NEEDS v.4.10 User GuideThe National Electric Energy Data System (NEEDS) is the database of existing and planned-committedunits which are modeled in the EPA Base Case v.4.10. Unitsthat are currently operational in the electric industry are termed as “existing” units. Units that are notcurrently operatingbut are firmly anticipated to be operational inthe future, and have either broken ground (initiated construction) or secured financing are termed “planned-committed”.NEEDS is maintained in spreadsheet format. Below is a guide to the fields found in NEEDS.Field NameColumnDefinitionKey to Recurring Column ValuesPlant NameA The plant's name.———UniqueID_FinalBThe unique identifier assigned to a boiler or generator within a plant. It consistsof the Plant ID (or ORIS Code), an indication of whether the unit is a boiler ("B"),generator ("G"), or committed unit ("C"), and the Unit ID. For example, for theUnique ID "113_B_1", "113" is the Plant ID,"B" indicates that this unit is a boiler,and "1" indicates that the ID of the boiler is 1.———ORIS Plant CodeCA unique identifier assigned to each power plant in NEEDS. While the ORIScode is unique for each plant, all generating units within a plant will typically havethe same ORIS code. For committed units (i.e., those not currently operating,but firmly anticipated to be operational in the future), the entry in this field mightbe a dummy ORIS code assigned as aplaceholder unique ID to the committedplant. (Note: ORIS originally referred to the Office of Regulatory InformationSystems in the Department of Energy (DOE) Energy Information Administration(EIA) which was responsible for assigning unique identification codes to utilitypower plants.)———B BoilerG GeneratorBoiler/Generator/CommittedUnitDAn indicator of whether the unit is a boiler, generator, or committed unit.Committed units are those with a futureexpected in-service date (see “On LineYear”)C Committed UnitUnit IDE The identifier assigned to each unit/boiler in a given plant. ———CAMD Database UnitIDFUnit-level identifier assigned by EPA's Clean Air Markets Division (CAMD)business system. Unlike other identification codes (e.g., ORIS codes), which aresubject to change, once assigned to a unit, the CAMD Database Unit ID doesnot change. Used primarily for internal tracking purposes at EPA.———Field NameColumnDefinitionKey to Recurring Column ValuesPlantTypeGThe type of electric generating unit, usuallydefined by the "prime mover" and/orfuels burned. "Prime mover" refers to the machine (e.g., engine, turbine, waterwheel) that drives an electric generatoror the device that converts energy toelectricity directly (e.g., photovoltaic solar and fuel cell(s)).BiomassCoal SteamCombined CycleCombustion TurbineFossil WasteFuel CellGeothermalHydroIGCCLandfill GasMunicipal Solid WasteNon-Fossil WasteNuclearO/G SteamPumped StorageSolarTiresWindCombustion Turbine/ICEngineHClarifies the engine type for units with“Combustion Turbine” plant type. AnInternal Combustion (IC) Engine is a reciprocating engine which uses pistons toextract energy from a fluid to performwork. A Combustion Turbine is a standalone turbine combusting fuel to drive a generator (a combined cycle less theHeat Recovery Steam Generator (HRSG)).Combustion TurbineIC EngineRegion NameIThe region, used in the Integrated Planning Model (IPM), where the generatingunit is located. IPM regions are defined to enable IPM to accurately representthe operation and structure of U.S. andCanada electric power system. IPMregions are generally subdivisions of the10 North American Electric ReliabilityCouncil (NERC) regions and aggregations ofthe electricity grid's contiguouscontrol areas. IPM also includes Alaska, Hawaii, Puerto Rico, and the U.S.Virgin Islands.See Appendix I and Appendix IIState NameJ———State CodeK———CountyL———County CodeM———FIPS5NThese four fields identify the geographiclocation of the unit. The State Code isthe FIPS State Code, and the County Code is the FIPS County Code. New unitshave blanks in these columns, while committed units have zeros. Federalinformation processing standards (FIPS) codes are a standardized set ofnumeric or alphabetic codes issued by the National Institute of Standards andTechnology (NIST) to ensure uniform identification of geographic entities throughall federal government agencies.———Capacity (MW)OThe net summer dependable capacity (in megawatts) of the unit available forgeneration for sale to the grid. Net summer dependable capacity is themaximum capacity that the unit can sustain over the summer peak demandperiod reduced by the capacity requiredfor station services or auxiliaryequipment.———Field NameColumnDefinitionKey to Recurring Column ValuesHeat Rate (Btu)PThe net heat input (in Btu) required to generate 1 kilowatt hour of electricity. It isa measure of a generating unit’s efficiency.———On Line YearQ The year in which the unit is commissioned. ———Retirement YearRThe year in which the unit is to be decommissioned. ("9999" indicates that theunit has not been retired.)———Cell:boilers that combine 2-3 standard burners into a compact,vertical assembly installed on the furnace wall; multiple cells utilizedwithin a furnace.Cyclone:A special type of burner for coals with low fusion pointashes. Combustion occurs within the horizontal burner generatinghigh temps which turn the ash into molten slag. The term "wetbottom" furnace often accompanies the cyclone burner.FBC:“fluidized bed combustion” where solid fuels are suspendedon upward-blowing jets of air, resulting in a turbulent mixing of gasand solids and a tumbling action which provides especially effectivechemical reactions and heat transfer during the combustionprocess.Stoker/SPR:stoker boilers where lump coal is fed continuouslyonto a moving grate or chain which moves the coal into thecombustion zone in which air is drawn through the grate and ignitiontakes place. The carbon gradually burns off, leaving ash whichdrops off at the end into a receptacle, from which it is removed fordisposal.Tangential(also referred to as "corner firing"): burners locatedalong furnace corners in multiplesof 4. Burner angle is off-setworking in conjunction with the opposing corner burner to create avertical, circular swirling combustion zone within the furnace.Turbo(wall fired burner): Burner design for pet coke and lowvolatile bituminous coals (Riley trademark name: "Turbo Furnace").Hour glass shaped furnace with rectangular shaped burners angleddownwards.Vertical: standard furnace (assume wall fired)FiringSThis field, which applies only to boilers, indicates the burner type andconfiguration (e.g., cell, cyclone, FBC (fluidized bed combustion), stoker/SPR,tangential, or vertical). A blank appears in instances where the firingcharacteristics of a boiler are unknown or the unit is a not a boiler.Wall: standard burner / furnace designused today. Circular burnerslocated on the front and rear furnace walls at multiple elevations.BottomTThis field, which applies only to boilers, indicates whether the bottom of thecombustion chamber is "wet" (i.e., ash is removed from the furnace in a moltenstate) or "dry" (i.e., the boiler has a furnace bottom temperature below the ashmelting point and the bottom ash is removed as a solid). A blank appears ininstances where the bottom characteristics of a boiler were not known or the unitwas not a boiler.DryWetCogen?U This field indicates whether a unitis a cogenerator. A unit is considered aY YesField NameColumnDefinitionKey to Recurring Column Valuescogenerator if it produces electricity andanother form of useful thermal energy(such as heat or steam), used for industrial, commercial, heating, or coolingpurposes.N NoModeled FuelsV Fuels that are reported to be combusted by the unit.BiomassBituminousDistillate Fuel OilFossil WasteGeothermalHydroLandfill GasLigniteMSWNatural GasNon-Fossil WasteNuclear FuelPetroleum CokePumped StorageResidual Fuel OilSolarSubbituminousTiresWaste CoalWindWet/DryScrubberWThis field indicates if a unit has an SO2scrubber, and, if so, whether it is a wet ordry scrubber. Also known as flue gas desulfurization (FGD) systems, SO2scrubbers use chemical and physical absorption to remove SO2from the fluegas. Wet scrubbers use a liquid sorbent to remove SO2and the flue gas leavingthe absorber is moisture saturated. With dry scrubbers the flue gas leaving theabsorber is not saturated. For circulating fluidized bed units (as shown in the"Firing" field), this field indicateswhether reagent injection is used for SO2control. Reagent injection involves adding finely crushed limestone to thefluidized bed. During combustion, the limestone is reduced to lime, the sulfur inthe fuel is oxidized to form SO2, and, in the presence of excess oxygen, the SO2reacts with the lime particles to form calcium sulfate, which can be removed withthe bottom ash or collected with the fly ash by a downstream particulate matter(PM) control device.Dry ScrubberWet ScrubberReagent InjectionScrubber_Online_YearX The first year of operation of an existing or committed SO2scrubber ———Scrubber EfficiencyY The removal efficiency of the SO2scrubber. ———AA Advanced Overfire AirBF Biased Firing (alternate burners)BOOS Burners-Out-Of-ServiceCM Combustion Modification/Fuel ReburningNOx Comb ControlZ This field indicates the NOXcombustion controls employed by a generating unit.Combustion controls reduce NOXemissions during the combustion processgenerally by regulating flame characteristics such as temperature and fuel-airmixing.CO Combustion OptimizationField NameColumnDefinitionKey to Recurring Column ValuesDLNB Dry Low NOx BurnersFR Flue Gas RecirculationFU Fuel ReburningH2O Water InjectionLA Low Excess AirLN Low NOx BurnerLNB Low NOx Burner Technology (Dry Bottom only)LNBO Low NOx Burner Technology w/ Overfire AirLNC1 Low NOx Burner Technology w/ Closed-coupled OFALNC2 Low NOx Burner Technology w/ Separated OFALNC3Low NOx Burner Technology w/ Closed-coupled/Separated OFALNCB Low NOx Cell BurnerLNF Low NOx FurnaceMR Methane ReburnN2 NitrogenNDI Nitrogen Diluent InjectionNGR Natural Gas ReburnNH3 Ammonia InjectionOFA Overfire Airother OtherROFA Rotating Overfire AirSC SlaggingSOFA Stationary Overfire AirSTC Staged CombustionSTM Steam InjectionWIR Underfire AirSCR Selective Catalytic ReductionNOx Post-CombControlAAThis column indicates the post-combustion NOXemission controls at agenerating unit. There are two NOXpost-combustion control options: SelectiveCatalytic Reduction (SCR) or Selective Non-Catalytic Reduction (SNCR). Postcombustion controls operate downstream of the combustion process and removeNOx emissions from the flue gas.SNCR Selective Noncatalytic ReductionSCR_Online_YearAB The first year of operation of an existing or committed SCR ———SNCR_Online_YearAC The first year of operation of an existing or committed SNCR ———B BaghouseC CycloneESP Electrostatic PreciptatorESPHHot side electrostatic precipitator with flue gasconditioningESPCCold side electrostatic precipitator with flue gasconditioningPM ControlAD This field indicates the presence of particulate matter (PM) controlsWS Wet ScrubberField NameColumnDefinitionKey to Recurring Column ValuesMercury_ControlsAE Dedicated Mercury emission controls in existenceat a generating unit ACI (Activated Carbon Injection)ACI_Online_YearAF The first year of operation of an existing or committed ACI ———Mercury_ControlsEfficiencyAG The removal efficiency of the mercury control device. ———SO2Permit RateAHThe SO2emission rate (in lb/mmBtu) limit that applies to the unit due to federal,state or local emission regulations.———Uncontrolled NOXBaseRate(or “Mode 1 NOXRate”)AIThe 4 NOXrates in NEEDS allow modeling of any conceivable scenario involvingNOXcontrols. The Mode 1 rate applies to units not covered by a NOXcontrolpolicy. Specifically, this is the NOXrate with post-combustion controls shut off.For units without post-combustioncontrols, it’s their uncontrolled NOXrate.———Controlled NOXBase Rate(or “Mode 2 NOXRate”)AJThe 4 NOXrates in NEEDS allow modeling of any conceivable scenario involvingNOXcontrols. The Mode 2 rate applies to units covered by a mercury emissionlimit. A unit with post-combustion controls operates them, but a unit withoutpost-combustion controls operates as usual. (Note: In the case of mercurylimits, Mode 2 applies since it implies operation of an SCR or SNCR. Thisequipment, in combination with SO2and particulate controls, provides reductionand capture of mercury as a co-benefit.)———Uncontrolled NOXPolicyRate(or “Mode 3 NOXRate”)AKThe 4 NOXrates in NEEDS allow modeling of any conceivable scenario involvingNOXcontrols. The Mode 3 rate applies to units affected by a seasonal (typicallysummer) NOXpolicy. The Mode 3 rate is the unit’s NOXrate in the off-season(winter). For units with post-combustion controls, this is the NOXrate with postcombustion controls shut off. For unitswithout post-combustion controls, it’s theNOXrate with state-of-the-art combustion controls operating. (Exception: In theSIP Call region current combustion controls are assumed to be retained.)———Controlled NOXPolicy Rate(or “Mode 4 NOXRate”)ALThe 4 NOXrates in NEEDS allow modeling of any conceivable scenario involvingNOXcontrols. The Mode 4 NOXrate applies to units covered by an annual NOXpolicy. For units with SCR, it’s the NOXrate with the SCR operating. For unitswith SNCR, it’s the NOXrate with SNCR operating plus state-of-the-artcombustion controls operating if required to attain rate limits. For units withoutpost-combustion controls, it’s the NOXrate with state-of-the-art combustioncontrols operating. (Exception: In the SIP Call region current combustion controlsare assumed to be retained.)———Field NameColumnDefinitionKey to Recurring Column ValuesHg EMF InputsAMThis field shows the combination of SO2scrubbers, NOXpost-combustioncontrols, and particulate matter controls thatalready exist at a unit. The entriesin this column are compiled from the "NOx Post-CombControl,""Wet/DryScrubber" and "Particulate MatterType" fields. Together with the entryin the "Firing" and "Modeled Fuels" fields,the entries in this field are used for theassignment of the Emission Modification Factors (EMFs) for mercury as shownin the six subsequent "Controlled Hg EMF"and "Uncontrolled Hg EMF" fields.The EMFs enable the model to capture mercury emission reductions that are afunction of the rank of coal burned (bituminous, subbituminous and lignite), thespecific burner type, and the configuration of SO2, NOX, and particulate mattercontrol devices. Consolidating the controls that impact mercury reductions intothis field helps to insure that the correct EMFs are assigned to each unit. Notethat EMFs are metrics that quantify the extent of mercury emission reductionachieved by these non-mercury controls. The impact of mercury-specific controls(e.g., ACI) is not taken into account in the EMFs.———Controlled Hg EMF for BITANMercury Emission Modification Factor (EMF) when the unit combusts bituminouscoal and existing NOx post combustion controls (SCR or SNCR) are operating.“Mercury EMF” is defined as the percentage of fuel mercury left after accountingfor the mercury removal obtained by the SO2, NOx, and particulate controlsshown in the “EMF_Controls” field.———Controlled Hg EMF for SUBAOMercury Emission Modification Factor (EMF) when the unit combustssubbituminous coal and existing NOx postcombustion controls (SCR or SNCR)are operating.———Controlled Hg EMF for LIGAPMercury Emission Modification Factor (EMF) when the unit combusts lignite coaland existing NOx post combustion controls (SCR or SNCR) are operating.———Uncontrolled Hg EMF forBITAQMercury Emission Modification Factor (EMF) when the unit combusts bituminouscoal and existing NOx post combustion controls (SCR or SNCR) are notoperating.———Uncontrolled Hg EMF forSUBARMercury Emission Modification Factor (EMF) when the unit combustssubbituminous coal and existing NOx postcombustion controls (SCR or SNCR)are not operating.———Uncontrolled Hg EMF forLIGASMercury Emission Modification Factor (EMF) when the unit combusts lignite\ coaland existing NOx post combustion controls (SCR or SNCR) are not operating.———Field NameColumnDefinitionKey to Recurring Column ValuesDispatchable ScrubberATOne-time option that allows certain generating units in the model to install ascrubber retrofit at zero capital cost.It applies to generating units known to haveexisting scrubbers that may not be operating because the original regulatorycause for their installation is no longer present. The model will use this retrofit ifthe control is economical to operate, but it will not use the retrofit if the control isnot economical. This “dispatchable” construct allows modeling behavior in areastransitioning from a more stringent to less stringent regulatory regime (forexample, a state affected by CAIR but potentially not affected by the proposedTransport Rule), where some operatorsmay have economic incentive to bypassor reduce operation of a previously installed emission control, while otheroperators still need to operate the control inorder to comply with settlements,state rules, or other past policies regardless of the status of the CAIR program.Yes = unit has the dispatchable scrubber option<blank> = unit does not have the dispatchable scrubber optionDispatchable SCRAUOne-time option that allows certain generating units in the model to install anSCR retrofit at zero capital cost. It applies to generating units known to haveexisting SCR that may not be operating because the original regulatory cause fortheir installation is no longer present. The model will use this retrofit if the controlis economical to operate, but it will not use the retrofit if the control is noteconomical. This “dispatchable” construct allows modeling behavior in areastransitioning from a more stringent to less stringent regulatory regime (forexample, a state affected by CAIR but potentially not affected by the proposedTransport Rule), where some operatorsmay have economic incentive to bypassor reduce operation of a previously installed emission control, while otheroperators still need to operate the control inorder to comply with settlements,state rules, or other past policies regardless of the status of the CAIR program.Yes = unit has the dispatchable SCR option<blank> = unit does not have the dispatchable SCR optionDispatchable ACIAVOne-time option that allows certain generating units in the model to install an ACIretrofit at zero capital cost. It applies to generating units known to have existingACI installations that may not be operating because the original regulatory causefor their installation is no longer present. The model will use this retrofit if thecontrol is economical to operate, but it will not use the retrofit if the control is noteconomical. This “dispatchable” construct allows modeling behavior in areastransitioning from a more stringent toless stringent regulatory regime, wheresome operators may have economic incentive to bypass or reduce operation of apreviously installed emission control,while other operators still need to operatethe control in order to comply with settlements, state rules, or other past policiesregardless of the status of the original regulatory program.Yes = unit has the dispatchable ACI option<blank> = unit does not have the dispatchable ACI optionAppendix I. IPM Model Regions Map

# Appendix II. Mapping of NERC Regions and NEMS Re gions with EPA Base Case v.4.10 Model Regions

NERC

Region NEMS

Region Model Region Model Region Description

TRE ERCOT ERCT Texas Regional Entity

FRCC FL FRCC Florida Reliability Coordinating Council

MAPP MRO Midwest Regional Planning Organization MRO

MAIN WUMS Wisconsin-Upper Michigan

NE NENG New England Power Pool

DSNY Downstate New York

LILC Long Island Company

NYC New York City NPCC NY

UPNY Upstate New York

RFCO Reliability First Corporation - MISO

MECS Michigan Electric Coordination System ECAR

RFCP Reliability First Corporation - PJM

MACE Legacy Mid-Atlantic Area Council - East

MACS Legacy Mid-Atlantic Area Council - South MAAC

MACW Legacy Mid-Atlantic Area Council - West RFC

MAIN COMD Commonwealth Edison

MAIN GWAY Gateway

ECAR TVAK Tennessee Valley Authority - MISO-KY

SOU Southern Company

TVA Tennessee Valley Authority

ENTG Entergy

VACA Virginia-Carolinas SERC

STV

VAPW Dominion Virginia Power

SPPN Southwest Power Pool - North SPP SPP

SPPS Southwest Power Pool - South

AZNM Western Electricity Coordinating Council - Arizona, New Mexico WECC-AZ-

NM-SNV RA SNV Western Electricity Coordinat ing Council - Southern Nevada

CA-N Western Electricity Coordinat ing Council - California North WECC-

California ISO CNV

CA-S Western Electricity Coordinat ing Council - California South

PNW Western Electricity Coordinati ng Council - Pacific Northwest WECC-NWPP NWP

NWPE Western Electricity Coordinating Council - Northwest Power Pool East

WECC-RMPA RA RMPA Western Electricity Coordinating Council - Rocky Mountain Power Area

CNAB Alberta

CNBC British Columbia

CNMB Manitoba

CNNB New Brunswick

CNNF Newfoundland

CNNL Labrador

CNNS Nova Scotia

CNON Ontario

CNPE Prince Edward Island

CNPQ Quebec Canada

CNSK Saskatchewan

ALSK Alaska

HAWI Hawaii

VIUS U.S. Virgin Islands Other

PRCW Puerto Rico