Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

UTILITY ID EIA-assigned identification number for the company that is 

responsible for the day-to-day operations of the generator

x

xxxxxxxxxxxxxxxxxxxx

UTILITY NAME Legal name of the company that is responsible for the dayto-day operations of the generator x

xxxxxxxxxxxxxx

PLANT CODE EIA-assigned plant codex

xxxxxxxxxxxxxxxxxxx

PLANT NAME Plant name

xxxxxxxxxxxxxxx

STATE Plant state

xxxxxxxxxxxxxxx

GENERATOR ID Generator identification number

xxxxxxxxx

INTERCONNECTION MONTH Month that the interconnection occurred

x

INTERCONNECTION YEAR Year that the interconnection occurred

x

INTERCONNECTION 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 OWNER NAME 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

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'

xxxxxx

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

x

OWNER NAME Name of owner

x

OWNER STATE State for owner

x

PERCENT OWNED Percent of generator ownership

x

MULTIPLE FUELS

Indicates whether the combustion system that will power 

each proposed generator expects to have the regulatory 

permits necessary to fuel switch

Yes / No

xxx

COFIRE FUELS

Indicates whether the combustion system that will power 

each proposed generator expects to have the regulatory 

permits necessary to co-fire 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'

xxx

Content and Layout of the Annual Electric Generator Report (EIA-860) Data Files for 2012
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

COFIRE ENERGY SOURCE 2 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference 

Tables I'

xxx

COFIRE ENERGY SOURCE 3 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference 

Tables I'

xxx

COFIRE ENERGY SOURCE 4 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference 

Tables I'

xxx

COFIRE ENERGY SOURCE 5 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference 

Tables I'

xxx

COFIRE ENERGY SOURCE 6 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference 

Tables I'

xxx

COFIRE OIL AND GAS Indicates whether the proposed unit expects to be able to 

co-fire fuel oil with natural gas Yes / No

xxx

COFIRE 100% OIL Indicates whether the proposed unit is expected to be able 

to run on 100 percent oil Yes / No

xxx

MAX OIL HEAT INPUT 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

xxx

FUEL SWITCH OIL GAS Indicates whether the unit can co-fire fuel oil with natural 

gas

Yes / No

xxx

Net Summer Capacity with Natural Gas

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 with 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 hours

over 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

AIR PERMIT 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

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 CAPACITY The highest value on the generator nameplate in 

megawatts rounded to the nearest tenth

xxx

SUMMER CAPABILITY The net summer capacity

xxx

WINTER CAPABILITY The net winter capacity

xxx

UNIT 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

xx

OPERATING YEAR Year the generator began commercial operation

xx

RETIREMENT MONTH Month the generator retired

x

RETIREMENT YEAR Year the generator retired

x

EFFECTIVE MONTH The original effective month on which the generator was 

scheduled to start operation

x

EFFECTIVE YEAR The original effective year on which the generator was 

scheduled to start operation

x

CURRENT MONTH The most recently updated effective month on which the 

generator is scheduled to start operation

x
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

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

xxx

Deliver Power to Transmission Grid Indicate whether the generator can deliver power to the 

transmission grid

xx

Synchronized to Transmission Grid Indicates whether standby generators (SB status) can be 

synchronized to the grid Yes / No

xx

OWNERSHIP Identifies the ownership for each generator

S=Single ownership

J= Joint ownership

W=Wholly owned by an other 

entity

xxx

TURBINES Number of wind turbines 

xxx

COGENERATOR Indicates whether the generator is associated with a 

combined heat and power system Yes / No

xxx

SECTOR NAME

Plant-level sector name, designated by the primary 

purpose, regulatory status and plant-level combined heat 

and power status

Commercial; Electric Utility; 

Industrial; Non-Combined Heat and 

Power Independent Power 

Producer (IPP); Combined Heat 

and Power (IPP CHP)

xx

SECTOR

Plant-level sector number, designated by the primary 

purpose, regulatory status and plant-level combined heat 

and power status

1 = Electric Utility

2 = Independent Power Producer, 

Non-Combined Heat and Power

3 = Independent Power Producer, 

Combined Heat and Power

4 = Commercial, Non-Combined 

Heat and Power

5 = Commercial, Combined Heat 

and Power

6 = Industrial, Non-Combined Heat 

and Power

7 = Industrial, Combined Heat and 

Power

xx

Topping or 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 = Topping

B = Bottoming

xx

DUCT BURNERS Indicates whether the unit has duct-burners for 

supplementary firing of the turbine exhaust gas

xxx

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

xx

Planned Uprates Net Summer Capacity Increase in summer capacity expected to be realized from 

the modification to the equipment

xx

Planned Uprates Net Winter Capacity Increase in winter capacity expected to be realized from 

the uprate modification to the equipment

xx

PLANNED UPRATES MONTH Planned effective month that the generator is scheduled to 

enter operation after the uprate modification

xx

PLANNED UPRATES YEAR Planned effective year that the generator is scheduled to 

enter operation after the uprate modification

xx

Planned Derates Net Summer Capacity Decrease in summer capacity expected to be realized 

from the derate modification to the equipment

xx

Planned Derates Net Winter Capacity Decrease in winter capacity expected to be realized from 

the derate modification to the equipment

xx

PLANNED DERATES MONTH Planned effective month that the generator is scheduled to 

enter operation after the derate modification

xx

PLANNED DERATES YEAR Planned effective year that the generator is scheduled to 

enter operation after the derate modification

xx

PLANNED NEW PRIME MOVER New prime mover for the planned repowered generator See Table 1 in tab 'Reference 

Tables I'

xx
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

PLANNED ENERGY SOURCE 1 New energy source code for the planned repowered 

generator

See Table 2 in tab 'Reference 

Tables I'

xx

PLANNED REPOWER MONTH Planned effective month that the generator is scheduled to 

enter operation after the repowering is complete

xx

PLANNED REPOWER YEAR Planned effective year that the generator is scheduled to 

enter operation after the repowering is complete

xx

Other Modifications Indicates whether there are there other modifications 

planned for the generator Yes / No

xx

Other Modifications Month

Planned effective month that the generator is scheduled to 

enter commercial operation after any other planned 

modification is complete

xx

Other Modifications Year

Planned effective year that the generator is scheduled to 

enter commercial operation after any other planned 

modofication is complete

xx

PLANNED RETIREMENT MONTH Planned effective month of the scheduled retirement of 

the generator

x

PLANNED RETIREMENT YEAR Planned effective year of the scheduled retirement of the 

generator

x

Solid Fuel Gasification System Indicates whether the generator is part of a solid fuel 

gasification system Yes / No

xxx

Pulverized Coal Technology Indicates that the generator uses pulverized coal 

technology

xxx

Fluidized Bed Technology Indicates that the generator uses fluidized bed technology

xxx

Subcritical Technology Indicates that the generator uses subcritical technology

xxx

Supercritical Technology Indicates that the generator uses supercritical technology

xxx

Ultrasupercritical Technology Indicates that the generator uses ultra-supercritical 

technology

xxx

Carbon Capture Technology Indicates that the generator uses carbon capture 

technology

xxx

STARTUP SOURCE 1

The code representing the first, second, third or fourth startup 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 startup 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 startup 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 startup and flame stabilization energy source used by the 

combustion unit(s) associated with this generator

See Table 2 in tab 'Reference 

Tables I'

xxx

STREET ADDRESS Street address of the operator/owner

x

COUNTY Name of the county in which the plant is located

xxxx

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

x

STATE State of the operator/owner

x

ZIP5 Zip code of the operator/owner

x

STREET ADDRESS Street address of the power plant

x

CITY Name of the city in which the plant is located

x

ZIP Zip code of the plant

x

NAME OF WATER SOURCE Name of water source associater with the plant

x

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

Tables I'

x

ISO RTO

Indicates whether the plant is located in the service 

territory of a Regional Transmission Organization (RTO) or 

Independent System Operator (ISO)

Yes / No

x

ISO RTO CODE

The code that represents the name of a Regional 

Transmission Organization (RTO) or Independent System 

Operator (ISO) 

See Table 6 in tab 'Reference 

Tables I'

x

PRIMARY PURPOSE (NAICS Code)

North American Industry Classification System (NAICS) 

code that best describes the primary purpose of the 

reporting plant

x

Transmission or Distribution System Owner Name of the owner of the transmission or distribution 

system to which the plant is interconnected

x

Transmission or Distribution System Owner ID EIA-assigned code for owner of transmission/distribution 

system to which the plant is interconnected

x

Transmission or Distribution System Owner 

State

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

x

FERC Cogeneration Status Indicates of whether the plant has FERC qualifying facility 

cogenerator status Yes / No

x

FERC Cogeneration Docket Number The docket number relating to the FERC qualifying facility 

cogenerator status

x
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

FERC Small Power Producer Status Indicates of whether the plant has FERC qualifying facility 

small power producer status Yes / No

x

FERC Small Power Producer Docket Number The docket number relating to the FERC qualifying facility 

small power producer status

x

FERC Exempt Wholesale Generator Status Indicates of whether the plant has FERC qualifying facility 

exempt wholesale generator status Yes / No

x

FERC Exempt Wholesale Generator Docket 

Number

The docket number relating to the FERC qualifying facility 

exempt wholesale generator status

x

BOILER ID Boiler identification number

xxxxxxx

GENERATOR ASSOCIATION Indicates whether boiler associations with generator during 

the year were actual or theoretical

A = Actual

T = Theoretical

x

COOLING ID Cooling system identification number

xx

FGD ID Flue gas desulfurization identification number

xx

FGP ID Flue gas particulate collector identification number 

xx

FLUE ID Flue identification number

xx

STACK ID Stack identification number

xx

BOILER STATUS Boiler status See Table 3d in tab 'Reference 

Tables I'

xx

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'

x

NSR Indicates whether the boiler is subject to New Source 

Review requirements Yes / No

x

NSR DATE MONTH Month of issued New Source Review permit

x

NSR DATE YR Year of issued New Source Review permit

x

NSR PERMIT New Source Review permit number

x

REGULATION PARTICULATE Most stringent type of statute or regulation code under 

which the boiler is operating for particulate matter

FD = Federal

ST=State

LO=Local

NA=Not Applicable

x

REGULATION SULFUR Most stringent type of statute or regulation code under 

which the boiler is operating for sulfur dioxide

FD = Federal

ST=State

LO=Local

NA=Not Applicable

x

REGULATION NITROGEN Most stringent type of statute or regulation code under 

which the boiler is operating for nitrogen oxides

FD = Federal

ST=State

LO=Local

NA=Not Applicable

x

STANDARD PARTICULATE RATE Numeric value for the unit of measurement specified for 

particulate matter

x

STANDARD SULFUR RATE Numeric value for the unit of measurement specified for 

sulfur dioxide

x

STANDARD NITROGEN RATE Numeric value for the unit of measurement specified for 

nitrogen oxide

x

UNIT PARTICULATE Unit of measurement specified for particulate matter See Table 11a in tab 'Reference 

Tables III'

x

UNIT SULFUR Unit of measurement specified for sulfur Dioxide See Table 11b in tab 'Reference 

Tables III'

x

UNIT NITROGEN Unit of measurement specified for Nitrogen Oxides See Table 11c in tab 'Reference 

Tables III'

x

PERIOD PARTICULATE Period of time over which measurements for particulate 

matter were averaged

See Table 5 in tab 'Reference 

Tables I'

x

PERIOD SULFUR Period of time over which measurements for sulfur dioxide 

were averaged

See Table 5 in tab 'Reference 

Tables I'

x

PERIOD NITROGEN Period of time over which measurements for nitrogen 

oxides were averaged

See Table 5 in tab 'Reference 

Tables I'

x

COMPLIANCE YEAR PARTICULATE Year boiler was or is expected to be in compliance with 

federal, state and/or local regulations for particulate matter

x

COMPLIANCE YEAR SULFUR Year boiler was or is expected to be in compliance with 

federal, state and/or local regulations for sulfur dioxide

x

COMPLIANCE YEAR NITROGEN Year boiler was or is expected to be in compliance with 

federal, state and/or local regulations for nitrogen oxide

x

STRATEGY PARTICULATE1 If boiler is not in compliance with particulate matter 

regulations, strategy for compliance

See Table 12a in tab 'Reference 

Tables III'

x

STRATEGY PARTICULATE2 If boiler is not in compliance with particulate matter 

regulations, strategy for compliance

See Table 12a in tab 'Reference 

Tables III'

x

STRATEGY PARTICULATE3 If boiler is not in compliance with particulate matter 

regulations, strategy for compliance

See Table 12a in tab 'Reference 

Tables III'

x

STRATEGY SULFUR1 If boiler is not in compliance with sulfur dioxide 

regulations, strategy for compliance

See Table 12b in tab 'Reference 

Tables III'

x

STRATEGY SULFUR2 If boiler is not in compliance with sulfur dioxide 

regulations, strategy for compliance

See Table 12b in tab 'Reference 

Tables III'

x

STRATEGY SULFUR3 If boiler is not in compliance with sulfur dioxide 

regulations, strategy for compliance

See Table 12b in tab 'Reference 

Tables III'

x
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

STRATEGY NITROGEN1 If boiler is not in compliance with nitrogen oxides 

regulations, strategy for compliance

See Table 12c in tab 'Reference 

Tables III'

x

STRATEGY NITROGEN2 If boiler is not in compliance with nitrogen oxides 

regulations, strategy for compliance

See Table 12c in tab 'Reference 

Tables III'

x

STRATEGY NITROGEN3 If boiler is not in compliance with nitrogen oxides 

regulations, strategy for compliance

See Table 12c in tab 'Reference 

Tables III'

x

Existing SO2 Strategy Clean Air Act 1 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'

x

Existing SO2 Strategy Clean Air Act 2 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'

x

Existing SO2 Strategy Clean Air Act 3 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'

x

Planned SO2 Strategy Clean Air Act 1 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'

x

Planned SO2 Strategy Clean Air Act 2 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'

x

Planned SO2 Strategy Clean Air Act 3 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'

x

Existing NOx Strategy Clean Air Act 1

Existing strategies to meet the nitrogen oxide 

requirements of Title IV of the Clean Air Act Amendment 

of 1990 

See Table 12c in tab 'Reference 

Tables III'

x

Existing NOx Strategy Clean Air Act 2

Existing strategies to meet the nitrogen oxide 

requirements of Title IV of the Clean Air Act Amendment 

of 1990 

See Table 12c in tab 'Reference 

Tables III'

x

Existing NOx Strategy Clean Air Act 3

Existing strategies to meet the nitrogen oxide 

requirements of Title IV of the Clean Air Act Amendment 

of 1990 

See Table 12c in tab 'Reference 

Tables III'

x

Planned NOx Strategy Clean Air Act 1

Planned strategies to meet the nitrogen oxide 

requirements of Title IV of the Clean Air Act Amendment 

of 1990 

See Table 12c in tab 'Reference 

Tables III'

x

Planned NOx Strategy Clean Air Act 2

Planned strategies to meet the nitrogen oxide 

requirements of Title IV of the Clean Air Act Amendment 

of 1990 

See Table 12c in tab 'Reference 

Tables III'

x

Planned NOx Strategy Clean Air Act 3

Planned strategies to meet the nitrogen dioxide 

requirements of Title IV of the Clean Air Act Amendment 

of 1990 

See Table 12c in tab 'Reference 

Tables III'

x

BOILER MANUFACTURER Boiler manufacturer code See Table 13 in tab 'Reference 

Tables IV'

x

INSERVICE MONTH Actual or projected month of commercial operation of the 

Boiler/Cooling System/FGD unit/FGP unit/Stack (or Flue)

xxxxx

INSERVICE YEAR Actual or projected year of commercial operation of the 

Boiler/Cooling System/FGD unit/FGP unit/Stack (or Flue)

xxxxx

RETIREMENT MONTH Actual or projected month of retirement

x

RETIREMENT YEAR Actual or projected month of retirement

x

MAX STEAM FLOW Maximum continuous steam flow at 100 percent load 

(thousand pounds per hour)

x

COAL FIRE STEAM FLOW Design firing rate at maximum continuous steam flow for 

coal (nearest 0.1 ton per hour)

x

PETROLEUM FIRE STEAM FLOW Design firing rate at maximum continuous steam flow for 

pet coke (nearest 0.1 barrels per hour)

x

GAS FIRE STEAM FLOW Design firing rate at maximum continuous steam flow for 

gas (nearest 0.1 cubic feet per hour)

x

OTHER FIRE STEAM FLOW Design firing rate at maximum continuous steam flow for 

waste heat

x

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 fuelburning process (million Btu per hour)

x

PRIMARY FUEL1 Primary fuels used in order of predominance See Table 2 in tab 'Reference 

Tables I'

x

PRIMARY FUEL2 Primary fuels used in order of predominance See Table 2 in tab 'Reference 

Tables I'

x

PRIMARY FUEL3 Primary fuels used in order of predominance See Table 2 in tab 'Reference 

Tables I'

x

PRIMARY FUEL4 Primary fuels used in order of predominance See Table 2 in tab 'Reference 

Tables I'

x
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

PRIMARY FUEL5 Primary fuels used in order of predominance See Table 2 in tab 'Reference 

Tables I'

x

PRIMARY FUEL6 Primary fuels used in order of predominance See Table 2 in tab 'Reference 

Tables I'

x

PRIMARY FUEL7 Primary fuels used in order of predominance See Table 2 in tab 'Reference 

Tables I'

x

PRIMARY FUEL8 Primary fuels used in order of predominance See Table 2 in tab 'Reference 

Tables I'

x

FIRE PRIMARY FUEL1 Indicates the first, second and third type of firing used with 

primary fuels

See Table 6c in tab 'Reference 

Tables II'

x

FIRE PRIMARY FUEL2 Indicates the first, second and third type of firing used with 

primary fuels

See Table 6c in tab 'Reference 

Tables II'

x

FIRE PRIMARY FUEL3 Indicates the first, second and third type of firing used with 

primary fuels

See Table 6c in tab 'Reference 

Tables II'

x

EFFICIENCY 100 PCT LOAD Boiler efficiency when burning at 100 percent load (nearest 

0.1 percent)

x

EFFICIENCY 50 PCT LOAD Boiler efficiency when burning at 50 percent load (nearest 

0.1 percent)

x

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)

x

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=Wet

D=Dry

x

FLY ASH REINJECTION Indicates whether the boiler has fly ash re-injection Yes / No

x

NOX CONTROL STATUS Nitrogen oxide control status code See Table 6b in tab 'Reference 

Tables II'

x

LOW NOX PROCESS1 Low nitrogen oxide control process See Table 6a in tab 'Reference 

Tables II'

x

LOW NOX PROCESS2 Low nitrogen oxide control process See Table 6a in tab 'Reference 

Tables II'

x

LOW NOX PROCESS3 Low nitrogen oxide control process See Table 6a in tab 'Reference 

Tables II'

x

LOW NOX MANUFACTURER Code indicating the low nitrogen oxide control burner 

manufacturer

See Table 13 in tab 'Reference 

Tables IV'

x

MERCURY EMISSION CONTROL Indicates whether the boiler has mercury emission controls Yes / No

x

Mercury Emission Activated Carbon Injection Indicates whether the boiler has an activated carbon 

injection system

x

Mercury Emission Dry Scrubber Indicates whether the boiler has a dry scrubber

x

Mercury Emission Flue Gas Desulfurization Indicates whether the boiler has a flue gas desulfurization 

system

x

Mercury Emission Lime Injecton Indicates whether the boiler has a lime injection system

x

Mercury Emission Wet Scrubber Indicates whether the boiler has a wet scrubber

x

Mercury Emission Baghouse, Shake and 

Deflate

Indicates whether the boiler has a baghouse, shake and 

deflate

x

Mercury Emission Baghouse, Pulse Indicates whether the boiler has a baghouse, pulsex

Mercury Emission Baghouse, Reverse Air Indicates whether the boiler has a baghouse, reverse airx

Mercury Emission Electrostatic Precipitator, 

Cold Side with Flue Gas Conditioning

Indicates whether the boiler has an electrostatic 

precipitator, cold side, with flue gas conditioning

x

Mercury Emission Electrostatic Precipitator, 

Hot Side with Flue Gas Conditioning

Indicates whether the boiler has an electrostatic 

precipitator, hot side, with flue gas conditioning

x

Mercury Emission Electrostatic Precipitator, 

Hot Side without Flue Gas Conditioning

Indicates whether the boiler has an electrostatic 

precipitator, cold side, without flue gas conditioning

x

Mercury Emission Electrostatic Precipitator, 

Cold Side without Flue Gas Conditioning

Indicates whether the boiler has an electrostatic 

precipitator, hot side, without flue gas conditioning

x

Mercury Emission Other Indicates whether the boiler has other mercury emission 

controls

x

COOLING STATUS Cooling system status See Table 3d in tab 'Reference 

Tables I'

x

COOLING TYPE1 Cooling system code for the first, second, third and/or 

fourth cooling system

See Table 7a in tab 'Reference 

Tables II'

x

COOLING TYPE2 Cooling system code for the first, second, third and/or 

fourth cooling system

See Table 7a in tab 'Reference 

Tables II'

x

COOLING TYPE3 Cooling system code for the first, second, third and/or 

fourth cooling system

See Table 7a in tab 'Reference 

Tables II'

x

COOLING TYPE4 Cooling system code for the first, second, third and/or 

fourth cooling system

See Table 7a in tab 'Reference 

Tables II'

x

PERCENT DRY COOLING Percent of cooling load served by dry cooling components

x

COOLING WATER SOURCE Name of river, lake, or water source that provides cooling 

water

x
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

WATER SOURCE CODE Type of cooling water source See Table 7b in tab 'Reference 

Tables II'

x

WATER TYPE CODE Type of cooling water See Table 7c in tab 'Reference 

Tables II'

x

INTAKE RATE AT 100 PCT Design cooling water flow rate at 100 percent load at intake (cubic feet per second)

x

CHLORINE INSERVICE MONTH Actual or projected in-service month for chlorine discharge 

control structures and equipment

x

CHLORINE INSERVICE YEAR Actual or projected in-service year for chlorine discharge 

control structures and equipment

x

POND INSERVICE MONTH Cooling ponds actual or projected in-service month

x

POND INSERVICE YEAR Cooling ponds actual or projected in-service year

x

POND SURFACE AREA Total surface area of cooling pond (in acres)

x

POND VOLUME Total volume of water in cooling pond (in acre-feet)

x

TOWER INSERVICE MONTH Cooling towers actual or projected in-service month

x

TOWER INSERVICE YEAR Cooling towers actual or projected in-service year

x

TOWER TYPE1 Code for first and/or second cooling tower See Table 7d in tab 'Reference 

Tables II'

x

TOWER TYPE2 Code for first and/or second cooling tower See Table 7d in tab 'Reference 

Tables II'

x

TOWER WATER RATE Maximum design rate of water flow at 100 percent load

x

POWER REQUIREMENT Maximum power requirement at 100 percent load

x

COST TOTAL

Actual installed cost for the existing system or the 

anticipated cost to bring the total system into commercial 

operation (thousands dollars)

x

COST PONDS

Actual installed cost for the existing cooling ponds or the 

anticipated cost to bring the cooling ponds into commercial 

operation (thousands dollars)

x

COST TOWERS

Actual installed cost for the existing cooling towers or the 

anticipated cost to bring the cooling towers into 

commercial operation (thousands dollars)

x

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)

x

INTAKE DISTANCE SHORE Maximum distance from shore to intake (in feet)

x

OUTLET DISTANCE SHORE Maximum distance from shore to outlet (in feet)

x

INTAKE DISTANCE SURFACE Average distance below water surface to intake (in feet)

x

OUTLET DISTANCE SURFACE Average distance below water surface to outlet (in feet)

x

FGD STATUS Flue gas desulfurization unit status See Table 3d in tab 'Reference 

Tables I'

x

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'

x

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'

x

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'

x

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'

x

SORBENT TYPE1 Sorbent code for the first, second, third and/or fourth 

sorbent used

See Table 9b in tab 'Reference 

Tables II'

x

SORBENT TYPE2 Sorbent code for the first, second, third and/or fourth 

sorbent used

See Table 9b in tab 'Reference 

Tables II'

x

SORBENT TYPE3 Sorbent code for the first, second, third and/or fourth 

sorbent used

See Table 9b in tab 'Reference 

Tables II'

x

SORBENT TYPE4 Sorbent code for the first, second, third and/or fourth 

sorbent used

See Table 9b in tab 'Reference 

Tables II'

x

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

x

FGD MANUFACTURER Flue gas desulfurization unit manufacturer code See Table 13 in tab 'Reference 

Tables IV'

x

POND LANDFILL REQUIREMENTS Annual pond and land fill requirements

x

SLUDGE POND LINED Indicates whether the sludge pond is lined Yes / No / NA

x

FLUE GAS BYPASS FGD Indicates whether flue gas can bypass flue gas 

desulfurization unit Yes / No

x

SPECIFICATIONS OF COAL ASH Design fuel specifications for coal for ash (nearest 0.1 

percent by weight)

x

SPECIFICATIONS OF COAL SULFUR Design fuel specifications for coal for sulfur (nearest 0.1 

percent by weight)

x

FGD TRAINS TOTAL Total number of flue gas desulfurization unit scrubber 

trains

x

FGD TRAINS 100 PCT Total number of flue gas desulfurization unit scrubber 

trains operated at 100 percent load

x

Removal Efficiency of Sulfur Removal efficiency as the percent by weight of gases 

removed from the flue gas (nearest 0.1 percent by weight)

x
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

SULFUR EMISION RATE Sulfur dioxide emission rate (pounds per hour)

x

FLUE GAS EXIT RATE Flue gas exit rate (actual cubic feet per minute)

x

FLUE GAS EXIT TEMPERATURE Flue gas exit temperature (degrees fahrenheit)

x

Flue Gas Entering FGD Flue gas entering flue gas desulfurization unit (percent of 

total)

x

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

x

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

x

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

x

COST TOTAL

Total actual installed costs for the existing systems or the 

anticipated costs to bring a planned system into 

commercial operation

x

FGP STATUS Flue gas particulate collector status See Table 3d in tab 'Reference 

Tables I'

x

COLLECTOR TYPE1 Flue gas particulate collector code for the first, second 

and/or third collector

See Table 8 in tab 'Reference 

Tables II'

x

COLLECTOR TYPE2 Flue gas particulate collector code for the first, second 

and/or third collector

See Table 8 in tab 'Reference 

Tables II'

x

COLLECTOR TYPE3 Flue gas particulate collector code for the first, second 

and/or third collector

See Table 8 in tab 'Reference 

Tables II'

x

INSTALLED COST

Actual installed cost for the existing system or the 

anticipated cost to bring a planned system into commercial 

operation (thousands dollars)

x

Fuel Specification Ash Coal (Low) Design fuel specifications for ash for coal; beginning of 

range for values (nearest 0.1 percent by weight)

x

Fuel Specification Ash Coal (High) Design fuel specifications for ash for coal; end of range for 

values (nearest 0.1 percent by weight)

x

Fuel Specification Ash Petroleum (Low) Design fuel specifications for ash for petroleum; beginning 

of range for values (nearest 0.1 percent by weight)

x

Fuel Specification Ash Petroleum (High) Design fuel specifications for ash for petroleum; end of 

range for values (nearest 0.1 percent by weight)

x

Fuel Specification Sulfur Coal (Low) Design Fuel Specifications for sulfur for Coal; Beginning of 

range for values (nearest 0.1 percent by weight)

x

Fuel Specification Sulfur Coal (High) Design fuel specifications for sulfur for coal; end of range 

for values (nearest 0.1 percent by weight)

x

Fuel Specification Sulfur Petroleum (Low)

Design fuel specifications for sulfur for petroleum; 

beginning of range for values (nearest 0.1 percent by 

weight)

x

Fuel Specification Sulfur Petroleum (High) Design fuel specifications for sulfur for petroleum; end of 

range for values (nearest 0.1 percent by weight)

x

COLLECTION EFFICIENCY Collection efficiency at 100 percent generator load 

(nearest 0.1 percent)

x

EMISSION RATE Particulate emission rate at 100 percent generator load 

(pounds per hour)

x

GAS EXIT RATE Particulate collector gas exit rate at 100 percent generator 

load (actual cubic feet per minute)

x

GAS EXIT TEMPERATURE Particulate collector gas exit temperature at 100 percent 

generator load (degrees fahrenheit)

x

STACK FLUE STATUS Equipment status code for the stack or flue See Table 3d in tab 'Reference 

Tables I'

x

FLUE HEIGHT Flue height at top from ground level (feet)

x

AREA AT TOP Cross-sectional area at top of flue (nearest square foot)

x

EXIT RATE 100 PCT Design flue gas exit rate at 100 percent load (actual cubic 

feet per minute)

x

EXIT RATE 50 PCT Design flue gas exit rate at 50 percent load (actual cubic 

feet per minute)

x

EXIT TEMPERATURE 100 PCT Design flue gas exit temperature at 100 percent load 

(degrees fahrenheit)

x

EXIT TEMPERATURE 50 PCT Design flue gas exit temperature at 50 percent load 

(degrees fahrenheit)

x

EXIT VELOCITY 100 PCT Design flue gas exit velocity at 100 percent load (feet per 

second)

x

EXIT VELOCITY 50 PCT Design flue gas exit velocity at 50 percent load (feet per 

second)

x

EXIT TEMPERATURE SUMMER

Average flue gas exit temperatures based on the 

arithmetic mean of measurements during operating hours 

of June, July, and August

x
Field Name Description Notes

Utility

Plant

Generator /

Operable

Generator /

Proposed

Generator / Retired

Ownership

MultiFuel / Operable

MultiFuel /

Proposed

MultiFuel / Retired

Interconnection

EnviroAssoc /

Boiler_Gen

EnviroAssoc /

Boiler_Cool

EnviroAssoc /

Boiler_FGD

EnviroAssoc /

Boiler_FGP

EnviroAssoc /

Boiler_SF

EnviroEquip / Boiler

EnviroEquip /

Controls

EnviroEquip /

Cooling

EnviroEquip / FGD

EnviroEquip / FGP

EnviroEquip /

StackFlue

EXIT TEMPERATURE WINTER

Average flue gas exit temperatures based on the 

arithmetic mean of measurements during operating hours 

of January, February, and December

x

EXIT TEMPERATURE SOURCE Source of seasonal flue gas temperatures M = Measured

E = Estimated

x

LATITUDE The latitude of a plant's coordinates

x

LONGITUDE The longitude of a plant's coordinates

x
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 operation) and producing some 

electricity. Includes peaking units that are run on an as needed 

(intermittent or seasonal) basis.

CE Energy Storage, Compressed Air ANT Anthracite Coal ST, CT SB Standby/Backup - available for service but not normally used (has little or 

no generation during the year) for this reporting period.

CP Energy Storage, Concentrated Solar Power BFG Blast-Furnace Gas OA

Out of service - was not used for some or all of the reporting period but 

was either returned to service on December 31 or will be returned to 

service in the next calendar year. 

FW Energy Storage, Flywheel BIT Bituminous Coal OS Out of service – was not used for some or all of the reporting period and is 

NOT expected to be returned to service in the next calendar year. 

ES Energy Storage, Other BLQ Black Liquor

ST Steam Turbine, including nuclear, geothermal and solar steam (does not 

include combined cycle) CUR Water, Current HA, HK Table 3b: Proposed Generator Status Codes

GT Combustion (Gas) Turbine (includes jet engine design) DFO Disillate Fuel Oil (all Diesel, and No. 1, No. 2, and No. 4 Fuel Oils)

IC Internal Combustion Engine (diesel, piston, reciprocating) GEO Geothermal Code Proposed Status Description

CA Combined Cycle Steam Part JF Jet Fuel TS Construction complete, but not yet in commercial operation (including low 

power testing of nuclear units)

CT Combined Cycle Combustion Turbine Part (type of coal or solid must be 

reported as energy source for integrated coal gasification). KER Kerosene P

Planned for installation but regulatory approvals not initiated; Not under 

construction

CS Combined Cycle Single Shaft (combustion turbine and steam turbine 

share a single generator) LFG Landfill Gas L

Regulatory approvals pending. Not under construction but site preparation 

could be underway

CC Combined Cycle Total Unit (use only for plants/generators that are in 

planning stage, for which specific generator details cannot be provided) LIG Lignite T

Regulatory approvals received. Not under construction but site 

preparation could be underway

HA Hydrokinetic, Axial Flow Turbine MWH Megawatt Hour (MWh) BA, CE, CP, ES, FW U

Under construction, less than or equal to 50 percent complete (based on 

construction time to date of operation)

HB Hydrokinetic, Wave Buoy MSW Municipal Solid Waste V

Under construction, more than 50 percent complete (based on 

construction time to date of operation)

HK Hydrokinetic, Other NA Not Available at this Time

HY Hydroelectric Turbine (includes turbines associated with delivery of water 

by pipeline) NG Natural Gas Table 3c: Other Generator Status Codes

PS Hydraulic Turbine, Reversible (pumped storage) NUC Nuclear (Uranium, Plutonium, Thorium)

BT Turbines Used in a Binary Cycle (including those used for geothermal 

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

PV Photovoltaic 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 not expected to be returned to service.

WT Wind Turbine, Onshore OBS Other Biomass Solids (Animal Manure and Waste, Solid Byproducts, and 

Other Solid Biomass not specified) IP Planned new generator canceled, indefinitely postponed, or no longer in resource plan

WS Wind Turbine, Offshore OG Other Gas (Coke-Oven, Coal Processes, Butane, Refinery, Other 

Process) OT Other

CE Compressed Air Energy Storage OTH Other (Batteries, Chemicals. Hydrogen, Pitch, Sulfur, Miscellaneous 

technologies)

FC Fuel Cell PC Petroleum Coke Table 3c: Boiler and Environmental Equipment Status Codes

OT Other PG Propane

PUR Purchased Steam Code Boiler and Environmental Equipment Status Description

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

RFO Residual Fuel Oil (Include No. 5, and No. 6 Fuel Oil, and Bunker C Fuel 

Oil) CO New unit under construction

SGP Synthesis Gas from Petroleum Coke OP Operating (in commercial service or out of service less than 365 days)

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

SLW Sludge waste PL Planned (expected to go into commercial service within 10 years)

SUB Subbituminous Coal RE Retired (no longer in service and not expected to be returned to service)

SUN Solar (Photovoltaic, Thermal) SB Standby (or inactive reserve); i.e., not normally used, but available for 

service

TDF Tires SC Cold Standby (Reserve); deactivated (usually requires 3 to 6 months to 

reactivate)

TID Water, Tides HA, HK TS Operating under test conditions (not in commercial service)

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 exceed

FRCC Florida Reliability Coordinating Council N FM 5 minutes

HICC Hawaii Coordinating Council N SM 6 minutes

MRO Midwest Reliability Organization N FT 15 minutes

MROC MRO Canada S OH 1 hour

MROU MRO United States S WO 2 hours

NPCC Northeast Power Coordinating Council N TH 3 hours

NPCCI NPCC ISO New England S EH 8 hours

NPCCM NPCC Maritime S DA 24 hours

NPCCN NPCC New York S WA 1 week

NPCCO NPCC Ontario S MO 30 Days

NPCCQ NPCC Quebec S ND 90 Days

RFC Reliability First Corporation N YR Annual

SERC Southeastern Electric Reliability Council N PS Periodic Stack Testing

SERCE SERC Entergy S DT Defined By Testing

SERCG SERC Gateway S NS Not Specified

SERCS SERC Southern S OT Other

SERCT SERC TVA S

SERCV SERC VACAR S Table 6: RTO/ISO Territory Codes

SPP Southwest Power Pool N

SPPN Southwest Power Pool Northern S Code RTO/ISO Territory Descriptions

SPPS Southwest Power Pool Southern S CAISO California ISO

TRE Texas Regional Entity N SPP Southwest Power Pool

WECC Western Systems Coordinating Council N PJM PJM Interconnection

WECCA Western Systems Coordinating Council - AZNMSNV S ISONE ISO New England

WECCC Western Systems Coordinating Council - California S ERCOT Electric Reliability Council of Texas

WECCN Western Systems Coordinating Council - NWPP S MISO Midwest ISO

WECCR Western Systems Coordinating Council - RMPA S NYISO New York ISO

OTHER Other
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 air

FR Flue Gas Recirculation HRI Hybrid: recirculating with induced draft cooling tower(s) with dry cooling EC Electrostatic precipitator, cold side, with flue gas conditioning

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

H20 Water Injection HT Helper Tower EK Electrostatic precipitator, cold side, without flue gas conditioning

LA Low Excess Air *ON Once through without cooling pond(s) or canal(s) EW Electrostatic precipitator, hot side, without flue gas conditioning

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 Slagging

SN Selective Noncatalytic Reduction

SR Selective Catalytic Reduction Table 7b: Type of Cooling Water Source 

STM Steam Injection

NC No change in historic operation of unit anticipated Code Type of Water Source

RP Repower Unit SW Surface Water (ex: river, canal, bay)

UE Decrease utilization - rely on energy conservation and/or improved 

efficiency

GW Ground Water (ex: aquifer, well)

ND Not determined at this time PD Plant Discharge Water (ex: wastewater treatment plant discharge)

NC No change in historic operation of unit anticipated OT Other

RP Repower Unit

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 control Table 7c: Type of Cooling Water 

OP Operating

OS Out of Service Code Type of Water

OZ Operating during the Ozone Season BR Brackish Water

PL Planned FR Fresh Water

RE Retired BE Reclaimed Water (ex: treated wastewater effluent)

SB Standby SA Saline Water

SC Cold Standby OT Other 

TS Operating under Test Condtions

Table 6c: NOX Control Firing Type Codes Table 7d: Cooling Tower Type Codes

Code NOX Control Firing Type Description Code Cooling Tower Type Description

AF Arch Firing MD Mechanical draft, dry process

CB Cell Burner MW Mechanical draft, wet process

CF Concentric Firing ND Natural draft, dry process

CY Cyclone Firing NW Natural draft, wet process

DB Duct Burner WD Combination wet and dry process

FB Fluidized Bed Firing

FF Front Firing 

OF Opposed Firing 

RF Rear Firing

SF Side Firing 

SS Spreader Stoker 

TF Tangential Firing 

*New cooling type code 'ON' (Once through without cooling pond(s) or 

canal(s) substitute previous cooling type codes 'OF' (Once through, fresh 

water) and 'OS' (Once through, saline water)

VF Vertical Firing 

OT Other

Page 1
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 type

TR Tray type

VE 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 ash

SB Sodium bicarbonate

SC Sodium carbonate

SF Sodium formate

SL Soda liquid

SS Sodium sulfite

TW Treated wastewater

WT Water

OT Other

Page 2
Table 11a: Particulate Matter Measurement Type Codes Table 12a: Particulate Matter Compliance Strategy Codes Table 12c: Nitrogen Oxides Compliance Strategy Codes

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

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 standard

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 governing regulation 

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 burners)

DC Ambient air quality concentration of SO2 CF Fluidized Bed Combustor

DH 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 operation of unit anticipated

OT Other OV Overfire air ND Not determined at this time

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 Reduction

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

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 on energy conservation and/or improved 

efficiency

NP Pounds of Nitrogen Oxide per million BTU in fuel (preferred 

measurement) RP Repower Unit NA Not Applicable

OT 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 

efficiency

US Decrease utilization - designate sulfur-free generators to compensate

UP 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 N N Y

AP AirPol N Y Y

API Air Polution Industries N N Y

AU Applied Utility Systems (AUS) N Y N

AX Amerex Industries N N Y

AZ Alzeta N Y N

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 N Y N

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 N N Y

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 N Y N

DX Deltex N Y N

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 N Y N

EPI Energy Products of Idaho N N Y

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

FB Faber N Y N

FL Flakt Inc N N Y

FM FMC N N Y

FN Forney N Y N

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 N N Y

HL Holman N Y N

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 N Y N

NL Noell Inc N Y N

NPA Neptune Airpol N N Y

NSP NSP N N Y

PA Procedair N Y Y

PI Power and Industrial N Y N

PL Pillard N Y N

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 N Y N

RJ RJM N Y N

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 N Y N

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

Code Manufacturer Description BOILER NOX FGD

AL Alstom Y Y Y

AS American Shack Y N N

AT Applied Thermal Systems Y Y N

BR BROS Y N N

BW Babcock and Wilcox Y Y Y

CE Combustion Engineering Y Y Y

CMI CMI Y N N

CN Coen Y Y N

DJ De Jong Coen bv Y N N

DL Deltak Y N N

DS Doosan Y N N

EC Econotherm Y N N

ER Eerie City Iron Works Y N N

ET Entek Y Y N

FW Foster Wheeler Y Y Y

GE General Electric Y Y Y

GT Gotaverken Y N N

HT Hitachi Y Y Y

ID Indeck Y Y N

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 Y N N

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 Y N N

TM Tampella Power Corporation Y Y N

TS Toshiba Y Y N

VO Vogt Machine Company/Vogt Power Y Y N

WE Westinghouse Y N N

WG Weigl Engineering Y Y N

WI Wickes Y N N

ZN Zurn Y N Y