# Field Name **Description Notes** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



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

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

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

PLANT CODE EIA-assigned plant code x x x x x x x x x x x x x x x x x x x x

PLANT NAME Plant name x x x x x x x x x x x x x x x

STATE Plant state x x x x x x x x x x x x x x x

GENERATOR ID Generator identification number x x x x x x x x x

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 OW NER 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' x x x x x x

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

'Reference Tables I' x x x x

OW NERSHIP ID EIA-assigned owner's identification number x

OW NER NAME Name of owner x

OW NER STATE State for owner x

PERCENT OW NED Percent of generator ownership x

MULTIPLE FUELS Indicates whether the combustion system that will power

each proposed generator expects to hav e the regulatory

permits necessary to fuel switch Yes / No x x x

COFIRE FUELS Indicates whether the combustion system that will power

each proposed generator expects to hav e the regulatory

permits necessary to co-fire fuels Yes / No x x x

COFIRE ENERGY SOURCE 1 The codes representing the type of fuel that will be co-fired See Table 2 in tab 'Reference

Tables I' x x x 

# Content and Layout of the Annual Electric Generator Report (EIA-860) Data Files for 2012

# Field Name **Description Notes** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



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

Tables I' x x x

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

Tables I' x x x

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

Tables I' x x x

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

Tables I' x x x

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

Tables I' x x x

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

co-fire fuel oil with natural gas Yes / No x x x

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

to run on 100 percent oil Yes / No x x x

MAX OIL HEAT INPUT The maximum oil heat input (% of MMBtus) expected for

proposed unit when co-firing with natural gas x x x

MAX OIL OUTPUT The maximum output (net MW ) expected for proposed

unit, when making the maximum use of oil and co-firing

natural gas x x x

FUEL SW ITCH Indicates whether unit will be able to switch fuels Yes / No x x x

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

gas Yes / No x x x

Net Summer Capacity with Natural Gas The maximum output (summer net MW ) that the unit is

expected to achiev e, taking into account all applicable

legal, regulatory, and technical limits, when running on

natural gas x x x

Net Summer Capacity with Oil The maximum output (summer net MW ) that the unit is

expected to achiev e, taking into account all applicable

legal, regulatory, and technical limits, when running on oil x x x

TIME TO SW ITCH 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

ov er 6 to 24 hours

ov er 24 to 72 hours

ov er 72 hours.

Unknown or uncertain x x x

REGULATORY LIMITS Indicates whether there are factors that limit the operation

of the generator when running on 100 percent oil Yes / No x x x

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 x x x

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 x x x

OTHER LIMITS Indicates that there are other factors that limit the

operation of the generator when running on 100 percent oil Yes / No x x x

FUEL SW ITCH 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' x x x

FUEL SW ITCH 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' x x x

FUEL SW ITCH 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' x x x

FUEL SW ITCH 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' x x x

FUEL SW ITCH 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' x x x

FUEL SW ITCH 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' x x x

NAMEPLATE CAPACITY The highest v alue on the generator nameplate in

megawatts rounded to the nearest tenth x x x

SUMMER CAPABILITY The net summer capacity x x x

WI NTER CAPABILITY The net winter capacity x x x

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 x x

OPERATING YEAR Year the generator began commercial operation x x

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** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



# 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' x x x

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' x x x

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' x x x

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' x x x

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' x x x

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' x x x

OPERATING SW ITCH Indicates whether the proposed unit will be able to switch

fuels while operating Yes / No x x x

Deliver Power to Transmission Grid Indicate whether the generator can deliv er power to the

transmission grid x x

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

synchronized to the grid Yes / No x x

OW NERSHIP Identifies the ownership for each generator S=Single ownership

J= Joint ownership

W=Wh olly owned by an other

entity x x x

TURBINES Number of wind turbines x x x

COGENERATOR Indicates whether the generator is associated with a

combined heat and power system Yes / No x x x

SECTOR NAME Plant-level sector name, designated by the primary

purpose, regulatory status and plant-lev el 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 Plant-level sector number, designated by the primary

purpose, regulatory status and plant-lev el 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 x x

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 x x

DUCT BURNERS Indicates whether the unit has duct-burners for

supplementary firing of the turbine exhaust gas x 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 Capacity Increase in summer capacity expected to be realized from

the modification to the equipment x x

Planned Uprates Net W inter Capacity 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 Capacity Decrease in summer capacity expected to be realized

from the derate modification to the equipment x x

Planned Derates Net W inter Capacity 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 PRIME MOVER New prime mover for the planned repowered generator See Table 1 in tab 'Reference

Tables I' x x

# Field Name **Description Notes** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



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

generator See Table 2 in tab 'Reference

Tables I' x x

PLANNED REPOW ER MONTH Planned effective month that the generator is scheduled to

enter operation after the repowering is complete x x

PLANNED REPOW ER YEAR Planned effective year that the generator is scheduled to

enter operation after the repowering is complete x x

Other Modifications Indicates whether there are there other modifications

planned for the generator Yes / No x x

Other Modifications Month Planned effective month that the generator is scheduled to

enter commercial operation after any other planned

modification is complete x x

Other Modifications 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 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 x x x

Pulverized Coal Technology Indicates that the generator uses pulv erized coal

technology x x x

Fluidized Bed Technology Indicates that the generator uses fluidized bed technology x x x

Subcritical Technology Indicates that the generator uses subcritical technology x x x

Supercritical Technology Indicates that the generator uses supercritical technology x x x

Ultrasupercritical Technology Indicates that the generator uses ultra-supercritical

technology x x x

Carbon Capture Technology Indicates that the generator uses carbon capture

technology x x x

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' x x x

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' x x x

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' x x x

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' x x x

STREET ADDRESS Street address of the operator/owner x

COUNTY Name of the county in which the plant is located x x x x

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 W ATER 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 serv ice

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** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



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

sm all power producer status Yes / No x

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

sm all power producer status x

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

exempt wholesale generator status Yes / No x

FERC Exempt W holesale Generator Docket

Number The docket number relating to the FERC qualifying facility

exempt wholesale generator status x

BOILER ID Boiler identification number x x x x x x x

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 x x

FGD ID Flue gas desulfurization identification number x x

FGP ID Flue gas particulate collector identification number x x

FLUE ID Flue identification number x x

STACK ID Stack identification number x x

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

Tables I' x x

TYPE OF BOILER Indicates the standards under which the boiler is operating

as described in the U.S. Env ironmental 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

Rev iew requirements Yes / No x

NSR DATE MONTH Month of issued New Source Rev iew permit x

NSR DATE YR Year of issued New Source Rev iew permit x

NSR PERMIT New Source Rev iew 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 av eraged See Table 5 in tab 'Reference

Tables I' x

PERIOD SULFUR Period of time over which measurements for sulfur dioxide

were av eraged See Table 5 in tab 'Reference

Tables I' x

PERIOD NITROGEN Period of time over which measurements for nitrogen

oxides were av eraged 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** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



# 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) x x x x x

INSERVICE YEAR Actual or projected year of commercial operation of the

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

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

WA STE HEAT INPUT Design waste-heat input rate at maximum continuous

steam flow where a waste-heat boiler is a boiler that

receiv es 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** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



# 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

WE T DRY BOTTOM We t or Dry Bottom where W et 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 hav ing no slag tanks at furnace throat area,

throat area is clear, and bottom ash drops through throat to

bottom ash water hoppers. W=We t

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 activ ated 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 W et 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, pulse x

Mercury Emission Baghouse, Rev erse Air Indicates whether the boiler has a baghouse, rev erse air x

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 serv ed by dry cooling components x

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

water x

# Field Name **Description Notes** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



# WA TER SOURCE CODE Type of cooling water source See Table 7b in tab 'Reference

Tables II' x

WA TER 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-serv ice month for chlorine discharge

control structures and equipment x

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

control structures and equipment x

POND INSERVICE MONTH Cooling ponds actual or projected in-serv ice month x

POND INSERVICE YEAR Cooling ponds actual or projected in-serv ice 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

TOW ER INSERVICE MONTH Cooling towers actual or projected in-serv ice month x

TOW ER INSERVICE YEAR Cooling towers actual or projected in-serv ice year x

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

Tables II' x

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

Tables II' x

TOW ER W ATER RATE Maximum design rate of water flow at 100 percent load x

POW ER 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 TOW ERS 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 Av erage distance below water surface to intake (in feet) x

OUTLET DISTANCE SURFACE Av erage 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 recov ered 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

Remov al Efficiency of Sulfur Remov al efficiency as the percent by weight of gases

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

# Field Name **Description Notes** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



# 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

va lues (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 Av erage flue gas exit temperatures based on the

arithmetic mean of measurements during operating hours

of June, July, and August x

# Field Name **Description Notes** **U t** **i l** **i t** **y P** **l a** **n t** **G e** **n e** **r a** **t o** **r /** **O p** **e r** **a b** **l e** **G e** **n e** **r a** **t o** **r /** **P r** **o p** **o s** **e d** **G e** **n e** **r a** **t o** **r /** **R e** **t i** **r e** **d O** **w n** **e r** **s h** **i p** **M u** **l t** **i F** **u e** **l /** **O p** **e r** **a b** **l e** **M u** **l t** **i F** **u e** **l /** **P r** **o p** **o s** **e d** **M u** **l t** **i F** **u e** **l /** **R e** **t i** **r e** **d I** **n t** **e r** **c o** **n n** **e c** **t i** **o n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ G** **e n** **E n** **v i** **r o** **A s** **s o** **c /** **B o** **i l** **e r** **_ C** **o o** **l E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **D E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **F G** **P E** **n v** **i r** **o A** **s s** **o c** **/ B** **o i** **l e** **r _** **S F** **E n** **v i** **r o** **E q** **u i** **p /** **B o** **i l** **e r** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **n t** **r o** **l s** **E n** **v i** **r o** **E q** **u i** **p /** **C o** **o l** **i n** **g E** **n v** **i r** **o E** **q u** **i p** **/ F** **G D** **E n** **v i** **r o** **E q** **u i** **p /** **F G** **P E** **n v** **i r** **o E** **q u** **i p** **/ S** **t a** **c k** **F l** **u e** 



# EXIT TEMPERATURE W INTER Av erage 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 nex

t calendar year.

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

NOT ex pected to be returned to service in the nex t 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, Ax ial Flow Turbine MW H 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 Tim e

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 ex pected to be returned to service.

WT Wi nd 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 Wi nd 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 (ex pected to go into commercial service within 10 years)

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

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

service

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

reactivate)

TI D 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 Wi nd

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 System s Coordinating Council N NV Never to ex ceed

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 Maritim e 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 Tex

as 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 Tex as

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 Wa ter 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 We t 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 W ater (ex: river, canal, bay)

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

efficiency GW Ground W ater (ex: aquifer, well)

ND Not determined at this time PD Plant Discharge W ater (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 W ater

PL Planned FR Fresh W ater

RE Retired BE Reclaimed W ater (ex: treated wastewater effluent)

SB Standby SA Saline W ater

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 Wa ter

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 Ma**  **nufacturer Description BOILER**  **NOX FGD** 

AA Advanced Air Technologies N N Y

AB Advanced Burner Technologies N Y N

ABB ABB Environm ental Sy stems N Y Y

AC Advanced Combustion Technology N Y N

AEE AEE Von Roll N Y N

AES Alliant Environm ental Solutions N N Y

AM Am erican 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

Sy stems (AUS) N Y N

AX Am erex 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 Bionom ics 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 Chiy oda N N Y

CB Cly de 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 Convey ing Sy stems 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

Sy stems Associates N Y N

DV Davis N Y N

DX Deltex N Y N

EA Eagle Air N Y N

EE Environm ental Engineering N N Y

EEC Environm ental Elem ents Corporation N N Y

EG Energy

and Environm ental 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 Environm ental 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 Ma**  **nufacturer Description BOILER**  **NOX FGD** 

GR GE Energy

and Environm ental Research Corp (GEEER) N Y N

HA Hamon N N Y

HL Holm an 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 Roy ce N Y N

RV RV Industries N Y N

SB Sm artBurn N Y N

SC Southern Company N Y N

SHU Saarberg-Holter Umweltechnick GmbH N N Y

SK Schenck W eigh Feeders N N Y

SM Sm oot Company N N Y

SW Siem ens-W estinghouse N Y N

TC Turbosonic N Y Y

TEC Thermal Equipment Corporation N Y N

TH Thy ssen/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

WA P Wh eelabrator Air Pollution Control N N Y

ZC Zeeco N Y N

AI Aalborg Industries Y N N

# Table 13: Environmental Equipment Manufacturer Codes

**Code Ma**  **nufacturer Description BOILER**  **NOX FGD** 

AL Alstom Y Y Y

AS Am erican Shack Y N N

AT Applied Thermal Sy stems Y Y N

BR BROS Y N N

BW Babcock and W ilcox 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 W orks Y N N

ET Entek Y Y N

FW Foster W heeler 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 Py ro 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 We stinghouse Y N N

WG We igl Engineering Y Y N

WI Wi ckes Y N N

ZN Zurn Y N Y