appendix c: ract
TRANSCRIPT
west virginia department of environmental protection
Appendix C: RACT
Promoting a healthy environment.
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WV DEP RACT Analysis
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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
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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
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RACT Analysis Mountain State Carbon, LLC
Follansbee, WV
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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".
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RACT Analysis Mountain State Carbon, LLC
Follansbee, WV
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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.
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November 30, 2015
RACT Analysis Mountain State Carbon, LLC
Follansbee, WV
2MSC SO RACT Proposal
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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
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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
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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)).
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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.
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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.
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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.
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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
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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
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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).
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Table1‐2.CokeOvenBatteryandCOGBoilerRACTSummary
Pollutant Limit Units ProposedRACTComplianceMethod
H2S 50 gr/100dscfPrimaryPre‐CombustionDesulfurization
H2SCEMS
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-22
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
Mountain State Carbon, LLC | SIP RACT Proposal Trinity Consultants 12
1.5. RACT EVALUATION FOR OUTAGE PERIODS
TheRACTevaluationforthecokeovenbatteriesandforthe90and98MMBtu/hrCOG‐firedboilersisprovidedinSection1.4.1.Asdiscussedabove,theRBLCwasusedinthisproposaltoidentifyemissioncontroltechnologiesandemissionlimitsdeterminedtobeRACTbythepermittingauthoritiesforemissionunitscomparabletothoseatthefacility.AppendixAprovidesasummaryofRBLCandpermitsearchresults.
1.5.1. SO2 RACT
1.5.1.1. Background on Pollutant Formation
Foratotalof20dayseachyear,MSCmusttemporarilyremovetheprimarydesulfurizationsystemfromservicetoconductinspectionsandimplementrepairsnecessarytomaintainthesystem(i.e.,outageperiods).Table1‐4inthissectionevaluatesRACTfortheseoutageperiods.ThemechanismsofSO2formationduringtheseoutageperiodsareconsistentwiththemechanismsdescribedinSection1.4.1.1;however,theRBLCdoesnotincluderecordsofanycontroltechnologydeterminationsspecificallyestablishedforoutageperiodsatbyproductrecoveryoperations.However,itshouldbenotedthatRBLCdoesprovidecleardocumentationthatoutagesofSO2controlsarepermittedforvariouscokeproductionoperationsasageneralmatter.
1.5.1.2. Analysis of RACT Alternatives
OneofthecontroltechniquesconsideredforoutageperiodsinvolvestheinstallationofaredundantdesulfurizationsystemcapableofmaintainingH2Sremovalduringplannedoutagesoftheexistingdesulfurizationsystem.Thiscontrolstrategyiseconomicallyinfeasibleandpresentssignificantoperationalchallengesgiventhatdesulfurizationsystemsarenotcapableofoperatingatlessthan30percentofthedesigncapacity.Asaresult,COGmustbedistributedbetweentheexistingandredundantdesulfurizationsystemsduringnormaloperation,andduringperiodsofdiminishedproduction,thecokeovenbatteriesmaynotgeneratesufficientCOGtosupplybothdesulfurizationsystems.Insuchascenario,operatorsofredundantsystemswouldberequiredtopurchase,store,andburnelementalsulfur(i.e.,intentionallygenerateSO2emissions)simplytomaintaintheoperationalintegrityofthedesulfurizationsystems.MSCconsideredtheseoperationalchallengeswhenevaluatingthetechnicalandeconomicalfeasibilityofthiscontroltechniqueinTable1‐4.
1.5.1.3. Selection of RACT
GiventhelimitednatureoftheseplannedoutageeventsandtheconclusionthatcurrentoperationsmeetRACT,weareproposingasulfurincoallimitationduringplannedoutagesastheRACTlimitation.Specifically,weproposethatcoalusedinthecokebatterieshaveanaverageblendedsulfurcontentofnogreaterthan1.25%.
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-24
Table1‐4.Top‐DownRACTProposalforDesulfurizationOutagePeriods‐SO2Process Pollutant
ControlTechnology
Pre‐CombustionRedundantDesulfurization
CoalSulfurContentRestrictions
ControlTechnologyDescription
UtilizesammoniawashtechnologyforthedissolutionofH2SwithNH4intheH2Swashertoensurethatsulfur
concentrationsinthecokeovengasarereducedpriortocombustion.The
systemalsoincludesadeacifiercolumnandacompactsulfuricacidplant.b
UtilizescoalwithasulfurcontentlimittoreducetheformationofH2SandSO2duringplannedoutagesoftheexisting
desulfurizationsystem.
TypicalWasteStreamInletFlowRate
63mmscfdb N/A
TypicalWasteStreamInletPollutantConcentration
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.
FeasibilityDiscussion
Feasible Feasible
Step3.RANKREMAINING
CONTROLTECHNOLOGIES
OverallControlEfficiency
Similarcontrolefficiencyasexistingdesulfurizationfor20daysduringthebi‐
annualshutdownoftheprimarydesulfurizer
N/A‐InputRestriction
Step4.EVALUATEANDDOCUMENTMOST
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
Step1. IDENTIFYAIRPOLLUTIONCONTROL
TECHNOLOGIES
Step2.
ELIMINATETECHNICALLYINFEASIBLEOPTIONS
Mountain State Carbon, LLC | SIP RACT ProposalTrinity Consultants
13PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-25
Mountain State Carbon, LLC | SIP RACT Proposal Trinity Consultants 14
1.6. ENGINE RACT EVALUATION
TheRACTevaluationforthe527and600horsepower(HP)dieselfiredenginesisprovidedinSection1.6.1.Asdiscussedabove,theRBLCwasusedinthisproposaltoidentifyemissioncontroltechnologiesandemissionlimitsdeterminedtobeRACTbythepermittingauthoritiesforemissionunitscomparabletothoseatthefacility.AppendixAprovidesasummaryofRBLCandpermitsearchresults.
1.6.1. SO2 RACT
1.6.1.1. Background on Pollutant Formation
ThemainsourceofSO2fromenginesisemittedthroughfluegasventing.TheenginesatMSC’sFollansbeeFacilityarefueledbydieselwhichcontainssulfur.Therefore,sulfurentersthecombustionprocessthroughthedieselfuel.DuringcombustionthesulfurinthedieselisoxidizedintoSOx,mostlySO2.TheformationofSO2ispredominatelydeterminedbytheinitialsulfurcontentinthediesel,andnottheengineparameters.Whendieseliscombusted,approximately95percentofthesulfurbecomesSO2,1to5percentbecomesSO3and1to3percentbecomessulfurparticulate9.Incombinationwithwatervapor,SO3quicklybecomesH2SO4,acorrosiveacid.
1.6.1.2. Analysis of RACT Alternatives
SO2reductionfromenginescanbeaccomplishedbythreegeneralmethodologies:fluegasdesulfurization,restrictionsonsulfurcontentoffuels,andgoodcombustionpractices.Fluegasdesulfurizationoxidizes,neutralizesorabsorbstheSO2fromthewastegasintoasolidcompoundwhilefuelrestrictionslimittheamountofsulfurinitiallyenteringtheprocess.Goodcombustionpracticesinvolvetheappropriateoperationandmaintenanceofequipmenttoensureproperfunctioningandnounintendedemissionincreases.UsingtheRBLCsearch,potentiallyapplicableSO2controltechnologiesfordieselfiredengineswereidentifiedbasedontheprinciplesofcontroltechnologyandengineeringexperienceforgeneralcombustionunits.Table1‐6outlinesthetop‐downRACTproposalforSO2emissionsfromtheengines.
1.6.1.3. Selection of RACT
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
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-26
Mountain State Carbon, LLC | SIP RACT Proposal Trinity Consultants 15
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
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-27
Table1‐6.Top‐DownRACTProposalforEngines‐SO2Process Pollutant
ControlTechnology
FlueGasDesulfurization FuelSulfurContentRestrictions GoodCombustionPractices
ControlTechnologyDescription
Injectsanalkalinereagentintothefluegasinaspraytowerordirectlyintotheductwhereitoxidizes,
neutralizes,and/orabsorbsSO2intoasolidcompound,eithercalciumor
sodiumsulfate.a
UtilizesfuelwithasulfurcontentlimittoreducetheformationofSO2during
combustion.
Operateandmaintaintheequipmentinaccordancewithgoodairpollutioncontrolpracticesandwithgoodcombustionpractices.
TypicalOperating
Temperature
300‐700°Fforwetscrubbers300‐1830°Ffordrysorbent
injectionaN/A N/A
TypicalWasteStreamInletFlowRate
15‐4300mmscfdb N/A N/A
TypicalWasteStreamInletPollutantConcentration
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.
FeasibilityDiscussion
Technicallyinfeasible.Fluegasdesulfurizationistypicallyappliedtostationarycoal‐andoil‐firedcombustionunitsranginginsizebetween50and15,000MMBtu/hr.Theenginesatthisfacilityarefiredbydieselbutareratedatcapacitieswellbelowthelowerendoftheapplicablesizerange.Theenginesonlyoperateonanemergencybasis.
Feasible Feasible
Step3.RANKREMAINING
CONTROLTECHNOLOGIES
OverallControlEfficiency
BaseCase BaseCase
Step4.EVALUATEANDDOCUMENTMOST
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
Step1. IDENTIFYAIRPOLLUTIONCONTROL
TECHNOLOGIES
Step2.
ELIMINATETECHNICALLYINFEASIBLEOPTIONS
Mountain State Carbon, LLC | SIP RACT ProposalTrinity Consultants
16PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-28
Mountain State Carbon, LLC | SIP RACT Proposal Trinity Consultants 17
1.7. NATURAL GAS COMBUSTION SOURCE RACT EVALUATION
TheFollansbeeFacilityincludesone(1)85MMBtu/hrnaturalgasfiredboilerandadditionalnaturalgasfiredcombustionsourcesratedlessthan10MMBtu/hrinsize.ThesesourcesproduceSO2throughfuelcombustionandcanbecontrolledthroughthesamemethodsoffluegasdesulfurization,fuelsulfurcontentrestrictions,andgoodcombustionpracticesdescribedabovefortheCOGboilersandengines.UsingtheRBLCsearch,potentiallyapplicableSO2controltechnologiesforthenaturalgascombustionsourceswereidentifiedbasedontheprinciplesofcontroltechnologyandengineeringexperienceforgeneralcombustionunits.Table1‐7outlinesthetop‐downRACTproposalforSO2emissionsfromtheengines.BasedonareviewoftheemissionlimitsachievableandrecentRACTdeterminationsforsimilarfacilities,SO2RACTfortheseunitsisgoodcombustionpractices.
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-29
Table1‐7.Top‐DownRACTProposalforNaturalGasCombustionUnits‐SO2Process Pollutant
ControlTechnology
FlueGasDesulfurization FuelSulfurContentRestrictions GoodCombustionPractices
ControlTechnologyDescription
Injectsanalkalinereagentintothefluegasinaspraytowerordirectlyintotheductwhereitoxidizes,neutralizes,and/orabsorbsSO2intoasolid
compound,eithercalciumorsodiumsulfate.a
UtilizesfuelwithlowsulfurcontenttoreducetheformationofSO2during
combustion.
Operateandmaintaintheequipmentinaccordancewithgoodairpollutioncontrolpracticesandwithgoodcombustionpractices.
TypicalOperating
Temperature
300‐700°Fforwetscrubbers300‐1830°Ffordrysorbent
injectionaN/A N/A
TypicalWasteStreamInletFlowRate
15‐4300mmscfdb N/A N/A
TypicalWasteStreamInletPollutantConcentration
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.
FeasibilityDiscussion
Technicallyinfeasible.Fluegasdesulfurizationistypicallyappliedtostationarycoal‐andoil‐firedcombustionunitsranginginsize
between50and15,000MMBtu/hr.Themiscellaneouscombustionunitsatthisfacilityaremuchsmallerthantheapplicablesizerange.
Feasible.Pipeline‐qualitynaturalgasisinherentlylowinsulfurcontent.
Feasible
Step3.RANKREMAINING
CONTROLTECHNOLOGIES
OverallControlEfficiency
BaseCase
Step4.EVALUATEANDDOCUMENTMOST
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
Step1. IDENTIFYAIRPOLLUTIONCONTROL
TECHNOLOGIES
Step2.
ELIMINATETECHNICALLYINFEASIBLEOPTIONS
Mountain State Carbon, LLC | SIP RACT ProposalTrinity Consultants
18PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-30
Mountain State Carbon, LLC | SIP RACT Proposal Trinity Consultants A-1
APPENDIX A
RACT Documentation
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-31
[This page intentionally left blank.]
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-32
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
LA‐0239 LAConsolidatedEnvironmentalManagementInc‐NucorSteelLouisiana
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
OH‐0305 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 12/11/2003 275,000 tons/yrcok 24 lbs/hr Unspecified Lowsulfurcoal<1%Additionallimitfornewbatteries:28.8lbsSO2perhourasa3‐houraverage.
OH‐0305 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 12/11/2003 275,000 tons/yrcok 24 lbs/hr Unspecified Lowsulfurcoal<1%
OH‐0297 OHU.S.CokingGroup,L.L.C.‐FDSCoke
Non‐recovery 6/14/2004 1.44milliontons/yr
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
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-33
SO2‐FerrousMetals/Industry‐CokeProcesses‐CokeOvenBatteries‐Charging
ID State CompanyCokemakingTechnique
PermitIssuanceDate Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
OH‐0272 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 2/27/2001 4.3milliontons/yr
0.2 lbs/hr Unspecified None
OH‐0272 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 2/27/2001 4.3milliontons/yr
0.2 lbs/hr Unspecified None
OH‐0305 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 12/11/2003 275,000 tons/yrcok 0.14 lbs/hr Unspecified Lowsulfurcoal<1%
OH‐0305 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 12/11/2003 275,000 tons/yrcok 0.14 lbs/hr Unspecified Lowsulfurcoal<1%
OH‐0297 OHU.S.CokingGroup,L.L.C.‐FDSCoke
Non‐recovery 6/14/2004 2.06milliontons/yr
0.1 lbs/hr Unspecified UnspecifiedorNone
OH‐0297 OHU.S.CokingGroup,L.L.C.‐FDSCoke
Non‐recovery 6/14/2004 2.06milliontons/yr
0.1 lbs/hr Unspecified UnspecifiedorNone
OH‐0332 OHSunCokeEnergy,Inc.‐MiddletownCokeCompany
Non‐recovery 2/9/2010 912,500 tons/yr 0.15 lbs/hr EPA/OARMethod6C NoneMethod6Conlyifrequired.Monthlycoalsamples.
OH‐0332 OHSunCokeEnergy,Inc.‐MiddletownCokeCompany
Non‐recovery 2/9/2010 912,500 tons/yr 0.15 lbs/hr EPA/OARMethod6C NoneMethod6Conlyifrequired.Monthlycoalsamples.
MountainStateCarbonSO2RBLCReview A‐3
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-34
SO2‐FerrousMetals/Industry‐CokeProcesses‐CokeOvenBatteries‐BatteryStack
ID State CompanyCokemakingTechnique
PermitIssuanceDate Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
OH‐0297 OHU.S.CokingGroup,L.L.C.‐FDSCoke
Non‐recovery 6/14/2004 2.06milliontons/yr
243.3 lbs/hr UnspecifiedLimespraydryer,lowsulfurcoal,combustionoptimization
AdditionalLimit:0.99lbsSO2 pertonofwetcoalchargedwithcoalcontaininglessthan0.9wt.%sulfur;1.06lbsSO2/tonwithcoalcontaining0.9wt.%orgreatersulfur
OH‐0297 OHU.S.CokingGroup,L.L.C.‐FDSCoke
Non‐recovery 6/14/2004 2.06milliontons/yr
243.3 lbs/hr UnspecifiedLimespraydryer,lowsulfurcoal,combustionoptimization
AdditionalLimit:0.99lbsSO2 pertonofwetcoalchargedwithcoalcontaininglessthan0.9wt.%sulfur;1.06lbsSO2/tonwithcoalcontaining0.9wt.%orgreatersulfur
OH‐0297 OHU.S.CokingGroup,L.L.C.‐FDSCoke
Non‐recovery 6/14/2004 2.06milliontons/yr
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
MountainStateCarbonSO2RBLCReview A‐4
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-35
SO2‐FerrousMetals/Industry‐CokeProcesses‐CokeOvenBatteries‐Coking
ID State CompanyCokemakingTechnique
PermitIssuanceDate Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
IN‐0012 IN InlandSteelCo.‐InlandSteelCo.By‐productRecovery
9/22/1980 0.35gr/100cfH2S
Unspecified LimitisLAER
LA‐0239 LAConsolidatedEnvironmentalManagementInc‐NucorSteelLouisiana
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.
By‐productRecovery
8/6/1979 1.4milliontons/yrcoal
26 lbs/hr UnspecifiedFuelSpec:Sinfuellimitto1.0%bywt.
OH‐0040 OHRepublicSteelCorp.‐RepublicSteelCorp.
By‐productRecovery
3/1/1983 32tons/hrcoke
35gr/100cfH2S
Unspecified Operating%mainten.proced.
OH‐0272 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 2/27/2001 4 milliontons 265 lbs/hrAsa3‐houraverage
SO2CEMSDryscrubber,limespraydryer,andlowsulfurcoal:<4%sulfur
Nocostanalysissubmittedfortechnologyinstalled.Additionallimit:594lbs/hrand968.42tons/yr.
OH‐0305 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 12/11/2003 275,000 tons/yrcok 192 lbs/hr SO2CEMSDryscrubberwithwetlimesprayinjectionandlowsulfur<1%coal
OH‐0305 OHSunCokeCompany‐HaverhillNorthCokeCompany
Non‐recovery 12/11/2003 275,000 tons/yrcok 192 lbs/hr SO2CEMSDryscrubberwithwetlimesprayinjectionandlowsulfur<1%coal
OH‐0332 OHSunCokeEnergy,Inc.‐MiddletownCokeCompany
Non‐recovery 2/9/2010 2,300 tons/day 498.33 lbs/hr SO2CEMSBypassoneHRSGatatime,onestack
Estimated23.92lbsSO2/tonofcoal.Restrictedto960hoursbypassofHRSG/yr(tpylimit)andoneHRSGbypassedatatime.
OH‐0332 OHSunCokeEnergy,Inc.‐MiddletownCokeCompany
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.
OH‐0332 OHSunCokeEnergy,Inc.‐MiddletownCokeCompany
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.
MountainStateCarbonSO2RBLCReview A‐5
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-36
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐NaturalGas
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
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 8.37 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly
NV‐0049 NV Harrah'sOperatingCompany,Inc. 08/20/2009 NaturalGas 14.34 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly
NV‐0049 NV Harrah'sOperatingCompany,Inc. 08/20/2009 NaturalGas 16.8 MMBtu/hr 0.0042 lb/MMBtu NaturalGasOnly
NV‐0049 NV Harrah'sOperatingCompany,Inc. 08/20/2009 NaturalGas 31.38 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly
NV‐0049 NV Harrah'sOperatingCompany,Inc. 08/20/2009 NaturalGas 35.4 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly
NV‐0049 NV Harrah'sOperatingCompany,Inc. 08/20/2009 NaturalGas 33.48 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly
NV‐0049 NV Harrah'sOperatingCompany,Inc. 08/20/2009 NaturalGas 24 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly
MountainStateCarbonSO2RBLCReview A‐6
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-37
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐NaturalGas
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
NV‐0049 NV Harrah'sOperatingCompany,Inc. 08/20/2009 NaturalGas 16.7 MMBtu/hr 0.0006 lb/MMBtu NaturalGasOnly
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 4.2 MMBtu/hr 0.0024 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 4.3 MMBtu/hr 0.0006 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
NV‐0050 NV MGMMirage 11/30/2009 NaturalGas 44 MMBtu/hr 0.0007 lb/MMBtu NaturalGasOnly
NV‐0050 NV MGMMirage 11/30/2009 NaturalGas 2 MMBtu/hr 0.005 lb/MMBtu NaturalGasOnly
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
MountainStateCarbonSO2RBLCReview A‐7
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-38
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐GaseousFuelandGaseousFuelMixtures
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
AK‐0056 AKARCOAlaska,Inc.‐AlpineDevelopmentProject,CentralProcessingFac
2/1/1999 Fuelgas 65.6 MMBtu/hr Seenote UnspecifiedFuelGasH2Snottoexceed200ppm
Fuellimit‐‐noemissionratelimit.
AK‐0056 AKARCOAlaska,Inc.‐AlpineDevelopmentProject,CentralProcessingFac
2/1/1999 Fuelgas 65.6 MMBtu/hr Seenote UnspecifiedFuelGasH2Snottoexceed200ppm
Fuelsulfurlimit‐‐noemissionratelimit
AK‐0056 AKARCOAlaska,Inc.‐AlpineDevelopmentProject,CentralProcessingFac
2/1/1999 Fuelgas 20 MMBtu/hr Seenote Unspecified
FuelGasH2Snottoexceed200ppmwhenoperatingusingliquidfuel:fuelsulfurlimitof215NG/J(0.50lb/Mmbtu)heatinput;or,asanalternative,0.5weightpercentsulfur.
Limitisfuelsulfurlimit.Noemissionratelimit
AK‐0056 AKARCOAlaska,Inc.‐AlpineDevelopmentProject,CentralProcessingFac
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.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
117 MMBtu/hr 35 ppmvDailyAverage
Unspecified Slimitedto35ppm.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasandgasesfromtanks
35 ppmvDailyAverage
UnspecifiedThissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Naturalgasorrefineryfuelgas
35 ppmvDailyAverage
Unspecified 35ppmsulfurlimitinfuel.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasandnaturalgas
122 MMBtu/hr 35 ppmvDailyAverage
UnspecifiedSulfurlimitedto35ppminfuel.
THE35PPMVSULFURLIMIT,ASH2S,ISARESTRICTIONONTHEINLETCONCENTRATIONOFTHEREFINERYFUELGASBEINGFIREDINTHEUNIT.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
12 MMBtu/hr 35 ppmvDailyAverage
UnspecifiedThissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasandnaturalgas
192 MMBtu/hr 35 ppmvDailyAverage
Unspecified Slimitedto35ppm.
THE35PPMVSULFURLIMIT,ASH2S,ISARESTRICTIONONTHEINLETCONCENTRATIONOFTHEREFINERYFUELGASBEINGFIREDINTHEUNIT.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
129 MMBtu/hr 35 ppmvDailyAverage
Unspecified Slimitedto35ppm.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
23.2 MMBtu/hr 35 ppmvDailyAverage
Unspecified Slimitedto35ppm.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
311 MMBtu/hr 35 ppmvDailyAverage
Unspecified35ppmsulfurlimitonfuelburned.
Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
328 MMBtu/hr 35 ppmvDailyAverage
Unspecified35ppmsulfurlimitonfuelburned.
Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
101 MMBtu/hr 35 ppmvDailyAverage
UnspecifiedThislimitisforsulfur,asH2S,andisalimitontheinletconcentrationoftherefineryfuelgas.
MountainStateCarbonSO2RBLCReview A‐8
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-39
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐GaseousFuelandGaseousFuelMixtures
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
70 MMBtu/hr 35 ppmvDailyAverage
Unspecified Slimitedto35ppm.Thislimitisforsulfur,asH2S,andisalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
211 MMBtu/hr 35 ppmvDailyAverage
Unspecified Slimitedto35ppm.Thislimitisonsulfur,asH2S,andisalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
21.4 MMBtu/hr 35 ppmvDailyAverage
Unspecified Slimitedto35ppm.Thislimitisonsulfur,asH2S,andisalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasandnaturalgas
222 MMBtu/hr 35 ppmvDailyAverage
UnspecifiedSulfurlimitedto35ppminfuelburned.
Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Naturalgasorrefineryfuelgas
346 MMBtu/hr 35 ppmv Daily Unspecified 35ppmsulfurlimitinfuel.
The35ppmvsulfurlimit,asH2S,isarestrictionontheinletconcentrationoftherefineryfuelgasbeingfiredintheunit.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
1435 MMBtu/hr 35 ppmvDailyAverage
Unspecified Slimitedto35ppm.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
44 MMBtu/hr 35 ppmvDailyAverage
UnspecifiedThissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
100 MMBtu/hr 33.5 lbs/hr1‐hraverage
UnspecifiedThissulfurlimitisforanygasesfromthesulfurrecoveryplant.
AZ‐0046 AZArizonaCleanFuelsYumaLLC‐ArizonaCleanFuelsYuma
4/14/2005Refineryfuelgasornaturalgas
99.5 MMBtu/hr 35 ppmvDailyAverage
Unspecified Fuellimitedto35ppmS.Thissulfurlimit,asH2S,isalimitontheinletconcentrationoftherefineryfuelgas.
LA‐0094 LAColumbianChemicalsCompany‐NorthBendPlant
9/29/1995 Tailgas 640 MMBtu/hr 1746.74 ppm Unspecified
Limitsulfurcontentoffeedstockto3wt%forrubbergradeand1.5wt%forindustrialgradeunits
LA‐0094 LAColumbianChemicalsCompany‐NorthBendPlant
9/29/1995 Tailgas 26 MMBtu/hr 2992.3 ppm Unspecified
Limitsulfurcontentoffeedstockto3wt%forrubbergradeand1.5wt%forindustrialgradeunits
LA‐0094 LAColumbianChemicalsCompany‐NorthBendPlant
9/29/1995 Tailgas 100 MMBtu/hr 3109.49 ppmv Unspecified
Limitsulfurcontentoffeedstockto3wt%forrubbergradeand1.5wt%forindustrialgradeunits
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
LA‐0149 LAMarathonAshlandPetroleumLLC‐Garyville‐LouisianaRefiningDivision
10/21/1999 Nat&refinerygas 69.4 MMBtu/hr 2.78 lbs/hr Unspecified Lowsulfurfuel
LA‐0149 LAMarathonAshlandPetroleumLLC‐Garyville‐LouisianaRefiningDivision
10/21/1999 Nat&refinerygas 221 MMBtu/hr 8.85 lbs/hr Unspecified Lowsulfurfuel
LA‐0149 LAMarathonAshlandPetroleumLLC‐Garyville‐LouisianaRefiningDivision
10/21/1999 Nat&refinerygas 350 MMBtu/hr 11.21 lbs/hr Unspecified Useoflowsulfurfuel
LA‐0149 LAMarathonAshlandPetroleumLLC‐Garyville‐LouisianaRefiningDivision
10/21/1999 Nat&refinerygas 268.6 MMBtu/hr 10.75 lbs/hr Unspecified Lowsulfurfuels
LA‐0149 LAMarathonAshlandPetroleumLLC‐Garyville‐LouisianaRefiningDivision
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
MountainStateCarbonSO2RBLCReview A‐9
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-40
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐GaseousFuelandGaseousFuelMixtures
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
12/27/2006 Refineryfuelgas 25ppmvasH2S
AnnualAverage
UnspecifiedUseoflowsulfurrefineryfuelgas
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
12/27/2006 Refineryfuelgas 25ppmvasH2S
AnnualAverage
UnspecifiedUseoflowsulfurrefineryfuelgas
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
12/27/2006 Refineryfuelgas 525.7 MMBtu/hr 25 ppmvAsH3Sannualaverage
UnspecifiedUseoflowsulfurrefineryfuelgas
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
12/27/2006 Refineryfuelgas MMBtu/hr 25 ppmvAsH2Sannualaverage
UnspecifiedUseoflowsulfurrefineryfuelgas
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
12/27/2006 Purgegas 1412.5 MMBtu/hr 25ppmvasH2S
AnnualAverage
UnspecifiedUseoflowsulfurrefineryfuelgas
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
12/27/2006 Refineryfuelgas MMBtu/hr 25ppmvasH2S
AnnualAverage
UnspecifiedUseoflowsulfurrefineryfuelgas
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
12/27/2006 Refineryfuelgas 155.2 MMBtu/hr 25 ppmvAsH2Sannualaverage
UnspecifiedUseoflowsulfurrefineryfuelgas
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
12/27/2006 Refineryfuelgas 9.6 MMBtu/hr 0.2 maxlbs/hr Unspecified
LA‐0211 LAMarathonPetroleumCoLLC‐GaryvilleRefinery
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).
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Processfuelgas Seenote UnspecifiedFueledbynaturalgasorprocessfuelgaswithH2S<=10ppmv(annualaverage)
Noemissionlimitsavailable
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Refineryfuelgas Seenote Unspecified
UseofpipelinequalitynaturalgasorrefineryfuelgaseswithanH2Sconcentrationlessthan100ppmv(annualaverage).
Noemissionlimits
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Processfuelgas Seenote Unspecified
UseofpipelinequalitynaturalgasorprocessfuelgaseswithanH2Sconcentrationlessthan10ppmv(annualaverage).
Noemissionlimits
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Refineryfuelgas 200 MMBtu/hr 0.45 LB/HHourlyMaximum
Unspecified
UseofpipelinequalitynaturalgasorprocessfuelgaseswithanH2Sconcentrationlessthan10ppmv(annualaverage).
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Refineryfuelgas Seenote Unspecified
UseofpipelinequalitynaturalgasorrefineryfuelgaseswithanH2Sconcentrationlessthan100ppmv(annualaverage).
Noemissionlimitsavailable
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Refineryfuelgas 0 Seenote Unspecified
UseofpipelinequalitynaturalgasorrefineryfuelgaseswithanH2Sconcentrationlessthan100ppmv(annualaverage).
Noemissionlimits
MountainStateCarbonSO2RBLCReview A‐10
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-41
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐GaseousFuelandGaseousFuelMixtures
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Refineryfuelgas 715 MMBtu/hr Seenote Unspecified
Fueledbynaturalgasand/orrefineryfuelgaswithH2S<=100ppmv(annualaverage)orprocessfuelgaswithH2S<=10ppmv(annualaverage)
Noemissionlimitsavailable
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Refineryfuelgas 70 MMBtu/hr Seenote UnspecifiedFueledbynaturalgasand/orrefineryfuelgaswithH2S<=100ppmv(annualaverage)
Noemissionlimitsavailable
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Refineryfuelgas 633 MMBtu/hr Seenote UnspecifiedFueledbynaturalgasand/orrefineryfuelgaswithH2S<=100ppmv(annualaverage)
Noemissionlimitsavailable
LA‐0213 LAValeroRefining‐NewOrleans,LLC‐St.CharlesRefinery
11/17/2009 Processfuelgas 15 MMBtu/hr Seenote UnspecifiedFueledbynaturalgasorprocessfuelgaswithH2S<=10ppmv(annualaverage)
Noemissionlimitsavailable
LA‐0234 LACITGOPetroleumCompany‐LakeCharlesComplex‐CatGasHydro
1/26/2009 Fuelgas 62.8 MMBtu/hr 5.08 lbs/hr UnspecifiedLowsulfurconcentrationinthefuelgas
OriginalPSDestablishedanaveragesulfurconcentrationof182ppmandamaximumof332ppminthefuelgas.Thisreconciliationafterdeterminingmoreupdatedsulfurconcentrationsraisesthosevaluestoanaverageof218.4ppmandamaximumof475ppminthefuelgas.
LA‐0234 LACITGOPetroleumCompany‐LakeCharlesComplex‐CatGasHydro
1/26/2009 Fuelgas 56.9 MMBtu/hr 5.08 lbs/hr UnspecifiedLowsulfurconcentrationinthefuelgas
OriginalPSDestablishedanaveragesulfurconcentrationof182ppmandamaximumof332ppminthefuelgas.Thisreconciliationafterdeterminingmoreupdatedsulfurconcentrationsraisesthosevaluestoanaverageof218.4ppmandamaximumof475ppminthefuelgas.
LA‐0234 LACITGOPetroleumCompany‐LakeCharlesComplex‐CatGasHydro
1/26/2009 Fuelgas 56.9 MMBtu/hr 5.08 lbs/hr UnspecifiedLowsulfurconcentrationinthefuelgas
OriginalPSDestablishedanaveragesulfurconcentrationof182ppmandamaximumof332ppminthefuelgas.Thisreconciliationafterdeterminingmoreupdatedsulfurconcentrationsraisesthosevaluestoanaverageof218.4ppmandamaximumof475ppminthefuelgas.
LA‐0234 LACITGOPetroleumCompany‐LakeCharlesComplex‐CatGasHydro
1/26/2009 Fuelgas 38.3 MMBtu/hr 3.1 lbs/hr UnspecifiedLowsulfurconcentrationinthefuelgas
OriginalPSDestablishedanaveragesulfurconcentrationof182ppmandamaximumof332ppminthefuelgas.Thisreconciliationafterdeterminingmoreupdatedsulfurconcentrationsraisesthosevaluestoanaverageof218.4ppmandamaximumof475ppminthefuelgas.
LA‐0234 LACITGOPetroleumCompany‐LakeCharlesComplex‐CatGasHydro
1/26/2009 Fuelgas 38.3 MMBtu/hr 3.1 lbs/hr UnspecifiedLowsulfurconcentrationinthefuelgas
OriginalPSDestablishedanaveragesulfurconcentrationof182ppmandamaximumof332ppminthefuelgas.Thisreconciliationafterdeterminingmoreupdatedsulfurconcentrationsraisesthosevaluestoanaverageof218.4ppmandamaximumof475ppminthefuelgas.
MountainStateCarbonSO2RBLCReview A‐11
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-42
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐GaseousFuelandGaseousFuelMixtures
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
LA‐0234 LACITGOPetroleumCompany‐LakeCharlesComplex‐CatGasHydro
1/26/2009 Fuelgas 62.8 MMBtu/hr 5.08 lbs/hr UnspecifiedUselowsulfurconcentrationfuelgas.
OriginalPSDestablishedanaveragesulfurconcentrationof182ppmandamaximumof332ppminthefuelgas.Thisreconciliationafterdeterminingmoreupdatedsulfurconcentrationsraisesthosevaluestoanaverageof218.4ppmandamaximumof475ppminthefuelgas.
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.
PA‐0231 PAUnitedRefineryCo‐UnitedRefineryCo.
10/9/2003 Refinerygas 91 MMBtu/hr 2.44 lbs/hr Unspecified LowsulfurrefinerygasBestavailabletechnology(BAT)reviewdone.
PA‐0231 PAUnitedRefineryCo‐UnitedRefineryCo.
10/9/2003 Refinerygas 344 MMBtu/hr 9.22 lbs/hr Unspecified GoodcombustionpracticeBestavailabletechnology(BAT)reviewdone.
PA‐0231 PAUnitedRefineryCo‐UnitedRefineryCo.
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.
TX‐0348 TXDiamondShamrockRefiningCompanyLP‐DiamondShamrockMcKeePlant
10/19/2001 Fuelgas 160.4 MMBtu/hr 6.07 lbs/hr Unspecified NoneindicatedStandardemissionlimitscalculatedfromhourlylimitsandprocessrating.
TX‐0348 TXDiamondShamrockRefiningCompanyLP‐DiamondShamrockMcKeePlant
10/19/2001 Fuelgas 13.5 MMBtu/hr 0.51 lbs/hr Unspecified NoneindicatedStandardemissionlimitscalculatedfromhourlylimitsandprocessrating.
TX‐0348 TXDiamondShamrockRefiningCompanyLP‐DiamondShamrockMcKeePlant
10/19/2001 Fuelgas 10.8 MMBtu/hr 0.41 lbs/hr Unspecified NoneindicatedStandardemissionlimitscalculatedfromhourlylimitsandprocessrating.
TX‐0348 TXDiamondShamrockRefiningCompanyLP‐DiamondShamrockMcKeePlant
10/19/2001 Fuelgas 30.1 MMBtu/hr 1.14 lbs/hr Unspecified NoneindicatedStandardemissionlimitscalculatedbydividingthehourlyemissionlimitbythethroughput.
TX‐0348 TXDiamondShamrockRefiningCompanyLP‐DiamondShamrockMcKeePlant
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.
MountainStateCarbonSO2RBLCReview A‐12
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-43
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐GaseousFuelandGaseousFuelMixtures
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
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
TX‐0395 TXDiamondShamrockRefiningCompany‐DiamondShamrockMcKeePlant
5/23/2000 Refinerygas 248 MMBtu/hr 9.33 lbs/hr Unspecified
TX‐0395 TXDiamondShamrockRefiningCompany‐DiamondShamrockMcKeePlant
5/23/2000 Refinerygas 20 MMBtu/hr 0.75 lbs/hr Unspecified
TX‐0395 TXDiamondShamrockRefiningCompany‐DiamondShamrockMcKeePlant
5/23/2000 Refinerygas 147.2 MMBtu/hr 5.54 lbs/hr Unspecified
TX‐0395 TXDiamondShamrockRefiningCompany‐DiamondShamrockMcKeePlant
5/23/2000 Refinerygas 45.7 MMBtu/hr 1.72 lbs/hr Unspecified
TX‐0395 TXDiamondShamrockRefiningCompany‐DiamondShamrockMcKeePlant
5/23/2000 Refinerygas 63.4 MMBtu/hr 2.39 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
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.6 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 3.2 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.6 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 4 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.6 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.1 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 4 lbs/hr Unspecified LimitH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 4.1 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 7.8 lbs/hr Unspecified LimitH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 2 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
MountainStateCarbonSO2RBLCReview A‐13
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-44
SO2‐Commercial/institutional‐sizeBoilers/Furnaces(<100MMBtu/hr)‐GaseousFuelandGaseousFuelMixtures
ID State Company
PermitIssuanceDate FuelType Capacity Units Limit Units
AveragingPeriod ComplianceMethod ControlType Note(s)
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.5 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.3 lbs/hr Unspecified LimitH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.2 lbs/hr Unspecified LimitH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.8 lbs/hr Unspecified LimitH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.3 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.7 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 1.4 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 1.1 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.9 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 7.2 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 1.5 lbs/hr Unspecified
TX‐0443 TXValeroRefining‐TexasLP‐ValeroCorpusChristiRefineryEastPlant
1/1/2005 Fuelgas 0.7 lbs/hr UnspecifiedLimitthecontentofH2Sinfuelgas
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
*WY‐0071 WYSinclairWyomingRefiningCompany‐SinclairRefinery
10/15/2012 Refineryfuelgas 233 MMBtu/hr UnspecifiedFollowSubpartJaFuelgasH2Slimits
*WY‐0071 WYSinclairWyomingRefiningCompany‐SinclairRefinery
10/15/2012 Refineryfuelgas 64.2 MMBtu/hr UnspecifiedFollowSubpartJaFuelgasH2Slimits
*WY‐0071 WYSinclairWyomingRefiningCompany‐SinclairRefinery
10/15/2012 Refineryfuelgas 46.3 MMBtu/hr UnspecifiedFollowSubpartJaFuelgasH2Slimits
*WY‐0071 WYSinclairWyomingRefiningCompany‐SinclairRefinery
10/15/2012 Refineryfuelgas 44.9 MMBtu/hr UnspecifiedFollowSubpartJaFuelgasH2Slimits
*WY‐0071 WYSinclairWyomingRefiningCompany‐SinclairRefinery
10/15/2012 Refineryfuelgas 33.4 MMBtu/hr UnspecifiedFollowSubpartJaFuelgasH2Slimits
MountainStateCarbonSO2RBLCReview A‐14
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-45
SO2‐InternalCombustionEngines‐LargeInternalCombustionEngines(>500HP)‐DieselFuel
ID State Company
PermitIssuanceDate FuelType Capacity Unit Limit Unit
AveragingPeriod ComplianceMethod ControlType Note(s)
*IN‐0158 INSt.JosephEnergyCenter,LLC‐St.JosephEnergyCenter,LLC
12/3/2012 Diesel 1,006 hpeach 0.012 lbs/hr UnspecifiedUltralowsulfurdistillateandusagelimits
Limitoneandtwoareforeachgenerator
*IN‐0158 INSt.JosephEnergyCenter,LLC‐St.JosephEnergyCenter,LLC
12/3/2012 Diesel 2,012 hp 0.024 lbs/hr 3HOURS UnspecifiedUltralowsulfurdistillateandusagelimits
Limitoneandtwoareforeachgenerator
*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.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 650 hpSeecontroldescription
UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 755 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
Ensuretheemissionlimitbycomplyingwiththefuelrestriction18AAC50.055:emissionlimit1
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 940 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
BACT:FuelsulfurcontentlimitState:emissionlimit1andhydrogensulfidecontentrestrictionstothefuel.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 949 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
BACT:FuelsulfurcontentlimitState:emissionlimit1andhydrogensulfidecontentrestrictionstothefuel.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 950 hpSeecontroldescription
UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 1,200 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
BACT:FuelsulfurcontentlimitSTATE:Emissionlimit1
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 1,215 hpSeecontroldescription
UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 2,195 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
BACT:FuelsulfurcontentlimitState:emissionlimit1andhydrogensulfidecontentrestrictionstothefuel.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 3,632 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
BACT:FuelsulfurcontentlimitState:emissionlimit1andhydrogensulfidecontentrestrictionstothefuel.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 4,240 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
BACT:FuelsulfurcontentlimitState:emissionlimit1andhydrogensulfidecontentrestrictionstothefuel.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 4,425 hp 500 ppm Avover3h UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
BACT:FuelsulfurcontentlimitState:emissionlimit1andhydrogensulfidecontentrestrictionstothefuel.
AK‐0038 AKBPExplorationInc.‐NorthstarDevelopmentProject
2/5/1999 Diesel 6,200 hpSeecontroldescription
UnspecifiedSulfurcontentoffueloilshallnotexceed0.15%byweight.
LA‐0122 LAInternationalPaper‐MansfieldMill‐MansfieldMill
8/14/2001 Diesel 587 hp 1.2 lbs/hr Unspecified Preventativemaintenance
LA‐0122 LAInternationalPaper‐MansfieldMill‐MansfieldMill
8/14/2001 Dieselfuel 775 hpeach 1.6 lbs/hr each Unspecified Preventativemaintenance
LA‐0122 LAInternationalPaper‐MansfieldMill‐MansfieldMill
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
MountainStateCarbonSO2RBLCReview A‐15
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-46
SO2‐InternalCombustionEngines‐LargeInternalCombustionEngines(>500HP)‐DieselFuel
ID State Company
PermitIssuanceDate FuelType Capacity Unit Limit Unit
AveragingPeriod ComplianceMethod ControlType Note(s)
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.
SC‐0113 SCPyramaxCeramics,LLC‐PyramaxCeramics,LLC
2/8/2012 Diesel 757 hp Unspecified
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.
AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant
5/8/2000 Diesel 500 kW 63.3tons/12mo.period
Combinedlimit,allfuelburningsources
Unspecified
Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.
OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.
AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant
5/8/2000 Diesel 1,050 kW 63.3tons/12mo.period
Combinedlimit,allfuelburningsources
Unspecified
Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.Followthepowergenerationlimitsasspecifiedintheprocessnotes.
OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.
AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant
5/8/2000 Diesel 1,050 kW 63.3tons/12mo.period
Combinedlimit,allfuelburningsources
Unspecified
Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.Followthepowergenerationlimitsasspecifiedintheprocessnotes.
OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.
AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant
5/8/2000 Diesel 1,050 kW 63.3tons/12mo.period
Combinedlimit,allfuelburningsources
Unspecified
Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.Followthepowergenerationlimitsasspecifiedintheprocessnotes.
OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.
AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant
5/8/2000 Diesel 1,000 kW 63.3tons/12mo.period
Combinedlimit,allfuelburningsources
Unspecified
Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.Followthepowergenerationlimitsasspecifiedintheprocessnotes.
OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.
AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant
5/8/2000 Diesel 835 kW 63.3tons/12mo.period
Combinedlimit,allfuelburningsources
Unspecified
Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.Followthepowergenerationlimitsasspecifiedintheprocessnotes.
OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.
MountainStateCarbonSO2RBLCReview A‐16
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-47
SO2‐InternalCombustionEngines‐LargeInternalCombustionEngines(>500HP)‐DieselFuel
ID State Company
PermitIssuanceDate FuelType Capacity Unit Limit Unit
AveragingPeriod ComplianceMethod ControlType Note(s)
AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant
5/8/2000 Diesel 750 kW 63.3tons/12mo.period
Combinedlimit,allfuelburningsources
Unspecified
Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.Followthepowergenerationlimitsasspecifiedintheprocessnotes.
OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.
AK‐0043 AKNushagakElectricCooperative,Inc(NEC)‐DillinghamPowerPlant
5/8/2000 Diesel 1,135 kW 63.3tons/12mo.period
Combinedlimit,allfuelburningsources
Unspecified
Thesulfurcontentofthefueloilburnedmustnotexceed0.50percentbyweightatanytime.Followthepowergenerationlimitsasspecifiedintheprocessnotes.
OwnerrequestedlimittoavoidPSDclassification.Sulfurcompoundsexpressedassulfurdioxide.BasisofppmlimitisSIP.
AK‐0045 AKPhillipsPetroleumCompany‐NorthCookInletUnit
6/6/2000 Diesel 500 kWeach 500 ppm 3hav,each Unspecified
Usenaturalgaswithahydrogensulfidecontentnottoexceed200ppmandafueloilwithasulfurcontentnottoexceed0.25%byweight
Limitsetaccordingto18AAC50.055(C)
AK‐0053 AKTesoroAlaskaCompany‐KenaiRefinery
3/21/2000 Fueloil 2 mWSeecontroldescription
Unspecified
Useonlyfuelgaswithahydrogensulfidecontentnottoexceed200ppmanduseadistillatefueloilwithasulfurcontentnottoexceed0.15%byweight
AK‐0053 AKTesoroAlaskaCompany‐KenaiRefinery
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
Tune‐upsandinspectionswillbeperformedasoutlinedinthegoodmanagementpracticeplan.
Annualemissionsfromthedieselfirepumparebasedonanoperationallimitof500hr/yr.
MountainStateCarbonSO2RBLCReview A‐17
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-48
SO2‐InternalCombustionEngines‐LargeInternalCombustionEngines(>500HP)‐DieselFuel
ID State Company
PermitIssuanceDate FuelType Capacity Unit Limit Unit
AveragingPeriod ComplianceMethod ControlType Note(s)
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
LA‐0122 LAInternationalPaper‐MansfieldMill‐MansfieldMill
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
MountainStateCarbonSO2RBLCReview A‐18
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-49
SO2‐InternalCombustionEngines‐LargeInternalCombustionEngines(>500HP)‐DieselFuel
ID State Company
PermitIssuanceDate FuelType Capacity Unit Limit Unit
AveragingPeriod ComplianceMethod ControlType Note(s)
AK‐0037 AKTesoroAlaskaCompany‐KenaiRefinery
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
SC‐0113 SCPyramaxCeramics,LLC‐PyramaxCeramics,LLC
2/8/2012 Diesel 757 hp Unspecified
Useoflowsulfurfueldiesel,sulfurcontentlessthan0.0015percent.Operatinghourslessthan100hoursperyearformaintenanceandtesting.
Sulfurcontentofdieselfueltobelessthat0.0015percent.Suppliercertificationoffuelsulfurcontentshallbemaintained.
LA‐0122 LAInternationalPaper‐MansfieldMill‐MansfieldMill
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
*IN‐0158 INSt.JosephEnergyCenter,LLC‐St.JosephEnergyCenter,LLC
12/3/2012 Diesel 1,006 hpeach 0.012 lbs/hr UnspecifiedUltralowsulfurdistillateandusinglimits
Limitoneandtwoareforeachgenerator
AK‐0066 AK
BritishPetroleumExplorationAlaska(BPXA)‐EndicottProductionFacility,LibertyDevelopmentProject
6/15/2009 Distillate 1,041 hp 15 ppmw Unspecified LimitsulfurinfuelBaselineselectedasBACT.ThisfuelsulfurlimitappliesorwillapplytoallnewemissionunitsinPrudhoeBay
LA‐0122 LAInternationalPaper‐MansfieldMill‐MansfieldMill
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
Tune‐upsandinspectionswillbeperformedasoutlinedinthegoodmanagementpracticeplan.
Annualemissionsfromthedieselemergencygeneratorarebasedonanoperationallimitof500hr/yr.
MountainStateCarbonSO2RBLCReview A‐19
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-50
SO2‐InternalCombustionEngines‐LargeInternalCombustionEngines(>500HP)‐DieselFuel
ID State Company
PermitIssuanceDate FuelType Capacity Unit Limit Unit
AveragingPeriod ComplianceMethod ControlType Note(s)
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
*IN‐0158 INSt.JosephEnergyCenter,LLC‐St.JosephEnergyCenter,LLC
12/3/2012 Diesel 2,012 hp 0.024 lbs/hr 3hours UnspecifiedUltralowsulfurdistillateandusagelimits
Limitoneandtwoareforeachgenerator
OK‐0129 OKAssociatedElectricCooperativeInc‐ChouteauPowerPlant
1/23/2009 Lowsulfurdiesel 2,200 hp 0.89 lbs/hr Unspecified Lowsulfurdiesel0.05%S
MountainStateCarbonSO2RBLCReview A‐20
PROPOSED Steubenville-Weirton, OH-WV 1-hour SO2 Attainment SIP Page C-51