To: Docket ID EPA-HQ-OAR-2013-0495Date: October 23, 2013Title: Review of Electric Utility Integrated Resource PlansIntegrated Resource Plan OverviewIntegrated resource plans (IRPs) are a tool that electric utilities use to plan operations and investments over long time horizons. Since much of the infrastructurerequired in the electric utility industry can takeseveral years to build and lasts for decades it isimportant to develop long-term plans. These plans typically cover10 to 20 years and are mandated by public utility commissions (PUCs). In order to develop these plansutilities model demand over a specified time periodandevaluate a suite of options for meeting that demand(e.g., demand side management programs, investment in transmission infrastructure or new capacity).Multiple scenarios are typically evaluated that look at variations in fuel prices, demand growth, carbon price and other factors that could impact the system.Additionally, IRPs account for existing environmental regulations and the potential for future regulations and, in many cases, provide plans for compliance.These plans are generally updated every two or three years per state law. States vary in the specificity of the content they require. Usually an overview ofsupply, demand and transmission are required, while some require a particular focus on certain areas such as demand-side initiatives. Some states provideguidelines for analysis.EPA conducted a review of current IRPs in order toinform the development of the proposed new source performance standard for emissions of carbon dioxidefor new affected fossil fuel-fired electric utilitygenerating units. An overview of the results of this review is provided below.Summary of IRPsUtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsTennesseeValleyAuthority(TVA)2011(through2030)•Peak: 1.3%annual growth(evaluated 0-2%)•EnergyRequirement:1% annualgrowth(evaluated 0-1.9%)EE and DSM/DRare significant inall cases(3,600MW5,100MW)•EE/DSM/DR: 3,600- 5,100MW by2020•Renewables: 1,500– 2,500MW by2020•NG: 900 –9,300MW in 2012to 2029•Nuclear: 1,150 –5,900MW in 2013to 2029•Energy Storage:850MW in 2020 to2024•Coal: 0 – 900MWby 2025 to 2029New coalbeginning in2025 with CCSif there isdramatic loadgrowthSignificantexisting coalcapacity idled(2,400MW4,700MW)Fuel diversityis1 of 4 metricsused toevaluate allportfolioresults.7 of 8scenariosincludedcarbon priceof at least$17/ton up to$45/ton by2030.Prices notgiven.UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsDominion2012(planthrough2027)•Peak: 1.8%annual growth•EnergyRequirement:1.9% annualgrowthFuture annualincreases in peakdemand andenergyrequirement arereduced to 1.6%and 1.7%respectively.•DSM: 206-615MWby 2027•Renewables:36MW (onshorewind and solar)•NG: 3512MW•Nuclear: 2,828MWNo new coalplannedthrough 2027.ConsideredIGCC with CCSand SCPC withCCS, not coalwithout CCS“PreferredPlan” 3.53%more costlythan cheapestplan in basecase scenario(4.10% onaverage acrossall scenarios)due to desireto maintainfuel diversityand pricestability.Notes nuclearandrenewablesincluded tomaintain fueldiversity eventhough theywere highercost thenrelying solelyon NG.Basecaseassumescarbon taxenacted by2023. Noprices given.Prices redacted.UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsDuke EnergyIndiana2011(planthrough2031)•Summer Peak:0.9% annualgrowth•Winter Peak:0.6% annualgrowth•EnergyRequirement:0.5% annualgrowthEEandDRprograms haveincreasedsignificantly.Project totalreduction in peakdemand of825MW by 2031•DR = 452.4MW•EE = 372.6MW•EE/DR: 825MW•Renewables(nameplate)oWind: 1400 MWoSolar: 160 MWoBiomass: 71 MW•NGoCT: 810MWoCC: 650MW•Nuclear (maybe2025-2030timeframe)EdwardsportIGCC beganoperations in2013.No new coalplannedthrough 2031.Notes thedifficulty ofgetting newcoalpermitted.Notes “fueldiversity”importantqualitativefactor whenevaluatingscenarios. Nodata given.Assumed arenewablerequirementof 1% startingin 2016increasing to10% of retailsales by 2025Evaluatedportfoliosunder capand-trade anda clean energyrequirement.No pricesgiven.Prices redacted.Black HillsPower2011(planthrough2030)•Peak: 1.0%annual growth•EnergyRequirement:1.0% annualgrowthProjectedreductions indemand from EEand DSM for 3years.•Year 1:737kW•Year 2:1,107kW•Year 3:1,450kW•NGoCT: 36MWoCC: 55MW in2014•Coal: 100MW in2024•Market Purchases:25– 50MWannuallyIncluded100MW ofcoal (2,627$/kW in 2010$s) in 2024but noted theuncertaintydue topotentialcarbon costs.Assumed CCSnot viable inthe IRP 20 yearhorizon.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.Carbon costsnot includedin base case.Sensitivityanalysis usedlinear risefrom 15.74$/ton (2015)to 54.06 $/ton(2030).Linear rise from4.45 $/MMBtu (Jan2011) to 11.60$/MMBtu (Dec2030).UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsAmeren MO2012(planthrough2032)Evaluate 0.5% and1.0% annualgrowth. No newgenerationneeded until2026.Scaling back DSMfrom 2011projections.•Wind coupled withCT:oWind: 800 MW(nameplate)oCT: 346 MWoTotal planningcapacity: 465MW•NGoCT: 692MWoCC: 600MW•SMR: 480MWNo new coalplanned.Specificallyidentifies SMRas hedgeagainst NGprice volatility.Evaluatedscenario withRES up to25%. No GHGpricesconsidered.Use rangeof 4-6$/MMBtu over 20year planninghorizon.DelmarvaPower &LightCompany2012(through2022)•Peak: 1.6%annual growth•EnergyRequirement:0.3% annualgrowthReduce overalldemand by603MW by 2022.No new resourcesneeded.May consider 300 MWNGCC unit.No new coalplanned.N/A, no newresourcesplannedDE subject toa RPS.No pricesgiven.No prices given.UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsCity ofPasadenaWater andPowerDepartment2012(through2030)•EnergyRequirement:0.5% annualgrowthEE goals includedin baselinescenario: energyrequirement14.8% lower in2030 with EE thanwithout EE.•DR: 5MW•Renewables(nameplate)oWind: 3MWoSolar: 19MWoBiomass: 10MWoLandfill Gas:10MWoGeothermal:10MWoFeed-in-Tariff:10MW•NGoCC: 67MWNo new coalplanned.Existing coaldeliverycontract(largest sourcein theirportfolio) willbediscontinued(108MW).Morerenewables canhelp mitigaterisks associatedwith higherNG and CO2compliancecosts. Diverseset ofrenewablespreferred.Portfolios wereevaluatedbased on thedifferencebetween thehigh and lowLCOE outcomesacross a rangeof marketdriversincluding fuelcosts.Evaluateda33% and 40%RPS.CO2Pricescenariosincluded bothstate andfederalregulatoryscenarios.Price range of15-50$/tonne.Referencecase: 15$/tonne in2013 rising to30 $/tonne in2030.Evaluated4 trends.Trends includeprices 4-12$/MMBtuReference case: 5$/MMBtu in 2013rising to 8$/MMBtu in 2030.UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsPortlandGeneralElectric2012(through2016)50MW/yr growthenergy demand•EnergyRequirement:2.0% annualgrowthAssume EEoffsets half of theload growthexpected through2016 (anadditional~25MW peryear).Contracted forminimum of 25MW of DR by2016.•DR: 25MW by 2016•Renewables:100MW (OregonRPS compliantreournces)•NGoCC: 300-500MWin 2016oCT: 100-200MWNo new coalplanned.BoardmanPlant ends theuse of coal by2020.AssumedaCO2compliancecost beginningin 2021, basedon adjustedWoodMackenzieprices.•2021: ~15$/tonrising to•2040: ~62$/tonForecast prices in2016•Reference: 4.57$/MMBtu•High: 7.15$/MMBtu•Low: 3.40$/MMBtuSan DiegoGas andElectric(SDG&E)2012(through2021)Must use CECforecasts•Peak: 1.28%annual growth•EnergyRequirement:1.31% annualgrowthSignificantreductions due toEE/DR/DSM/CHPby 2021•PeakReduction:27.49%•EnergyRequirementReduction:22.62%In need of peakingcapacity due to largeamount of renewablesbeing added to system•EE/DR/DSM/CHP:664MW•Other Generation(e.g., storage orCC): 1742MW•RenewablesoBiomass: 54MWoGeothermal:19MWoHydro: 3MWoSolar: 102MWoWind: 27MWNo coalconsidered.CA has“preferredloading order”•cost-effectiveEE and DR•renewableresources tomeet RPS•cost-effectiveCHP•otherresourcesSubject toAB32 whichincludes acarbontradingscheme. Noprices given.No prices given.UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsGeorgiaPower2013(through2032)•EnergyRequirement:1.2% annualgrowth (avg)DSM:2011 - achieved130.4 GWhenergy savings2012 - achieved215 GWh ofenergy savingsPlanned DSMprogram 2014savingsprojections:•Demand:~64MW•Energy:~290GWhSourcesrecommended afterfeasibility review(capacity mixredacted):•NGoCToCCoCC with CCS•Nuclear•Coal with CCSCurrently have1,007MW of nuclearunder construction tobe completed by 2018.Only includecoal with CCSin generationmix feasibilityreview.Working onIGCC with CCSdemonstrationplant (KemperCounty).Applied todecertify2,093MW ofcoal.Switching coalto NG at YatesUnits 6 -7 andGaston Units1-4.Switching coalto biomass atMitchell Unit3.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.Base caseassumed nocarbon price.Sensitivities of10 $/tonne(beginning2017), and 20$/tonne(beginning2020).Escalationratesredacted.Prices redacted.UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsIdaho Power2013(through2032)•Peak: 1.4%(55MW)annual growth(avg)•EnergyRequirement:1.1% annualgrowth (avg)Planned DRCapacity:•150MW by2016-2017(needed priorto completionoftransmissionline)•370MW by2024-2032•DR: 370MW by2032•Transmission Line:500kV 300 miles toconnect Boardmanto Hemingway by2018No coalplanned.Coal/CCSwere notadded in anysensitivityanalysis.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.3 Scenarios:•No cost•14.64$/ton in2018escalatingat 3%annually•35 $/tonin 2018escalatingat 9%annuallyBoard ofDirectorsguidelinesreduce avg.CO2emissionsintensity from2010 through2013 to 10-15% below2005 level of1,194lbs/MWhRPS in Oregonof 10% by2025; no RPSin Idaho.Use EIA AEO 2012forecasts (9-17$/MMBtu by 2032,nominal $s).UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsDuke EnergyCarolinas2012(through2032)•EnergyRequirement:1.5% annualgrowth (avg)•Peak: 1.7%annual growth(avg); 1.9% ifEE programsnot countedNeed capacitybeginning 2016(410MWs).NCUC requiresexamination ofDSM to meetpeak and DSM/EEmarket potentialstudies.EE can be used tomeet RPS.By 2032 theprograms willreduce demandby:•EE: 1320MW•DSM:1206MW(includes135MW ofgridmodernization)Consider nuclear aviable option,especially regionalnuclear (i.e., multipleowners).•EE: 1320MW•DSM: 1206MW(includes 135MWof gridmodernization)•NGoCT: 1750MWoCC: 2270MW•Nuclear: 2,345MW(either 1 plant fullownership ormultiple plantspartial ownership);mostly 2017-2028•RenewablesoBiomass:173MWoSolar: 1004MWoWind: 457MWNo coalconsideredwithout CCS.Noted EPArules for newcoal.ConsideredSCPC and IPCCwith CCS butdetermined nocost-effectiveCO2controlsfor fossilplants.Projects majoradvancementin CCS overnext 20 yrs.Doing R&D onNG with CCS.Nuclearincluded inportfolio inorder tomaintain fueldiversity.Developed aseparatecarbonneutral plan.Must makeCliffside Unit 6carbonneutral by2018 for airpermit.Referencecase:•$17/ton in2020•$44/ton2032High case:•$31/ton in2020•$80/ton2032Currently the fleethas lowdependence ongas. Greaterdependence in thefuture.Only reportedvariability frombaseline:•High boundary:35% higher•Low boundary:20% lowerUtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsProgressEnergyCarolinas,Inc.2012(through2027)•RetailDemand: 1.2%annualgrowth; 1.6%if DSMprograms notcountedNCUC requiresexamination ofDSM to meetpeak and DSM/EEmarket potentialstudies.EE can be used tomeet RPS.•EE&DSM: 613MW•NGoCT: 1051MWoCC: 3119MW•Nuclear: 552MW(regional partialownershipagreements)No coalplanned.ModeledNGCC costs(capital andO&M) lowerthan PC costsacross allcapacityfactors.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.Base case:•$26/ton in2017•$80/ton2031Low case:•$20/ton in2017•$45/ton2031High case:•$70/ton in2017•$170/ton2031Prices redacted.IndianapolisPower &LightCompany2011(through2031 butfocusthrough2021)•Energyrequirementbefore anyDSM areexpected togrow at 1.34%annually overthe next threeyears, and1.09% overthe next 10years.IURC Rulesrequire by 2021:EE: 337 MWDSM: 119 MW•EE: 337MW•DSM: 119MW(includes DR)•NGoCC: 600MWNo coalplanned.IdentifiedNGCC as theleast-costsupplyresource overwind, coal, andnuclear over arange of futurehorizons.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.BaseCase:•$0/ton in2031EnvironmentalLandscape:•$62/ton in2031ModerateEnvironmentalLandscape:•$31/ton in2031$5-$6/MMBtu(2011$) over thenext 10YearsReference Case:•$11.92/MMBtuin 2031High Gas Prices:•$17.37/MMBtuin 2031Low Gas Prices:•$6.92/MMBtuin 2031UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsIndianaMichiganPowerCompany2011(through2031)•EnergyRequirement:0.3% annualgrowth (avg)•Peak: 0.4%annual growth(avg)Plan to have423MW of DR/EEto meet statemandates by2031.Plan to have258MW ofcontractedinterruptibledemand.New capacity neededto replace retired coalcapacity.•DR/EE: 423MW•ContractedInterruptible:258MW•NGoCC: 562MW•RenewablesoWind: 500MWnameplateDo not view newnuclear as viable in theAEP System-East Zonefrom 2012-2031.No coalplanned in anymodeledscenario.Plan to retire985MW ofcoal.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.Project carbontax to takeeffect in the2017-2022time frame.Base Case:Nominal CO2pricing rangeof $15 to$30/tonne by2031.High Case:Nominal CO2pricing rangeof $30 to$60/tonne by2031.UseEIA’s 2010Annual EnergyOutlook forecasts.IndianaMunicipalPowerAgency2011(through2031)•EnergyRequirement:0.97% annualgrowth (High:1.15%, Low:0.63%)•Peak: 0.90%annual growth(High: 1.21%,Low: 0.70%)Target tosupply 40% ofenergy forecastwith energyefficiencymeasures,renewableresources andno/low carbonresources by2020.EE: 200MW by2031New peaking andintermediate capacityneeded to replaceretiring capacity.•EE: 200MW•NGoCT: 150MW•RenewablesoWind: 200MWnameplateExploring substitutingwind with otherrenewables.Nocoalplanned in anymodeledscenario.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.Include amodelscenario withCO2cap andtradelegislationenacted in2015.Prices notincluded.UseEIA’s AnnualEnergy Outlookforecasts.UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsNorthernIndianaPublicServiceCompany2011(through2032)•EnergyRequirement:0.6% annualgrowth•Peak: 0.6%annual growthFocus is oninterruptiblecapacity.•DSM: 50MW(interruptiblecapacity)•NGoCC: 898MW(2023 and 2029)No coalplanned.The mostpreferredresources inmodeledscenarios wereNG CC and CT.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.No price oncarbon priorto 2020.Pricesredacted.Prices redacted.VectrenCorporation:SouthernIndiana Gasand ElectricCompany(VectrenSouth)2011(through2031)•EnergyRequirement:-0.17% annualgrowth•Peak: 0.21%annual growthStatewide electricsavings goals forutilities:0.3% of averagesales in 2010 andramping up to 2%per year in2019.Incrementalenergy savings of0.5% per yearbeginning in2020.No additionalgeneration needed.In high load growthscenarios additionaldemand was met withNGCC.No newgenerationplanned.No newgenerationplanned.Base case:no carbonprice.CarbonScenario:Cap and tradebeginning2016. Price$14 / tonne in2016, growing6% annually,reaching $32 /tonne by2030.Base Case (2011$s):•$4.41/MMBtuin 2012•$7.15/MMBtuin 2031High Gas Price Case(2011 $s):•$4.41/MMBtuin 2012•$10.00/MMBtuin 2031UtilityYearFuture DemandEnergy EfficiencyNewResources toMeet DemandFutureCoaland CCSFuel DiversityChoicesCarbon PriceAssumptionsNatural Gas PriceProjectionsWabashValleyPowerAssociation,Inc.2011(through2030)•EnergyRequirement:0.7% annualgrowth(includingPassThroughs)•Peak: 0.6%annual growth(includingPassThroughs)Do notserve anyretail customersdirectly.Customers servedby theAssociation’smembers.Have EE and DRcommittees thatrecommend EEand DR programsto members.•EE: specificcapacity was notincluded but EEwas referenced asa planned source.•NGoCT: 150MW(2022)oCC: 200MW in2018 and600MW in 2027•Renewables:specific capacitywas not includedbut renewableswere referencedas a plannedsource.No coalplanned.IdentifiedNGCC as theleast-costsupplyresource overcoal fired unitsfor baseloadcapacity.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.No carbonpriceassumption inthe base casescenario.Carbonlegislationscenarioincludes acarbon pricebeginning in2018. Pricenot given.Include scenariosincreasing currentNG prices by 50%and decreasingthem by 25%. Pricenot given.GreatRiver’sEnergy2011(through2027)•EnergyRequirement:1.7% annualgrowth•Peak: 1.6%annual growthEE is a focus ofthe “preferredplan” but nospecific capacitiesare given.Addition ofrenewables needed in2024 to meet the MNRenewable EnergyStandard. No othercapacity needed.•RenewablesoWind: 600MWnameplate by2026No coalplanned.No nonrenewablecapacity isneeded in theplanningperiod.Exposure tofuel pricevolatility wasfactored intogeneration mixchoices but noquantitativemeasurementsgiven.Scenariosincluded CO2prices valuesof $9, $22 and$34 per ton.Prices wereprojected byblending brokerquotes with WoodMackenzie priceforecast. Prices notgiven.IRP Titles and LinksUtilityDocument TitleWeb Link to IRPTennessee ValleyAuthority (TVA)Integrated Resource Plan: TVA’sEnvironmental & Energy Future, March2011http://www.tva.gov/environment/reports/irp/pdf/Final_IRP_complete.pdfDominionDominion North Carolina Power's andDominion Virginia Power's Report of ItsIntegrated Resource Plan, August 2012https://www.dom.com/about/pdf/irp/irp-083112.pdfDuke Energy IndianaThe Duke Energy Indiana 2011Integrated Resource Plan, November2011http://www.duke-energy.com/pdfs/2011_Indiana_IRP_Plan.pdfBlack Hills Power2011-2030 Integrated Resource Plan ForBlack Hills Power, 2011http://psc.state.wy.us/pscdocs/dwnload/BHP%20EFP%20IRP%20&CLFP%20IRP/BHP%202011-2030%20IRP.pdfAmeren MOIntegrated Resource Plan Update, Spring2012http://www.ameren.com/sites/aue/Environment/Renewables/Documents/AM2012IRPAnnualUpdate.pdfDelmarva Power & LightCompanyDelmarva Power & Light Company 2012Integrated Resource Plan, December2012www.delmarva.com/_res/documents/2012IntegratedResourcePlan.pdfCity of Pasadena Waterand Power DepartmentIntegrated Resource Plan Update,February 2012http://cityofpasadena.net/waterandpower/IRP/Portland GeneralElectric2012 Integrated Resource Plan Update,November 2012http://www.portlandgeneral.com/our_company/energy_strategy/resource_planning/docs/irp_nov2012.pdfSan Diego Gas andElectric (SDG&E)San Diego Gas and Electric Company2012 Long-Term Procurement Plan, 2012http://www.cpuc.ca.gov/NR/rdonlyres/6072C3B5-755A-4E60-B5C7-947DE06FE8FC/0/SDGE2010LTPP1AB57BundledProcurementPlan.pdfGeorgia PowerGeorgia Power Company’s 2013Integrated Resource Planand Application for Decertification ofPlant Branch Units 3 and 4, PlantMcManus Units 1 and 2, Plant KraftUnits 1-4, Plant Yates Units 1-5, PlantBoulevard Units 2 and 3, and PlantBowen Unit 6, 2013http://www.psc.state.ga.us/factsv2/Document.aspx?documentNumber=145981Idaho Power2013 Integrated Resource Plan, June2013http://www.idahopower.com/AboutUs/PlanningForFuture/irp/default.cfmDuke Energy CarolinasDuke Energy Carolinas’ 2012 IntegratedResource Plan and 2012 REPSCompliance Plan, September 2012http://ncuc.commerce.state.nc.us/cgi-bin/webview/senddoc.pgm?dispfmt=&itype=Q&authorization=&parm2=KBAAAA05221B&parm3=000139578Progress EnergyCarolinas, Inc.Progress Energy Carolinas, Inc.’sIntegrated Resource Plan, September2012http://ncuc.commerce.state.nc.us/cgi-bin/webview/senddoc.pgm?dispfmt=&itype=Q&authorization=&parm2=BAAAAA45221B&parm3=000139578Indianapolis Power &Light CompanyIndianapolis Power & Light Company2011 Integrated Resource Planhttp://www.in.gov/iurc/files/IPL_2011_IRP_12-12-11.pdfIndiana MichiganPowerCompanyIndiana Michigan Power CompanyIntegrated Resource Planning Report,November 2011http://www.in.gov/iurc/files/IRP_2011_Indiana_Michigan_Power_Company.pdfIndiana MunicipalPower AgencyIndiana Municipal Power Agency 2011Integrated Resource Plan, November2011http://www.in.gov/iurc/files/IRP_2011_Indiana_Municipal_Power_Agency.pdfNorthern Indiana PublicService CompanyNIPSCO 2011 Integrated Resource Plan,November 2011http://www.in.gov/iurc/files/NIPSCO_IRP_Revised-Redacted_1-24-12(1).pdfVectren Corporation:Southern Indiana Gasand Electric Company(Vectren South)Vectren 2011 Integrated Resource Plan,November 2011http://www.in.gov/iurc/files/IRP_2011_Vectren.pdfWabash Valley PowerAssociation, Inc.Wabash Valley Power Association, Inc.2011 Integrated Resource Plan,November 2011http://www.in.gov/iurc/files/IRP_2011_Wabash_Valley_Power_Association.pdfGreat River’s EnergyGreat River EnergyResource Plan2013-2027, November 2012http://www.greatriverenergy.com/makingelectricity/resourceplan/pdoc295631.pdfAbbreviationsAEO – Annual Energy OutlookAEP – American Electric PowerCC – Combined cycleCCS – Carbon capture and sequestrationCHP – Combined heat and powerCT – Combustion turbineDR – Demand responseDSM – Demand side managementEE – Energy efficiencyEIA – Energy Information AdministrationEPA – Environmental Protection AgencyIGCC – Integrated gasification combined cycleIRP – Integrated resource planIURC – Indiana Utility Regulatory CommissionkV – KilovoltskW – KilowattkWh – Kilowatt hoursLCOE – Levelized cost of electricityMMBtu – Million British thermal unitsMW – MegawattsMWh – Megawatt hoursNCUC – North Carolina Utility CommissionNG – Natural gasRPS – Renewable portfolio standardsSMR – Small modular reactor