GEORGIAPOWER‐SubmittalforPLANTMITCHELLElectricUtilitySteamGeneratingUnit(EGU)HazardousAirPollutantEmissions(HAPs)InformationCollectionRequest(ICR),OMBControlNo.2060‐0631April5,2010PARTI:GENERALFACILITYINFORMATIONProcessInformation1Nameoflegalowneroffacility:GeorgiaPower2Nameoflegaloperatoroffacility,ifdifferentfromlegalowner:3Addressof_X__legalowneror____operator:241RalphMcGillBlvdNE,Bin10221Atlanta,GA303084aPlantName(asreportedonU.S.DOE/EIAForm‐860(2007),"AnnualElectricGeneratorReport",schedule2,line1,page37,question1)ORPlantName(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport",schedule2,page1,question1):Mitchell4bEIAPlantCode(asreportedonU.S.DOE/EIAForm‐860(2007),schedule2,line1,page37,question2)ORPlantID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),schedule2,page1,question2):7275Completestreetaddressoffacility(physicallocation):5200RadiumSpringsRd.Albany,GA317056Providemailingaddressifdifferent:241RalphMcGillBlvdNE,Bin10221Atlanta,GA303087Nameandtitleofcontact(s)abletoanswertechnicalquestionsaboutthecompletedsurvey:SarahMarkham,EngineerII8Contact(s)telephonenumber(s):(205)257‐6780ande‐mailaddress(es):sasander@southernco.com9IsthisfacilityconsideredtobeownedoroperatedbyasmallentityasdefinedbytheRegulatoryFlexibilityAct?____Yes_X__No____Don'tknowPage1of26 partI,1‐14GEORGIAPOWER‐SubmittalforPLANTMITCHELLElectricUtilitySteamGeneratingUnit(EGU)HazardousAirPollutantEmissions(HAPs)InformationCollectionRequest(ICR),OMBControlNo.2060‐0631April5,2010PARTI:GENERALFACILITYINFORMATION10Whichofthefollowingfossilfuelsorothermaterial(s)arefiredinanysteamgeneratingunitatthisfacility?_X__coal__X__oil(includingpetcoke)___naturalgas___other(specifyinquestion14below)11Whichofthefollowingfossilfuelorothermaterial(s)arepermitted1tobefiredinanysteamgeneratingunitatthisfacility?_X__coal_X__oil(includingpetcoke)___naturalgas_X__other(specifyinquestion14below)12Ifcoalorsolidfuel,asdescribedbelow,derivedfromafossilsourceisfired,indicatewhichrankofcoalorsolidfuelwasutilizedduringtheprevious12monthspriortothereceiptofthisICR:2,3____lignite(%_____)____subbituminous(%_____)_X__bituminous(%_100____)____anthracite(%_____)____coalrefuse(includinggob,culm,andsubbituminous‐derivedcoalrefuse)(%_____)____synfuel(including,butnotlimitedto,briquettes,pellets,orextrusionswhichareformedbybindingmaterials,orprocessesthatrecyclematerials)(%_____)(pleasespecifythetypeorformofsynfuelused___________________________________________)____petroleumcoke(%_____)13Ifoilisfired,indicatewhichtypeofoilwasutilizedduringtheprevious12monthspriortothereceiptofthisICR:4_X__distillate(%_100____)____other(specify__________)(%_____)____residualorbunkerC(%_____)Page2of26 partI,1‐14GEORGIAPOWER‐SubmittalforPLANTMITCHELLElectricUtilitySteamGeneratingUnit(EGU)HazardousAirPollutantEmissions(HAPs)InformationCollectionRequest(ICR),OMBControlNo.2060‐0631April5,2010PARTI:GENERALFACILITYINFORMATION14aIf"other"wascheckedinquestions10or11aboveindicatingthatanynon‐fossilfuelorothermaterial(including,butnotlimitedto,plastics,treatedwood,rubberbeltingorgaskets,wholetires,tire‐derivedfuel,boilercleaningsolutions,animalwastes,etc.)iseitherutilizedorpermittedtobeused,pleaseindicatebelowwhatmaterialsarecombustedintheboilerandinwhatquantities(specifywhetherthisquantityisonaweightpercentageorheat[Btu]basis).Alsoindicate(yes/no)whetheryouarepermitted5toburnnon‐fossilfuel(s)orothermaterial(s)evenifyoudonotactuallyburnthem.14bIf"other"wascheckedinquestions10or11aboveindicatingthatanynon‐fossilfuelorothermaterial(including,butnotlimitedto,plastics,treatedwood,rubberbeltingorgaskets,wholetires,tire‐derivedfuel,boilercleaningsolutions,animalwastes,etc.)iseitherutilizedorpermittedtobeused,weresuchmaterialtobeclassifiedas"solidwaste"undertheResourceConservationandRecoveryActand,thusmaketheutilizingunitsubjecttoCAAsection129,wouldyoucontinuetoutilize(i.e.,useasafuel)thematerial?____Yes____NoExplain:Untiltheregulationsarefinalized,wecannotdeterminewithcertaintywhetherwewouldusetheseothermaterialsornot.1"Permitted"inthiscontext,referstothefuelsthatthepermitanticipateswillbecombustedatthefacility.2Iftheboilerisfiredbyablendofcoalranks,pleasespecifypercentage(separately,onbothamassandonaBtubasis)ofeachcoalrank(e.g.,85%subbituminuous/15%bituminous).3Inreferencetofootnote1,ifnecessary,anotationcanbeaddedtoautilizedfueltypethatisnotlistedintheoperatingpermitnotingthereasonthefueltypewascombusted(e.g.,"thepermittingagencyallowedthisfueltobecombustedforspecialtestingandresearchpurposes").4Iftheboilerisfiredbyablendoffueloilranks,pleasespecifypercentage(separately,onbothavolumeandonaBtubasis)ofeachfueloilrank(e.g.,85%residualoil/15%distillate).5Ifnecessary,anotationcanbeaddedtoautilizedfueltypethatisnotlistedintheoperatingpermitnotingthereasonthefuelwascombusted(e.g.,"thepermittingagencyallowedthisfueltobecombustedforspecialtestingandresearchpurposes").Nonein2009PermittedtoburnYesYesNonein2009Quantity/yearNonein2009Nonein2009Nonein2009Nonein2009SynfuelNonein2009OtherMaterialSawdustBiomassUsedOilYesActuallyburnNonein2009YesPage3of26 partI,1‐14GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201015Identification(ordesignation)ofallcoal‐andoil‐firedsteamgeneratingunits(boilers)(asdefinedbyCleanAirActsection112(a)(8))locatedatthisfacility.SEENOTESBELOWforexplanationsofresponses.



# Boiler ID 6 

# Original design fuel (i.e.,

coal rank or type of oil) Design heat input,

(MMBtu/hr) 7 

# Present maximum heat

input, (MMBtu/hr) 8 

# MWe Gross capacity

summer MWe Net Capacity

summer Original design gross

efficiency (%, HHV) Present operating gross

efficiency (%, HHV) Design steam pressure

(psig) Operating steam pressure

(psig) Design steam temperature

( o 

# F) Operating steam

temperature ( o 

# F) Design steam reheat

temperature ( o 

# F) 9 

# Operating steam reheat

temperature ( o 

# F) 10 

# Fuel 11 

# Hours/year operated 12 

# Average annual capacity

factor for the past 3 years Applicable NSPS Estimated year of

retirement 133 bituminous CBI CBI 164 155 89.18 88.91 1800 1801 1000 989 1000 995 bituminouscoal(100%),distillateoil(100%)CBI CBI NotapplicableNoneplanned6BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).7Perfuelburnedintheboiler.Reportthisbasedonhigherheatingvalue(HHV).8Perfuelburnedintheboiler.Reportthisbasedonhigherheatingvalue(HHV).9Pleaseindicateifmorethanonesteamreheatcycleisutilized,and,ifso,pleaseprovideinformationforboth.10Pleaseindicateifmorethanonesteamreheatcycleisutilized,and,ifso,pleaseprovideinformationforboth.11Indicatethefuelsutilizedfortheindicatedboiler,andpercentages,asindicatedinquestions11‐13.12The"hours/yearoperated"wouldbetheaverageoftheactualnumberofhourstheunitoperatedin1yearbasedonthelast3yearsofoperation.13ThiscanbetreatedasCBIandcanbesubmittedthroughtheproperCBIprocedureifdesired.NOTES:OriginalDesignFuelBasedontheoriginalcontractboilerdatasheet;onlytheprimaryfuelislistedifmultiplefuelswereincludedonthedatasheet.DesignHeatInputConfidentialBusinessInformationPresentMaximumHeatInputConfidentialBusinessInformationMWeGrossCapacitySummerIdentifiesthegrossnormalfullload.GeorgiaPowerdoesnotchangeunitcapacitiesseasonfromseason.MWeNetCapacitySummerIdentifiesthenetnormalfullload;takendirectlyfromthe2010installedandauthorizeddocument.GeorgiaPowerdoesnotchangeunitcapacitiesfromseasontoseason.OriginalDesignGrossEfficiencyTakendirectlyfromtheoriginalcontractboilerdatasheet.PresentOperatingGrossEfficiencyBasedonthemostrecentactualtestoftheboilerefficiency,unlessnorecentboilerefficiencytestwasavailable.Wherenorecenttestwasavailable,thatstatusisindicated.DesignSteamPressureBasedonthethermaldesignoftheunitasrepresentedontheturbineheatbalancesheet.Page4of26partI,15GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201015Identification(ordesignation)ofallcoal‐andoil‐firedsteamgeneratingunits(boilers)(asdefinedbyCleanAirActsection112(a)(8))locatedatthisfacility.SEENOTESBELOWforexplanationsofresponses.



# Boiler ID 6 

# Original design fuel (i.e.,

coal rank or type of oil) Design heat input,

(MMBtu/hr) 7 

# Present maximum heat

input, (MMBtu/hr) 8 

# MWe Gross capacity

summer MWe Net Capacity

summer Original design gross

efficiency (%, HHV) Present operating gross

efficiency (%, HHV) Design steam pressure

(psig) Operating steam pressure

(psig) Design steam temperature

( o 

# F) Operating steam

temperature ( o 

# F) Design steam reheat

temperature ( o 

# F) 9 

# Operating steam reheat

temperature ( o 

# F) 10 

# Fuel 11 

# Hours/year operated 12 

# Average annual capacity

factor for the past 3 years Applicable NSPS Estimated year of

retirement 13OperatingSteamPressureRepresentstheaveragethrottlepressurewhentheunitoperatedatgrossnormalfullloadoverathreeyearperiod(January2007toDecember2009).DesignSteamTemperatureBasedonthethermaldesignoftheunitasrepresentedontheturbineheatbalancesheet.OperatingSteamTemperatureRepresentstheaveragesteamtemperaturewhentheunitoperatedatgrossnormalfullloadoverathreeyearperiod(January2007toDecember2009).DesignSteamReheatTemperatureBasedonthethermaldesignoftheunitasrepresentedontheturbineheatbalancesheet.OperatingSteamReheatTemperatureRepresentstheaveragereheatsteamtemperaturewhentheunitoperatedatgrossnormalfullloadoverathreeyearperiod(January2007toDecember2009).FuelIndicatesthefuelsburnedinthepreviouscalendaryear(JanuarytoDecember2009).Hours/YearOperatedConfidentialBusinessInformationAnnualAverageCapacityFactorforthePast3YearsConfidentialBusinessInformationApplicableNSPSWherenoNSPSisidentified,theunitisnotcurrentlysubjecttoanyNSPS.RetirementYearGeorgiaPowerhasnotcommittedtoanactualretirementdateforPlantMitchellUnit3.GeorgiaPowercontinuallyevaluatesretirementscenarioswithrespecttoitsgeneratingunitsforavarietyofplanningpurposes,takingintoaccountawiderangeofvariables.Whilethecompanyassumesfinancial"retirementdates"foraccountingpurposes,forexample,fordepreciationschedulesorforFERCorPublicServiceCommissionuses,thesedatesarenotindicativeoftheunit'sactualretirementdate.Page5of26partI,15GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201016ForeachboilernotedinPartI,question15,providethefollowinginformationforeachcurrentemissioncontroldeviceinstalledandoperatingand/orplanned(pleasedesignatetheorderoftheemissioncontrols‐1forthefirstcontrolfollowingtheboiler,2forthesecondcontrolfollowingtheboiler,etc.):BoilerID14Type15NOxcontrol16SO2control17PMcontrol18Othercontrol193 tangential‐fired Notapplicable Notapplicable (1)cold‐sideelectrostaticprecipitator(ESP)(4/1975)Notapplicable14BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).15Examples:tangential‐fired;cyclone;wall‐fired;circulatingfluidizedbed(CFB)16Examples:low‐NOxburners;selectivecatalyticreduction(SCR);selectivenon‐catalyticreduction(SNCR);over‐fireair(OFA).Includespecificdatethatcontrolwentonlineorplannedoperationaldatefornewinstallation.Ifthisboiler'scontrolconfigurationutilizesaSCR,pleaseincludethetypeofmaterialfromwhichthecatalystismanufacturedandthetypeofreductantusedinwiththeSCR(e.g.,anhydrousammonia,urea,other).Also,pleasenoteifthecatalystisspecificallydesignedtoreduceSO3formation?17Examples:wetfluegasdesulfurization(FGD;anytype);dryscrubbing(anytype);specifywhethercalcium‐orsodium‐based.Includespecificdatethatcontrolwentonlineorplannedoperationaldatefornewinstallation.18Examples:fabricfilter;cold‐sideelectrostaticprecipitator(ESP);hot‐sideESP;cycloneormulticlone;venturiscrubber.Includespecificdatethatcontrolwentonlineorplannedoperationaldatefornewinstallation.19Pleaseindicatesystemsinstalledspecificallytocontrolanyotherpollutants(e.g.,Hg,SO3,etc.).Examples:activatedcarboninjection(ACI);PowerspanECO®;drysorbentinjectionorwetESPforSO3control;fluegasconditioningtocontrolopacity(e.g.,SO3injection,ammonia,other);additiveuseformercurycontrol(e.g.,bromine;scrubberadditives).Includespecificdatethatcontrolwentonlineorplannedoperationaldatefornewinstallation.Alsoincludeanypollutantscontrolledbythistechnology(e.g.,controltechnology[pollutantcontrolled]).Page6of26 partI,16GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201017ForeachboilernotedinPartI,question15,providethecompany(primevendor)nameandcompanycontactinformationforeachHAP‐specific(e.g.,mercury,hydrogenchloride)controltechnologythatyouhaveeithercontractedfor,areinstalling,orhaveinstalledforthepurposeofparticipatinginacontroltechnologydemonstrationproject20(e.g.,U.S.DepartmentofEnergyprogram,consentdecree,etc.).Name Telephone Address3 Notapplicable Notapplicable Notapplicable Notapplicable20AcontroltechnologydemonstrationprojectisdefinedasaU.S.Government(e.g.,U.S.DepartmentofEnergyprogram)sponsored(inwholeorinpart)projectormandate(e.g.,asaresultofaconsentdecree)thataddsaHAPcontroltechnologytoafacility'sunittodemonstratethetechnology'sHAPremovalperformance.21BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).Company(vendor)contactinformationBoilerID21Company(vendor)namePage7of26 partI,17GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201018ForthecontroltechnologiesidentifiedinPartI,question17,providethedateofactualstart‐upofthedemonstration(ifthecontroliscurrentlyoperating),thedateofexpectedorprojectedstart‐up,thedatethedemonstrationwascompleted,thetypeofHAPcontrolinstalled(e.g.,sorbentandtype;pre‐combustionboilerchemicaladditive;combustionboilerchemicaladditive),thedesiredHAPemissionreductionorrate(ifany),andthecoalrank(s)uponwhichthedemonstrationwasconducted.PleasespecifytheformatofthetargetHAPemissionreductionrate(e.g.,lb/MWh,lb/TBtu,percentreduction,etc.).Iftheformatofthetargetend‐pointispercentreduction,provide(1)anestimateofwhatanequivalentemissionratewouldbe(andspecifytheformatoftheequivalentemissionrate),and(2)thebasisforcalculatingthepercentreduction(i.e.,wherethe"inlet"and"outlet"are).BoilerID22Demonstrationactivityactualstart‐updateDemonstrationactivityprojectedstart‐updateDemonstrationactivityend‐dateorprojectedend‐dateTypeofcontrol(e.g.,sorbentandtype;chemicaladditive23)DesiredHAPemissionreduction(%)oremissionrateCoalrank(s)inuse3 Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable22BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).23Ifadditiveisused,pleaseindicateinjectionpoint.Page8of26 partI,18GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201019ForeachboilernotedinPartI,question15,providethecompany(primevendor)nameandcompanycontactinformationforeachHAP(e.g.,mercury,hydrogenchloride,etc.)controltechnologythatyouhaveeithercontractedfor,areinstalling,orhaveinstalledforthepurposeofprovideanon‐demonstration,full‐scaleoperatingsystem.Name Telephone Address3 Notapplicable Notapplicable Notapplicable Notapplicable24BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).Company(vendor)contactinformationBoilerID24Company(vendor)namePage9of26 partI,19GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201020ForthecontroltechnologiesidentifiedinPartI,question19,providethedateofactualstart‐up(ifthecontroliscurrentlyoperating),thedateofexpectedorprojectedstart‐up,thetypeofHAPcontrolinstalled(e.g.,sorbentandtype;pre‐constructionboilerchemicaladditive;combustionofboilerchemicaladditive),theguaranteedHAPemissionreductionoremissionrate,thesorbentfeedrateuponwhichtheguaranteeisbased,andthecoalrank(s)uponwhichtheguaranteeisbased.Pleasespecifytheformatoftheguarantee(e.g.,lb/MWh,lb/TBtu,percentreduction,etc.).Iftheformatoftheguaranteeispercentreduction,provide(1)anestimateofwhatanequivalentemissionratewouldbe(andspecifytheformatoftheequivalentemissionrate),and(2)thebasisforcalculatingthepercentreduction(i.e.,wherethe"inlet"and"outlet"are).BoilerID25Actualstart‐updateExpectedorprojectedstart‐updateTypeofcontrol(e.g.,sorbentandtype;chemicaladditive)26GuaranteedHAPemissionreduction(%)oremissionrateSorbentoradditivefeedrateonwhichguaranteeisbasedCoalrank(s)uponwhichguaranteeisbased3 Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable25BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).26Ifadditiveisused,pleaseindicateinjectionpoint.Page10of26 partI,20GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201021ForeachboilernotedinPartI,question15,providethefollowinginformation:PM28PM10(29)PM2.5(30)SO2HCland/orHFHCNMetalHAP31Hg COOtherorganics(specify)Otherpollutant(specify)3 E=0.7x(10/R)^0.202,whereEequalstheallowableparticulateemissionrateinpoundspermillionBtuheatinputandRequalstheheatinputinmillionBtuperhour(TitleVpermit;basedon3‐runstacktestusingMethod5of17;testconductedevery13months,butmaybedeferredfor12monthsiftestresultsfromthepreviousannualtestsarefiftypercentorlessofthelimit)NotapplicableNotapplicable3%fuelsulfurcontent(TitleVpermit;basedonanalysisofcoalsampleacquiredforeachoperatingdayandsuppliercertificationstatementforNo.2oil)NotapplicableNotapplicableNotapplicableNotapplicableNotapplicableNotapplicableNOxMulti‐UnitPlan:SouthernCompanyPhaseIINOxAveragingPlan0.46lb/MMBtuannualaverageoverallunits(TitleVpermit;determinedbyCEMS).27BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).28IftheboilerhasseparatepermittedemissionlimitsforfilterableandcondensablePM,respectively,pleaseindicatethoseseparatelimits.Alsoincludethecompliancetestmethodutilized.29Listthecompliancetestmethodutilized.30Listthecompliancetestmethodutilized.31MetalHAPincludecompoundsofantimony,arsenic,beryllium,cadmium,chromium,cobalt,lead,manganese,nickel,phosphorus,andselenium;indicatepermitlevelforallmetalHAPforwhichapermitlevelhasbeendeveloped.Permittedemissionlimit(indicatetypeofpermitandformatofemissionlimit)BoilerID27Page11of26partI,21GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201022ForeachboilernotedinPartI,question15,providethefollowinginformation:NOTES:Allguaranteesarebasedonanddemonstratedwithcertainfuelandoperatingconditions.Guaranteesarenotnecessarilyrepresentativeofthelongtermordaytodayvariabilitythatmayoccurwithchangesinfuelspecifications,operatingconditions,normalwearandtearofequipmentovertime,startups,shutdowns,andmalfunctions.PM33PM10PM2.5SO2HCland/orHFHCNMetalHAP34Hg COOtherorganics(specify)Otherpollutant(specify)3 ESPrebuild:0.12lb/MMBtufilterable(expiredin2000)NotapplicableNotapplicableNotapplicable NotapplicableNotapplicableNotapplicableNotapplicableNotapplicableNotapplicableNotapplicable23Wasanyotherguaranteelevelsoughtoroffered?____Yes_X___NoPleaseelaborate.32BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).33IftheboilerhasseparateguaranteedemissionrateforfilterableandcondensablePM,respectively,pleaseindicatethoseseparateemissionrates.34MetalHAPincludecompoundsofantimony,arsenic,beryllium,cadmium,cobalt,lead,manganese,nickel,phosphorus,andselenium;indicatepermitlevelforallmetalHAPforwhichapermitlevelhasbeendeveloped.MostrecentguaranteedemissionrateforeachpollutantforwhichthereisapermittedemissionlimitBoilerID32Page12of26partI,22‐23GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201024ForeachboilernotedinPartI,question15,providethefollowinginformation:PM36PM10PM2.5SO2HCland/orHFHCNMetalHAP37Hg COOtherorganics(specify)3 Stacktestconductedevery13months,butmaybedeferredfor12monthsiftestresultsfromthepreviousannualtestsarefiftypercentorlessofthelimit;undertheCAMplan,opacitymonitoredcontinuouslybyCOMS,excursions(3‐hourblockaveragesgreaterthan40%)reportedquarterly.Thefacilityshallsubmit30‐dayadvancenotificationsofrequiredtestingandtestreportswithin60daysofcompletionofthetesting.AllrecordsrelatedtotheTitleVpermitareretainedforfiveyears.NotapplicableNotapplicableCoalsulfurcontentmonitoredthroughdailycoalsampling;fueloilsulfurcontentmonitoredthroughvendorcertification;exceedancesof3%limitreportedquarterly;recordsretainedfor5years.NotapplicableNotapplicableNotapplicableNotapplicableNotapplicableNotapplicable35BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).36Iftheboiler'smonitoring,recordkeeping,andreportingrequirementsrequireyourcompanytomonitoring,keeprecords,andreportfilterableandcondensablePMseparately,pleasedescribetheseparateactionsrequired.37MetalHAPincludecompoundsofantimony,arsenic,beryllium,cadmium,chromium,cobalt,lead,manganese,nickel,phosphorus,andselenium;indicatepermitlevelforallmetalHAPforwhichapermitlevelhasbeendeveloped.Requiredmonitoring,recordkeeping,andreportingrequirementsforeachpollutantforwhichthereisapermittedemissionlimitBoilerID35Page13of26partI,24GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201025ForthecontroltechnologiesidentifiedinPartI,questions17and19,providethecostinformationrequested.38FacilityName/UnitNo.:NotapplicableRetrofittoexistingboiler?NotapplicableInstallationonanewboiler?NotapplicableTotalCapitalInvestment:‐$TotalAnnualOperatingandMaintenanceCosts:‐$(Includebaseyearforoperatingcosts[e.g.,2006]26Areanyothermeansofemissioncontrol(foranypollutant)employedonanyboilernotedinPartI,question15(e.g.,low‐ashcoal,coaloroilwithlowtraceconstituents,etc.)?Pleasespecify.No.38ThiscanbetreatedasCBIandcanbesubmittedthroughtheproperCBIprocedureifdesired.Page14of26 partI,25‐26GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,2010PARTII:FUELANALYSISANDEMISSIONDATAFuelAnalysis391aPlantorfacilitynamefromPartI,question4a:Mitchell1bPlantorfacilitycodefromPartI,question4b:72739TherespondentshouldreplytothisICRwithseparatepages18through24(PartII)foreachoftheirfacilities.Page15of26 partII,1GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,20102Foreachindividualcoalandoilshipmentreceivedduringthepreceding12calendarmonths,providethefollowinginformation,asavailable(indicatedN/Aifnotavailable;useadditionalpages,asnecessary):NOTE:Multipleseamsmaybelistedtoaccountfortheflexibilitywrittenintothepurchaseorders.Actualshipmentsmaynothaveoriginatedfromeachseamlisted.Theinformationbeingprovidedisonashipmentbyshipmentbasis.GeorgiaPowercannotguaranteethatwhatwasshippedinthepreceding12calendarmonthsiswhatwasburnedinthepreceding12calendarmonths.D.B. D.B. D.B.State/CountryCounty42Coalseam43%Sulf %Ash Btu/lb10,425 3 KY HARLANHARLAN,HIGHSPLINT,IMBODE,LOWSPLINT,WINIFREDETRAIN 0.97 9.55 13,76510,454 3 KY HARLANHARLAN,HIGHSPLINT,IMBODE,LOWSPLINT,WINIFREDETRAIN 0.97 12.21 13,22710,326 3 KY HARLANHARLAN,HIGHSPLINT,IMBODE,LOWSPLINT,WINIFREDETRAIN 0.93 11.35 13,49210,221 3 KY HARLANHARLAN,HIGHSPLINT,IMBODE,LOWSPLINT,WINIFREDETRAIN 1.09 9.86 13,64340EPArecognizesthatfacilitieshave(sometimes)severalmonthsinventoryandthattheamountreceivedisnotnecessarilythesameastheamountfired.41BoilerID(asreportedonU.S.DOE/EIAFormEIA‐860(2007),"AnnualElectricGeneratingReport,"schedule6,partA,line1,page53,[forplantsequaltoorgreaterthan10MWbutlessthan100MW]oronschedule6,partB,line1,page54,[forplantsgreaterthan100MW])ORGeneratorID(asreportedonU.S.DOE/EIAFormEIA‐923(2008),"PowerPlantOperationsReport,"schedule5,partA,page8).42Ifknown.43Ifknown.VendorAnalysesFuelsourceAmountreceived,drybasis,shorttons40ID#ofboiler(s)firingfuel41FuelshipmentmethodPage16of26 partII,2GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,20103Foreachindividualcoalandoilshipmentreceivedduringthepreceding12calendarmonths,providethefollowinginformation44,asavailable(drybasis)(indicateN/Aifnotavailable):NOTES:"ND"indicatesresultsarenondetect.Allresultspresentedonadrybasis.GeorgiaPowercollectsthisinformationonselectcoalshipmentsonaquarterlybasis,butdoesnothavethisinformationavailableonashipmentbyshipmentbasis.TheinformationGeorgiaPowerprovidesinthisquestioncannotbelinkedtotheinformationinPartII,Question2becausetheinformationcomesfromtwoseparatedatabases.Thustheinformationprovidedinthisquestionrepresentsonlyaverysmallportionofouractualshipments.Antimony Arsenic Beryllium Cadmium Chromium Cobalt Lead Manganese Selenium09‐208 22,300 1.01 10.53 13,482 0.056 1301 71 12.3 1.1 6.8 2.5 0.04 14.6 6.9 8.8 31.4 2.8 KYPerry,LetcherHazard4,Hazard4R,Hazard8,Hazard7Train09‐404 11,324 0.96 10.64 13,265 ND 95 64 12.0 1.2 7.2 2.0 0.05 16.7 7.0 8.4 21.8 2.8 KYHarlanHighsplint,Winifrede,Lowsplint,LowerHarlan,Dseam,Kellioki,Imbodden,OwlTrain09‐222 11,142 0.89 8.72 13,685 ND ND 59 10.3 1.0 3.8 3.1 0.02 11.6 6.1 7.8 17.5 2.3 kYPerry,LetcherHazard4,Hazard4R,Hazard8,Hazard7Train09‐418 12,392 1.12 11.36 13,390 ND 111 89 13.9 1.3 9.7 2.1 <0.02 17.3 8.0 8.8 26.4 2.4 KYHarlanHighsplint,Winifrede,Lowsplint,LowerHarlan,Dseam,Kellioki,Imbodden,OwlTrain09‐424 11,170 1.06 10.8 13,433 ND 111 84 18.0 1.0 6.7 2.5 0.07 19.6 10.5 12.0 30.3 2.5 KYHarlanHighsplint,Winifrede,Lowsplint,LowerHarlan,Dseam,Kellioki,Imbodden,OwlTrain09‐240 12,908 1.01 9.46 13,576 ND 1501 133 11.7 1.0 5.7 2.5 0.05 14.0 7.0 8.2 19.5 2.5 KYPerry,LetcherHazard4,Hazard5A,AlmaTrain09‐443 12,664 0.9 10.3 13,598 ND 105 60 12.4 1.0 4.7 2.1 0.03 16.7 7.9 9.1 23.4 2.8 KYHarlanHighsplint,Winifrede,Lowsplint,LowerHarlan,Dseam,Kellioki,Imbodden,OwlTrain44TotheextentthatavendorprovidesthesedataorthatafacilityisrequiredbyStateorlocalagencytoanalyzeitsfuelforHAPconstituents(e.g.,Cl,F),andanymetallicHAP(e.g.,Hg,Pb,As,Se,etc.),EPAwishestherespondingfacilitytoprovidethosefuelanalysesresults.Otherwise,this12‐monthfuelanalysisrequirementcanbebypassedbytherespondent.45MetalHAPincludescompoundsofantimony,arsenic,beryllium,cadmium,chromium,cobalt,lead,manganese,nickel,phosphorus,andselenium.FuelShipmentMethodTotalamountoffuelrepresentedbysample,tonsSampleID#State/CountryCounty CoalSeamNickel,ppmOthertracemetalHAP,ppm45TotalSulfur,%AshContent,%HeatingValue,Btu/lbMercury,ppmChlorine,ppmFluorine,ppmPage17of26partII,3GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,20104WerethedataprovidedinPartII,question3above,acquiredpursuantto:__X__permitrequirements(forcoal)____contractualobligations____standardoperationalprocedures__X__other(pleasespecify_atthediscretionoftheplantandtosupportotherprojects__)5AnalysesprovidedinPartII,question3above,suppliedby____Fuelsupplier(nameandaddress)__X__Other(nameandaddress)GeorgiaPowerEnvironmentalLab5131ManerRoad,SmyrnaGA300806Nameandaddressoflaboratoryperforminganalyses:GeorgiaPowerEnvironmentalLab(sameasabove)Page18of26 partII,4‐6GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,20107InadditiontotheanalysesrequiredinPartII,question3above,forsamplesforwhichanalysesofchlorineand/oranyoftheHAPmetalswereconducted,pleaseprovidecopiesofanyanalysesconductedoverthepreceding12calendarmonthsfor(a)completeproximateandultimateanalyses,(b)additionaltracemetals,and(c)themineralogyoftheashthatarereadilyavailablefortheoil(s)orcoal(s)listedinPartII,question2above.TheAgencyisrequestingthesedataonlyastheymayalreadybeavailable;noadditionalsamplingoranalysesarerequiredtoprovidethesedata.TotalMoistureVolatiles AshFixedCarbonCarbonHydrogenNitrogenTotalSulfurOxygen Barium CopperMagnesiumSodiumVanadiumZinc Al2O3Fe2O3CaO MgO K2O SiO2 Na2O SO3 TiO209‐2086.52 36.53 10.53 52.94 76.33 4.92 1.65 1.01 5.56 112 19.3 0.073 0.032 28.2 19.2 26.3 8.31 1.78 1.13 2.61 52.8 0.512 1.32 1.3409‐4046.37 34.25 10.64 55.11 77.44 4.83 1.51 0.96 4.6 122 20.9 0.071 0.034 33.5 15.7 27.4 7.05 1.59 0.955 2.68 53.7 0.422 0.878 1.4309‐2226.43 36.45 8.72 54.83 74.25 4.95 1.82 0.89 9.37 92 17.0 0.045 0.035 26.1 14.9 27.2 6.94 1.34 0.819 1.93 49.7 0.564 0.835 1.3709‐4185.99 34.06 11.36 54.58 75.53 4.88 1.48 1.12 5.63 102 20.7 0.075 0.037 35.9 16.4 26.4 8.43 1.58 1.02 2.53 49.3 0.532 1.15 1.5209‐4246.46 34.53 10.8 54.66 75.06 4.72 1.6 1.06 6.76 81 27.0 0.062 0.030 40.6 17.6 28.3 5.86 1.56 0.979 2.37 54 0.453 1.28 1.5409‐2407.39 35.3 9.46 55.23 75.99 4.79 1.72 1.01 7.04 92 16.2 0.051 0.032 26.4 15.8 25.5 7.8 1.54 0.916 2.23 54.7 0.532 0.795 1.5109‐4436.03 34.1 10.3 55.59 76.39 4.73 1.53 0.9 6.14 81 19.5 0.064 0.033 32.1 14.7 25.8 6 1.92 0.922 2.28 55.1 0.463 1.3 1.54AshMineralogy,%bywtSampleID#ProximateAnalyses,%bywt UltimateAnalyses,%bywtOtherTraceMetals,ppm,drybasisPage19of26partII,7GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,20108aWhatemissiontestreport(s),parametricmonitoringdata,andotherdataormonitoringareavailablefortheboilersnotedinPartI,question15,fortestsconductedsinceJanuary1,2005.Pleaseconsiderreportspreparedforalltestingandmonitoringprograms,forallpollutants,including(butnotlimitedto)thoserequiredunderTitleV,compliancewithStateorlocalrequirements,fulfillmentofcontractualobligations,U.S.DepartmentofEnergy(DOE)programs,etc.(NOTE:EPAisnotrequestingcopiesofthetestreportsordataatthistime;howeverwemayrequestactualcopiesinthefuture.)Useadditionalpagesasnecessary.Report1 Unit3ParticulateEmissionsTest(August8,2006)Report2 Unit3ParticulateEmissionsTest(August6,2008)Report3 Unit3BoilerBaselineTest(February27,2008toFebruary28,2008)8bPleaseindicatethedate(s)andtypes(e.g.,stack,fuel,parametric,etc.)ofthetest(s)andtheconstituents(includingcriteriaandhazardousairpollutants)sampledfor:Report1Date:8/8/2006Type:stackConstituents:PMReport2Date:8/6/2008Type:stackConstituents:PMReport3Date:2/27/2008‐2/28/2008Type:ductConstituents:CO8cDoanyofthesetestreportsreflecttestingatalocationupstreamofanyemissioncontroldevices?Yes_X___No____ Ifyes,pleasenotewhichreportsandprovideadetaileddescriptionofthelocationoftheemissionssamplingpoint(s).Report3reflectstestingattheeconomizeroutlet(upstreamofallpost‐combustioncontroldevices).NotethattherearenocontroldevicesdownstreamdesignedtoreduceCO.8dWereanyofthesetestreportsconductedwhenuseofothermaterial(s)ornon‐fossilfuelswerefiredintheboiler?Yes____No_X___Ifyes,pleasenotwhichreportsandidentifytheothermaterial(s)ornon‐fossilfuelsused.8eDoanyofthesetestreportsreflecttestingduringperiodsofstartup,shutdown,andmalfunction?Yes____No_X___Ifyes,pleasenotewhichreports.8fDidtheunit'scontrolconfigurationdifferfromthatshowninPartI,question16,atthetimeofthesetestresults?Yes____No_X___Ifyes,pleaselisttheunit'scompletecontrolconfigurationattimeoftestinginasimilarformattoPartI,question16.Page20of26 partII,8GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,20108gDoanyofthesetestreportsreflecttestingatalocationbeforeapostcombustionSO2emissioncontroldevice(e.g.,FGD,SDA,DryScrubber)?Yes____No_X___Ifyes,pleasenotewhichreportsand,inadditiontothedetaileddescriptionofthelocationofthesamplingpoint(s)(question8cabove),includedetailabouthowmuch,ifany,bypassofunscrubbedfluegaswasutilizedatatthetimeoftesting(includingpercentageoftotalscrubberfluegasflow).Notebydiagramwheresamplingportswerelocatedinrelationtothebypassductwork.Page21of26 partII,8GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,20109Whattypeofdeviationreportingisrequiredforviolationsofpermitrequirements?Specifieddeviationsarereportedquarterly.Emissionsexceedingastandardforaperiodof4hoursormorearereportedwithin7days.Otherdeviationsarereportedsemiannually.Note:Notallreporteddeviationsareconsideredviolationsofpermitrequirements10Aredeviationreportsavailableformalfunctionsorotherperiodsofnoncompliancewithpermittermsandconditions?Yes_X__No____ Ifyes,pleasenotewhichreports.Deviationreportsincludingperiodsofmalfuncationareavailablewhererequiredinquarterlymonitorbreakdownreportsandexcessemissions,exdeedances,andexcursionreports.Note:Amalfunctionisnotnecessarilyaperiodofnoncompliancewithpermittermsandconditions.Notallreporteddeviationsareconsideredviolationsofpermitrequirements11Arecontinuousemissionsmonitoringsystem(CEMS)dataavailable(e.g.,mercury,continuousopacitymonitoringsystems)thatarenotalreadybeingprovidedtotheU.S.EPA,eveniffromshort‐termtesting?Yes_X__No____Ifyes46,pleasenoteforwhichpollutantsCEMSdataareavailableandtheperiodoftime(bothtotalperiodandcalendarperiod)forwhichthedataareavailable.IfCEMdataarebeingprovidedtoEPA,pleasenotetowhichOfficethedataarebeingprovided.COMSdataareavailableforthelastfiveyearsormore.46WhereunitsaremonitoredbyCEMs(eitherfollowingCAMR,State,orNISTQA/QCprocedures),andwheredataareavailable,EPArequeststhatthisCEMdatabysubmittedbytherespondent.Therespondentshouldalsomarktheperiodsofstartup,shutdownandmalfunctionevents(SSM)inthedatasets.Page22of26 partII,9‐11GEORGIAPOWER‐PLANTMITCHELLEGUHAPsICR,OMBControlNo.2060‐0631April5,201012ForeachboilernotedinPartI,question15,providethefollowinginformation:NOTE:Netgenerationdatanotavailableintestreports.Otherparametersmayormaynotbeavailabledependingonthetestreport.DateoftestPM49SO2 HCl/HF/HCNMetalHAP50Hg51COOtherorganics(specify)3 8/8/2006 SeeAttachment1 Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable3 8/6/2008 SeeAttachment2 Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable3 2/27/2008‐2/28/2008 Notapplicable Notapplicable Notapplicable Notapplicable Notapplicable SeeAttachment3 Notapplicable47ProvideemissiontestdataforalltestsconductedsinceJanuary1,2005.Pleaseindicatetestdataacquiredbothbeforeandafteranycontroldevice.Useadditionalpagesasnecessary.EPAmay,atsomefuturedate,requestacopyofoneormoreemissiontestreports.DatageneratedtofulfillbothFederalandStaterequirementsmustbeprovided.NotethatdatageneratedpursuanttoCAATitleVmustbemaintainedandavailablefor5years.Alsoincludeaveragingtimesandmeasurementunitsforallpollutants.48Foreachemissionstestruntherespondentshouldprovidethefollowingprocessinformation:UnitLoad(MW),Netgenerationduringrun(MWhnet),Fluegasmoisturecontent(%),Fluegasflowrate(dscfmorNm3/hr),Fluegasoxygencontent(%,dry),Fluegascarbondioxidecontent(%,dry),Fluegastemperatureatsamplingpoint(oF),Fluegaspressureatsamplingpoint(atm),Standardtemperature(oF),Standardpressure(atm).49IfemissiontestingrecordedtheemissionsoffilterableandcondensablePM,separately,pleaseincludethoseseparateemissionresults.Also,pleaseincludeseparateemissionresultsfortotalPM,PM10,andPM2.5.50MetalHAPincludecompoundsofantimony,arsenic,beryllium,cadmium,chromium,cobalt,lead,manganese,nickel,phosphorus,andselenium;indicateemissionlevelforallmetalHAPforwhichanemissiontesthasbeenconducted.51PleaseprovideseparateresultsfortotalHg,elementalHg,oxidizedHg,andparticulateHg,asavailable.Iftheemissionstestingrecordedtheamountofunburnedcarboninflyash(asreflectedbythe"LossofIgnition"[L.O.I])atthetimeofanyHgtesting,pleaseincludethesedata.BoilerIDEmissionstestresults(indicateformatofemissiondata)47,48Page23of26 partII,12

# ATTACHMENT 1

‐ Mitchell Report 1 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida



# Run 1 Run 2 Run 3

Test Date 8/8/2006 8/8/2006 8/8/2006



# Run Start Time 11:50 13:25 1455



# Run End Time 13:00 14:35 16:05



# Meter Volume (dacf), Vm: 36.66 37.055 37.455



# Sqrt Delta P ("wc): 0.48 0.48 0.48



# Sampling Time (min): 60 60 60



# Barometric Pressure ("Hg), Pbar: 29.92 29.89 29.88



# Delta H ("wc): 1.1 1.1 1.1



# Volume in Impingers (mls), VIc: 63.3 67.4 65.4



# Static Pressure ("wc), Pg: -1.00 -0.98 -1.00



# Stack Pressure ("Hg), Ps: 29.85 29.82 29.81



# Stack Temperature (F), Ts: 284 290 291



# Meter Coefficient (no units), Y: 0.997 0.997 0.997



# Pitot Coefficient (no units) Cp: 0.840 0.840 0.840



# Meter OutletTemperature (F), Tm: 100 100 102



# Stack Diameter (inches): 252 252 252



# Area Stack (sq. ft.), As: 346.36 346.36 346.36



# Nozzle Diameter (inches), dp: 0.292 0.292 0.292



# Area Nozzle (sq. ft.), An: 0.000465 0.000465 0.000465



# Percent CO2 (% dry volume): 11.9 12.0 12.1



# Percent O2 (% dry volume): 6.8 6.9 6.8



# Percent (N2 + CO) (% dry volume): 81.3 81.1 81.1



# Particulate Collected (mg), Mn: 31.5 20.9 19.5



# Molec. Wt. Dry (lb/lb-mole), Md: 30.176 30.196 30.208



# Volume Water (scf), Vwstd 2.980 3.173 3.078



# Meter Volume (dscf), Vmstd: 34.562 34.867 35.142



# Wet Fraction (v/v), Bws: 0.079 0.083 0.081



# Molec. Wt. Wet (lb/lb-mole), Ms: 29.210 29.179 29.225



# Stack Gas Sampled (acf), Vma: 53.047 54.243 54.588 

# Averages

Stack Gas Velocity (fps), Vs: 32.10 32.10 31.99 32



# Volumetric Flowrate (dscfm), Qs: 434,618 428,864 427,955 430,479



# Volumetric Flowrate (acfm), Qa: 667,076 667,182 664,765 666,341



# Grainloading (gr/dscf), cs: 0.0140 0.0093 0.0085 0.01



# Emission Rate (lb/hour), E: 52.33 34.03 31.35 39.2



# Percent Isokinetic Sampling (%), I: 98.78 100.99 102.00 100.59



# F-Factor (dscf/mmBtu), F: 9780 9780 9780 9780



# Heat Input (mmBtu/hour): 1798.84 1762.44 1771.27 1777.52



# Emission Rate (lbs/mmBtu), E: 0.03 0.02 0.02 0.02



# Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 0.24



# Average Unit Gross Load (MW) 164 164 164 164 

# Particulate Emission Results Summary

Mitchell Unit 3

Page 24 of 26 Att. 1

# ATTACHMENT 2

‐ Mitchell Report 2 Test Results

Performed By: Spectrum Systems, Inc., Pensacola, Florida



# Run 1 Run 2 Run 3

Test Date 8/6/2008 8/6/2008 8/6/2008



# Run Start Time 11:45 13:20 14:45



# Run End Time 12:55 14:30 15:55



# Meter Volume (dacf), Vm: 34.429 35.906 36.245



# Sqrt Delta P ("wc): 0.44 0.45 0.46



# Sampling Time (min): 60 60 60



# Barometric Pressure ("Hg), Pbar: 29.75 29.75 29.75



# Delta H ("wc): 0.9 1.0 1.0



# Volume in Impingers (mls), VIc: 45.8 47.1 48.2



# Static Pressure ("wc), Pg: -0.95 -1.00 -0.90



# Stack Pressure ("Hg), Ps: 29.68 29.68 29.68



# Stack Temperature (F), Ts: 296 299 299



# Meter Coefficient (no units), Y: 0.987 0.987 0.987



# Pitot Coefficient (no units) Cp: 0.840 0.840 0.840



# Meter OutletTemperature (F), Tm: 102 108 109



# Stack Diameter (inches): 252 252 252



# Area Stack (sq. ft.), As: 346.36 346.36 346.36



# Nozzle Diameter (inches), dp: 0.292 0.292 0.292



# Area Nozzle (sq. ft.), An: 0.000465 0.000465 0.000465



# Percent CO2 (% dry volume): 12.6 12.3 12.4



# Percent O2 (% dry volume): 6.1 6.2 6.3



# Percent (N2 + CO) (% dry volume): 81.4 81.5 81.3



# Particulate Collected (mg), Mn: 33.2 62.1 56.9



# Molec. Wt. Dry (lb/lb-mole), Md: 30.253 30.221 30.231



# Volume Water (scf), Vwstd 2.156 2.217 2.269



# Meter Volume (dscf), Vmstd: 31.809 32.797 33.075



# Wet Fraction (v/v), Bws: 0.063 0.063 0.064



# Molec. Wt. Wet (lb/lb-mole), Ms: 29.476 29.448 29.446



# Stack Gas Sampled (acf), Vma: 49.009 50.729 51.205



# Stack Gas Velocity (fps), Vs: 29.56 30.16 30.55



# Volumetric Flowrate (dscfm), Qs: 398,761 405,229 410,078



# Volumetric Flowrate (acfm), Qa: 614,372 626,790 634,865



# Grainloading (gr/dscf), cs: 0.0161 0.0292 0.0266



# Emission Rate (lb/hour), E: 55.03 101.53 93.36



# Percent Isokinetic Sampling (%), I: 99.08 100.53 100.18



# F-Factor (dscf/mmBtu), F: 9780 9780 9780



# Heat Input (mmBtu/hour): 1736.27 1748.57 1757.46



# Emission Rate (lbs/mmBtu), E: 0.03 0.06 0.05



# Allowable Rate (lb/mmBtu): 0.24 0.24 0.24 

# Particulate Emission Results Summary

Mitchell Unit 3

Page 25 of 26 Att. 2

# ATTACHMENT 3

‐ Mitchell Report 3 Test Results

Title of

Run Description Date Start Time End Time Test Load Avg. Econ.

Gas Outlet

CO Avg. Econ.

Gas Outlet

O2 Avg. Econ.

Gas Outlet

CO2 Avg. Econ.

Gas Outlet

Temp



# Military Military MW ppm % Dry % Dry Deg F

Test 1 2/27/2008 7:40 10:00 164.01 6.1 3.41 15.2 686.2

Test 2 D Mill off 2/27/2008 11:45 13:45 100.12 5 4.96 13.75 582.3

Test 3 D Mill off 2/27/2008 14:40 16:40 79.99 4 5.31 13.41 547

Test 4 D Mill off 2/28/2008 8:00 10:00 65.07 5 5.62 13.17 517.2

Test 5 D Mill off 2/28/2008 11:30 13:30 80.01 5 5.14 13.57 557.8 Boiler Baseline Test Results Summary (In Preparation for Biomass Project)

Mitchell Unit 3

Page 26 of 26 Att. 3