Content and Layout of the Annual Electric Generator Report (EIA-860) Data Files for 2009 (v1.0)

Note: The actual file names include a suffix with the applicable data year. For more information and historic data go to www.eia.doe.gov/cneaf/electricity/page/eia860.html.

Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

UTILITY_ID

EIA-assigned identification number for the company that is responsible for the day-to-day operations of the generator

xxxxxxxxxxxxxx

UTILITY_NAME Legal name of the company that is responsible for the day-to-day operations of the generator x xxxxxxxx PLANT_CODE EIA-assigned plant code xxxxxxxxxxxxxPLANT_NAME Plant name xxxxxxxxx STATE Plant state xxxxxxxxx COUNTY Plant county xxxx xxxx GENERATOR_ID Generator identification number xxxxxxxxxINTERCONNECTION_MONTH Month that the interconnection occurred xINTERCONNECTION_YEAR Year that the interconnection occurred xINTERCONNECTION_REQUEST_MONTH Month that the first request for interconnection was filed with the grid operator x

INTERCONNECTION_REQUEST_YEAR Year that the first request for interconnection was filed with the grid operator x

INTERCONNECTION_CITY Nearest city or town where the interconnection equipment is located x

INTERCONNECTION_STATE State of nearest city or town where the interconnection equipment is located x

GRID_VOLTAGE

Grid voltage in kV at the point of interconnection between the generator and the grid

x

TRANSMISSION_OWNERNAME

Name of the owner of the transmission or distribution facilities to which the generator is interconnected

x

INTERCONNECTION_COST Total cost incurred (in thousand dollars) to accomplish the physical interconnection x

TRANSMISSION_LINE

Indicates whether the transmission or distribution lines, transformers, protective devices, substation or switching stations, and/or other equipment, as appropriate, are included in the interconnection cost

Yes / No x

TRANSFORMER

Indicates whether the transmission or distribution lines, transformers, protective devices, substation or switching stations, and/or other equipment, as appropriate, are included in the interconnection cost

Yes / No x

PROTECTIVE_DEVICES

Indicates whether the transmission or distribution lines, transformers, protective devices, substation or switching stations, and/or other equipment, as appropriate, are included in the interconnection cost

Yes / No x

SUBSTATION

Indicates whether the transmission or distribution lines, transformers, protective devices, substation or switching stations, and/or other equipment, as appropriate, are included in the interconnection cost

Yes / No x

OTHER_EQUIPMENT

Indicates whether the transmission or distribution lines, transformers, protective devices, substation or switching stations, and/or other equipment, as appropriate, are included in the interconnection cost

Yes / No x

GRID_ENHANCEMENT_COST

Amount incurred for any other grid enhancements or reinforcements that were needed to accommodate power deliveries from the new generator

x

GRID_COST_REPAID

Indicates whether the grid enhancement costs, or some portion of them, will be repaid to the company at some point by the owner of the grid, or by the party with whom the company contracted for the interconnection

Yes / No x

TRANSMISSION_RIGHTS_SECURED

Indicates whether the specific transmission use rights were secured as a result of the interconnection costs incurred

Yes / No x
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

PRIME_MOVER

EIA assigned code for the prime mover (i.e. the engine, turbine, water wheel, or similar machine that drives an electric generator)

See Table 1 in tab 'Reference Tables I' xxx xxx

STATUS The operating status of the generator See Tables 3a, 3b and 3c in tab 'Reference Tables I' xxxx

OWNERSHIP_ID EIA-assigned owner's identification number xOWNER_NAME Name of owner xOWNER_STATE State for owner xPERCENT_OWNED Percent of generator ownership xMULTIPLE_FUELS

Indicates whether the combustion system that will power each proposed generator expects to have the regulatory permits necessary to fuel switch

Yes / No x x x x x x

COFIRE_FUELS

Indicates whether the combustion system that will power each proposed generator expects to have the regulatory permits necessary to cofire fuels Yes / No xxx

COFIRE_ENERGY_SOURCE_1 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference Tables I' xxxCOFIRE_ENERGY_SOURCE_2 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference Tables I' xxxCOFIRE_ENERGY_SOURCE_3 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference Tables I' xxxCOFIRE_ENERGY_SOURCE_4 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference Tables I' xxxCOFIRE_ENERGY_SOURCE_5 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference Tables I' xxxCOFIRE_ENERGY_SOURCE_6 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference Tables I' xxxCOFIRE_OIL_GAS Indicates whether the proposed unit expects to be able to co-fire fuel oil with natural gas Yes / No xxxCOFIRE_100_OIL Indicates whether the proposed unit is expected to be able to run on 100 percent oil Yes / No xxxMAX_OIL_HEAT

The maximum oil heat input (% of MMBtus) expected for proposed unit when co-firing with natural gas

xxx

MAX_OIL_OUTPUT

The maximum output (net MW) expected for proposed unit, when making the maximum use of oil and co-firing natural gas

xxx

FUEL_SWITCH Indicates whether unit will be able to switch fuels Yes / No xxxFUEL_SWITCH_OIL_GAS Indicates whether the unit can co-fire fuel oil with natural gas Yes / No xxxNET_SUMMER_CAPACITY_NG

The maximum output (summer net MW) that the unit is expected to achieve, taking into account all applicable legal, regulatory, and technical limits, when running on natural gas

xxx

NET_SUMMER_CAPACITY_OIL

The maximum output (summer net MW) that the unit is expected to achieve, taking into account all applicable legal, regulatory, and technical limits, when running on oil

xxx

TIME_TO_SWITCH

The amount of time it is expected to take to switch the generator from using 100 percent natural gas to 100 percent oil

0 to 6 hours over 6 to 24 hours over 24 to 72 hoursover 72 hours.Unknown or uncertain

xxx

REGULATORY_LIMITS

Indicates whether there are factors that limit the operation of the generator when running on 100 percent oil

Yes / No xxx

STORAGE_LIMITS

Indicates that limited on site fuel storage is a factor that limits the operation of the generator when running on 100 percent oil

Yes / No xxx

AIRPERMIT_LIMITS

Indicates that air permit limits is a factor that limits the operation of the generator when running on 100 percent oil

Yes / No xxx

OTHER_LIMITS

Indicates that there are other factors that limit the operation of the generator when running on 100 percent oil

Yes / No xxx
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

FUEL_SWITCH_ENERGY_SOURCE_1

The codes representing the type of fuel that will be able to be used as a sole source of fuel for this unit

See Table 2 in tab 'Reference Tables I' xxx

FUEL_SWITCH_ENERGY_SOURCE_2

The codes representing the type of fuel that will be able to be used as a sole source of fuel for this unit

See Table 2 in tab 'Reference Tables I' xxx

FUEL_SWITCH_ENERGY_SOURCE_3

The codes representing the type of fuel that will be able to be used as a sole source of fuel for this unit

See Table 2 in tab 'Reference Tables I' xxx

FUEL_SWITCH_ENERGY_SOURCE_4

The codes representing the type of fuel that will be able to be used as a sole source of fuel for this unit

See Table 2 in tab 'Reference Tables I' xxx

FUEL_SWITCH_ENERGY_SOURCE_5

The codes representing the type of fuel that will be able to be used as a sole source of fuel for this unit

See Table 2 in tab 'Reference Tables I' xxx

FUEL_SWITCH_ENERGY_SOURCE_6

The codes representing the type of fuel that will be able to be used as a sole source of fuel for this unit

See Table 2 in tab 'Reference Tables I' xxx

NAMEPLATE The highest value on the generator nameplate in megawatts rounded to the nearest tenth xxx

SUMMER_CAPABILITY The net summer capacity xxxWINTER_CAPABILITY The net winter capacity xxxSUMMER_ESTIMATED_CAPABILITY EIA estimated summer capacity (in MWh) xWINTER_ESTIMATED_CAPABILITY EIA estimated winter capacity (in MWh) xUNIT_CODE

Multi-generator code that identifies all generators that are operated with other generators as a single unit

OPERATING_MONTH Month the generator began commercial operation x xOPERATING_YEAR Year the generator began commercial operation x xRETIREMENT_MONTH Month the generator retired xRETIREMENT_YEAR Year the generator retired xEFFECTIVE_MONTH The original effective month on which the generator was scheduled to start operation xEFFECTIVE_YEAR The original effective year on which the generator was scheduled to start operation xCURRENT_MONTH

The most recently updated effective month on which the generator is scheduled to start operation

x

CURRENT_YEAR

The most recently updated effective year on which the generator is scheduled to start operation

x

ENERGY_SOURCE_1 The code representing the most predominant type of energy that fuels the generator See Table 2 in tab 'Reference Tables I' xxx

ENERGY_SOURCE_2

The code representing the second most predominant type of energy that fuels the generator

See Table 2 in tab 'Reference Tables I' xxx

ENERGY_SOURCE_3

The code representing the third, fourth, fifth and sixth most predominant type of energy that fuels the generator

See Table 2 in tab 'Reference Tables I' xxx

ENERGY_SOURCE_4

The code representing the third, fourth, fifth and sixth most predominant type of energy that fuels the generator

See Table 2 in tab 'Reference 

Tables I' xxx

ENERGY_SOURCE_5

The code representing the third, fourth, fifth and sixth most predominant type of energy that fuels the generator

See Table 2 in tab 'Reference Tables I' xxx

ENERGY_SOURCE_6

The code representing the third, fourth, fifth and sixth most predominant type of energy that fuels the generator

See Table 2 in tab 'Reference Tables I' xxx

OPERATING_SWITCH Indicates whether the proposed unit will be able to switch fuels while operating Yes / No xxxDELIVER_POWER_TRANSGRID Indicate whether the generator can deliver power to the transmission grid x x

SYNCHRONIZED_GRID Indicates whether standby generators (SB status) can be synchronized to the grid Yes / No x xOWNERSHIP Identifies the ownership for each generator

S=Single ownershipJ= Joint ownershipW=Wholly owned by an other entity

xxx

TURBINES Number of wind turbines xxx
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

COGENERATOR Indicates whether the generator is associated with a combined heat and power system Yes / No x x xSECTOR_NAME

Plant-level sector name, designated by the primary purpose, regulatory status and plantlevel combined heat and power status

Commercial; Electric Utility; Industrial; Non-Combined Heat and Power Independent Power Producer (IPP); Combined Heat and Power (IPP CHP)

x x

SECTOR_NUMBER

Plant-level sector number, designated by the primary purpose, regulatory status and plantlevel combined heat and power status

1 = Electric Utility2 = Independent Power Producer, Non-Combined Heat and Power3 = Independent Power Producer, Combined Heat and Power4 = Commercial, Non-Combined Heat and Power5 = Commercial, Combined Heat and Power6 = Industrial, Non-Combined Heat and Power7 = Industrial, Combined Heat and Power

x x

TOPPING_BOTTOMING

If the generator is associated with a combined heat and power system, indicates whether the generator is part of a topping cycle or a bottoming cycle

T = ToppingB = Bottoming x x

DUCT_BURNERS

Indicates whether the unit has duct-burners for supplementary firing of the turbine exhaust gas

x x

PLANNED_MODIFICATIONS

Indicates whether there are any planned capacity uprates/derates, repowering, other modifications, or generator retirements scheduled for the next 5 years

Yes / No x x

PLANNED_UPRATES_NET_SUMMER_CAP

Increase in summer capacity expected to be realized from the modification to the equipment

x x

PLANNED_UPRATES_NET_WINTER_CAP

Increase in winter capacity expected to be realized from the uprate modification to the equipment

x x

PLANNED_UPRATES_MONTH

Planned effective month that the generator is scheduled to enter operation after the uprate modification

x x

PLANNED_UPRATES_YEAR

Planned effective year that the generator is scheduled to enter operation after the uprate modification

x x

PLANNED_DERATES_NET_SUMMER_CAP

Decrease in summer capacity expected to be realized from the derate modification to the equipment

x x

PLANNED_DERATES_NET_WINTER_CAP

Decrease in winter capacity expected to be realized from the derate modification to the equipment

x x

PLANNED_DERATES_MONTH

Planned effective month that the generator is scheduled to enter operation after the derate modification

x x

PLANNED_DERATES_YEAR

Planned effective year that the generator is scheduled to enter operation after the derate modification

x x

PLANNED_NEW_PRIMEMOVER New prime mover for the planned repowered generator See Table 1 in tab 'Reference Tables I' x x

PLANNED_ENERGY_SOURCE_1 New energy source code for the planned repowered generator See Table 2 in tab 'Reference Tables I' x x

PLANNED_REPOWER_MONTH

Planned effective month that the generator is scheduled to enter operation after the repowering is complete

x x

PLANNED_REPOWER_YEAR

Planned effective year that the generator is scheduled to enter operation after the repowering is complete

x x

OTHER_MODS Indicates whether there are there other modifications planned for the generator Yes / No x xOTHER_MOD_MONTH

Planned effective month that the generator is scheduled to enter commercial operation after any other planned modification is complete

x x
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

OTHER_MOD_YEAR

Planned effective year that the generator is scheduled to enter commercial operation after any other planned modofication is complete

x x

PLANNED_RETIREMENT_MONTH Planned effective month of the scheduled retirement of the generator xPLANNED_RETIREMENT_YEAR Planned effective year of the scheduled retirement of the generator xSFG_SYSTEM Indicates whether the generator is part of a solid fuel gasification system Yes / No x x xPULVERIZED_COAL Indicates that the generator uses pulverized coal technology xxxFLUIDIZED_BED Indicates that the generator uses fluidized bed technology xxxSUBCRITICAL Indicates that the generator uses subcritical technology xxxSUPERCRITICAL Indicates that the generator uses supercritical technology xxxULTRASUPERCRITICAL Indicates that the generator uses ultra- supercritical technology xxxCARBONCAPTURE Indicates that the generator uses carbon capture technology xxxSTARTUP_SOURCE_1

The code representing the first, second, third or fourth start-up and flame stabilization energy source used by the combustion unit(s) associated with this generator

See Table 2 in tab 'Reference Tables I' xxx

STARTUP_SOURCE_2

The code representing the first, second, third or fourth start-up and flame stabilization energy source used by the combustion unit(s) associated with this generator

See Table 2 in tab 'Reference Tables I' xxx

STARTUP_SOURCE_3

The code representing the first, second, third or fourth start-up and flame stabilization energy source used by the combustion unit(s) associated with this generator

See Table 2 in tab 'Reference Tables I' xxx

STARTUP_SOURCE_4

The code representing the first, second, third or fourth start-up and flame stabilization energy source used by the combustion unit(s) associated with this generator

See Table 2 in tab 'Reference Tables I' xxx

UTILITY_ATTENTION_LINE Mail attention name of the operator/owner xUTILITY_PO_BOX_LINE Post office box address of the operator/owner xUTILITY_STREET_ADDRESS Street address of the operator/owner xUTILITY_CITY

Name of the city in which operator/owner is located x

UTILITY_STATE State of the operator/owner xUTILITY_ZIP5 Zip code of the operator/owner xUTILITY_ZIP4 Zip code extension of the operator/owner xCONTACT_FIRSTNAME First name of primary contact xCONTACT_NAME Last name of primary contact xCONTACT_TITLE Title of primary contact xCONTACT_FIRSTNAME2 First name of primary contact's supervisor xCONTACT_NAME2 Last name of primary contact's supervisor xCONTACT_TITLE2 Title of primary contact's supervisor x

STREET_ADDRESS Street address of the power plant xCITY Name of the city in which the plant is located xZIP5 Zip code of the plant xNAME_OF_WATER_SOURCE

Name of the principal source from which cooling water for thermal-electric plants and water for generating power for hydroelectric plants is directly obtained

x 

NERC NERC region in which the plant is located See Table 4 in tab 'Reference Tables I' x

PRIMARY_PURPOSE

North American Industry Classification System (NAICS) code that best describes the primary purpose of the reporting plant

x

OWNERTRANSDIST

Name of the owner of the transmission or distribution system to which the plant is interconnected

x
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

OWNERTRANSID

EIA-assigned code for owner of transmission/distribution system to which the plant is interconnected

x

OWNERSTATE

State location for owner of transmission/distribution system to which the plant is interconnected

x

REGULATORY_STATUS Indicates whether the plant is regulated or non- regulated xFERC_COGEN Indicates of whether the plant has FERC qualifying facility cogenerator status Yes / No xFERC_COGEN_DOCKET The docket number relating to the FERC qualifying facility cogenerator status xFERC_SMALL_POWER Indicates of whether the plant has FERC qualifying facility small power producer status Yes / No xFERC_SMALL_POWER_DOCKET The docket number relating to the FERC qualifying facility small power producer status xFERC_EXEMPT_WHOLESALE

Indicates of whether the plant has FERC qualifying facility exempt wholesale generator status

Yes / No x

FERC_EXEMPT_WHOLESALE_DOCKET

The docket number relating to the FERC qualifying facility exempt wholesale generator status

x

BOILER_ID Boiler identification number xxxxGENERATOR_ASSOCIATION

Indicates whether boiler associations with generator during the year were actual or theoretical

A = ActualT = Theoretical x

COOLING_ID Cooling system identification number x FGD_ID Flue gas desulfurization identification number x FGP_ID Flue gas particulate collector identification number x FLUE_ID Flue identification number STACK_ID Stack identification number BOILER_STATUS Boiler status See Table 3d in tab 'Reference Tables I' 

PLANT_SUM_CAP The plany summer capacity associated with the operating generators at the plant 

TYPE_OF_BOILER

Indicates the standards under which the boiler is operating as described in the U.S. Environmental Protection Agency regulation under 40 CFR

See Table 10 in tab 'Reference Tables II' 

NSR Indicates whether the boiler is subject to New Source Review requirements Yes / No 

NSR_DATE_MM Month of issued New Source Review permit NSR_DATE_YR Year of issued New Source Review permit NSR_PERMIT New Source Review permit number REGULATION_PARTICULATE

Most stringent type of statute or regulation code under which the boiler is operating for particulate matter

FD = FederalST=StateLO=LocalNA=Not Applicable

REGULATION_SULFUR

Most stringent type of statute or regulation code under which the boiler is operating for sulfur dioxide

FD = FederalST=StateLO=LocalNA=Not Applicable

REGULATION_NITROGEN

Most stringent type of statute or regulation code under which the boiler is operating for nitrogen oxides

FD = FederalST=StateLO=LocalNA=Not Applicable

STANDARD_PARTICULATE_RATE Numeric value for the unit of measurement specified for particulate matter 

STANDARD_SULFUR_RATE Numeric value for the unit of measurement specified for sulfur dioxide 

STANDARD_NITROGEN_RATE Numeric value for the unit of measurement specified for nitrogen oxide 

UNIT_PARTICULATE Unit of measurement specified for particulate matter See Table 11a in tab 'Reference Tables III' 

UNIT_SULFUR Unit of measurement specified for sulfur Dioxide See Table 11b in tab 'Reference Tables III' 

UNIT_NITROGEN Unit of measurement specified for Nitrogen Oxides See Table 11c in tab 'Reference Tables III' 

PERIOD_PARTICULATE Period of time over which measurements for particulate matter were averaged See Table 5 in tab 'Reference Tables I' 
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

PERIOD_SULFUR Period of time over which measurements for sulfur dioxide were averaged See Table 5 in tab 'Reference Tables I' 

PERIOD_NITROGEN Period of time over which measurements for nitrogen oxides were averaged See Table 5 in tab 'Reference Tables I' 

COMP_YEAR_PARTICULATE

Year boiler was or is expected to be in compliance with federal, state and/or local regulations for particulate matter

COMP_YEAR_SULFUR

Year boiler was or is expected to be in compliance with federal, state and/or local regulations for sulfur dioxide

COMP_YEAR_NITROGEN

Year boiler was or is expected to be in compliance with federal, state and/or local regulations for nitrogen oxide

STRATEGY_PARTICULATE1 If boiler is not in compliance with particulate matter regulations, strategy for compliance See Table 12a in tab 'Reference Tables III' 

STRATEGY_PARTICULATE2 If boiler is not in compliance with particulate matter regulations, strategy for compliance See Table 12a in tab 'Reference Tables III' 

STRATEGY_PARTICULATE3 If boiler is not in compliance with particulate matter regulations, strategy for compliance See Table 12a in tab 'Reference Tables III' 

STRATEGY_SULFUR1 If boiler is not in compliance with sulfur dioxide regulations, strategy for compliance See Table 12b in tab 'Reference Tables III' 

STRATEGY_SULFUR2 If boiler is not in compliance with sulfur dioxide regulations, strategy for compliance See Table 12b in tab 'Reference Tables III' 

STRATEGY_SULFUR3 If boiler is not in compliance with sulfur dioxide regulations, strategy for compliance See Table 12b in tab 'Reference Tables III' 

STRATEGY_NITROGEN1 If boiler is not in compliance with nitrogen oxides regulations, strategy for compliance See Table 12c in tab 'Reference Tables III' 

STRATEGY_NITROGEN2 If boiler is not in compliance with nitrogen oxides regulations, strategy for compliance See Table 12c in tab 'Reference Tables III' 

STRATEGY_NITROGEN3 If boiler is not in compliance with nitrogen oxides regulations, strategy for compliance See Table 12c in tab 'Reference Tables III' 

STRATEGY_FOR_CAAA1

Existing strategies to meet the sulfur dioxide requirements of Title IV of the Clean Air Act Amendment of 1990 

See Table 12b in tab 'Reference Tables III' 

STRATEGY_FOR_CAAA2

Existing strategies to meet the sulfur dioxide requirements of Title IV of the Clean Air Act Amendment of 1990 

See Table 12b in tab 'Reference Tables III' 

STRATEGY_FOR_CAAA3

Existing strategies to meet the sulfur dioxide requirements of Title IV of the Clean Air Act Amendment of 1990 

See Table 12b in tab 'Reference Tables III' 

PLANNED_FOR_CAAA1

Planned strategies to meet the sulfur dioxide requirements of Title IV of the Clean Air Act Amendment of 1990 

See Table 12b in tab 'Reference Tables III' 

PLANNED_FOR_CAAA2

Planned strategies to meet the sulfur dioxide requirements of Title IV of the Clean Air Act Amendment of 1990 

See Table 12b in tab 'Reference Tables III' 

PLANNED_FOR_CAAA3

Planned strategies to meet the sulfur dioxide requirements of Title IV of the Clean Air Act Amendment of 1990 

See Table 12b in tab 'Reference Tables III' 

BOILER_MANUFACTURER Boiler manufacturer code See Table 13 in tab 'Reference Tables IV' 

INSERVICE_MM

Actual or projected month of commercial operation of the Boiler/Cooling System/FGD unit/FGP unit/Stack (or Flue)

INSERVICE_YR

Actual or projected year of commercial operation of the Boiler/Cooling System/FGD unit/FGP unit/Stack (or Flue)

RETIREMENT_MM Actual or projected month of retirement RETIREMENT_YR Actual or projected month of retirement MAX_STEAM_FLOW Maximum continuous steam flow at 100 percent load (thousand pounds per hour) 

COAL_FIRE_STEAM_FLOW Design firing rate at maximum continuous steam flow for coal (nearest 0.1 ton per hour) 

PET_FIRE_STEAM_FLOW

Design firing rate at maximum continuous steam flow for pet coke (nearest 0.1 barrels per hour)

GAS_FIRE_STEAM_FLOW

Design firing rate at maximum continuous steam flow for gas (nearest 0.1 cubic feet per hour)

OTHER_FIRE_STEAM_FLOW Design firing rate at maximum continuous steam flow for waste heat 
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

WASTE_HEAT_INPUT

Design waste-heat input rate at maximum continuous steam flow where a waste-heat boiler is a boiler that receives all or a substantial portion of its energy input from the noncumbustible exhaust gases of a separate fuel-burning process (million Btu per hour)

PRIMARY_FUEL1 Primary fuels used in order of predominance See Table 2 in tab 'Reference Tables I' 

PRIMARY_FUEL2 Primary fuels used in order of predominance See Table 2 in tab 'Reference Tables I' 

PRIMARY_FUEL3 Primary fuels used in order of predominance See Table 2 in tab 'Reference Tables I' 

PRIMARY_FUEL4 Primary fuels used in order of predominance See Table 2 in tab 'Reference Tables I' 

PRIMARY_FUEL5 Primary fuels used in order of predominance See Table 2 in tab 'Reference Tables I' 

PRIMARY_FUEL6 Primary fuels used in order of predominance See Table 2 in tab 'Reference Tables I' 

PRIMARY_FUEL7 Primary fuels used in order of predominance See Table 2 in tab 'Reference Tables I' 

PRIMARY_FUEL8 Primary fuels used in order of predominance See Table 2 in tab 'Reference Tables I' 

FIRE_PRIMARY_FUEL1 Indicates the first, second and third type of firing used with primary fuels See Table 6c in tab 'Reference Tables II' 

FIRE_PRIMARY_FUEL2 Indicates the first, second and third type of firing used with primary fuels See Table 6c in tab 'Reference Tables II' 

FIRE_PRIMARY_FUEL3 Indicates the first, second and third type of firing used with primary fuels See Table 6c in tab 'Reference Tables II' 

EFFICIENCY_100_PCT_LOAD Boiler efficiency when burning at 100 percent load (nearest 0.1 percent) 

EFFICIENCY_50_PCT_LOAD Boiler efficiency when burning at 50 percent load (nearest 0.1 percent) 

AIR_FLOW_100_PCT_LOAD

Total air flow including excess air at 100 percent load, reported at standard temperature and pressure (i.e. 68 F and one atmosphere pressure)

WET_DRY_BOTTOM

Wet or Dry Bottom where Wet Bottom is defined as slag tanks that are installed at furnace throat to contain and remove molten ash from the furnace, and Dry Bottom is defined as having no slag tanks at furnace throat area, throat area is clear, and bottom ash drops through throat to bottom ash water hoppers.

W=WetD=Dry 

FLY_ASH_REINJECTION Indicates whether the boiler has fly ash re- injection Yes / No 

NOX_CONTROL_STATUS Nitrogen oxide control status code See Table 6b in tab 'Reference Tables II' 

LOW_NOX_PROCESS1 Low nitrogen oxide control process See Table 6a in tab 'Reference Tables II' 

LOW_NOX_PROCESS2 Low nitrogen oxide control process See Table 6a in tab 'Reference Tables II' 

LOW_NOX_PROCESS3 Low nitrogen oxide control process See Table 6a in tab 'Reference Tables II' 

LOW_NOX_MANUFACTURER Code indicating the low nitrogen oxide control burner manufacturer See Table 13 in tab 'Reference Tables IV' 

MERCURY_EMISSION_CONTROL Indicates whether the boiler has mercury emission controls Yes / No 

MERCURY_EMISSION_ACJ Indicates whether the boiler has an activated carbon injection system MERCURY_EMISSION_BH Indicates whether the boiler has a baghouse MERCURY_EMISSION_DS Indicates whether the boiler has a dry scrubber MERCURY_EMISSION_EP Indicates whether the boiler has an electrostatic precipitator MERCURY_EMISSION_FGD Indicates whether the boiler has a flue gas desulfurization system MERCURY_EMISSION_LI Indicates whether the boiler has a lime injection system MERCURY_EMISSION_WS Indicates whether the boiler has a wet scrubber 
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

MERCURY_EMISSION_OT Indicates whether the boiler has other mercury emission controls 

COOLING_STATUS Cooling system status See Table 3d in tab 'Reference Tables I' 

COOLING_TYPE1 Cooling system code for the first, second, third and/or fourth cooling system See Table 7a in tab 'Reference Tables II' 

COOLING_TYPE2 Cooling system code for the first, second, third and/or fourth cooling system See Table 7a in tab 'Reference Tables II' 

COOLING_TYPE3 Cooling system code for the first, second, third and/or fourth cooling system See Table 7a in tab 'Reference Tables II' 

COOLING_TYPE4 Cooling system code for the first, second, third and/or fourth cooling system See Table 7a in tab 'Reference Tables II' 

COOLING_WATER_SOURCE Name of river, lake, or water source that provides cooling water 

INTAKE_RATE_AT_100_PCT Design cooling water flow rate at 100 percent load at in-take (cubic feet per second) 

CHLORINE_INSERVICE_MM

Actual or projected in-service month for chlorine discharge control structures and equipment

CHLORINE_INSERVICE_YR Actual or projected in-service year for chlorine discharge control structures and equipment 

POND_INSERVICE_MM Cooling ponds actual or projected in-service month 

POND_INSERVICE_YR Cooling ponds actual or projected in-service year 

POND_SURFACE_AREA Total surface area of cooling pond (in acres) POND_VOLUME Total volume of water in cooling pond (in acre- feet) 

TOWER_INSERVICE_MM Cooling towers actual or projected in-service month 

TOWER_INSERVICE_YR Cooling towers actual or projected in-service year 

TOWER_TYPE1 Code for first and/or second cooling tower See Table 7b in tab 'Reference Tables II' 

TOWER_TYPE2 Code for first and/or second cooling tower See Table 7b in tab 'Reference Tables II' 

TOWER_WATER_RATE_PCT Maximum design rate of water flow at 100 percent load 

POWER_REQUIREMENT_KWH Maximum power requirement at 100 percent load 

COST_TOTAL

Actual installed cost for the existing system or the anticipated cost to bring the total system into commercial operation (thousands dollars)

COST_PONDS

Actual installed cost for the existing cooling ponds or the anticipated cost to bring the cooling ponds into commercial operation (thousands dollars)

COST_TOWERS

Actual installed cost for the existing cooling towers or the anticipated cost to bring the cooling towers into commercial operation (thousands dollars)

COST_CHLORINE_EQUIPMENT

Actual installed cost for the existing chlorine discharge control system or the anticipated 

cost to bring the chlorine discharge control system into commercial operation (thousands dollars)

INTAKE_DISTANCE_SHORE Maximum distance from shore to intake (in feet) 

OUTLET_DISTANCE_SHORE Maximum distance from shore to outlet (in feet) 

INTAKE_DISTANCE_SURFACE Average distance below water surface to intake (in feet) 

OUTLET_DISTANCE_SURFACE Average distance below water surface to outlet (in feet) 

FGD_STATUS Flue gas desulfurization unit status See Table 3d in tab 'Reference Tables I' 

FGD_TYPE1 FGD unit code for the first, second, third and/or fourth flue gas desulfurization unit See Table 9a in tab 'Reference Tables II' 

FGD_TYPE2 FGD unit code for the first, second, third and/or fourth flue gas desulfurization unit See Table 9a in tab 'Reference Tables II' 
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

FGD_TYPE3 FGD unit code for the first, second, third and/or fourth flue gas desulfurization unit See Table 9a in tab 'Reference Tables II' 

FGD_TYPE4 FGD unit code for the first, second, third and/or fourth flue gas desulfurization unit See Table 9a in tab 'Reference Tables II' 

SORBENT_TYPE1 Sorbent code for the first, second, third and/or fourth sorbent used See Table 9b in tab 'Reference Tables II' 

SORBENT_TYPE2 Sorbent code for the first, second, third and/or fourth sorbent used See Table 9b in tab 'Reference Tables II' 

SORBENT_TYPE3 Sorbent code for the first, second, third and/or fourth sorbent used See Table 9b in tab 'Reference Tables II' 

SORBENT_TYPE4 Sorbent code for the first, second, third and/or fourth sorbent used See Table 9b in tab 'Reference Tables II' 

BYPRODUCT_RECOVERY Indicate whether salable byproduct is recovered by the unit Yes / No 

FGD_MANUFACTURER Flue gas desulfurization unit manufacturer code See Table 13 in tab 'Reference Tables IV' 

POND_LANDFILL_REQ Annual pond and land fill requirements SLUDGE_POND_LINED Indicates whether the sludge pond is lined Yes / No / NA FLUE_GAS_BYPASS_FGD Indicates whether flue gas can bypass flue gas desulfurization unit Yes / No 

SPEC_FOR_COAL_ASH Design fuel specifications for coal for ash (nearest 0.1 percent by weight) 

SPEC_FOR_COAL_SULFUR Design fuel specifications for coal for sulfur (nearest 0.1 percent by weight) 

FGD_TRAINS_TOTAL Total number of flue gas desulfurization unit scrubber trains 

FGD_TRAINS_100_PCT Total number of flue gas desulfurization unit scrubber trains operated at 100 percent load 

REMOVAL_EFF_SULFUR

Removal efficiency as the percent by weight of gases removed from the flue gas (nearest 0.1 percent by weight)

SULFUR_EMISION_RATE Sulfur dioxide emission rate (pounds per hour) FLUE_GAS_EXIT_RATE Flue gas exit rate (actual cubic feet per minute) 

FLUE_GAS_EXIT_TEMP Flue gas exit temperature (degrees fahrenheit) FLUE_GAS_ENTERING Flue gas entering flue gas desulfurization unit (percent of total) 

COST_STRUCTURE

Actual installed costs for the existing systems or the anticipated costs of structures and equipment to bring a planned system into commercial operation

COST_DISPOSAL

Actual installed costs for the existing sludge transport and disposal systems or the anticipated costs of sludge transport and disposal systems to bring a planned system into commercial operation

COST_OTHER

Actual installed costs for the of other items pertaining to the installation of the existing systems or the anticipated costs of other items pertaining to the installation of the unit to bring a planned system into commercial operation

COST_TOTAL

Total actual installed costs for the existing systems or the anticipated costs to bring a planned system into commercial operation

FGP_STATUS Flue gas particulate collector status See Table 3d in tab 'Reference Tables I' COLLECTOR_TYPE1 Flue gas particulate collector code for the first, second and/or third collector See Table 8 in tab 'Reference Tables II' COLLECTOR_TYPE2 Flue gas particulate collector code for the first, second and/or third collector See Table 8 in tab 'Reference Tables II' COLLECTOR_TYPE3 Flue gas particulate collector code for the first, second and/or third collector See Table 8 in tab 'Reference Tables II' INSTALLED_COST

Actual installed cost for the existing system or the anticipated cost to bring a planned system into commercial operation (thousands dollars)

FUEL_SPEC_ASH_COAL

Design fuel specifications for ash for coal; beginning of range for values (nearest 0.1 percent by weight)
Field Name Description Notes

Utility

Plant

Generator / 

Exist

Generator / 

Prop

Generator / 

Ret_IP

Owner

MultiFuel / 

Exist

MultiFuel / 

Prop

MultiFuel / 

Ret_IP

Interconnect

EnviroAssoc / 

Boiler_Gen

EnviroAssoc / 

Boiler_Cool

EnviroAssoc / 

Boiler_FGD

EnviroAssoc / 

BoilerFGP

FUEL_SPEC_ASH_COAL2

Design fuel specifications for ash for coal; end of range for values (nearest 0.1 percent by weight)

FUEL_SPEC_ASH_PET

Design fuel specifications for ash for petroleum; beginning of range for values (nearest 0.1 percent by weight)

FUEL_SPEC_ASH_PET2

Design fuel specifications for ash for petroleum; end of range for values (nearest 0.1 percent by weight)

FUEL_SPEC_SULFUR_COAL

Design Fuel Specifications for sulfur for Coal; Beginning of range for values (nearest 0.1 percent by weight)

FUEL_SPEC_SULFUR_COAL2

Design fuel specifications for sulfur for coal; end of range for values (nearest 0.1 percent by weight)

FUEL_SPEC_SULFUR_PET

Design fuel specifications for sulfur for petroleum; beginning of range for values (nearest 0.1 percent by weight)

FUEL_SPEC_SULFUR_PET2

Design fuel specifications for sulfur for petroleum; end of range for values (nearest 0.1 percent by weight)

COLLECTION_EFFICIENCY Collection efficiency at 100 percent generator load (nearest 0.1 percent) EMISSION_RATE Particulate emission rate at 100 percent generator load (pounds per hour) GAS_EXIT_RATE

Particulate collector gas exit rate at 100 percent generator load (actual cubic feet per minute)

GAS_EXIT_TEMP

Particulate collector gas exit temperature at 100 percent generator load (degrees fahrenheit)

STACK_FLUE_STATUS Equipment status code for the stack or flue See Table 3d in tab 'Reference Tables I' 

FLUE_HEIGHT Flue height at top from ground level (feet) AREA_AT_TOP Cross-sectional area at top of flue (nearest square foot) EXIT_RATE_100_PCT Design flue gas exit rate at 100 percent load (actual cubic feet per minute) EXIT_RATE_50_PCT Design flue gas exit rate at 50 percent load (actual cubic feet per minute) EXIT_TEMP_100_PCT Design flue gas exit temperature at 100 percent load (degrees fahrenheit) EXIT_TEMP_50_PCT Design flue gas exit temperature at 50 percent load (degrees fahrenheit) EXIT_VELOCITY_100_PCT Design flue gas exit velocity at 100 percent load (feet per second) EXIT_VELOCITY_50_PCT Design flue gas exit velocity at 50 percent load (feet per second) EXIT_TEMP_SUMMER

Average flue gas exit temperatures based on the arithmetic mean of measurements during operating hours of June, July, and August

EXIT_TEMP_WINTER

Average flue gas exit temperatures based on the arithmetic mean of measurements during operating hours of January, February, and December

EXIT_TEMP_SOURCE Source of seasonal flue gas temperatures M = Measured E = Estimated LATITUDE_DEGREES The degrees latitude of the plant Available upon requestLATITUDE_MINUTES The minutes latitude of the plant Available upon requestLATITUDE_SECONDS The seconds latitude of the plant Available upon requestLONGITUDE_DEGREES The degrees longitude of the plant Available upon requestLONGITUDE_MINUTES The minutes longitude of the plant Available upon requestLONGITUDE_SECONDS The seconds longitude of the plant Available upon request
Table 1: Prime Mover Codes Table 2: Energy Source Codes Table 3a: Existing Generator Status Codes

Code Prime Mover Description Code Energy Source Description Corresponding Prime Mover(s) Code Existing Status Description

BA Energy Storage, Battery AB Agriculture Crop Byproducts/Straw/Energy Crops OP

Operating - in service (commercial electricity. Includes peaking units thor seasonal) basis.

CP Energy Storage, Concentrated Solar Power ANT Anthracite Coal ST, CT SB Standby/Backup - available for serv

generation during the year) for this 

FW Energy Storage, Flywheel BFG Blast-Furnace Gas OA

Out of service - was not used for soeither returned to service on Decemthe next calendar year. 

ES Energy Storage, Other BIT Bituminous Coal OS Out of service – was not used for so

NOT expected to be returned to ser

ST Steam Turbine, including nuclear, geothermal and solar steam (does not include combined cycle) BLQ Black Liquor

GT Combustion (Gas) Turbine (includes jet engine design) CUR Water, Current HA, HK Table 3b: Proposed Generator Status Codes

IC Internal Combustion Engine (diesel, piston, reciprocating) DFO Disillate Fuel Oil (all Diesel, and No. 1, No. 2, and No. 4 Fuel Oils)

CA Combined Cycle Steam Part EP Electric Power BA, CP, ES, FW Code Proposed Status DescriptionCT Combined Cycle Combustion Turbine Part (type of coal or solid must be reported as energy source for integrated coal gasification). GEO Geothermal TS Construction complete, but not yet i

power testing of nuclear units)

CS Combined Cycle Single Shaft (combustion turbine and steam turbine share a single generator) JF Jet Fuel P Planned for installation but regulato

construction

CC Combined Cycle Total Unit (use only for plants/generators that are in planning stage, for which specific generator details cannot be provided) KER Kerosene L Regulatory approvals pending. Not 

could be underway

HA Hydrokinetic, Axial Flow Turbine LFG Landfill Gas T Regulatory approvals received. No

could be underway

HB Hydrokinetic, Wave Buoy LIG Lignite U Under construction, less than or eq

construction time to date of operatio

HK Hydrokinetic, Other MSW Municipal Solid Waste V Under construction, more than 50 p

time to date of operation)

HY Hydroelectric Turbine (includes turbines associated with delivery of water by pipeline) NA Not Available at this Time

PS Hydraulic Turbine, Reversible (pumped storage) NG Natural Gas Table 3c: Other Generator Status Codes

BT Turbines Used in a Binary Cycle (including those used for geothermal applications) NUC Nuclear (Uranium, Plutonium, Thorium)

PV Photovoltaic OBG Other Biomass Gases (Digester Gas, Methane, and other Biomass Gases) Code Other Status Description

WT Wind Turbine OBL Other Biomass Liquids (Fish Oil, Liquid Acetonitrite Waste, Medical Waste, Tall Oil, ethanol, Waste Alcohol, and other Biomass Liquids not specified) RE Retired - no longer in service and n

CE Compressed Air Energy Storage OBS Other Biomass Solids (Animal Manure and Waste, Solid Byproducts, and Other Solid Biomass not specified) IP Planned new generator canceled, in

resource plan

FC Fuel Cell OG Other Gas (Coke-Oven, Coal Processes, Butane, Refinery, Other Process) OT Other

OT Other OTH Other (Batteries, Chemicals. Hydrogen, Pitch, Sulfur, Miscellaneous technologies)

PC Petroleum Coke Table 3c: Boiler and Environmental Equipmen

PG Propane

PUR Purchased Steam Code Boiler and Environmental Equipm

RC Refined Coal ST, CT CN Cancelled (previously reported as “

RFO Residual Fuel Oil (Include No. 5, and No. 6 Fuel Oil, and Bunker C Fuel Oil) CO New unit under construction

SG Synthetic Gas, other than coal-derived OP Operating (in commercial service or 

SGC Coal-Derived Synthetic Gas OS Out of service (365 days or longer)

SLW Sludge waste PL Planned (expected to go into comm

SUB Subbituminous Coal RE Retired (no longer in service and no

SUN Solar (Photovoltaic, Thermal) SB Standby (or inactive reserve); i.e., n

service

TDF Tires SC Cold Standby (Reserve); deactivate

reactivate)

TID Water, Tides HA, HK TS Operating under test conditions (no

WAT Water, Conventional or Pumped Storage

WC Waste/Other Coal (Culm, Gob, Coke, and Breeze)

WDL Woos Waste Liquids (Red Liquor, Sludge Wood, Spent Sulfite Liquor, and other Wood Related Liquids not specified)

WDS Wood/Wood Waste Solids (Paper Pellets, Railroad Ties, Utility Poles, Wood Chips, and Other Wood Solids)

WH Waste Heat

WND Wind

WO Oil-Other, and Waste Oil (Butane (liquid), Crude Oil, Liquid Byproducts, Propane (liquid), Oil Waste, Re-Refined Motor Oil, Sludge Oil, Tar Oil)

WV Water, Waves HB, HK
Table 4: NERC Region Type and Description Codes Table 5: Time Period Codes

Code NERC Region Description NERC Type Code Time Period Description

ASCC Alaska Systems Coordinating Council N NV Never to exceedFRCC Florida Reliability Coordinating Council N FM 5 minutesHICC Hawaii Coordinating Council N SM 6 minutesMRO Midwest Reliability Organization N FT 15 minutesMROC MRO Canada S OH 1 hourMROU MRO United States S WO 2 hoursNPCC Northeast Power Coordinating Council N TH 3 hoursNPCCI NPCC ISO New England S EH 8 hoursNPCCM NPCC Maritime S DA 24 hoursNPCCN NPCC New York S WA 1 weekNPCCO NPCC Ontario S MO 30 DaysNPCCQ NPCC Quebec S ND 90 DaysRFC Reliability First Corporation N YR AnnualSERC Southeastern Electric Reliability Council N PS Periodic Stack TestingSERCE SERC Entergy S DT Defined By TestingSERCG SERC Gateway S NS Not SpecifiedSERCS SERC Southern S OT OtherSERCT SERC TVA SSERCV SERC VACAR SSPP Southwest Power Pool NSPPN Southwest Power Pool Northern SSPPS Southwest Power Pool Southern STRE Texas Regional Entity NWECC Western Systems Coordinating Council NWECCA Western Systems Coordinating Council - AZNMSNV SWECCC Western Systems Coordinating Council - California SWECCN Western Systems Coordinating Council - NWPP SWECCR Western Systems Coordinating Council - RMPA S
Table 6a: Low NOX Control Process Codes Table 7a: Cooling System Type Codes Table 8: FGP Type Codes

Code Low NOX Control Process Description Code Cooling System Type Description Code FGP Type Description

AA Advanced Overfire Air DC Dry (air) cooling system BS Baghouse, shake and deflate

BF Biased Firing HRC Hybrid: recirculating cooling pond(s) or canal(s) with dry cooling BP Baghouse, pulse

CF Fluidized Bed Combuster HRF Hybrid: recirculating with forced draft cooling tower(s) with dry cooling BR Baghouse, reverse airFR Flue Gas Recirculation HRI Hybrid: recirculating with induced draft cooling tower(s) with dry cooling EC Electrostatic precipitator, cold side

FU Fuel Reburning OC Once through with cooling pond(s) or canal(s) EH Electrostatic precipitator, hot side, 

H20 Water Injection OF Once through, fresh water EK Electrostatic precipitator, cold side

LA Low Excess Air OS Once through, saline water EW Electrostatic precipitator, hot side, 

LN Low NOX Burner RC Recirculating with cooling pond(s) or canal(s) MC Multiple Cyclone

NA Not Applicable RF Recirculating with forced draft cooling tower(s) SC Single Cyclone

NH3 Ammonia Injection RI Recirculating with induced draft cooling tower(s) WS Wet Scrubber

OT Other RN Recirculating with natural draft cooling tower(s) OT Other

OV Overfire Air OT Other

SC SlaggingSN Selective Noncatalytic Reduction Table 7b: Cooling Tower Type CodesSR Selective Catalytic Reduction

STM Steam Injection Code Cooling Tower Type Description

NC No change in historic operation of unit anticipated MD Mechanical draft, dry process

RP Repower Unit MW Mechanical draft, wet process

UE Decrease utilization - rely on energy conservation and/or improved efficiency ND Natural draft, dry process

ND Not determined at this time NW Natural draft, wet processNC No change in historic operation of unit anticipated WD Combination wet and dry process

RP Repower Unit OT Other

UF Decrease utilization - rely on energy conservation and/or improved efficiency

Table 6b: NOX Control Status Codes

Code NOX Control Status Description

CN Cancelled

CO New Unit Under Construction

NA Not Applicable

NC No plans to controlOP OperatingOS Out of Service

OZ Operating during the Ozone Season

PL Planned

RE Retired

SB Standby

SC Cold Standby

TS Operating under Test Condtions

Table 11c: NOX Control Firing Type Codes

Code NOX Control Firing Type Description

AF Arch Firing

CB Cell Burner

CF Concentric FiringCY Cyclone Firing 

DB Duct Burner 

FB Fluidized Bed Firing

FF Front Firing 

OF Opposed Firing 

RF Rear Firing

SF Side Firing 

SS Spreader Stoker 

TF Tangential Firing 

VF Vertical Firing 

OT Other

Page 14
Table 9a: FGD Type Codes Table 10: Boiler Standard Codes

Code FGD Type Description Type of Boiler Standard Type

BR Jet Bubbling Reactor D Standards of Performance for fossil-fuel fired steam boilers for which construction began after August 17, 1971.

CD Circulating Dry Scrubber Da Standards of Performance for fossil-fuel fired steam boilers for which construction began after September 18, 1978.

DP Dry Powder Injection type Db Standards of Performance for fossil-fuel fired steam boilers for which construction began after June 19, 1984.

MA Mechanically aided type Dc Standards of Performance for small industrial-commercial-institutional steam generating units.

PA Packed type N Not covered under New Source Performance Standards.

SD Spray dryer type

SP Spray typeTR Tray typeVE Venture type

OT Other

Table 9b: Sorbent Type Codes

Code Sorbent Type Description

AF Alkaline fly ash

CC Calcium carbide slurry

CEF CE filtrate

CSH Caustic Sodium hydroxide

DB Dibasic acid

DL Dolomitic limestone

LA Lime and alkaline fly ash

LF Limestone and alkaline fly ash

LI Lime

LS Limestone

MO Magnesium oxide

SA Soda ashSB Sodium bicarbonate

SC Sodium carbonate

SF Sodium formate

SL Soda liquid

SS Sodium sulfite

TW Treated wastewaterWT Water

OT Other

Page 15
Table 11a: Particulate Matter Measurement Type Codes Table 12a: Particulate Matter Compliance Strategy Codes Table 12c: Nitrogen Oxides Complia

Code Particulate Matter Measurement Type Description Code Particulate Matter Compliance Strategy Description Code Nitrogen Oxides Compl

OP Percent of opacity BO Burner out of service BO Burner out of service

PB Pounds of PM per million Btu in fuel (preferred measurement) FR Flue gas recirculation FR Flue gas recirculation

PC Grains of PM per std. cubic foot stack gas LA Low excess air LA Low excess air

PG Pounds of PM per thousand pounds stack gas LN Low nitrogen oxide burner LN Low nitrogen oxide burner

PH Pounds of PM emitted per hour MS Currently meeting standard MS Currently meeting standar

UG Micrograms of PM per cubic metere NC No plans to control NC No plans to control

OT Other OV Overfire air OV Overfire air

SE Seeking revision of governing regulation SE Seeking revision of govern

Table 11b: Sulfur Dioxide Measurement Type Codes OT Other OT Other

AA Advanced Overfire Air

Code Sulfur Dioxide Measurement Type Description Table 12b: Sulfur Dioxide Compliance Strategy Codes BF Biased Firing (alternative 

DC Ambient air quality concentration of SO2 CF Fluidized Bed CombustoDH Pounds of SO2 emitted per hour Code Sulfur Dioxide Compliance Strategy Description FR Flue Gas Recirculation 

DL Annual SO2 emission level less than previous year BO Burner out of service FU Fuel Reburning

DM Parts per million of SO2 in stack gas FR Flue gas recirculation H2O Water Injection

DP Pounds of SO2 per million BTU in fuel (preferred measurement) LA Low excess air LA Low Excess Air

SB Pounds of Sulfur per million BTU in fuel LN Low nitrogen oxide burner LN Low NOx Burner

SR Percent Sulfur removal efficiency MS Currently meeting standard NH3 Ammonia Injection

SU Percent Sulfur content by fuel NC No plans to control NC No change in historic ope

OT Other OV Overfire air ND Not determined at this tim

SE Seeking revision of governing regulation OV Overfire Air

Table 11c: Nitrogen Oxides Measurement Type Codes OT Other RP Repower Unit

CF Fluidized Bed Combustor SC Slagging

Code Nitrogen Oxides Measurement Type Description CU Control unit under Phase I extension plan SN Selective Noncatalytic Re

NH Pounds of NO emitted per hour IF Install flue gas desulfurization unit (other than Phase I extension plan) SR Selective Catalytic Reduc

NL Annual NO emission level less than previous year NC No change in historic operation of unit anticipated STM Steam Injection

NM Parts per million of NO in stack gas ND Not determined at this time UE Decrease utilization - rely 

efficiency

NP Pounds of Nitrogen Oxide per million BTU in fuel (preferred measurement) RP Repower Unit NA Not ApplicableOT Other SS Switch to lower sulfur fuel OT Other

NO Ambient air quality concentration of nitrogen oxides (parts per million) SU Designate Phase II unit(s) as substitution unit(s)

TU Transfer unit under Phase I extension plan

UC Decrease utilization - designate Phase II unit(s) as compensating unit(s)

UE Decrease utilization - rely on energy conservation and/or improved efficiencyUS Decrease utilization - designate sulfur-free generators to compensateUP Decrease utilization - purchase power

WA Allocated allowances and purchase allowances

OT Other
Table 13: Environmental Equipment Manufacturer Codes

Code Manufacturer Description BOILER NOX FGD

AA Advanced Air Technologies N N Y

AB Advanced Burner Technologies N Y N

ABB ABB Environmental Systems N Y Y

AC Advanced Combustion Technology N Y N

AEE AEE Von Roll N Y N

AES Alliant Environmental Solutions N N Y

AM American Air Filter N N Y

AN Andritz NNY

AP AirPol NYY

API Air Polution Industries N N Y

AU Applied Utility Systems (AUS) N Y N

AX Amerex Industries N N Y

AZ Alzeta NYN

BC Babcock Borsig Power N Y N

BE Bact Engineering N N Y

BI Bleco Industries N N Y

BL Bechtel Corporation N N Y

BM Bloom NYN

BMD Burns & McDonnell N Y Y

BO Bionomics N N Y

BPC Belco Pollution Control N N Y

BPE Babcock Power Environmental Inc (BPEI) N N Y

BT Belco Technologies N N Y

CA Chiyoda N N Y

CB Clyde Bergeman EEC N N Y

CC Chemico N N Y

CM Combustion Components Associates Inc N Y N

CO Combustion Equipment N N Y

CSI Combustion Solutions Inc N Y N

CT Callidus Technologies N Y N

DA Delta Conveying Systems N N Y

DB Deutsche-Babcock N Y N

DC Ducon NNY

DD Damper Design Inc N Y N

DM Davey McKee N N Y

DQ Duquense Light Company & Energy Systems Associates N Y N

DV Davis NYN

DX Deltex NYN

EA Eagle Air N Y N

EE Environmental Engineering N N Y

EEC Environmental Elements Corporation N N Y

EG Energy and Environmental Research Corp (EER) N Y N

EI Entollter Inc N N Y

EL Electric Power Technologies N Y N

EP EPRI NYN

EPI Energy Products of Idaho N N Y

ETE Entropy Technology and Environmental Consultants (ETEC Inc) N Y N

FB Faber NYN

FL Flakt Inc N N Y

FM FMC NNY

FN Forney NYN

FT Fuel Tech Inc N Y N

GF Grafwolff N N Y
Table 13: Environmental Equipment Manufacturer Codes

Code Manufacturer Description BOILER NOX FGD

GR GE Energy and Environmental Research Corp (GEEER) N Y N

HA Hamon NNY

HL Holman NYN

IC International Combustion Limited N Y N

JO Joy Manufacturing N N Y

JZ John Zink Todd Combustion/Todd Combustion N Y N

KC Korea Cottrell N N Y

KE M. W. Kellogg N N Y

KR Krebs Engineers N N Y

LLB Lurgi Lentjes Bischoff N N Y

MB Mitsui-Babcock N Y N

MC Macrotek N N Y

MG McGill Air Clean N N Y

MI Mitsubishi Heavy Industries N Y Y

MK Merrick Industries N N Y

MT Mobotec N Y Y

MX Marselex N N Y

NA Not Applicable N Y N

NC Natcom Inc N Y N

NE NEI NYN

NL Noell Inc N Y N

NPA Neptune Airpol N N Y

NSP NSP NNY

PA Procedair N Y Y

PI Power and Industrial N Y N

PL Pillard NYN

PPC PPC Industries N N Y

PS Peerless Manufacturing Company N Y N

PU Pure Air N N Y

PX Phoenix Combustion N Y N

RC Research Cottrell N N Y

RD Rodenhuis and Verloop N Y N

RI Riley NYN

RJ RJM NYN

RR Rolls Royce N Y N

RV RV Industries N Y N

SB SmartBurn N Y N

SC Southern Company N Y N

SHU Saarberg-Holter Umweltechnick GmbH N N Y

SK Schenck Weigh Feeders N N Y

SM Smoot Company N N Y

SW Siemens-Westinghouse N Y N

TC Turbosonic N Y Y

TEC Thermal Equipment Corporation N Y N

TH Thyssen/CEA N N Y

TK Turbotak N N Y

TP Tempala Power N N Y

UE Utility Engineering N N Y

UM United McGill N N Y

UO Universal Oil Products N N Y

WAP Wheelabrator Air Pollution Control N N Y

ZC Zeeco NYN

AI Aalborg Industries Y N N
Table 13: Environmental Equipment Manufacturer Codes

Code Manufacturer Description BOILER NOX FGD

AL Alstom YYY

AS American Shack Y N N

AT Applied Thermal Systems Y Y N

BR BROS YNN

BW Babcock and Wilcox Y Y Y

CE Combustion Engineering Y Y Y

CMI CMI YNN

CN Coen YYN

DJ De Jong Coen bv Y N N

DL Deltak YNN

DS Doosan YNN

EC Econotherm Y N N

ER Eerie City Iron Works Y N N

ET Entek YYN

FW Foster Wheeler Y Y Y

GE General Electric Y Y Y

GT Gotaverken Y N N

HT Hitachi YYY

ID Indeck YYN

IH In house design Y Y Y

IHI Ishikawajima-Harima Heavy Industries (IHI Corp) Y Y N

IS Innovative Steam Technology Y N N

KL Keeler Dorr Oliver Y Y N

KP Kvaerner Pulping Y N N

KW Kawaski Heavy Industires Y N N

ME Mitchell Engineering Y N N

NB Nebraska Boiler Y Y N

NM NEM YNN

NT Nooter Erickson Y N N

OT Other (specify in a Footnote on SCHEDULE 7, COMMENTS) Y Y Y

PB Peabody Y Y Y

PR Pyro Power Y N Y

RS Riley-Stoker/Riley Power Y Y Y

ST Sterling YNN

TM Tampella Power Corporation Y Y N

TS Toshiba YYN

VO Vogt Machine Company/Vogt Power Y Y N

WE Westinghouse Y N N

WG Weigl Engineering Y Y N

WI Wickes YNN

ZN Zurn YNY
Description of Revisions to the 2009 EIA-860 Data File

Friday, December 10, 2010 2009 EIA-860 data files postedTuesday, January 4, 2011 GeneratorY09 file reposted with revised energy source data for generators CS7, CS9, CS10 an

CS11 at plant 56833 and generator CS8 at plant 56880, both in Montana