03 lb/hr Low‐sulfurFuel

OK‐0129 OK ChouteauPowerPlant 01/23/2009 18.8 MMBtu/hr 0.01 lb/hr Low‐sulfurFuel

OK‐0134 OK PryorPlantChemical 02/23/2009 NaturalGas 20 MMBtu/hr 0.03 lb/hr NaturalGasOnly

OK‐0135 OK PryorPlantChemical 02/23/2009 NaturalGas 20 MMBtu/hr 0.03 lb/hr

OK‐0135 OK PryorPlantChemical 02/23/2009 NaturalGas 80 MMBtu/hr 0.2 lb/hr

*PA‐0291 PA HickoryRunEnergyStation 04/23/2013 NaturalGas 40 MMBtu/hr 0.0021 lb/MMBtu

*PA‐0296 PABerksHollowEnergyAssoc.LLC/Ontelaunee

12/17/2013 NaturalGas 8.5 MMBtu/hr 0.002 lb/MMBtu

*PA‐0296 PABerksHollowEnergyAssoc.LLC/Ontelaunee

12/17/2013 NaturalGas 40 MMBtu/hr 0.19 tpy12‐MonthRollingTotal

SC‐0112 SC NucorSteel‐Berkeley 05/05/2008 NaturalGas 50.21 MMBtu/hr 0.0006 lb/MMBtuGoodCombustionPracticesandNaturalGasOnly

SC‐0113 SC PyramaxCeramics,LLC 02/08/2012 NaturalGas 5 MMBtu/hr 0 NaturalGasandPropane

SC‐0114 SC GPAllendaleLP 11/25/2008 NaturalGas 20.89 MMBtu/hr 0.01 lb/hr

SC‐0114 SC GPAllendaleLP 11/25/2008 NaturalGas 75 MMBtu/hr 0.04 lb/hr GoodCombustionPractices

SC‐0115 SC GPClarendonLP 02/10/2009 NaturalGas 75 MMBtu/hr 0.04 lb/hr GoodCombustionPractices

SC‐0115 SC GPClarendonLP 02/10/2009 NaturalGas 20.89 MMBtu/hr 0.01 lb/hr

TX‐0501 TX TexstarGasProcessFacility 07/11/2006 NaturalGas 93 MMBtu/hr 0.05 lb/hr



SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐GaseousFuelandGaseousFuelMixtures

ID State Company



AK‐0056 AKARCOAlaska,Inc.‐AlpineDevelopmentProject,CentralProcessingFac

2/1/1999 Fuelgas 65.6 MMBtu/hr Seenote UnspecifiedFuelGasH2Snottoexceed200ppm

Fuellimit‐‐noemissionratelimit.


2/1/1999 Fuelgas 65.6 MMBtu/hr Seenote UnspecifiedFuelGasH2Snottoexceed200ppm

Fuelsulfurlimit‐‐noemissionratelimit


2/1/1999 Fuelgas 20 MMBtu/hr Seenote Unspecified

FuelGasH2Snottoexceed200ppmwhenoperatingusingliquidfuel:fuelsulfurlimitof215NG/J(0.50lb/Mmbtu)heatinput;or,asanalternative,0.5weightpercentsulfur.

Limitisfuelsulfurlimit.Noemissionratelimit


2/1/1999 Fuelgas 20 MMBtu/hr Seenote Unspecified

FuelGasH2Snottoexceed200ppmwhenoperatingusingliquidfuel:fuelsulfurlimitof215NG/J(0.50lb/Mmbtu)heatinput;or,asanalternative,0.5weightpercentsulfur.

Limitisfuelsulfurlimits.Noemissionratelimits

AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma

4/14/2005Refineryfuelgasornaturalgas

25 MMBtu/hr 35 ppmvDailyAverage

Unspecified Slimitedto35ppm.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.






4/14/2005Refineryfuelgasandgasesfromtanks

35 ppmvDailyAverage

UnspecifiedThissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.


4/14/2005Naturalgasorrefineryfuelgas

35 ppmvDailyAverage

Unspecified 35ppmsulfurlimitinfuel.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.


4/14/2005Refineryfuelgasandnaturalgas


UnspecifiedSulfurlimitedto35ppminfuel.

THE35PPMVSULFURLIMIT,ASH2S,ISARESTRICTIONONTHEINLETCONCENTRATIONOFTHEREFINERYFUELGASBEINGFIREDINTHEUNIT.








Unspecified Slimitedto35ppm.

THE35PPMVSULFURLIMIT,ASH2S,ISARESTRICTIONONTHEINLETCONCENTRATIONOFTHEREFINERYFUELGASBEINGFIREDINTHEUNIT.







23.2 MMBtu/hr 35 ppmvDailyAverage





Unspecified35ppmsulfurlimitonfuelburned.

Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.




Unspecified35ppmsulfurlimitonfuelburned.





UnspecifiedThislimitisforsulfur,asH2S,andisalimitontheinletconcentrationoftherefineryfuelgas.




ID State Company






Unspecified Slimitedto35ppm.Thislimitisforsulfur,asH2S,andisalimitontheinletconcentrationoftherefineryfuelgas.




Unspecified Slimitedto35ppm.Thislimitisonsulfur,asH2S,andisalimitontheinletconcentrationoftherefineryfuelgas.




Unspecified Slimitedto35ppm.Thislimitisonsulfur,asH2S,andisalimitontheinletconcentrationoftherefineryfuelgas.




UnspecifiedSulfurlimitedto35ppminfuelburned.



4/14/2005Naturalgasorrefineryfuelgas

346 MMBtu/hr 35 ppmv Daily Unspecified 35ppmsulfurlimitinfuel.

The35ppmvsulfurlimit,asH2S,isarestrictionontheinletconcentrationoftherefineryfuelgasbeingfiredintheunit.











100 MMBtu/hr 33.5 lbs/hr1‐hraverage

UnspecifiedThissulfurlimitisforanygasesfromthesulfurrecoveryplant.




Unspecified Fuellimitedto35ppmS.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.

LA‐0094 LAColumbianChemicalsCompany‐NorthBendPlant

9/29/1995 Tailgas 640 MMBtu/hr 1746.74 ppm Unspecified

Limitsulfurcontentoffeedstockto3wt%forrubbergradeand1.5wt%forindustrialgradeunits


9/29/1995 Tailgas 26 MMBtu/hr 2992.3 ppm Unspecified



9/29/1995 Tailgas 100 MMBtu/hr 3109.49 ppmv Unspecified


AdditionalEmissionLimit:2,269.44tons/yr

LA‐0149 LAMarathonAshlandPetroleumLLC‐Garyville‐LouisianaRefiningDivision

10/21/1999 Nat&refinerygas 281.1 MMBtu/hr 11.25 lbs/hr each Unspecified Lowsulfurfuel


10/21/1999 Nat&refinerygas 69.4 MMBtu/hr 2.78 lbs/hr Unspecified Lowsulfurfuel


10/21/1999 Nat&refinerygas 221 MMBtu/hr 8.85 lbs/hr Unspecified Lowsulfurfuel


10/21/1999 Nat&refinerygas 350 MMBtu/hr 11.21 lbs/hr Unspecified Useoflowsulfurfuel


10/21/1999 Nat&refinerygas 268.6 MMBtu/hr 10.75 lbs/hr Unspecified Lowsulfurfuels


10/21/1999 Nat&refinerygas 78 MMBtu/hr 3.13 lbs/hr Unspecified Lowsulfurfuel

LA‐0166 LAOrionRefiningCorp(nowValero)‐OrionRefiningCorp(nowValero)

1/10/2002 Refineryfuelgas 528 MMBtu/hr 14.2 lbs/hr Unspecified Lowsulfurrefinerygasfuel




ID State Company



LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery

12/27/2006 Refineryfuelgas 25ppmvasH2S

AnnualAverage

UnspecifiedUseoflowsulfurrefineryfuelgas


12/27/2006 Refineryfuelgas 25ppmvasH2S

AnnualAverage



12/27/2006 Refineryfuelgas 525.7 MMBtu/hr 25 ppmvAsH3Sannualaverage



12/27/2006 Refineryfuelgas MMBtu/hr 25 ppmvAsH2Sannualaverage



12/27/2006 Purgegas 1412.5 MMBtu/hr 25ppmvasH2S

AnnualAverage



12/27/2006 Refineryfuelgas MMBtu/hr 25ppmvasH2S

AnnualAverage



12/27/2006 Refineryfuelgas 155.2 MMBtu/hr 25 ppmvAsH2Sannualaverage



12/27/2006 Refineryfuelgas 9.6 MMBtu/hr 0.2 maxlbs/hr Unspecified


12/27/2006 H2plantfeedgas 2472 MMBtu/hr 0.01 maxlbs/hr Unspecified Complywith40CFR60.18

LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery

11/17/2009 Refineryfuelgas 354 MMBtu/hr 9.43 lbs/hrHourlyMaximum

Unspecified

UseofpipelinequalitynaturalgasorrefineryfuelgaseswithanH2Sconcentrationlessthan100ppmv(annualaverage).


11/17/2009 Processfuelgas Seenote UnspecifiedFueledbynaturalgasorprocessfuelgaswithH2S<=10ppmv(annualaverage)

Noemissionlimitsavailable


11/17/2009 Refineryfuelgas Seenote Unspecified


Noemissionlimits


11/17/2009 Processfuelgas Seenote Unspecified

UseofpipelinequalitynaturalgasorprocessfuelgaseswithanH2Sconcentrationlessthan10ppmv(annualaverage).

Noemissionlimits


11/17/2009 Refineryfuelgas 200 MMBtu/hr 0.45 LB/HHourlyMaximum

Unspecified

UseofpipelinequalitynaturalgasorprocessfuelgaseswithanH2Sconcentrationlessthan10ppmv(annualaverage).


11/17/2009 Refineryfuelgas Seenote Unspecified




11/17/2009 Refineryfuelgas 0 Seenote Unspecified


Noemissionlimits




ID State Company




11/17/2009 Refineryfuelgas 715 MMBtu/hr Seenote Unspecified

Fueledbynaturalgasand/orrefineryfuelgaswithH2S<=100ppmv(annualaverage)orprocessfuelgaswithH2S<=10ppmv(annualaverage)



11/17/2009 Refineryfuelgas 70 MMBtu/hr Seenote UnspecifiedFueledbynaturalgasand/orrefineryfuelgaswithH2S<=100ppmv(annualaverage)



11/17/2009 Refineryfuelgas 633 MMBtu/hr Seenote UnspecifiedFueledbynaturalgasand/orrefineryfuelgaswithH2S<=100ppmv(annualaverage)



11/17/2009 Processfuelgas 15 MMBtu/hr Seenote UnspecifiedFueledbynaturalgasorprocessfuelgaswithH2S<=10ppmv(annualaverage)


LA‐0234 LACITGOPetroleumCompany‐LakeCharlesComplex‐CatGasHydro

1/26/2009 Fuelgas 62.8 MMBtu/hr 5.08 lbs/hr UnspecifiedLowsulfurconcentrationinthefuelgas

OriginalPSDestablishedanaveragesulfurconcentrationof182ppmandamaximumof332ppminthefuelgas.Thisreconciliationafterdeterminingmoreupdatedsulfurconcentrationsraisesthosevaluestoanaverageof218.4ppmandamaximumof475ppminthefuelgas.
















ID State Company




1/26/2009 Fuelgas 62.8 MMBtu/hr 5.08 lbs/hr UnspecifiedUselowsulfurconcentrationfuelgas.


NJ‐0053 NJMCUALandfillGasUtilizationProject‐MCUA

3/9/1999 Landfillgas 31 MMBtu/hr 1.73 lbs/hr Unspecified None

NJ‐0053 NJMCUALandfillGasUtilizationProject‐MCUA

3/9/1999 Landfillgas 90 MMBtu/hr 3.6 lbs/hr Unspecified NoneAdditionalEmissionLimit:0.04lbs/MMbtu

NJ‐0061 NJ Merck‐Merck‐RahwayPlant 9/18/2003Naturalgasco‐firedwithwastesolvent

99.5 MMBtu/hr 5.1 lbs/hr Unspecified

Theuseoflowsulfurcontentinfuel:0.055%sulfurinfuelbyweightforthemixtureofnaturalgasandwastesolventisconsideredBACTforSO2.

PA‐0231 PAUnitedRefineryCo‐UnitedRefineryCo.

10/9/2003 Refinerygas 116 MMBtu/hr 2.71 lbs/hr Unspecified LowsulfurrefinerygasBestavailabletechnology(BAT)reviewdone.


10/9/2003 Refinerygas 91 MMBtu/hr 2.44 lbs/hr Unspecified LowsulfurrefinerygasBestavailabletechnology(BAT)reviewdone.


10/9/2003 Refinerygas 344 MMBtu/hr 9.22 lbs/hr Unspecified GoodcombustionpracticeBestavailabletechnology(BAT)reviewdone.


10/9/2003 Refinerygas 147 MMBtu/hr 46.22 lbs/hr UnspecifiedUseofdesulfurizedrefinerygas

Bestavailabletechnology(BAT)reviewdone.

TX‐0284 TXPraxairIncorporated‐PraxairSynthesisGasPlant

10/20/1998 Processgas MMBtu/hr 1.14 lbs/hr Unspecified Noneindicated

TX‐0348 TXDiamondShamrockRefiningCompanyLP‐DiamondShamrockMcKeePlant

10/19/2001 Fuelgas 38.5 MMBtu/hr 1.46 lbs/hr Unspecified NoneindicatedStandardemissionlimitscalculatedfromhourlylimitsandprocessrating.








10/19/2001 Fuelgas 30.1 MMBtu/hr 1.14 lbs/hr Unspecified NoneindicatedStandardemissionlimitscalculatedbydividingthehourlyemissionlimitbythethroughput.


10/19/2001 Fuelgas 37 MMBtu/hr 1.4 lbs/hr Unspecified NoneindicatedStandardemissionlimitscalculatedfromhourlylimitsandprocessrating.

TX‐0375 TXLyondell‐CITGORefining,LP‐Lyondell‐CITGORefining,LP

3/14/2002 Petrorefingas 586 MMBtu/hr 15.1 lbs/hr EACH Unspecified

LowSfuel:FuelgaswithH2Scontentnomorethan0.1gr/dscfovera3hrollingbasis,ornaturalgaswithH2Scontentnomorethan0.25gr/100dscfandtotalScontentnomorethan5.0gr/100dscf.




ID State Company



TX‐0375 TXLyondell‐CITGORefining,LP‐Lyondell‐CITGORefining,LP

3/14/2002 Petrorefingas 38.34 MMBtu/hr 1 lbs/hr Unspecified

LowSfuel:FuelgaswithH2Scontentnomorethan0.1gr/dscfovera3hrollingbasis,ornaturalgaswithH2Scontentnomorethan0.25gr/100dscfandtotalScontentnomorethan5.0gr/100dscf.

TX‐0395 TXDiamondShamrockRefiningCompany‐DiamondShamrockMcKeePlant

5/23/2000 Refinerygas 32.7 MMBtu/hr 1.23 lbs/hr Unspecified


5/23/2000 Refinerygas 248 MMBtu/hr 9.33 lbs/hr Unspecified


5/23/2000 Refinerygas 20 MMBtu/hr 0.75 lbs/hr Unspecified







TX‐0442 TXShellOilCompany‐ShellOilDeerPark

7/30/2004 Refineryfuelgas 300 ppm Unspecified

TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant

1/1/2005 Fuelgas 0.8 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas








1/1/2005 Fuelgas 4 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas






1/1/2005 Fuelgas 4 lbs/hr Unspecified LimitH2Sinfuelgas




1/1/2005 Fuelgas 7.8 lbs/hr Unspecified LimitH2Sinfuelgas


1/1/2005 Fuelgas 2 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas




ID State Company
























1/1/2005 Fuelgas 1.5 lbs/hr Unspecified



TX‐0472 TXFlintHillsResourcesLP‐FlintHillsResourcesCorpusChristiWestPlant

1/24/2005Naturalgasandrefineryfuelgas

100%CombconvtoSO2

Unspecified

SO2emissionsareestimatedusingthemaximumandaverageH2Scontentinthefuelgasandassuming100%combustionconversiontoSO2.Theshort‐termmaximumH2Scontentis162ppmvona3‐hourrollingaverageinaccordancewithNSPSSubpartJ.TheaverageH2Scontentis81ppmvona365‐dayrollingaverage.

*WY‐0071 WYSinclairWyomingRefiningCompany‐SinclairRefinery

10/15/2012 Refineryfuelgas 50 MMBtu/hr UnspecifiedFollowSubpartJaFuelgasH2Slimits


10/15/2012 Refineryfuelgas 233 MMBtu/hr UnspecifiedFollowSubpartJaFuelgasH2Slimits


10/15/2012 Refineryfuelgas 64.2 MMBtu/hr UnspecifiedFollowSubpartJaFuelgasH2Slimits









SO2‐InternalCombustionEngines‐LargeInternalCombustionEngines(>500HP)‐DieselFuel

ID State Company

PermitIssuanceDate FuelType Capacity Unit Limit Unit


*IN‐0158 INSt.JosephEnergyCenter,LLC‐St.JosephEnergyCenter,LLC

12/3/2012 Diesel 1,006 hpeach 0.012 lbs/hr UnspecifiedUltralowsulfurdistillateandusagelimits

Limitoneandtwoareforeachgenerator


12/3/2012 Diesel 2,012 hp 0.024 lbs/hr 3HOURS UnspecifiedUltralowsulfurdistillateandusagelimits


*WY‐0070 WYBlackHillsPower,Inc.‐CheyennePrairieGeneratingStation

8/28/2012Ultralowsulfur

diesel839 hp EPA/OARMethod6 UltraLowSulfurDiesel

limitedto500hoursofnon‐emergencyoperationpercalendaryear

AK‐0037 AKTesoroAlaskaCompany‐KenaiRefinery

3/21/2000 Diesel 660 hp 500 ppmAveragedover3hours

Unspecified

Fuelsulfurcontentlimitsasfollows:Dieselfuel,0.35%sulfur;Naturalgas,0.01%sulfur;LPG,0.01%sulfur;refinerygas,168ppmvH2S.

Estimatedemissionsare0.2tons/year,butthisisnotanemissionlimit.

AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject

2/5/1999 Diesel 500 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.

BACT:Fuelsulfurcontentlimitstate:emissionlimit1andhydrogensulfidecontentrestrictionstothefuel.


2/5/1999 Diesel 650 hpSeecontroldescription

UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.



Ensuretheemissionlimitbycomplyingwiththefuelrestriction18AAC50.055:emissionlimit1



BACT:FuelsulfurcontentlimitState:emissionlimit1andhydrogensulfidecontentrestrictionstothefuel.





2/5/1999 Diesel 950 hpSeecontroldescription



2/5/1999 Diesel 1,200 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.

BACT:FuelsulfurcontentlimitSTATE:Emissionlimit1


2/5/1999 Diesel 1,215 hpSeecontroldescription















2/5/1999 Diesel 6,200 hpSeecontroldescription


LA‐0122 LAInternationalPaper‐MansfieldMill‐MansfieldMill

8/14/2001 Diesel 587 hp 1.2 lbs/hr Unspecified Preventativemaintenance


8/14/2001 Dieselfuel 775 hpeach 1.6 lbs/hr each Unspecified Preventativemaintenance


8/14/2001 Dieselfuel 1,100 hpeach 2.2 lbs/hr each Unspecified Preventativemaintenance

MN‐0053 MNMNMunicipalPowerAgency‐FairbaultEnergyPark

7/15/2004 Diesel 670 hp 0.051 lb/MMbtu Unspecified Lowsulfurfuel

MN‐0054 MN ‐MankatoEnergyCenter 12/4/2003 Dieselfuel 1,850 hp 0.59 G/B‐HP‐H Unspecified Lowsulfurfuel

OK‐0056 OKMustangPowerLLC‐HorseshoeEnergyProject

2/12/2002 Dieselfuel 1,000 hp 0.05 lb/MMbtu Unspecified Lowsulfurdieselfuel

OK‐0072 OKRedbudEnergyLP‐RedbudPowerPlt

5/6/2002 Dieselfuel 1,818 hp 0.4 lb/MMbtu Unspecified




ID State Company



OK‐0090 OKDukeEnergy‐DukeEnergyStephens,LLCStephensEnergy

3/21/2003 Diesel 749 bhp 0.3 lbs/hr UnspecifiedUseoflowsulfurdieselfuel(<0.05%Sbywt)

OK‐0129 OKAssociatedElectricCooperativeInc‐ChourteauPowerPlant

1/23/2009 Lowsulfurdiesel 2,200 hp 0.89 lbs/hr Unspecified Lowsulfurdiesel0.05%S

SC‐0113 SCPyramaxCeramics,LLC‐PyramaxCeramics,LLC

2/8/2012 Diesel 500 hp Unspecified

Useoflowsulfurdiesel,sulfurcontentlessthan0.0015percent.Operatinghourslessthan100hoursperyearformaintenanceandtesting.

Dieselfuelsulfurcontentshallbe<0.0015percent.Reportsoffuelsulfurcontentshallbemaintained.



Useoflowsulfurdiesel,sulfurcontentlessthan0.0015percent.Operatinghourslessthan100hoursperyearformaintenanceandtesting.

Dieselfuelsulfurcontentshallbe<0.0015percent.Reportsoffuelsulfurcontentshallbemaintained.

TX‐0407 TXSteagPowerLLC‐SterneElectricGeneratingFacility

12/6/2002 Diesel 1,350 hp 2.77 lbs/hr UnspecifiedDistillatefueloilcontainingnomorethan0.2weightpercentofsulfur.

WV‐0023 WV LongviewPower,LLC‐Maidsville 3/2/2004 Diesel 1,801 hp 6.5 lbs/hr UnspecifiedSulfurcontentlimitedto0.05%byweight

Limitedto500hoursofoperationayear

AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant

5/8/2000 Diesel 835 kW 63.3tons/12mo.period

Combinedlimit,allfuelburningsources

Unspecified

Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.

OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.




Unspecified

Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.



5/8/2000 Diesel 1,050 kW 63.3tons/12mo.period


Unspecified

Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.Followthepowergenerationlimitsasspecifiedintheprocessnotes.





Unspecified






Unspecified






Unspecified






Unspecified






ID State Company






Unspecified






Unspecified



AK‐0045 AKPhillipsPetroleumCompany‐NorthCookInletUnit

6/6/2000 Diesel 500 kWeach 500 ppm 3hav,each Unspecified

Usenaturalgaswithahydrogensulfidecontentnottoexceed200ppmandafueloilwithasulfurcontentnottoexceed0.25%byweight

Limitsetaccordingto18AAC50.055(C)


3/21/2000 Fueloil 2 mWSeecontroldescription

Unspecified

Useonlyfuelgaswithahydrogensulfidecontentnottoexceed200ppmanduseadistillatefueloilwithasulfurcontentnottoexceed0.15%byweight


3/21/2000 Fueloil 2 mWSeecontroldescription

Unspecified

Useonlyfuelgaswithahydrogensulfidecontentnottoexceed200ppmanduseadistillatefueloilwithasulfurcontentnottoexceed0.15%byweight

AK‐0059 AKUSAFEarecksonAirStation‐USAFEarecksonAirStation

9/29/2003 Diesel Seenote Unspecified Lowsulfurfuel:<0.3%SbywtBACTisfuelsulfurlimit.Noemissionratelimit.

AK‐0060 AKWestwardSeafoods,Inc.‐DutchHarborSeafoodProcessingFacility

10/10/2003 Distillatefueloil 2,220 kW Seenote Unspecified

Lowsulfurfuel:sulfurrestrictionof0.24%SbywtforajetAanddieselno.2fuelblend.

BACTisfuelsulfurlimit.Massbalancecalculationsresultinanestimated56ppmv.

AK‐0061 AKNomeJointUtilitiesSystem‐SnakeRiverPowerPlant

11/5/2004 Dieselfuel 5,211 kW 0.5 %SbywtPershipmentdelivered

UnspecifiedLimitsulfurcontentindieselfuel.

FL‐0310 FLShadyHillsPowerCompany‐ShadyHillsGeneratingStation

1/12/2009 UltraLowSoil 3 mW 0.0015 %SbywtNA/recordkeeping

Other‐ULSOFiringultralowsulfuroilwithamaximumhoursofoperationof500hrs/yr.

Compliancedemonstratedbyverificationdeliveryreceipts

*FL‐0346 FLFloridaPower&Light‐LauderdalePlant

4/22/2014 ULSD 2MMBtu/hr(HHV)perengine

15ppmsulfurinfuel

Unspecified ULSDrequiredBACT=NSPSIIII;CertifiedIIIIenginemeetsBACT.ULSDrequiredinNSPS.

IA‐0088 IAArcherDanielsMidland‐ADMCornProcessing‐CedarRapids

6/29/2007 Diesel 1,500 kW 0.17 G/B‐HP‐HAverageof3testruns

UnspecifiedBurnlow‐sulfurdieselfuel.0.05%bywtorlessnottoexceedtheNSPSrequirement.

IA‐0095 IA‐Tate&LyleIngredientsAmericas,Inc.

9/19/2008 Diesel 700 kW 0.23 G/KW‐HAverageofthreestacktestruns

Unspecified Fuelsulfurlimit

KS‐0028 KSKansasCityBoardOfPublicUtilities‐NearmanCreekPowerStation

10/18/2005 No.2fueloil 24 MMBtu/hr 1.2 lbs/hrFullloadoperations

Unspecified Goodcombustioncontrol

SC‐0114 SC GPAllendaleLP‐GPAllendaleLP 11/25/2008 Diesel 525 hp 0.39 lbs/hr EPA/OARMethod6C

Tune‐upsandinspectionswillbeperformedasoutlinedinthegoodmanagementpracticeplan.

Annualemissionsfromthedieselfirepumparebasedonanoperationallimitof500hr/yr.

SC‐0115 SCGPClarendonLP‐GPClarendonLP

2/10/2009 Diesel 525 hp 0.39 lbs/hr EPA/OARMethod6C


Annualemissionsfromthedieselfirepumparebasedonanoperationallimitof500hr/yr.




ID State Company



IA‐0088 IAArcherDanielsMidland‐ADMCornProcessing‐CedarRapids

6/29/2007 Diesel#2 540 hp 0.17 G/B‐HP‐HAverageof3testruns

UnspecifiedBurnlow‐sulfurdieselfuel.0.05%bywtorlessnottoexceedtheNSPSrequirement.

MN‐0050 MNLakefieldJunctionLP‐LakefieldJunctionLPGeneratingStation

5/4/2000 Diesel 2 mW 0.5 lb/MMbtu UnspecifiedLowsulfurfuel;limitedoperationto1,000h/rolling12‐mo

VA‐0276 VAIngencoDistributedEnergy‐Ingenco‐CharlesCityPlant

6/20/2003 Fueloil 550 hp 0.5 lb/MMbtu Unspecified Goodcombustionpractices

Additionallimits:29.0t/yrtotalfacility,1.5G/BHP‐H(calculated).emissionsfromtheoperationofanyindividualengine,groupofsixengineswhenthefacilityisoperatedineitherthesinglefuelorthedualfuelmodeshallnotexceedthelimitsspecified.

VA‐0305 VA Ingenco‐IngencoK&OFacility 9/26/2007 Distillateoil 550 hp 30.7 tons/yr UnspecifiedGoodcombustionpracticesandcontinuousmonitoringdevices

Emissionlimitsarefor1of48engines.

IA‐0095 IA‐Tate&LyleIngredientsAmericas,Inc.

9/19/2008 Diesel 575 hp 0.23 G/KW‐HAverageofthreestacktestruns

Unspecified Limitonsulfurinfuel

*IN‐0166 INIndianaGasification,LLC‐IndianaGasification,LLC

6/27/2012 Diesel 575 hpeach 15 ppmsulfur UnspecifiedUseoflow‐Sdieselandlimitedhoursofnon‐emergencyoperation

Emissionlimits:eachemergencygeneratorshallnotexceed52hoursperyearofnonemergencyoperation.

MN‐0070 MN ‐MinnesotaSteelIndustries,LLC 9/7/2007 Diesel 0.05 %Sulfurbyweightinfuel

UnspecifiedLimitedhours,limitedsulfurinfuel

Limitedto500hoursperyear(12monthrollingaverage);sulfurlimitforfuellimitsSO2emissions.

MN‐0071 MNMinnesotaMunicipalPowerAgency‐FairbaultEnergyPark

6/5/2007 No.2 1,750 kW 0.0004 LB/HP‐H3houraverage

UnspecifiedIncludingssm.10hour/dayoperatinglimit

NC‐0074 NC

Bridgestone/FirestoneNorthAmericanTire‐Bridgestone/FirestoneNorthAmericanTire

1/24/2003 Diesel 16 MMBtu/hr 2.3 lb/MMbtu Unspecified

NC‐0074 NC

Bridgestone/FirestoneNorthAmericanTire‐Bridgestone/FirestoneNorthAmericanTire

1/24/2003 Diesel 4 MMBtu/hr 2.3 lb/MMbtu Unspecified

NJ‐0036 NJAESRedOakLLC‐AESRedOakLLC

10/24/2001 Dieselfuel 49 MMBtu/hr 2.45 lbs/hr Unspecified Lowsulfurfuel

NV‐0047 NV99CivilEngineerSquadronOfUsaf‐NellisAirForceBase

2/26/2008 Dieseloil 0.02 G/B‐HP‐H UnspecifiedLimitingsulfurcontentinthedieseloilto0.05%

OH‐0254 OHDukeEnergyNorthAmerica‐DukeEnergyWashingtonCountyLLC

8/14/2003 Diesel 600 kW 0.4 lbs/hr UnspecifiedLowsulfurfuel,combustioncontrol

LA‐0231 LALakeCharlesCogeneration,LLC‐LakeCharlesGasificationFacility

6/22/2009 Diesel 575 hpeach 0.01 lbs/hrMaximum(each)

UnspecifiedComplywith40CFR60SUBPARTIIII

OH‐0255 OHAmericanElectricPower‐AEPWaterfordEnergyLLC

3/29/2001 Diesel 1,000 kW 0.01 tons/yr Unspecified LowsulfurfuelUnitlimitedto500hoursper12monthperiod.

OH‐0266 OHUniversityOfCincinnati‐UniversityOfCincinnati

8/15/2002 Dieselfueloil 19 MMBtu/hr 0.043 lb/MMbtu UnspecifiedSulfurcontentofdieselfuellessthan0.05percent.

Limitsareforeachengine.

OH‐0275 OHCinergy‐PSIEnergy‐MadisonStation

8/24/2004 Dieselfuel 17 MMBtu/hr 8.61 lbs/hr UnspecifiedSulfurlimitedto0.05%byweight.Operationslimitedto499hourperyear

Eachgeneratorrestrictedto499h/yrofoperation


8/14/2001 Diesel 587 hp 1.2 lbs/hr Unspecified Preventativemaintenance

*OH‐0352 OHArcadis,Us,Inc.‐OregonCleanEnergyCenter

6/18/2013 Diesel 2,250 kW 0.03 lbs/hr EPA/OARMethod6C Method6cifrequired




ID State Company




3/21/2000 Diesel 660 hp 500 ppmAveragedover3hours

Unspecified

Fuelsulfurcontentlimitsasfollows:diesel,0.35%sulfur;naturalgas,0.01%sulfur;LPG,0.01%sulfur;refinerygas,168ppmvH2S.

Estimatedemissionsare0.5t/yr,butthisisnotanemissionlimit.

MN‐0053 MNMNMunicipalPowerAgency‐FairbaultEnergyPark

7/15/2004 Diesel 670 hp 0.051 lb/MMbtu Unspecified Lowsulfurfuel

AR‐0051 ARDukeEnergy‐DukeEnergy‐JacksonFacility

4/1/2002 Dieselfuel 671 hp Seenotes Unspecified Fuelslimit:0.05%Sbywt Noemissionratelimit,limitisfuelslimit.

OK‐0090 OKDukeEnergy‐DukeEnergyStephens,LLCStephensEnergy

3/21/2003 Diesel 749 bhp 0.3 lbs/hr UnspecifiedUseofLowSulfurdieselfuel(<0.05%Sbywt)

OK‐0091 OKCardinalFGCo.‐CardinalFGCo./CardinalGlassPlant

3/18/2003 Diesel 2,000 kW 0.05 lb/MMbtu Unspecified Lowsulfurfuel,<0.05%S



Useoflowsulfurfueldiesel,sulfurcontentlessthan0.0015percent.Operatinghourslessthan100hoursperyearformaintenanceandtesting.

Sulfurcontentofdieselfueltobelessthat0.0015percent.Suppliercertificationoffuelsulfurcontentshallbemaintained.


8/14/2001 Dieselfuel 775 hpeach 1.6 lbs/hr Each Unspecified Preventativemaintenance

*WY‐0070 WYBlackHillsPower,Inc.‐CheyennePrairieGeneratingStation

8/28/2012Ultralowsulfur

diesel839 hp EPA/OARMethod6 Ultralowsulfurdiesel

limitedto500hoursofnon‐emergencyoperationpercalendaryear

PR‐0005 PRPuertoRicoElectricAuthority(PREPA)‐SanJuanRepoweringProject

3/2/2000 Dieselfuel 5,000 kW 2.65 lbs/hr Unspecified Goodcombustioncontrol

SC‐0064 SCSCE&G‐SCE&G‐JasperCountyGeneratingFacility

5/23/2002 Diesel 2,000 kW 0.9 lbs/hr Unspecified Lowsulfur(0.05%)diesel


12/3/2012 Diesel 1,006 hpeach 0.012 lbs/hr UnspecifiedUltralowsulfurdistillateandusinglimits


AK‐0066 AK

BritishPetroleumExplorationAlaska(BPXA)‐EndicottProductionFacility,LibertyDevelopmentProject

6/15/2009 Distillate 1,041 hp 15 ppmw Unspecified LimitsulfurinfuelBaselineselectedasBACT.ThisfuelsulfurlimitappliesorwillapplytoallnewemissionunitsinPrudhoeBay


8/14/2001 Dieselfuel 1,100 hpeach 2.2 lbs/hr Each Unspecified Preventativemaintenance

OK‐0128 OKMidAmericanSteelAndWireCompany‐MidAmericanSteelRollingMill

9/8/2008 No.2diesel 1,200 hp 0.49 lbs/hr Unspecified500hoursperyear,0.05%sulfurdieselfuel

*IN‐0166 INIndianaGasification,LLC‐IndianaGasification,LLC

6/27/2012 Diesel 1,341 hpeach 15 ppmsulfur UnspecifiedUseoflow‐Sdieselandlimitedhoursofnon‐emergencyoperation.

Emissionlimit:eachemergencygeneratorshallnotexceed52hoursperyearofnonemergencyoperation.

LA‐0231 LALakeCharlesCogeneration,LLC‐LakeCharlesGasificationFacility

6/22/2009 Diesel 1,341 hpeach 0.01 lbs/hrMaximum(each)

UnspecifiedComplywith40CFR60SUBPARTIIII

TX‐0407 TXSteagPowerLLC‐SterneElectricGeneratingFacility

12/6/2002 Diesel 1,350 hp 2.77 lbs/hr UnspecifiedDistillatefueloilcontainingnomorethan0.2weightpercentofsulfur.

*SC‐0132 SC ArgosUsa‐ArgosHarleyvillePlant 12/14/2007 Diesel 1,000 kW NoneselectedinSAEMustmeet40CFR60subpartIIIIrequirements

TX‐0262 TXArcherPowerPartners,L.P.‐ArcherGeneratingStation

1/3/2000 Dieselfuel 2,000 kW 1.9 lbs/hr Unspecified Additionalemissionlimit:.32G/BHP‐H.

SC‐0114 SC GPAllendaleLP‐GPAllendaleLP 11/25/2008 Diesel 1,400 hp 5.4 lbs/hr EPA/OARMethod6C

SC‐0115 SCGPClarendonLP‐GPClarendonLP

2/10/2009 Diesel 1,400 hp 5.4 lbs/hr EPA/OARMethod6C


Annualemissionsfromthedieselemergencygeneratorarebasedonanoperationallimitof500hr/yr.




ID State Company



CO‐0055 COLamarUtilitiesBoardDBALamarLight&Power‐LamarLight&PowerPowerPlant

2/3/2006 Diesel 1,500 hp 0.06 lb/MMbtu UnspecifiedLowsulfurfuel.Lessthan0.05byweight

WV‐0023 WV LongviewPower,LLC‐Maidsville 3/2/2004 Diesel 1,801 hp 6.5 lbs/hr UnspecifiedSulfurcontentinthefuellimitedto0.05%byweight

Limitedto500hoursofoperationayear

OK‐0072 OKRedbudEnergyLP‐RedbudPowerPlt

5/6/2002 Dieselfuel 1,818 hp 0.4 lb/MMbtu Unspecified

WA‐0328 WABPWestCoastProducts,LLC‐BPCherryPointCogenerationProject

1/11/2005 Dieselfuel 2 mW UnspecifiedFuelmustsatisfyrequirementsofon‐roaddieselspecificationsattimeoffuelpurchase

*Seenotes‐seecontrolmethoddescriptionforSO2above

WI‐0174 WIBadgerGeneratingCoLLC‐BadgerGeneratingCoLLC

9/20/2000 Diesel 4 MMBtu/hr 1.02 lbs/hr Unspecified

Sulfurcontent<=.05%bywt.Permitlimitsarefuelsulfurcontentlimitandlb/hlimit,notG/BHP‐H.

WI‐0174 WIBadgerGeneratingCoLLC‐BadgerGeneratingCoLLC

9/20/2000 Diesel 4 MMBtu/hr 1.1 lbs/hr Unspecified

Theuseofdieselfuelhavingasulfurcontentof.05%bywt.,andequipmentusagelimits.Permitlimitsarefuelsulfurcontentlimitsandlb/hlimit,notlimitinG/BHP‐H.

MN‐0054 MN ‐MankatoEnergyCenter 12/4/2003 Dieselfuel 1,850 hp 0.59 G/B‐HP‐H Unspecified Lowsulfurfuel

AK‐0062 AKBPExplorationAlaska‐BadamiDevelopmentFacility

8/19/2005 Dieselfuel 1,855 hp 0.15 %bywtSulfurinfueloil

UnspecifiedLimitsulfurcontentoffuelcombusted

Seenotes:limitsulfurcontentoffuelcombusted


12/3/2012 Diesel 2,012 hp 0.024 lbs/hr 3hours UnspecifiedUltralowsulfurdistillateandusagelimits


OK‐0129 OKAssociatedElectricCooperativeInc‐ChouteauPowerPlant

1/23/2009 Lowsulfurdiesel 2,200 hp 0.89 lbs/hr Unspecified Lowsulfurdiesel0.05%S



appendix c: ract

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