860 Instructions_2022

Electric Power and Renewable Electricity Surveys

860 Instructions_2022

OMB: 1905-0129

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FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

PURPOSE

Form EIA-860 collects data on the status of existing electric generating plants and associated
equipment (including generators, boilers, cooling systems and air emission control systems)
in the United States and Puerto Rico, and those scheduled for initial commercial operation
within 5 or 10 years, as applicable. The data from this form appear in EIA publications and
public databases. The data collected on this form are used to monitor the current status and
trends of the electric power industry and to evaluate the future of the industry.

REQUIRED
RESPONDENTS

Existing plants are required to respond to Form EIA-860 if:
•

The plant’s total generator nameplate capacity is 1 Megawatt (MW) or greater and

•

The plant’s generator(s), or the facility in which the generator(s) resides, are connected to
the local or regional electric power grid and have the ability to draw power from or deliver
power to the grid

If the existing plant is jointly-owned, only the operator of that plant should respond to Form
EIA-860.
Proposed plants are required to respond to Form EIA-860 if:
•

The plant’s proposed total generator(s) nameplate capacity will be 1 MW or greater; and

•

The plant’s proposed generator(s), or the facility in which the proposed generator(s)
resides, will be connected to the local or regional electric power grid and will be able to
draw power from or deliver power to the grid; and

•

The plant meets one of these two conditions:
o

The plant will be primarily fueled by coal or nuclear energy and is expected to
begin commercial operation within 10 years; or

The plant will be primarily fueled by energy sources other than coal or nuclear
energy and is expected to begin commercial operation within 5 years.

The five and ten year reporting horizons are calculated from January 1 of the
reporting year. For example, reports made in 2014 should reflect plans through
December 31, 2018 (five year horizon) and December 31, 2023 (ten year horizon).
If the proposed plant is jointly-owned, only the planned operator of that plant should respond
to Form EIA-860.
Generators located in Alaska, Hawaii, and Puerto Rico are required to respond to Form EIA860 if:
•

The generators are connected to a local or regional transmission or distribution system
that supplies power to the public.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

For all plants:
•

The total generator nameplate capacity is the sum of the maximum ratings in MW on
the nameplates of all applicable generators at a specific site. For photovoltaic solar,
the total generator nameplate capacity is the sum of the AC ratings of the array.

Note that energy storage systems that output electricity or otherwise store energy for the
purpose of electricity output are considered to be generators.
RESPONSE DUE
DATE

1) Submit the completed Form EIA-860 directly to EIA annually between the first business
day of January and the last business day of February. For existing equipment the filing
should reflect the status of that equipment as of December 31 of the reporting year. For
proposed actions (e.g. planned retirements, planned additions, or planned modifications)
the filing should reflect the most up to date information available to the respondent at the
time the filing is made. Note: if EIA is late in opening its Internet Data Collection system
the filing deadline will be extended day for day (respondents will be notified by email).
2) If subsequent to the submission date for the annual filing a respondent either (a) takes an
action, not previously reported to EIA, to add, retire, or uprate/derate generating units or
environmental control equipment; or (b) makes a decision, not previously reported to EIA,
to add, retire, or uprate/derate generating units or environmental control equipment; then
the respondent should notify EIA as soon as practical by an email to EIA-860@eia.gov.
EIA staff will then assist the respondent in amending its filing or making a first-time filing.

METHODS OF
FILING
RESPONSE

If this is your first time submitting Form EIA-860, fill out all applicable portions of this form and
submit it to: EIA-860@eia.gov. All subsequent filings can be done electronically using EIA’s
secure e-filing system. This system uses security protocols to protect information against
unauthorized access during transmission.
If you have any questions on filling out this form or have not registered with the e-file Single
Sign-On (SSO) system, send an email requesting assistance to: EIA-860@eia.gov.
If you have registered with SSO, log on at https://signon.eia.doe.gov/ssoserver/login.
Please retain a completed copy of this form for your files.

CONTACTS

If you have a question about the data requested on this form, email EIA-860@eia.gov
(preferred) or contact one of the survey managers listed below.
Alex Mey

Suparna Ray

Raymond Chen

Alex.Mey@eia.gov
(202) 287-5868

Suparna.Ray@eia.gov
(202) 586-5077

Raymond.Chen@eia.gov
(202) 287-6532

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT
GENERAL
INSTRUCTIONS

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

1. Verify all EIA-provided information. If incorrect, revise the incorrect entry and provide the
correct information. Provide any missing information. If filing a paper copy of this form,
typed or legible handwritten entries are acceptable.
2. Check all data for consistency with the same or related data that appear in more than one
schedule of this form or in other forms or reports submitted to EIA. Use SCHEDULE 7 to
explain inconsistencies or anomalies with data or to provide any further details that are
pertinent to the data.
3. For planned power plants and/or planned equipment, use planning data to complete the
form.
4. Number formats:
a. Report in whole numbers (i.e., no decimal points), except where explicitly instructed
to report otherwise.
b. Indicate negative amounts by using a minus sign before the number.
c.

Report date information as a two-digit month and four-digit year, e.g., “11 - 1980.”

5. The reporting year is the calendar year that you are filing the survey for. For example, if
you are reporting data as of December 31, 2013, then the reporting year is 2013.
6. Furnish the requested information to reflect the status of your current or planned
operations as of the end of the reporting year. If your company no longer operated a
specific power plant as of December 31, report the name of the operator as of December
31 along with related contact information (including contact person’s name, telephone
number, and email address, if known) in SCHEDULE 7. Do not complete the form for that
power plant.
7. The blank hardcopy form can be downloaded from
www.eia.gov/cneaf/electricity/page/forms.html.
8. For definitions of terms, refer to the U.S. Energy Information Administration glossary at
www.eia.gov/glossary/index.html.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT
ITEM-BY-ITEM
INSTRUCTIONS

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

SCHEDULE 1. IDENTIFICATION
1. Survey Contact: Provide the name, title, address, telephone number, cell phone
number, and email address for the person that will be the primary contact for this form.
2. Supervisor of Survey Contact: Provide the name, title, address, telephone number, cell
phone number and email address of the primary contact’s supervisor.
3. Entity Name and Address: Provide the name and address of the entity that is reporting
for the plants reported on this form.
4. Entity Relationship: Indicate the relationship between the reporting entity and the power
plants reported on this form. Select all that apply: owner, operator, asset manager or
other. If you select “Other,” provide details in SCHEDULE 7.
5. Entity Type: Select the category that best describes the entity that owns and/or operates
the plants reported on this form from the list below:
•
•
•
•

Cooperative
Federally-Owned Utility
Investor-Owned Utility (IOU)
Independent Power Producer (IPP)

•
•
•
•
•

Municipally-Owned Utility
Political Subdivision
State-Owned Utility
Industrial
Commercial

SCHEDULE 2. POWER PLANT DATA
Complete one section for each power plant. A plant can consist of a single generator or of
multiple generators at a single location. In general a single location will be a contiguous piece
of property. Breaks in property lines from publicly owned roads should be ignored when
considering whether property is contiguous. Note that in some case a single facility may
expand over nearby but discontinuous pieces of property. For example universities in an
urban setting may reside on nearby but discontinuous pieces of property. For purposes of
reporting the generators owned or operated by this university on nearby but discontinuous
pieces of property would be considered to be part of one facility.
For the purpose of wind plants and solar plants, a plant can be defined based on phased
expansions or other grouping methodologies used by the reporting entity. Include all plants
that are (1) in commercial operation, (2) capable of commercial operation but currently
inactive or on standby, or (3) expected to be in commercial operation within 10 years in the
case of coal and nuclear units, or within 5 years for all other units.
1. For line 1, What are the plant name and EIA Plant Code for this plant? Enter the
name of the power plant. When assigning a name to a plant, use its full name (i.e. do not
shorten Alpha Generating Station to Alpha) and include as much detail as possible (e.g.
Beta Paper Mill, Gamma Landfill Gas Plant, Delta Dam). The plant name may include
additional details like owner name and business structure but “Corporation” should be
shorted to “Corp” and “Incorporated” should be shortened to “Inc.” Enter “NA 1,” “NA 2,”
etc., for unnamed planned facilities.
The EIA Plant Code is generated and provided by EIA upon the initial submission of the
Form EIA-860.
2. For line 2, What is this plant’s physical address? Enter the physical address where
the plant is located or will be located. Do not enter the plant’s mailing address. Do not
4

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

enter the address of the plant’s operator, holding company or other corporate entity. If
the plant does not have a single, permanent address, indicate it with a note in
SCHEDULE 7.
3. For line 3, What is this plant’s latitude and longitude? Enter the latitude and longitude
of the plant in decimal format. The coordinates should relate to a central point within the
plant’s property such as a generator. Do not enter the coordinates of the plant’s
operator, holding company or other corporate entity.
4. For line 4, Which North American Electric Reliability Corporation region does this
plant operate in? Select the North American Electric Reliability Corporation (NERC)
region in which the plant operates.
5. For line 5, What is this plant’s balancing authority? Select the plant’s Balancing
Authority. A balancing authority manages supply, demand, and interchanges within an
electrically defined area. It may or may not be the same as the Owner of
Transmission/Distribution Facilities, requested below. If you believe the plant is
connected to more than one balancing authority, explain in SCHEDULE 7.
6. For line 6, What is the name of the principle water source used by this plant for
cooling or hydroelectric generation? Enter the name of the principal source from
which cooling water or water for generating power for hydroelectric plants is obtained. If
water is from an underground aquifer, provide name of aquifer, if known. If name of
aquifer is not known, enter “Wells.” Enter “Municipality” if the water is from a municipality.
Enter “UNK” for planned facilities for which the water source is not known. Enter “NA” for
plants that do not use a water source for cooling or hydroelectric generation.
7. The response for line 7, What is this plant’s steam plant type? is entered by EIA staff
for all plants. If you are filling out this form on EIA’s Internet Data Collection System and
believe that the designation is not accurate, please contact the survey manager.
8. For line 8, Which North American Industry Classification System (NAICS) Code that
best describes this plant’s primary purpose? Enter the North American Industry
Classification System (NAICS) code found in Table 29 at the end of these instructions
that best describes the primary purpose of the plant. Electric utility plants and
independent power producers whose primary purpose is generating electricity for sale
will generally use code 22. For generators whose primary business is an industrial or
commercial process (e.g., paper mills, refineries, chemical plants, etc.) and for which
generating electricity is a secondary purpose, use a code other than 22. For plants with
multiple purposes, select the NAICS code corresponding to the line of business that
generates - or where the chartered intent of the line of business is intended to generate the highest value for the company.

9. For lines 9a and 9b, Does this plant have Federal Energy Regulatory Commission
Qualifying Facility (QF) Cogenerator status? Check “Yes” or “No”; if “Yes” provide all
QF docket numbers granted to the facility. Please do not include the prefix (e.g. QF,
EWG, etc.) when entering the docket numbers. Only include the numerical portion of the
docket number, including dashes.
10. For lines 10a and 10b, Does this plant have Federal Energy Regulatory Commission
Qualifying Facility (QF) Small Power Producer status? Check “Yes” or “No”; if “Yes”
5

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

provide all QF docket numbers granted to the facility. Please do not include the prefix
(e.g. QF, EWG, etc.) when entering the docket numbers. Only include the numerical
portion of the docket number, including dashes.
11. For lines 11a and 11b, Does this plant have Federal Energy Regulatory Commission
Qualifying Facility (QF) Exempt Wholesale Generator status? Check “Yes” or “No”; if
“Yes,” provide all QF docket numbers granted to the facility. Please do not include the
prefix (e.g. QF, EWG, etc.) when entering the docket numbers. Only include the
numerical portion of the docket number, including dashes.
12. For line 12a, Is there an ash impoundment (e.g. pond, reservoir) at the plant?
Indicate whether there is an impoundment (e.g. pond, reservoir) at the plant where fly
ash, bottom ash or other ash byproducts can be stored.
If you entered “yes" to Question 12a, for Question 12b, Is this ash impoundment
lined? Indicate whether the impoundment is lined and, in Question 12c, What was this
ash impoundment’s status as of December 31 of the reporting year? select the
impoundment’s status from the list of codes in Table 1 below.
Table 1. Ash Impoundment Status Codes and Descriptions
Ash Impoundment
Status Code
OP
SB
OA
OS

Ash Impoundment Status Code Description
Operating - in service (commercial operation)
Standby/Backup - available for service but not normally used
for this reporting period
Out of service – was not used for some or all of the reporting
period but is expected to be returned to service in the next
calendar year
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

13. For line 13, Who is the current owner of the transmission lines and/ or distribution
facilities that this plant is interconnected to? Enter the name of the current owner of
the transmission or distribution facilities to which the plant is interconnected and which
receives or may receive the plant’s output. If the plant is interconnected to multiple
owners, enter the name of the principal owner and list the other owners and their roles in
SCHEDULE 7.
14. For line 14, What is this plant’s grid voltage at the point(s) of interconnection to
transmission or distribution facilities? Enter up to three grid voltages, in kilovolts, at
the points of interconnection to the transmission/distribution facilities. If the plant is
interconnected to more than three transmission/distribution facilities, enter the three
highest grid voltages.
15. For Line 15, Does this facility have energy storage capabilities? Indicate whether
this facility has the capability to store excess electrical generation. Please note energy
storage is not limited to only batteries. Examples of energy storage capabilities that
should be reported include batteries, pumped storage, thermal storage supporting

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

electrical generation, flywheels, and compressed air. Note emergency battery rooms
used only for the safe shutdown of generator units do not need to be reported. Also note
that if a facility has an integrated energy storage system located offsite then the energy
storage system does not need to be reported at this facility; however the remote energy
storage system may need to be reported as a separate facility if it has generating
capacity >1 MW.
16. Plants that receive natural gas should answer lines 16a-16d.
For line 16a, If this facility has an existing natural gas-fired generator for which it
has pipeline connection to a Local Distribution Company (LDC), provide the name
of the LDC, Identify the name(s) of the a natural gas Local Distribution Company to
which the facility is directly connected.
For line 16b, If this facility has an existing natural gas-fired generator and has a
pipeline connection other than to a Local Distribution Company, provide the
name(s) of the owner or operator of each natural gas pipeline that connects directly to
this facility or that connects to a lateral pipeline owned by this facility. Identify the
name(s) of the natural gas pipeline(s) that connect to the facility or that connect to a
lateral pipeline owned by the facility.
For line 16c, Does this facility have on-site natural gas storage? Specify whether the
facility has on-site natural gas storage.
For line 16d, If this facility has on-site storage of natural gas, does the facility have
the capability to store the natural gas in the form of liquefied natural gas? Specify
whether the facility has the capability to store natural gas in the form of liquefied natural
gas.

SCHEDULE 3. GENERATOR INFORMATION
Complete SCHEDULE 3 for each generator at this plant that is:
•

In commercial operation;

•

Capable of commercial operation but currently inactive or on standby;

•

Retired;

•

Expected to be in commercial operation within 10 years in the case of coal and
nuclear generators; or

•

Expected to be in commercial operation within 5 years for all generators other than
coal and nuclear generators.

1. Do not report auxiliary generators that are typically used solely for blackstart or
maintenance purposes.
2. For generators associated with wind and solar plants, a generator can be any grouping of
photovoltaic panels or wind turbines with similar characteristics (e.g. manufacturer,
technical parameters, location, commercial operating date, etc.).

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

3. Treat energy storage facilities as generators and provide all necessary data requested
below.
4. Include generators with maximum capability of less than 1 MW if located at a plant with a
total nameplate capacity of 1 MW or greater.
5. To report a new generator, use a separate and blank section of SCHEDULE 3.
6. To report a new generator that has replaced one that is no longer in service, update the
status of the generator that has been replaced along with other related information (e.g.,
retirement date), then use a separate and blank section of SCHEDULE 3 to report all of
the applicable data about the new generator.
7. Each generator must be uniquely identified within a plant. The EIA cannot use the same
generator ID for the new generator that was used for the generator that was replaced.
SCHEDULE 3. PART A. GENERATOR INFORMATION – GENERATORS
1. For line 1, What is the generator ID for this generator? Enter the unique generator
identification commonly used by plant management. Generator identification should be
the same identification as reported on other EIA forms to be uniquely defined within a
plant. For new wind and solar projects a unique generator ID should be used for each
installation phase of the project. For new solar projects also select unique generator IDs
for fixed tilt arrays having different tilt or azimuth angles. This identification code is
restricted to five characters and cannot be changed once provided to EIA.
2. For line 2, What is this generator’s prime mover? Enter one of the prime mover codes
in Table 2. For combined cycle units, a prime mover code must be entered for each
generator.
Table 2. Prime Mover Codes and Descriptions
Prime Mover Code
BA
CE
CP
FW
PS
ES
ST
GT
IC
CA
CT
CS
CC

Prime Mover Description
Energy Storage, Battery
Energy Storage, Compressed Air
Energy Storage, Concentrated Solar Power
Energy Storage, Flywheel
Energy Storage, Reversible Hydraulic Turbine (Pumped
Storage)
Energy Storage, Other (specify in SCHEDULE 7)
Steam Turbine, including nuclear, geothermal and solar steam
(does not include combined cycle)
Combustion (Gas) Turbine (does not include the combustion
turbine part of a combined cycle; see code CT, below)
Internal Combustion Engine (diesel, piston, reciprocating)
Combined Cycle Steam Part
Combined Cycle Combustion Turbine Part
Combined Cycle Single Shaft (combustion turbine and steam
turbine share a single generator)
Combined Cycle Total Unit (use only for plants/generators that
are in planning stage, for which specific generator details

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

HA
HB
HK
HY
BT
PV
WT
WS
FC
OT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

cannot be provided)
Hydrokinetic, Axial Flow Turbine
Hydrokinetic, Wave Buoy
Hydrokinetic, Other (specify in SCHEDULE 7)
Hydroelectric Turbine (includes turbines associated with
delivery of water by pipeline)
Turbines Used in a Binary Cycle (including those used for
geothermal applications)
Photovoltaic
Wind Turbine, Onshore
Wind Turbine, Offshore
Fuel Cell
Other (specify in SCHEDULE 7)

Combined heat and power systems often generate steam with multiple sources and
generate electric power with multiple prime movers. For reporting purposes, a simple
cycle prime mover should be distinguished from a combined cycle prime mover by
determining whether the power generation part of the steam system can operate
independently of the rest of the steam system. If these system components cannot be
operated independently, then the prime movers should be reported as combined cycle
types.
3. For line 3, What is this generator’s unit or multi-generator code? If this generator
operates as a single unit with another generator (including as a combined cycle unit),
enter a unique 4-character code for the unit. All generators that operate as a unit must
have the same unit code. Leave blank if this generator does not operate as a single unit
with another generator.
4. For line 4, What is this generator’s ownership code? Identify the ownership for each
generator using the following codes:
Table 3: Generator Ownership Codes and Descriptions
Ownership
Code
S
J
W

Ownership Code Description
Single ownership by respondent
Jointly owned with another entity
Wholly owned by an entity other than respondent

5. For line 5, Does this generator have duct burners for the supplementary firing of
the turbine exhaust gas? Check “Yes” if 1) the generator has a combined cycle prime
mover code of “Combined Cycle Steam Part (CA)” “Combined Cycle Single Shaft (CS),”
or “Combined Cycle Total Unit (CC,)” and 2) if the unit has duct-burners for
supplementary firing of the turbine exhaust gas. Otherwise, check “No.”
6. For line 6, Can this generator operate while bypassing the heat recovery steam
generator? Check “Yes” if 1) the generator has a combined cycle prime mover code of
“Combined Cycle Combustion Turbine Part (CT)” or “Combined Cycle Total Unit (CC)”
and 2) the combustion turbine can operate while bypassing the heat recovery steam
generator. Otherwise, check “No.”

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

7. For line 7a, For this generator what is the RTO/ISO LMP price node designation? If
this generator operates in an electric system operated by a Regional Transmission
Organization (RTO) or Independent System Operator (ISO) and the RTO/ISO calculates
a nodal Locational Marginal Price (LMP) at the generator location, then provide the nodal
designation used to identify the price node in RTO/ISO LMP price reports.
For line 7b, For this generator what is the RTO/ISO location designation for
reporting wholesale sales data to FERC? If this generator operates in an electric
system operated by a Regional Transmission Organization (RTO) or Independent
System Operator (ISO) and the generator’s wholesale sales transaction data is reported
to FERC for the Electric Quarterly Report, then provide the designation used to report the
specific location of the wholesale sales transactions to FERC. In many cases the
RTO/ISO location designation may be the same as the RTO/ISO LMP price node
designation submitted in line 7a. In these cases enter the same response in both line 7a
and line 7b.

SCHEDULE 3, PART B. GENERATOR INFORMATION – EXISTING GENERATORS
Complete one SCHEDULE 3, Part B for each generator at this plant that is in commercial
operation.
1.

For line 1a, What is the nameplate capacity for this generator? Report the highest
value on the generator nameplate in MW rounded to the nearest tenth, as measured in
alternating current (AC). If the nameplate capacity is expressed in kilovolt amperes
(kVA), first convert the nameplate capacity to kilowatts by multiplying the corresponding
power factor by the kVA and then convert to megawatts by dividing by 1,000. Round this
value to the nearest tenth. If generator nameplate capacity is less than net summer
capacity, provide the reason(s) in SCHEDULE 7. In order to correct erroneous
nameplate reported in prior year(s) send an image of the nameplate to EIA860@eia.gov.
For line 1b, What is the nameplate power factor for this generator? Enter the power
factor stamped on the generator nameplate. This should be the same power factor used
to convert the generator’s kilovolt-ampere rating (kVA) to megawatts (MW) as directed
for line 1a above. Solar photovoltaic systems, wind turbines, batteries, fuel cells, and
flywheels may skip this question.

For line 2a, What is this generator’s net capacity? Enter the generator's net summer
and net winter capacities for the primary energy source. Report in MW rounded to the
nearest tenth, as measured in alternating current (AC). For generators that are out of
service for an extended period or on standby, report the estimated capacities based on
historical performance. For generators that are tested as a unit, report a single aggregate
net summer capacity and a single aggregate net winter capacity. For hydroelectric
generators, report the instantaneous capacity at maximum water flow. For solar
photovoltaic generators report the peak net capacity during the day for the generator
assuming clear sky conditions on June 21 for summer capacity and on December 21 for
winter capacity; assume average seasonal temperatures and average wind speeds for
June 21 and December 21, respectively. If net capacity is only available as direct
current (DC), estimate the effective AC output and explain in SCHEDULE 7.
Answer the question on lines 2b only if the generator is powered by a photovoltaic solar

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

technology
For line 2b, What is the net capacity of this photovoltaic generator in direct current
(DC) under standard test conditions (STC) of 1000 W/m2 solar irradiance and 25
degrees Celsius PV module temperature? Enter the sum of the DC capacity ratings of
the photovoltaic modules associated with this generator.
3.

For line 3, What minimum load can this generator operate at continuously? Enter
the minimum load (MW) at which the unit can operate continuously. Solar-powered
generators are not required to answer this question. For generators operating as a
single unit that entered a Unit Code (Multi-Generator Code) on SCHEDULE 3, Part A,
Line 3, provide the load when all generators are operating at their minimum load.

For line 4a, Was an uprate or derate project completed on this generator during the
reporting year? Check “Yes” if an uprate or derate project was implemented during the
reporting year. Check “No” if it was not. If both an uprate and derate were implemented
during the reporting year, check “Yes” and explain in SCHEDULE 7.
For line 4b, When was this uprate or derate project completed? Enter the date when
the uprate or derate project identified in line 4a was completed.

For line 5a, What was the status of this generator as of December 31 of the
reporting year? Enter one of the following status codes:

Table 4. Generator Status Codes and Descriptions
Code
OP
SB
OS
OA
RE

Code Description
Operating - in service (commercial operation) and producing some
electricity. Includes peaking units that are run on an as needed
(intermittent or seasonal) basis.
Standby/Backup - available for service but not normally used (has
little or no generation during the year) for this reporting period.
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.
Out of service – was not used for some or all of the reporting
period but is expected to be returned to service in the next
calendar year.
Retired - no longer in service and not expected to be returned to
service.

For line 5b, If Is this generator equipped to be synchronized to the grid? If the status
code entered on line 5a is standby (SB), check “Yes” if the generator is currently
equipped to be synchronized to the grid when operating. Check “No” if it is not.
6.

For line 6, When did this generator begin commercial operation? Enter the month
and year of initial commercial operation in the format MM-YYYY.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

For line 7, When was this generator retired? Enter the month and year that the
generator was retired in the format (MM-YYYY).

For line 8, If this generator will be retired in the next ten years, what is its estimated
retirement date? If you expect this generator to be retired in the next 10 years, enter
your best estimate for this planned retirement date in the format MM-YYYY.

For line 9 Is this generator associated with a combined heat and power system?
Check “Yes” if this generator is associated with a combined heat and power system.
Check “No” if it is not.

10. For line 10, Is this generator part of a topping or bottoming cycle? If you checked
“Yes” on line 9, check “Topping” if this generator is part of a topping cycle. In a topping
cycle system, electricity is produced first and any waste heat from that production is used
in a manufacturing or commercial application. Check “Bottoming” if this generator is part
of a bottoming cycle. In a bottoming cycle system, thermal output is used in a process
other than electricity production and any waste heat is then used to produce electricity.
11. For line 11, What is this generator’s predominant energy source? Enter the energy
source code for the fuel used in the largest quantity (Btus) during the reporting year to
power the generator. For generators that are out of service for an extended period of
time or on standby, report the energy sources based on the generator’s latest operating
experience. For generators driven by turbines using steam that is produced from waste
heat or reject heat, report the original energy source used to produce the waste heat
(reject heat). Do not include fuels expected to be used only for start-up or flame
stabilization. Select the appropriate energy source code from Table 28 in these
instructions.
12. For line 12, What are the energy sources used by this generator’s combustion
units for start-up and flame stabilization? If the prime mover is steam turbine (ST),
report the energy sources used by the combustion unit(s) associated with this generator
for start-up and flame stabilization; otherwise leave blank. Select the appropriate energy
source code from Table 28 in these instructions.
13. For line 13, What is this generator’s second most predominant energy source?
Enter the energy source code for the energy source used in the second largest quantity
(Btus) during the reporting year to power the generator. DO NOT include a fuel used only
for start-up or flame stabilization. For generators driven by turbines using steam that is
produced from waste heat or reject heat, report the original energy source used to
produce the waste heat or reject heat. Select the appropriate energy source code from
Table 28 in these instructions.
14. For line 14, What other energy sources are used by the generator? Enter the codes
for other energy sources that can be used by the generator to generate electricity: first,
list the energy sources actually used in order of predominance (based on quantity of
Btus), then list ones that the generator was capable of using but was not used to
generate electricity during the last 12 months. For generators that are out of service for
an extended period of time or on standby, report the energy sources based on the
generator’s latest operating experience. For generators driven by turbines using steam
that is produced from waste heat or reject heat, report the original energy source used to
produce the waste heat or reject heat. Select the appropriate energy source codes from
Table 28 in these instructions.
15. For line 15, Is this generator part of a solid fuel gasification system? Check “Yes” if

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

this generator is part of a solid fuel gasification system. Check “No” if it is not.
16. For line 16, What is the tested heat rate for this generator? Enter the tested heat rate
under full load conditions for all combustible-fueled generators and nuclear-fueled
generators. The tested heat rate is the amount of fuel, measured in British thermal units
(Btus) necessary to generate one net kilowatt-hour of electric energy. Do not report the
actual heat rate, which is the quotient of the total Btu(s), consumed and total net
generation. If generators are tested as a unit (not tested individually), report the same
test result for each generator. For generators that are out of service for an extended
period or on standby, report the heat rate based on the unit’s latest test. If the generator
is associated with a combined heat and power (CHP) system, and no tested heat rate
data are available, report either the manufacturer’s specification for heat rate or an
estimated heat rate. DO NOT report a heat rate that includes the fuel used for the
production of useful thermal output. For Internal Combustion units, a manufacturer’s
specification or estimated heat rate should be reported, if no tested heat rate is available.
If the reported value is not a tested heat rate, specify in SCHEDULE 7.
This information will be protected and not disclosed to the extent that it satisfies the
criteria for exemption under the Freedom of Information Act (FOIA), 5 U.S.C. §552, the
Department of Energy (DOE) regulations, 10 C.F.R. §1004.11, implementing the FOIA,
and the Trade Secrets Act, 18 U.S.C. §1905
17. For line 17, What fuel was used to determine this generator’s tested heat rate?
Enter the fuel code for the fuel used to determine the heat rate reported in line 16. Enter
“M” if multiple fuels were used to calculate the heat rate reported in line 16. For
generators driven by turbines using steam that is produced from waste heat or reject
heat, report the original energy source used to produce the waste or reject heat). Select
appropriate energy source codes from Table 28 in these instructions.
18. For line 18, Is the generator associated with a carbon dioxide capture process?
Check “Yes” if this generator is associated with carbon dioxide capture. Check “No” if it
is not.
19. For line 19, How many wind turbines or hydrokinetic buoys are there at this
generator? Wind generators should enter the number of wind turbines and hydrokinetic
generators should enter the number of hydrokinetic buoys. All other generators should
enter 0.
20. Line 20 is reserved for future use.
21. For line 21, What is the minimum amount of time required to bring this generator
from cold shut down to full load? Select the minimum amount of time required to bring
the unit to full load from cold shutdown. Wind and solar-powered generators should not
answer this question.
22. Line 22 is reserved for future use.
Answer questions on lines 23 and 24 only if generator is fueled by coal or petroleum coke
23. For line 23, What combustion technology applies to this generator? Select the
appropriate combustion technology that applies to the generator.
24. For line 24, What steam conditions apply to this generator? Select the appropriate
steam conditions that apply to the unit.
Answer questions on lines 25 through 28 only if generator is wind-powered
13

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

25. For line 25, What is the predominant manufacturer of the turbines at this
generator? Enter the predominant manufacturer of the turbines at the generator. If the
predominant manufacturer is not known, enter “UNKNOWN.”
26. For line 26, What is the predominant turbine model number at this generator? Enter
the predominant model number. If the predominant model number is not known, enter
“UNKNOWN.”
27. On line 27a, What is the average annual wind speed at this generator site? Enter the
average annual wind speed in miles per hour for the turbines included in the generator. If
more than one value exists, select the one that best represents the turbines.
On line 27b, What is the International Electrotechnical Commission wind quality
class for turbines included in this generator? Select the wind quality class for the
turbines included in the generator, as defined by the International Electrotechnical
Commission (IEC 61400-1 ed. 2) and Table 5 below. If more than one wind class exists,
select the one that best represents the turbines.
Table 5. Wind Quality Class and Descriptions
Class

Annual Average
Wind Speed

Extreme 50-Year
Gust

Class 1 – High Wind

10 m/s (22.4 mph)

70 m/s (156 mph)

Class 2 – Medium Wind

8.5 m/s (19.0 mph)

59.5 m/s (133 mph)

Class 3 – Low Wind

7.5 m/s (16.8 mph)

52.5 m/s (117 mph)

Class 4 – Very Low
Wind

6 m/s (13.4 mph)

42 m/s (94 mph)

Turbulence
Intensity
A: 0.210
B: 0.180
A: 0.226
B: 0.191
A: 0.240
B: 0.200
A: 0.270
B: 0.220

28. On line 28, What is the hub height for the turbines in this generator? Enter the hub
height in feet for the turbines at the generator. If this generator consists of turbines with
multiple hub heights, select the one that best represents all of the turbines.
Answer questions on lines 29 through 33 only if generator is powered by photovoltaic or
concentrated solar thermal technology
29. On line 29, What are the solar tracking, concentrating and collector technologies
used at this generator? Select all applicable solar tracking, concentrating or collector
technologies used at the unit. If you select “Other,” provide details in SCHEDULE 7.
30. On line 30a, For generators having fixed tilt technologies or single-axis
technologies with a fixed azimuth angle, what is the azimuth angle of the unit?
Provide the azimuth angle of the unit (Specify an angle ranging from 0 degrees to 359
degrees: North = 0 degrees, East = 90 degrees, South = 180 degrees, and West = 270).
If the units included in the “generator” have various azimuth angles provide a
representative angle. Skip this question for units configured with an East-West Fixed Tilt
(alternating rows) technology.
On line 30b, For generators having fixed tilt technologies or single-axis
technologies with a fixed tilt angle, what is the tilt angle of the unit? Provide the tilt
14

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

angle of the unit (Specify an angle ranging from 0 degrees to 90 degrees: horizontal
surface = 0 degrees, vertical surface = 90 degrees). If the units included in the
“generator” have various tilt angles provide a representative angle.

31. On line 31, What materials are the photovoltaic panels included in this generator
made of? Select the material of the Photovoltaic panels. If the panels included in the
“generator” are made of different materials, select all materials used. If you select
“Other,” provide details on the material in SCHEDULE 7.
32. On line 32a, Is the output from this generator part of a net metering agreement?
Indicate whether the output from this generator is part of an arrangement that allows
output from renewable resources to be credited against a customer’s electric bill. For
purposes of this question do not include virtual net metering agreements (see the
instructions to line 33a for the definition of virtual net metering).
On line 32b, If the output from this generator is part of a net metering agreement
how much DC capacity (in MW) is part of the net metering agreement (exclude
virtual net metering)? Specify the amount of DC capacity from the generator that is part
of a net metering agreement. For purposes of this question do not include capacity that
is part of a virtual net metering agreement.
33. On line 33a, Is the output from this generator part of a known virtual net metering
agreement? Indicate whether the output from this generator is part of a known billing
arrangement that allows multiple energy customers to receive net metering credit from a
shared onsite or remote renewable energy system much as if it was located behind the
customer’s own meter.
On line 33b, If the output from this generator is part of a known virtual net metering
agreement how much DC capacity (in MW) is part of the known virtual net
metering? Specify the amount of DC capacity from the generator that is part of a known
virtual net metering agreement.
Answer questions on lines 34 through 40 only if generator is an energy storage device other
than pumped storage or thermal storage (examples include battery, flywheel, and
compressed air).
34. On line 34, What is the nameplate energy capacity (MWh)? Specify the nameplate
energy capacity

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

35. On line 35, What is the maximum charge rate (MW)? Specify the maximum charge
rate
36. On line 36, What is the maximum discharge rate (MW)? Specify the maximum
discharge rate
37. On line 37, For battery applications, what electro-chemical storage technology(s)
are used? Enter the electro-chemical storage technology(s) used for batter applications.
Select appropriate technology codes from Table 5b in these instructions.
Table 5b. Electro-chemical Storage Technology Codes and Descriptions
Electro-chemical
Storage
Technology Code

Electro-chemical Storage Technology Description

ECC

Electro-chemical capacitor

FLB

Flow battery

PBB

Lead-acid battery

LIB

Lithium-ion battery

MAB

Metal air battery

NIB

Nickel based battery

NAB

Sodium based battery

OTH

Other (specify in SCHEDULE 7)

38. On line 38, What is the nameplate reactive power rating for the energy storage
device? Specify the nameplate reactive power rating for the energy storage device.
39. On line 39, Which enclosure type best describes where the generator is located?
Select the enclosure type that best describes where the generator is located. Select
appropriate enclosure type codes from Table 5c in these instructions
Table 5c. Storage Technology Enclosure Type Codes and Descriptions
Enclosure Type
Code

Enclosure Type Code Description

Building

Containerized - Stationary

Containerized - Transportable

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Other (specify in SCHEDULE 7)

40. On line 40, For which applications did this energy storage device serve during the
reporting year (select all that apply)? Select all applications for which this energy
storage device served during the reporting year.
Lines 41-44 apply to proposed changes to existing generators
41. If a capacity uprate is planned within the next 10 years, answer Questions 41a – 41c.
For line 41a, What is the expected incremental increase in the net summer
capacity? If an uprate is planned within the next 10 years enter the incremental amount
by which the net summer capacity is expected to increase. If no uprate is planned in the
next ten years, leave this blank.
For line 41b, What is the expected incremental increase in the net winter capacity?
If an uprate is planned within the next 10 years, enter the incremental amount by which
the net winter capacity is expected to increase. If no uprate is planned in the next ten
years, leave this blank.
For line 41c, What is the planned effective date for this capacity uprate? If an uprate
is planned within the next 10 years, enter the date on which the generator is scheduled to
re-enter commercial operation after the planned uprate. Enter the date in the format MMYYYY. If no uprate is planned in the next 10 years, leave this blank.
42. If a capacity derate is planned within the next 10 years, answer Questions 42a – 42c.
For line 42a, What is the expected incremental decrease in the net summer
capacity? If a derate is planned within the next 10 years, enter the incremental amount
by which the net summer capacity is expected to decrease. If no derate is planned in the
next 10 years, leave this blank.
For line 42b, What is the expected incremental decrease in the net winter capacity?
If a derate is planned within the next 10 years, enter the incremental amount by which
the net winter capacity is expected to decrease. If no derate is planned in the next ten
years, leave this blank.
For line 42c, What is the planned effective date for this capacity derate? If a derate
is planned in the next 10 years, enter the date on which the generator is scheduled to reenter commercial operation after the planned derate. Enter the date in the format MMYYYY. If no derate is planned in the next 10 years, leave this blank.
43. For line 43a, What is the expected new prime mover for this generator? If a
repowering is planned within the next 10 years, enter the new prime mover for this
generator. Select the prime mover code from those listed in the instructions for
SCHEDULE 3 Part A, Table 2. If no repowering is planned within the next 10 years,
leave this blank.
For line 43b, What is the expected new energy source for this generator? If a
repowering is planned within the next 10 years, enter the new energy source for this
generator. Select the energy source code from Table 28 in these instructions. If no
repowering is planned in the next ten years, leave this blank.
For line 43c, What is the expected new nameplate capacity for this generator? If a
repowering is planned for within the next 10 years, enter the new nameplate capacity for
17

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

this generator.
For line 43d, What is the planned effective date for this repowering? Enter the date
on which this generator is scheduled to re-enter operation after the repowering. Enter the
date in the format MM-YYYY. If no repowering is planned, leave this blank.
44. On line 44a, Are any other modifications planned within the next 10 years? Check
“Yes” if any other significant modifications are planned for this generator in the next 10
years. Explain these modifications on SCHEDULE 7 of this form. Check “No” If no other
significant modifications are planned within the next 10 years.
On line 44b, What is the planned date of these other modifications? If you checked
“Yes” on line 44a, enter the date on which this generator will reenter service after the
modification. Enter the date in the format MM-YYYY. If you selected “No,” leave this
blank.
45. On line 45a, Can this generator burns multiple fuels? Indicate if the combustion
system that powers each generator has both:
•

The regulatory permits necessary to either co-fire fuels or fuel switch, and

•

The equipment, including fuel storage facilities in working order, necessary to
either co-fire fuels or fuel switch.

If the answer to this question is “No,” go to SCHEDULE 3, PART C. GENERATOR
INFORMATION - PROPOSED GENERATORS.
For line 45b, Can this generator co-fire fuels? Indicate yes if the combustion system
that powers each generator has both:
•

The regulatory permits necessary to co-fire fuels, and

•

The equipment, including fuel storage facilities in working order, necessary to either
co-fire fuels or fuel switch.

Note: Co-firing means the simultaneous use of two or more fuels by a single
combustion system to meet load. Co-firing excludes the limited use of a secondary fuel
for start-up or flame stabilization.
Line 45c applies only if the generator can co-fire fuels
For line 45c, What are the fuel options for co-firing? Indicate up to six fuels that can
be co-fired. Select appropriate energy source codes from Table 28 in these instructions.
Note: fuel options listed for co-firing must also be included under either “Predominant
Energy Source,” Second Most Predominant Energy Source,” or “Other Energy Sources.”
46. For line 46a, Can this generator switch between oil and natural gas? Check “Yes” if:
•

the primary energy source of the unit is oil or natural gas;

•

the combustion system that powers the generator has, in working order, the
equipment (including fuel oil storage tanks) necessary to switch between natural
gas and oil; and

•

this combustion system has the regulatory permits necessary to switch between
natural gas and oil.

Note: Fuel switching means the ability of a combustion system running on one fuel

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

to replace that fuel in its entirety with a substitute fuel. Fuel switching excludes the
limited use of a secondary fuel for start-up or flame stabilization.
Answer questions on lines 46b through 50 only if generator can fuel switch between oil
and natural gas
For line 46b, Can this generator switch between oil and natural gas while
operating? Check “Yes,” if 1) you checked “Yes” for line 38a, and 2) if the combustion
system that powers this generator is able to switch between natural gas and oil while
operating.
47. For line 47a, What is the maximum net summer output achievable when running on
natural gas? Enter the maximum net summer output in MW that the unit can achieve
when running on natural gas, taking into account all applicable legal, regulatory, and
technical limits.
For line 47b, What is the maximum net winter output achievable when running on
natural gas? Enter the maximum net winter output in MW that the unit can achieve
when running on natural gas, taking into account all applicable legal, regulatory, and
technical limits.
48. For line 48a, What is the maximum net summer output achievable when running on
oil? Enter the maximum net summer output in MW that the unit can achieve when
running on fuel oil, taking into account all applicable legal, regulatory, and technical
limits.
For line 48b, What is the maximum net winter output achievable when running on
oil? Enter the maximum net winter output in MW that the unit can achieve when running
on fuel oil, taking into account all applicable legal, regulatory, and technical limits.
49. For lines 49a, How much time is required to switch the generator from using 100
percent natural gas to 100 percent oil? Enter the amount of time that it takes to switch
the generator from using 100 percent natural gas to 100 percent oil.
For line 49b, How much time is required to switch this generator from using 100
percent oil to using 100 percent natural gas? Enter the amount of time that it takes to
switch the generator from using 100 percent oil to 100 percent natural gas.
50. For line 50a, Are there factors that limit this generator’s ability to switch between
natural gas and oil? These factors may include limits on maximum output, limits on
annual operating hours, or other limitations.
For line 50b, Which factors limit this generator’s ability to switch between natural
gas and oil? If you selected “Yes” on line 50a, select all of the factors that limit the
ability to switch fuels. If you select “Other” provide explanation in SCHEDULE 7.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

SCHEDULE 3, PART C. GENERATOR INFORMATION – PROPOSED GENERATORS
Complete this Schedule for all generators at this plant that are:
•

Expected to be in commercial operation within 10 years in the case of coal and
nuclear generators; or

•

Expected to be in commercial operation within 5 years for all generators other than
coal and nuclear generators.

1. For line 1a, What is the expected nameplate capacity for this generator? Enter the
expected nameplate capacity in MW rounded to the nearest tenth, as measured in
alternating current (AC). If the expected nameplate capacity is expressed in kilovolt
amperes (kVA), first convert the expected nameplate capacity to kilowatts by multiplying
the corresponding power factor by the kVA and then convert to megawatts by dividing by
1,000. Round this value to the nearest tenth.
For line 1b, What is the expected nameplate power factor for this generator? Enter
the expected power factor. This should be the same power factor used to convert the
generator’s kilovolt-ampere rating (kVA) to megawatts (MW) as directed for line 1a
above.
2. For line 2, What is the expected net capacity for this generator? Enter the generator’s
net summer and net winter capacities for the primary energy source that are expected
when the generator goes into commercial operation. Report these values in MW rounded
to the nearest tenth, as measured in alternating current (AC).
3. For line 3, What was the status of this proposed generator as of December 31 of the
reporting year? Enter one of the following status codes:
Table 6. Proposed Generator Status Codes and Descriptions
Proposed
Generator Status
Code
CN
IP
TS
P
L
T

Proposed Generator Status Code Descriptions

Planned new generator has been canceled
Planned new generator indefinitely postponed, or no longer in
resource plan
Construction complete, but not yet in commercial operation
(including low power testing of nuclear units)
Planned for installation but regulatory approvals not initiated;
Not under construction
Regulatory approvals pending. Not under construction but site
preparation could be underway
Regulatory approvals received. Not under construction but site
preparation could be underway

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

U
V
OT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Under construction, less than or equal to 50 percent complete
(based on construction time to date of operation)
Under construction, more than 50 percent complete (based on
construction time to date of operation)
Other (specify in SCHEDULE 7)

4. For line 4, What is the planned original effective date for this generator? Enter the
date on which the generator is scheduled to start commercial operation. Enter the date in
the format MM-YYYY. This date will not change after it has been reported the first time.
5. For line 5, What is the planned current effective date for this generator? If a Planned
Original Effective Date was submitted an earlier filing and is no longer accurate, enter the
updated date on which the generator is scheduled to start commercial operation. Enter
the date in the format MM-YYYY. Leave blank if this is your first time filling out this form.
6. For line 6, Will this generator be associated with a combined heat and power
system? Check “Yes” if this generator will be associated with combined heat and power
system. If it will not, check “No.”
7. For line 7, Is this generator part of a site that was previously reported as
indefinitely postponed or cancelled? Check “Yes” if this generator is part of a site that
was previously reported by either your company or a previous owner as an indefinitely
postponed or cancelled plant. Check “No” if it is not. Check “Unknown” if this history is
not known.
8. For line 8, What is the predominant expected energy source for this generator?
Enter the energy source code for the energy source expected to be used in the largest
quantity, as measured in Btus, when the generator starts commercial operation. Select
appropriate energy source codes from Table 28 in these instructions.
9. For line 9, What is the second most predominant expected energy source for this
generator? Enter the energy source code for the energy sources expected to be used in
the second largest quantity, as measured in Btus, when the generator starts commercial
operation. Do not include fuels expected to be used only for start-up or flame
stabilization. Select the appropriate energy source code from Table 28 in these
instructions.
10. For line 10, What other energy sources do you expect to use for this generator?
Enter the codes for other energy sources that will be used at the plant to power the
generator. Enter up to four codes. Enter these codes in order of their expected
predominance as measured in Btus. Select appropriate energy source codes from Table
28 in these instructions.
11. For line 11, How many turbines, or buoys is this generator expected to have? Wind
generators should enter the number of turbines, and hydroelectric generators should
enter the number of buoys.
12. For line 12, What combustion technology will apply to this generator? If the
generator will be fired by coal or petroleum coke, select the appropriate combustion
technology. If you select “Other” provide explanation in SCHEDULE 7.
13. For line 13 What steam conditions will apply to this generator? If the generator will
be fired by coal or petroleum coke, select the appropriate steam conditions.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

14. For line 14, Will this generator be part of a solid fuel gasification system? Check
“Yes” if this generator will be part of a solid fuel gasification system. Check “No” if it will
not be.
15. For line 15, Will this generator be associated with a carbon dioxide capture
process? Check “Yes” if this generator will be associated with a carbon capture
process. Check “No” if it will not be associated with carbon capture.
Line 16 applies only if the generator will be able to burn multiple fuels.
Line 17 applies only if the generator will be able to fuel switch.
Lines 18a and 18b apply only if the generator will be able to co-fire fuels.
16. Note: Co-firing means the simultaneous use of two or more fuels by a single combustion
system to meet load. Fuel switching means the ability of a combustion system running
on one fuel to replace that fuel in its entirety with a substitute fuel. Co-firing and fuel
switching exclude the limited use of a secondary fuel for start-up or flame stabilizationFor
line 16, Will this generator be able to burn multiple fuels? Indicate if the combustion
system that will power the generator will have 1) the regulatory permits necessary to
either co-fire fuels or fuel switch, and 2) the equipment (including fuel storage facilities)
necessary to either co-fire or fuel switch are in working order.
If the answer is “No” or “Undetermined”, go to SCHEDULE 4. OWNERSHIP OF
GENERATORS OWNED JOINTLY OR BY OTHERS
17. For line 17, Will the combustion system that powers this generator be able to
switch between natural gas and oil? Check “Yes” if 1) the primary energy source of the
generator will be natural gas or oil and 2) the combustion system that will power the
generator will have the ability and equipment necessary (including fuel oil storage tanks)
to switch between natural gas and oil. Check “No” if it will not. Check “Undetermined” if
a determination on switching between natural gas and oil has not yet been made.
18. For line 18a, Will the combustion system that powers this generator be able to cofire fuels? Indicate whether or not the combustion system that will power the generator
will have the necessary equipment and regulatory permits to co-fire fuels.
For line 18b, What are the fuel options for co-firing? Indicate up to six fuels that the
generator will be designed to co-fire. Select the energy source codes from Table 28 in
these instructions. Note: fuel options listed for co-firing must also be included under
“Predominant Energy Source,” Second Most Predominant Energy Source,” and/or “Other
Energy Sources.”

SCHEDULE 4. OWNERSHIP OF GENERATORS OWNED JOINTLY OR BY OTHERS
1. Complete SCHEDULE 4 for each operable or planned generator that is or will be either
jointly owned with another entity or wholly owned by an entity other than the reporting
entity as entered on SCHEDULE 1, Line 3.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

2. For each generator that is either jointly owned with another entity or wholly owned by
another specify the Plant Name, EIA Plant Code, and Generator Identification Code, as
listed on SCHEDULE 3, PART A.
3. For each owner of either a jointly owned generator or wholly owned by an entity other
than the reporting entity generator, enter the name, address and percentage owned. The
total percentage of reported ownership must equal 100 percent.
4. If known, enter the EIA Owner Code for the owner, otherwise leave blank. The EIA
Owner Code is the same as the EIA Utility Identification Code and EIA Entity
Identification Code.
5. Enter the Percent Owned to two decimal places, i.e., 12.5 percent as “12.50.” Include
any notes or comments in SCHEDULE 7.

SCHEDULE 5. GENERATOR CONSTRUCTION COST INFORMATION
1. The reporting year is the calendar year that you are filing the survey for. For example, if
you are reporting data as of December 31, 2013, then the reporting year is 2013.
2. Include all construction costs in SCHEDULE 5 regardless of which party is ultimately
responsible for those costs. All disputed costs must be included in the reported estimated
or final project costs. If disputed costs are included in the reported estimated or final
project costs, you can note this in SCHEDULE 7.
SCHEDULE 5, PART A. GENERATOR CONSTRUCTION COST INFORMATION - COAL
AND NUCLEAR GENERATORS
Complete a separate SCHEDULE 5, PART A for each coal or nuclear generator that, during
the reporting year:
•

Began commercial operation; or

•

Was under construction, in final testing or in the process of receiving permits and
regulatory approvals; or

•

Was a nuclear generator that has applied for a combined operating license (COL)
from the Nuclear Regulatory Commission.

Enter the Plant Name, EIA Plant Code, and Generator ID as previously reported in
SCHEDULE 3, PART A.
1. For line 1, What is the total construction cost for this generator (in thousands of
dollars)? If the generator did not enter commercial operation during the reporting year,
provide the best available projection of the total construction cost to completion. If the
project entered commercial operation during the reporting year, provide the best
available estimate of total construction costs. Total Construction Costs should be
provided in nominal dollars (do not discount future costs to reflect the time value of
money and do not adjust past costs to reflect inflation) and typically include the following
items:
•

Civil and structural costs - allowance for site preparation, drainage, installation of

FORM EIA-860
INSTRUCTIONS
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Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

underground utilities, structural steel supply, and construction of buildings on the site.
Exclude land acquisition or leasing costs.
•

Mechanical equipment supply and installation - major equipment, including but
not limited to, boilers, flue gas desulfurization scrubbers, cooling towers, steam
turbine generators, condensers, and other auxiliary equipment.

•

Electrical and instrumentation control – electrical transformers, switchgear, motor
control centers, switchyards, distributed control systems, and other electrical
commodities.

•

Project indirect costs – engineering, distributable labor and materials, craft labor
overtime and incentives, scaffolding costs, construction management start up and
commissioning, and fees for contingency (including contractor overhead costs, fees,
profits, and construction).

•

Owner Costs – development costs, preliminary feasibility and engineering studies,
environmental studies and permitting, legal fees, insurance costs, property taxes
during construction, and the electrical interconnection costs, including a tie-in to a
nearby electrical transmission system.

Exclude financing, government grants, tax benefits, or other incentives from this number.
2. For line 2, What are the total financing costs for construction of this generator (in
thousands of dollars)? Enter the total financing costs including (1) the interest cost of
debt financing, (2) any imputed cost of equity financing, and (3) funds recovered to
maintain a debt service coverage ratio for the project. In the cast of investor-owned
utilities, financing costs include any allowance for funds used during construction
(AFUDC). For example, the net cost for the period of construction of borrowed funds
used for construction purposes and a reasonable rate on other funds when so used.
3. For line 3, What is the total cost to construct this generator including financing
costs (in thousands of dollars)? Enter the total cost to construct the generator
including both construction costs and financing. This value should be the sum of the
answers to the two previous questions.

SCHEDULE 5, PART B. GENERATOR CONSTRUCTION COST INFORMATION - OTHER
THAN COAL AND NUCLEAR GENERATORS
Complete a separate SCHEDULE 5, PART B for each generator other than coal or nuclear

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generators that, during the reporting year:
•

Began commercial operation

Do not report for any units reported on SCHEDULE 5, PART A.
Enter the Plant Name, EIA Plant Code, and Generator ID as previously reported in
SCHEDULE 3, PART A.
1. For line 1, What is the total construction cost for this generator (in thousands of
dollars)? Enter the total construction cost to completion. Total Construction Costs should
be provided in nominal dollars (do not discount future costs to reflect the time value of
money and do not adjust past costs to reflect inflation) and typically include the following
items:
•

Civil and structural costs - allowance for site preparation, drainage, installation of
underground utilities, structural steel supply, and construction of buildings on the site.
Exclude land acquisition or leasing costs.

•

Electrical and instrumentation control – electrical transformers, switchgear, motor
control centers, switchyards, distributed control systems, and other electrical
commodities.

•

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answers to the two previous questions.

SCHEDULE 6. INFORMATION ON BOILERS AND ASSOCIATED EQUIPMENT
SCHEDULE 6 collects information on existing and planned boilers and associated equipment
serving steam electric generators, including units burning combustible fuels, nuclear units,
and solar thermal units. Complete for EACH boiler.
Complete SCHEDULE 6 as follows:
Required Respondents
Plants where the sum of the nameplate capacity of the steamelectric generators, including duct fired steam components of
combined cycle units, sum to 100 MW or more.
All nuclear plants, solar thermal plants and steam components
of combined cycle units without duct firing where the sum of the
nameplate capacity of the steam-electric generators is 100 MW
or more.

Schedule 6 Parts
to be Completed
Parts A - G

Part A
Part D

Part A

Plants where the sum of the nameplate capacity of the steamelectric generators, including duct fired steam components of
combined cycle units, sum to 10 MW or more, but less than 100
MW.

Part B, Lines 3, to 8
and 11 to 14 (SO2,
NOx and Mercury
questions)
Part C, Lines 1 to 3
Part E
Part F

SCHEDULE 6, PART A. PLANT CONFIGURATION AND ENVIRONMENTAL EQUIPMENT
INFORMATION

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Complete SCHEDULE 6, Part A, if you are reporting for a plant where the sum of the
nameplate capacity of the steam-electric generators, including duct-fired steam components
of combined cycle units, sum to 10 MW or more.
For line 1, What equipment is associated with each boiler at this plant?

Enter the unique identification codes commonly used by plant management to identify the
boiler and all associated equipment: generators, cooling systems, particulate matter control
systems, sulfur dioxide control systems, NOx control, mercury control and stacks.
These identification codes are generally restricted to six characters and cannot be changed
once provided to EIA. However, the identification codes for generators are restricted to five
characters.
Include all equipment that:
•

Was operable in the past calendar year; or

•

Is expected to be in commercial operation within 10 years in the case of equipment
associated with coal and nuclear generators; or

•

Is expected to be in commercial operation within 5 in the case of equipment not
associated with coal and nuclear generators

If two or more pieces of equipment (e.g., two generators) are associated with a single boiler,
report each identification code separated by commas under the appropriate boiler.
If any equipment is associated with multiple boilers, repeat the equipment identification code
under each boiler. Do not change prepopulated equipment identification codes.
Note equipment such as selective catalytic reduction, activated carbon injection, and dry
sorbent injection into a fluidized bed boiler will require an identification code entry as these
were not collected in past reporting years.
•

Row 1 – Enter boiler ID

•

Row 2 – Enter all generator ID(s) associated with the boiler (Generator ID must
match those entered on SCHEDULE 3 PART A.

•

Row 3 – Enter associated cooling system ID(s)

•

Row 4 – Enter associated particulate matter control system ID(s)

•

Row 5 – Enter associated sulfur dioxide control system ID(s) including dry sorbent
injection (DSI) in a fluidized bed combustion boiler

•

Row 6 – Enter associated nitrogen oxide (NOx) control equipment ID(s) (assign an ID
to each selective catalytic reduction and selective noncatalytic reduction device).

•

Row 7 – Enter associated mercury control ID(s), including activated carbon injection
(assign an ID to each mercury control system).

•

Row 8 – Enter associated stack (or flue) ID(s)

2. For Line 2, What are the characteristics of each piece of emissions control
equipment?
Enter in Column A, the Equipment Type code from Table 7.
27

FORM EIA-860
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ANNUAL ELECTRIC
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Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Table 7. Equipment Type Code and Description
Equipment

Equipment Type Description

Type Code
JB

Jet bubbling reactor (wet) scrubber

Mechanically aided type (wet) scrubber

Packed type (wet) scrubber

Spray type (wet) scrubber

Tray type (wet) scrubber

Venturi type (wet) scrubber

Baghouse (fabric filter), shake and deflate

Baghouse (fabric filter), pulse

Baghouse (fabric filter), reverse air

Electrostatic precipitator, cold side, with flue gas conditioning

Electrostatic precipitator, hot side, with flue gas conditioning

Electrostatic precipitator, cold side, without flue gas conditioning

Electrostatic precipitator, hot side, without flue gas conditioning

Multiple cyclone

Single cyclone

Circulating dry scrubber

Spray dryer type / dry FGD / semi-dry FGD

DSI

Dry sorbent (powder) injection type (DSI)

ACI

Activated carbon injection system

Selective noncatalytic reduction

Selective catalytic reduction

Other equipment (Specify in SCHEDULE 7)

For Columns B to J:
Enter the identification codes from the above table in the appropriate columns for
emissions controls. If a piece of equipment controls multiple air emissions, enter the
appropriate code in multiple columns (for example, if a wet scrubber controls for both
sulfur dioxide, particulate matter and mercury, enter the associated identification code
from the table above in Columns B, C and E).

FORM EIA-860
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ANNUAL ELECTRIC
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•
•
•
•
•
•

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

For Particulate Control (PM) equipment, enter identification code(s) in Column B
For Sulfur Dioxide Control (SO2) equipment, enter the identification code(s) in Column C
For Nitrogen Oxide Control (NOx) equipment, enter the identification code(s) in Column D
For Mercury Control (Hg) equipment, enter the identification code(s) in Column E
For HCl gas control, enter an X in Column F (no identification codes are required).
For Column G, enter the status for the equipment as of December 31 of the reporting
year from Table 8 in the instructions.

Table 8. Equipment Status Codes and Descriptions
Status Code
CN
CO
OP
OS
OZ
PL
RE
SB
SC
TS

Status Description
Cancelled (previously reported as “planned”)
New unit under construction
Operating (in commercial service or out of service less than 365
days)
Out of service (365 days or longer)
Operated only during the ozone season (May through September)
Planned (expected to go into commercial service within 10 years)
Retired (no longer in service and not expected to be returned to
service)
Standby (or inactive reserve); i.e., not normally used, but available
for service
Cold Standby (Reserve); deactivated (usually requires 3 to 6 months
to reactivate)
Operating under test conditions (not in commercial service)

In Column H, In-service Date, enter the date on which the equipment began commercial
operation or the date on which it is expected to begin commercial operation (MM/YYYY).
In Column I, Retirement Date, enter the date on which the equipment retired or is
expected to be retired. If the expected retirement date is unknown leave blank.
In Column J, Total Costs (Thousand Dollars), enter the nominal installed cost for the
existing system or the anticipated cost to bring a planned piece of equipment into
commercial operation (in thousands of dollars). Installed cost should include the cost of
all major modifications. A major modification is any physical change which results in a
change in the amount of air emissions or pollutants or which results in a different
pollutant being emitted. Costs should be provided in nominal dollars (do not discount
future costs to reflect the time value of money and do not adjust past costs to reflect
inflation)
SCHEDULE 6, PART B. BOILER INFORMATION – AIR EMISSION STANDARDS AND
CONTROL STRATEGIES
For plants with a total steam-electric nameplate capacity of 10 MW or greater but less than

FORM EIA-860
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ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

100 MW:
Complete ONLY questions 1, 3 to 8, 11,12, 13 and 14 (SO2, NOx and Mercury
questions) SCHEDULE 6, Part B for each boiler and its associated equipment that serve
or are expected to serve combustible-fueled steam electric generators or combined cycle
steam generators with duct firing.
For plants with a total steam-electric nameplate capacity of 100 MW or greater:
Complete one SCHEDULE 6, Part B in its entirety for each boiler and its associated
equipment that serve or are expected to serve combustible-fueled steam electric
generators and combined cycle steam generators with duct firing.
Include all boilers that:
•

Were operable in the past calendar year; or

•

Are expected to be in commercial operation within 10 years in the case of coal plans;
or

•

Are expected to be in commercial operation within 5 years in the case of non-coal
plants

1. For line 1, What is this boiler’s identification code? Enter the boiler identification
number corresponding to each boiler listed on SCHEDULE 6, PART A.
2. For Line 2a, Type of Boiler Standards under Which the Boiler is Operating, indicate
the standards as described in the U. S. Environmental Protection Agency regulation
under 40 CFR. Select from the codes in Table 9 of the New Source Performance
Standards (NSPS):
Table 9. Boiler Standards Codes and Descriptions
D

Standards of Performance for fossil-fuel fired steam boilers for which
construction began after August 17, 1971.

Standards of Performance for fossil-fuel fired steam boilers for which
construction began after September 18, 1978

Standards of Performance for fossil-fuel fired steam boilers for which
construction began after June 19, 1984.

Standards of Performance for small industrial-commercial-institutional steam
generating units

Not covered under New Source Performance Standards.

For line 2b, Is this boiler operating under a new Source Review (NSR) permit?,
indicate whether the boiler is operating under a new source review permit
For line 2c, if the boiler is operating under a NSR permit, provide the NSR Permit List
Date and NSR Permit identification number.

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Lines 3-5 apply to sulfur dioxide compliance
Boilers that burn only natural gas may select “Not Applicable” for line 3a and skip questions 3b, 3c, 3d, 3e
4, 5a, and 5b .

3. For line 3a, What is the regulatory level of the most stringent regulation that this
boiler is operating under to meet sulfur dioxide control standards? Select the most
stringent regulation that the boiler operates under to meet sulfur dioxide control
standards.
For line 3b, What is the emission rate specified by the most stringent sulfur dioxide
regulation? Enter the emission rate corresponding to the most stringent sulfur dioxide
regulation. Pounds of sulfur dioxide per million Btu in fuel is the preferred measurement
or use Units of Measurement in Table 10.
For line 3c, What is the percent of sulfur to be scrubbed specified by the most
stringent sulfur dioxide regulation? If the most stringent regulation specifies a percent
(by weight) of sulfur to be scrubbed enter the percent.
For line 3d, What is the unit of measurement specified by the most stringent sulfur
dioxide regulation? Select the unit of measure corresponding to the emission rate
entered in line 3b from the values in Table 10. Note that DP*, “Pounds of sulfur dioxide
per million Btu in fuel” is the preferred measurement.
Table 10. Sulfur Dioxide Unit of Measurement Codes
Sulfur Dioxide Unit
of Measurement
Code
DC
DH
DL
DM
DP*
SB
SR
SU
OT

Sulfur Dioxide Unit of Measurement Code Description
Ambient air quality concentration of sulfur dioxide (parts per
million)
Pounds of sulfur dioxide emitted per hour
Annual sulfur dioxide emission level less than a level in a
previous year
Parts per million of sulfur dioxide in stack gas
Pounds of sulfur dioxide per million Btu in fuel
Pounds of sulfur per million Btu in fuel
Percent sulfur removal efficiency (by weight)
Percent sulfur content of fuel (by weight)
Other (specify in SCHEDULE 7)

For line 3e, What is the time period specified by the most stringent sulfur dioxide
regulation? Enter the time period corresponding to the emission rate entered in line 3b
from the values in Table 11.
Table 11. Time Period Codes
Time Period Code

Time Period Code Description

FORM EIA-860
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ANNUAL ELECTRIC
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NV
FM
SM
FT
OH
WO
TH
EH
DA
WA
MO
ND
YR
PS
DT
NS
OT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Never to exceed
5 minutes
6 minutes
15 minutes
1 hour
2 hours
3 hours
8 hours
24 hours
1 week
30 days
90 days
Annual
Periodic stack testing
Defined by testing
Not specified
Other (specify in SCHEDULE 7)

4. For line 4, In what year did the boiler became compliant or is expected to become
compliant with the most stringent sulfur dioxide regulation? Indicate the year in
which the boiler came into compliance or is expected to come into compliance with
Federal, State and Local Regulations as they relate to sulfur dioxide control.
5. For line 5a, What is your existing strategy for complying with the most stringent
sulfur dioxide regulation? Identify up to three strategies from Table 12 that are
currently used to address Federal, State or local regulations as they relate to sulfur
dioxide control.
Table 12. Sulfur Dioxide Compliance Strategies
Sulfur Dioxide
Compliance Codes
CF
IF
SS
WA
OT
SE
ND
NP
NA

Sulfur Dioxide Compliance Code Descriptions
Fluidized Bed Combustor
Use flue gas desulfurization unit or other SO2 control process
(specify the specific type of equipment in Schedule 6A)
Switch to lower sulfur fuel
Allocated allowances and purchase allowances
Other (specify in SCHEDULE 7)
Seeking revision of government regulation
Not determined at this time
No plans to control
Not applicable

For line 5b, What is your proposed strategy for complying with the most stringent
sulfur dioxide regulation? Identify up to three strategies from Table 12 that are
planned to be used to address Federal, State or local regulations as they relate to sulfur

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dioxide control.
Lines 6-8 apply to nitrogen oxide compliance
6. For line 6a, What is the regulatory level of the most stringent regulation that this
boiler is operating under to meet nitrogen oxide control standards? Select the most
stringent regulation that the boiler operates under to meet nitrogen oxide control
standards.
For line 6b, What is the emission rate specified by the most stringent nitrogen
oxide regulation? Enter the emission rate corresponding to the most stringent nitrogen
oxide regulation. Pounds of nitrogen oxides per million Btu in fuel is the preferred
measurement or use Units of Measurement in Table 13.
For line 6c, What is the unit of measurement specified by the most stringent
nitrogen oxide regulation? Select the unit of measure corresponding to the emission
rate entered in line 6b from the values in Table 13. Note that “Pounds of nitrogen oxides
per million Btu in fuel” is the preferred measurement.
Table 13. Nitrogen Oxide Unit of Measurement Codes
Nitrogen Oxide
Unit of
Measurement Code
NH
NL
NM
NO
NP*
OT

Nitrogen Oxide Unit of Measurement Code Description
Pounds of nitrogen oxides emitted per hour
Annual nitrogen oxides emission level less than a level in a
previous year
Parts per million of nitrogen oxides in stack gas
Ambient air quality concentration of nitrogen oxides (parts per
million)
Pounds of nitrogen oxides per million Btu in fuel
Other (specify in SCHEDULE 7)

For line 6d, What is the time period specified by the most stringent nitrogen oxide
regulation? Enter the time period corresponding to the emission rate entered in line 6b
from the values in Table 11.
7. For line 7, In what year did the boiler became compliant or is expected to become
compliant with the most stringent nitrogen oxide regulation? Indicate the year in
which the boiler came into compliance or is expected to come into compliance with
Federal, State and Local Regulations as they relate to nitrogen oxide control.
8. For line 8a, What is your existing strategy for complying with the most stringent
nitrogen oxide regulation? Identify up to three strategies from Table 14 that are
currently used to address Federal, State or local regulations as they relate to nitrogen
oxide control.
Table 14. Nitrogen Oxide Compliance Codes and Strategies
Nitrogen Oxide
Compliance Codes
AA
BO

Nitrogen Oxide Compliance Strategies
Advanced overfire air
Burner out of service

FORM EIA-860
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BF
CF
FR
FU
H2O
LA
LN
NH3
OV
RP
SN
SR
STM
UE

Approval: OMB No. 1905-0129
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OT
SE

Biased firing (alternative burners)
Fluidized bed combustor
Flue gas recirculation
Fuel reburning
Water injection
Low excess air
Low NOx burner
Ammonia injection
Overfire air
Repower unit
Selective noncatalytic reduction
Selective catalytic reduction
Steam injection
Decrease utilization – rely on energy conservation and/or
improved efficiency
Other (specify in SCHEDULE 7)
Seeking revision of government regulation

ND
NP
NA

Not determined at this time
No plans to control
Not applicable

For line 8b, What is your proposed strategy for complying with the most stringent
nitrogen oxide regulation? Identify up to three strategies from Table 14 that are
planned to be used to address Federal, State or local regulations as they relate to
nitrogen oxide control.
Lines 9-10 apply to particulate matter compliance
9. For line 9a, What is the regulatory level of the most stringent regulation that this
boiler is operating under to meet particulate matter control standards? Select the
most stringent regulation that the boiler operates under to meet particulate matter control
standards.
For line 9b, What is the emission rate specified by the most stringent particulate
matter regulation? Enter the emission rate corresponding to the most stringent
particulate matter regulation. Pounds of particulate matter per million Btu in fuel is the
preferred measurement or use Units of Measurement in Table 15.
For line 9c, What is the unit of measurement specified by the most stringent
particulate matter regulation? Select the unit of measure corresponding to the
emission rate entered in line 9b from the values in Table 15. Note that “Pounds of
Particulate matter per million Btu in fuel” is the preferred measurement.
Table 15. Particulate Matter Unit of Measurement Codes
Particulate Matter
Unit of
Measurement Code
OP
PB*
PC

Particulate Matter Unit of Measurement Code Description
Percent of opacity
Pounds of Particulate matter per million Btu in fuel
Grains of particulate matter per standard cubic foot of stack gas
34

FORM EIA-860
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PG
PH
UG
OT

Approval: OMB No. 1905-0129
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Pounds of particulate matter per thousand pounds of stack gas
Pounds of particulate matter emitted per hour
Micrograms of particulate matter per cubic meter
Other (specify in SCHEDULE 7)

For line 9d, What is the time period specified by the most stringent particulate
matter regulation? Enter the time period corresponding to the emission rate entered in
line 9b from the values in Table 11.
10. For line 10, In what year did the boiler became compliant or is expected to become
compliant with the most stringent particulate matter regulation? Indicate the year in
which the boiler came into compliance or is expected to come into compliance with
Federal, State and Local Regulations as they relate to particulate matter control.
Lines 11-14 apply to mercury and acid gas compliance
11. For line 11, What is the regulatory level of the most stringent regulation that this
boiler is operating under to meet mercury and acid gas standards? Select the most
stringent regulation that the boiler operates under to meet mercury and acid gas control
standards.
12. For line 12, In what year did the boiler became compliant or is expected to become
compliant with the most stringent mercury and acid gas regulation? Indicate the
year in which the boiler came into compliance or is expected to come into compliance
with Federal, State and Local Regulations as they relate to mercury and acid gas control.
13. For line 13, What are the existing strategies to control mercury emissions? Identify
up to three strategies from Table 16 that are currently used to address Federal, State or
local regulations as they relate to mercury control. .
Table 16. Mercury Compliance Codes and Descriptions
Strategy Type
Code
BS
BP
BR
CD
SD
DSI
ACI
LIJ
EC
EH
EK
EW
JB
MA
PA
SP
TR

Strategy Type Description
Baghouse (fabric filter), shake and deflate
Baghouse (fabric filter), pulse
Baghouse (fabric filter), reverse air
Circulating dry scrubber
Spray dryer type / dry FGD / semi-dry FGD
Dry sorbent (powder) injection type
Activated carbon injection system
Lime injection
Electrostatic precipitator, cold side, with flue gas conditioning
Electrostatic precipitator, hot side, with flue gas conditioning
Electrostatic precipitator, cold side, without flue gas conditioning
Electrostatic precipitator, hot side, without flue gas conditioning
Jet bubbling reactor (wet) scrubber
Mechanically aided type (wet) scrubber
Packed type (wet) scrubber
Spray type (wet) scrubber
Tray type (wet) scrubber

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VE
OT
SE

Venturi type (wet) scrubber
Other (specify in SCHEDULE 7)
Seeking revision of government regulation

ND
NP
NA

Not determined at this time
No plans to control
Not applicable

14. For line 14, What are the proposed strategies to control mercury emissions?
Identify up to three strategies from Table 16 that are planned to be used to address
Federal, State or local regulations as they relate to mercury control.

SCHEDULE 6, PART C. BOILER INFORMATION – DESIGN PARAMETERS
Complete SCHEDULE 6, Part C, ONLY Lines 1 through 3 if you are reporting for a plant
where the sum of the nameplate capacity of the steam-electric generators, including duct
fired steam components of combined cycle units, sum to at least 10 MW, but less than 100
MW.
Complete SCHEDULE 6, Part C in its entirety if you are reporting for a plant where the sum
of the nameplate capacity of the steam-electric generators, including duct fired steam
components of combined cycle units, sum to 100 MW or more.
Complete one SCHEDULE 6, Part C for each unique Boiler ID as reported on SCHEDULE 6
PART A, Line 1, Row 1
1. For Line 1a, Is this boiler a heat recovery steam generator (HRSG)? Indicated
whether the boiler being identified is actually a heat recovery steam generator.
For line 1b, What was this boiler’s status as of December 31 of the reporting year?
Select the boiler status from Table 17:

Table 17. Boiler Status Codes and Descriptions
Boiler
Status Code
CN
CO
OP
OS
PL
RE

Boiler Status Description
Cancelled (previously reported as “planned”)
New unit under construction
Operating (in commercial service or out of service less than
365 days)
Out of service (365 days or longer)
Planned (expected to go into commercial service within 10
years)
Retired (no longer in service and not expected to be returned
to service)
36

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SB
SC
TS

Approval: OMB No. 1905-0129
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Burden: 16.0 Hours

Standby (or inactive reserve); i.e., not normally used, but
available for service
Cold Standby (Reserve); deactivated (usually requires 3 to 6
months to reactivate)
Operating under test conditions (not in commercial service)

2. For line 2, What is the actual or projected in-service date for this boiler? Enter the
month during which the boiler came into service or is expected to come into service. The
month-year date should be entered as follows: August 1959 as 08-1959. If the month is
unknown, use the month of June.
3. For line 3, What is the actual or projected retirement date for this boiler? Enter the
month during whicht the boiler was retired or is expected to be retired. The month-year
date should be entered as follows: August 1959 as 08-1959. If the month is unknown,
use the month of June.
4. For line 4, What type of boiler is this? Enter up to three of the firing codes from Table
18.
Table 18. Boiler Firing Type Code and Description
Boiler Type Code
CB
CY
DB
FB
SS
TF
VF
WF
OT

Boiler Type Description
Cell Burner
Cyclone Firing
Duct Burner
Fluidized Bed Firing (Circulating Fluidized Bed, Bubbling
Fluidized Bed)
Stoker (Spreader, Vibrating Gate, Slinger)
Tangential Firing / Concentric Firing / Corner Firing
Vertical Firing / Arch Firing
Wall Fired (Opposed Wall, Rear Wall, Front Wall, Side Wall)
Other (specify in SCHEDULE 7)

5. For lines 5, What is the maximum continuous steam flow at 100 percent load for
this boiler? Enter the maxium, design steam flow for the boiler at 100 percent load in
1000 pounds per hour.
6. For line 6, What is the design firing rate at the maximum continuous steam flow for
coal and petroleum coke? Enter the design firing rate data for burning coal and
petroleum coke to the nearest 0.1 tons per hour. Do not enter firing rate data for startup
or flame stabilization fuels. For waste-heat boilers with auxiliary firing, enter the firing rate
for auxiliary firing.
7. For line 7, What is the design firing rate at the maximum continuous steam flow for
petroleum liquids? Enter the design firing rate data for burning petroleum liquids to the
nearest 0.1 barrels per hour. Do not enter firing rate data for startup or flame stabilization
fuels. For waste-heat boilers with auxiliary firing, enter the firing rate for auxiliary firing.
8. For line 8, What is the design firing rate at the maximum continuous steam flow for
natural gas? Enter the design firing rate data for burning natural gas to the nearest 0.1

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

thousand cubic feet per hour. Do not enter firing rate data for startup or flame
stabilization fuels. For waste-heat boilers with auxiliary firing, enter the firing rate for
auxiliary firing.
9. For line 9, What is the design firing rate at the maximum continuous steam flow for
energy sources other than coal, petroleum or natural gas? Enter the design firing
rate data for burning any other primary fuel other than coal, petroleum or natural gas. Do
not enter firing rate data for startup or flame stabilization fuels. For waste-heat boilers
with auxiliary firing, enter the firing rate for auxiliary firing. Specify the primary fuel (use
codes from Table 28) for which value is provided along with related measurement unit in
SCHEDULE 7.
10. For line 10, What is the design waste-heat input rate at maximum continuous steam
flow for this boiler? If the boiler receives all or a substantial portion of its energy input
from the noncombustible exhaust gases of a separate fuel-burning process, enter the
design waste-heat input rate as measured in million Btu per hour at maximum continuous
steam flow.
11. For line 11, What fuels are used by this boiler in order of predominance? Enter the
fuels used by this boiler in order of predominance. Select energy source codes from
Table 28 in the instructions in order of predominance based on Btu. Enter up to six
energy sources.
12. For line 12, What is the turndown ratio for this boiler? Calculate (to nearest 0.1) the
turndown ratio for the boiler as the ratio of the boiler’s maximum output to its minimum
output.
13. For line 13, What is the efficiency of this boiler when it is burning the reported
primary fuel at 100 percent load? Enter the efficiency of the boiler when burning the
reported primary fuel at 100 percent load.
14. For line 14, What is the efficiency of this boiler when it is burning reported primary
fuel at 50 percent load? Enter the efficiency of the boiler when burning the reported
primary fuel at 50 percent load.
15. For line 15, What is the total air flow (including excess air) at 100 percent load?
Report the total air flow (including excess air) at 100 percent load. Report air flow at
standard temperature and pressure (i.e., 68 degrees Fahrenheit and one atmosphere
pressure).
16. For line 16, Does the boiler have a wet bottom or a dry bottom? Indicate whether the
boiler has a wet bottom or dry bottom. Report only for coal-capable boilers. Wet Bottom is
defined as having slag tanks installed at the furnace’s throat to contain and remove
molten ash from the furnace. Dry Bottom is defined as having no slag tanks installed at
the furnace’s throat so bottom ash drops through throat to bottom ash water hoppers.
17. For line 17, Is the boiler capable of fly ash re-injection? Indicate whether the boiler is
capable of re-injecting fly ash.
SCHEDULE 6, PART D. COOLING SYSTEM INFORMATION – DESIGN PARAMETERS
Complete SCHEDULE 6, PART D for plants with a total steam-electric nameplate capacity of

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Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

100 MW or greater consisting of:
•

Combustible fueled steam-electric generators, including combined cycle steam
generators with duct firing;

•

Combined cycle steam-electric generators without duct firing;

•

Nuclear generators; or

•

Solar thermal units using a steam cycle.

Complete one SCHEDULE 6 PART D for each unique Cooling system ID as reported on
SCHEDULE 6 PART A, Line 1, Row 3.
1. For line 1, What is this identification code of the cooling system? Enter the cooling
system’s identification code commonly used by plant management to refer to this cooling
system. Cooling system identification should be the same identification as entered on
SCHEDULE 6, PART A, Line 1, Row 3 and as reported on other EIA forms. This
identification code is restricted to six characters and cannot be changed once provided to
EIA.
2. For line 2, What was the status of this cooling system as of December 31 of the
reporting year? Select from the cooling system’s status codes in Table 19.
Table 19. Cooling System Status Codes and Descriptions
Cooling System
Status Code

Cooling System Status Description

CN
CO
OP

Cancelled (previously reported as “planned”)
New unit under construction
Operating (in commercial service or out of service less than 365 days)

OS
PL
RE

Out of service (365 days or longer)
Planned (expected to go into commercial service within 10 years)
Retired (no longer in service and not expected to be returned to
service)
Standby (or inactive reserve); i.e., not normally used, but available for
service)
Cold Standby (Reserve); deactivated (usually requires 3 to 6 months
to reactivate)
Operating under test conditions (not in commercial service)

SB
SC
TS

3. For line 3, What is the actual or projected in-service date of commercial operation
for this cooling system? Enter either the date on which the cooling system began
commercial operation or the date on which the system is expected to begin commercial
operation.
4. For line 4a, What type of cooling system is this? Select up to four types from the
cooling system type codes in Table 20 that reflect that components of the cooling system.
If the plant has a downstream helper tower that is associated with all boilers at a plant
instead of any particular boiler or combination of boilers, treat it as a distinct cooling
system and select “HT” from the list of codes.

FORM EIA-860
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ANNUAL ELECTRIC
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Approval: OMB No. 1905-0129
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Burden: 16.0 Hours

Table 20. Cooling System Type Codes and Descriptions
Cooling System
Type Code
DC
HRC
HRF
HRI
OC
ON
RC
RF
RI
RN
HT
OT

Cooling System Type Description
Dry (air) cooling system
Hybrid: cooling pond(s) or canal(s) with dry cooling
Hybrid: forced draft cooling tower(s) with dry cooling
Hybrid: induced draft cooling tower(s) with dry cooling
Once through with cooling pond(s)
Once through without cooling pond(s)
Recirculating with cooling pond(s) or canal(s)
Recirculating with forced draft cooling tower(s)
Recirculating with induced draft cooling tower(s)
Recirculating with natural draft cooling tower(s)
Helper Tower
Other (specify in SCHEDULE 7)

For line 4b, If this is a hybrid cooling system, what percent of the cooling load is
served by dry cooling components? In the case of a hybrid cooling system, indicate
the percent of total cooling load that is served by any dry cooling components.
5. For line 5, What is the name of the water source for this cooling system? Provide
the name of the river, lake, or other water source for the cooling system if different than
the water source listed on question 6 of SCHEDULE 2.
6. For line 6, What is the name of the cooling system’s discharge body of water? If the
discharge body of water is different than the source of the cooling water, enter the name
of the water.
7. For line 7, What is the cooling water source code for this system? Select the
appropriate cooling water source from Table 21:
Table 21. Cooling Water Source Code and Description
Cooling Water
Source Code
SW
GW
PD
OT

Cooling Water Source Description
Surface Water (ex: river, canal, bay)
Ground Water (ex: aquifer, well)
Plant Discharge Water (ex: wastewater treatment plant discharge)
Other (specify in SCHEDULE 7)

8. For line 8, What type of cooling water is used for this system? Select the type of
cooling water used by the cooling system from Table 22.
Table 22. Cooling Water Type Codes and Description
Type of Cooling
Water Code
BR
FR
BE
SA

Type of Cooling Water Description
Brackish Water
Fresh Water
Reclaimed Water (ex: treated wastewater effluent)
Saline Water

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
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OT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Other (specify in SCHEDULE 7)

9. For line 9, What is the design maximum cooling water flow rate at 100 percent load
at intake? Enter the design maximum flow rate (gallons per minute) for the cooling
system when operating at 100 percent load.
10. For line 10, What is the actual or projected in-service date for the chlorine
discharge control structures and equipment? Enter either the date on which the
chlorine discharge control structures and equipment began commercial operation or the
date on which the chlorine discharge control structures and equipment are expected to
begin commercial operation, if applicable.
11. For lines 11, What is the actual or projected in-service date for the cooling pond(s)?
Enter either the date on which the cooling pond(s) began commercial operation or the
date on which cooling pond(s) is expected to begin commercial operation, if applicable. A
cooling pond is a natural or man-made body of water that is used for dissipating waste
heat from power plants.
12. For line 12 What is the total surface area for the cooling pond(s)? Enter the total
surface area for the cooling pond(s), if applicable. A cooling pond is a natural or manmade body of water that is used for dissipating waste heat from power plants.
13. For line 13, What is the total volume of the cooling ponds? Enter the total volume of
the cooling pond(s), if applicable. A cooling pond is a natural or man-made body of water
that is used for dissipating waste heat from power plants.
14. For line 14, What is the actual or projected in-service date for cooling towers? Enter
either the date on which the cooling tower(s) began commercial operation or the date on
which the cooling tower(s) is expected to begin commercial operation, if applicable.
15. For line 15, What types of cooling towers are at this plant or are planned to be at
this plant? Enter all tower types that apply from the cooling tower codes in Table 23.
Table 23. Types of Towers
Tower Type Code
MD
MW
ND
NW
WD
OT

Tower Type Description
Mechanical draft, dry process
Mechanical draft, wet process
Natural draft, dry process
Natural draft, wet process
Combination wet and dry processes
Other (specify in SCHEDULE 7)

16. For line 16 What is the design rate of water flow at 100 percent load for the cooling
towers? Enter the design flow rate (gallons per minute) for the cooling tower when
operating at 100 percent generator load in gallons per minute.
17. For line 17, What is the maximum power requirement for the cooling towers at 100
percent load? Enter the maximum design power requirement for the cooling tower when
operating at 100 percent generator load in megawatts.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
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Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

18. For line 18, What is the total installed cost for this cooling system? Enter the total
nominal installed cost for the existing system or the anticipated cost to bring a planned
system into commercial operation in thousands of dollars. Installed cost should include
the cost of all major modifications. The Total System Cost should include amounts for
items such as pumps, piping, canals, ducts, intake and outlet structures, dams and dikes,
reservoirs, cooling towers, and appurtenant equipment.
19. For line 19, What is the installed cost for the cooling ponds? Enter the nominal
installed cost for the existing ponds or the anticipated cost to bring a planned pond into
commercial operation in thousands of dollars. Installed cost should include the cost of all
major modifications.
20. For line 20, What is the installed cost for the cooling towers? Enter the nominal
installed cost for the existing towers or the anticipated cost to bring a planned tower into
commercial operation in thousands of dollars. Installed cost should include the cost of all
major modifications. A major modification is any physical change which results in a
change in the amount of air or water pollutants or which results in a different pollutant
being emitted.
21. For line 21, What is the installed cost for the chlorine discharge control structures
and equipment? Enter in thousands of dollars, the nominal installed cost for the existing
chlorine discharge control structures and equipment or the anticipated cost to bring
planned chlorine discharge control structures and equipment into commercial operation.
Installed cost should include the cost of all major modifications. A major modification is
any physical change which results in a change in the amount of air or water pollutants or
which results in a different pollutant being emitted.
22. For line 22a, What is the maximum distance of water intake from shore? Enter the
maximum distance of the water intake from the shore, in feet.
For line 22b, What is the maximum distance of the water outlet from shore? Enter
the maximum distance of the water outlet from the shore, in feet (not required for
recirculating systems).
23. For lines 23a, What is the average distance of the water intake point below the
surface of the water? Enter the average distance of the water intake point below the
surface of the water, in feet.
For line 23b, What is the average distance of the water outlet point below the
surface of the water? Enter the average distance of the water outlet points below the
surface of the water, in feet (not required for recirculating systems).

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

SCHEDULE 6, PART E. FLUE GAS PARTICULATE COLLECTOR INFORMATION
Complete SCHEDULE 6, Part E for plants where the sum of the nameplate capacity of the
steam-electric generators, including duct fired steam components of combined cycle units,
sum to 10 MW or more.
Complete one SCHEDULE 6 PART E for each unique Particulate Matter Control system ID
as reported on SCHEDULE 6 PART A, Line 1, Row 4.
1. For line 1, What is the identification code for the equipment controlling particulate
matter? Enter the particulate matter control identification code as it was reported on
SCHEDULE 6, Part A, Line 1, Row 4 (Associated Particulate Matter Control Systems).
2. For line 2, What type of flue gas particulate matter control is this? Select the flue gas
particulate matter control type from Table 24. These should be the same equipment type
entered on SCHEDULE 6, PART A, Line 2, COLUMN A for Particulate Matter Control.
Enter up to three codes. If more than three exist, enter others in SCHEDULE 7,
COMMENTS.
Table 24. Flue Gas Particulate Matter Control
Flue Gas
Particulate
Matter Control
BS
BP

Flue Gas Particulate Matter Control Description
Baghouse (fabric filter), shake and deflate
Baghouse (fabric filter), pulse

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT
BR
EC
EH
EK
EW
MC
SC
JB
MA
PA
SP
TR
VE
OT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Baghouse (fabric filter), reverse air
Electrostatic precipitator, cold side, with flue gas conditioning
Electrostatic precipitator, hot side, with flue gas conditioning
Electrostatic precipitator, cold side, without flue gas conditioning
Electrostatic precipitator, hot side, without flue gas conditioning
Multiple cyclone
Single cyclone
Jet bubbling reactor (wet) scrubber
Mechanically aided type (wet) scrubber
Packed type (wet) scrubber
Spray type (wet) scrubber
Tray type (wet) scrubber
Venturi type (wet) scrubber
Other (specify in SCHEDULE 7)

3. For line 3, What is the design fuel specification for ash when burning coal or
petroleum coke? Enter the design fuel specification for ash (as burned) to the nearest
0.1 percent of weight, when burning coal or petroleum coke, if applicable.
4. For line 4, What is the design fuel specification for ash when burning petroleum
liquids? Enter the design fuel specification for ash (as burned) to the nearest 0.1 percent
of weight, when burning petroleum liquids, if applicable.
5. For line 5, What is the design fuel specification for sulfur when burning coal or
petroleum coke? Enter the design fuel specification for sulfur (as burned) to the nearest
0.1 percent of weight, when burning coal or petroleum coke, if applicable.
6. For line 6, What is the design fuel specification for sulfur when burning petroleum
liquids? Enter design fuel specification for sulfur (as burned) to the nearest 0.1 percent
of weight, when burning petroleum liquids, if applicable.
7. For line 7, What is the design collection efficiency for this flue gas particulate
collector at 100 percent load? Enter the design collection efficiency (to nearest 0.1
percent) of the equipment at 100 percent generator load.
8. For line 8, What is the design particulate emission rate for this collector at 100
percent load? Enter the design particulate emission rate in pounds per hour at 100
percent generator load.
9. For line 9, What is the particulate collector gas exit rate at 100 percent load? Enter
equipment’s gas exit rate in cubic feet per minute at 100 percent generator load.
10. For line 10, What is the particulate collector gas exit temperature? Enter the
equipment’s gas exit temperature in degrees Fahrenheit.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

SCHEDULE 6, PART F. FLUE GAS DESULFURIZATION UNIT INFORMATION
(INCLUDES COMBUSTION TECHNOLOGIES)
Complete SCHEDULE 6, Part F for plants where the sum of the nameplate capacity of the
steam-electric generators, including duct fired steam components of combined cycle units,
sum to 10 MW or more.
Complete one SCHEDULE 6 PART F for each unique Sulfur Dioxide Control System ID as
reported on SCHEDULE 6 PART A, Line 1, Row 5.
1. For line 1, What is the identification code for the equipment associated with this
sulfur dioxide control? Enter the sulfur dioxide control identification code as reported
on SCHEDULE 6, PART A, Line 1, Row 5 (Associated Sulfur Dioxide Control Systems)
2. For line 2, What type of sulfur dioxide control is this? Select the sulfur dioxide control
code from Table 25. Enter up to three for each Sulfur Dioxide Control Identification Code.
Table 25. Sulfur Dioxide Control Codes and Descriptions
Sulfur Dioxide
Control Codes
ACI
JB
MA
PA
SP
TR

Sulfur Dioxide Control Description
Activated carbon injection system
Jet bubbling reactor (wet) scrubber
Mechanically aided type (wet) scrubber
Packed type (wet) scrubber
Spray type (wet) scrubber
Tray type (wet) scrubber

FORM EIA-860
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ANNUAL ELECTRIC
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VE
CD
SD
DSI
OT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Venturi type (wet) scrubber
Circulating dry scrubber
Spray dryer type / dry FGD / semi-dry FGD
Dry sorbent (powder) injection type
Other (specify in SCHEDULE 7)

3. For line 3, What type(s) of sorbent(s) is used by this unit? Select up to four sorbent
codes from Table 26.
Table 26. Sorbent Type Codes and Descriptions
Sorbent Type Code
AF
AM
CSH
DB
LI
LS
MO
SA
TR
WT
OT

Type of Sorbent

Alkaline fly ash
Ammonia
Caustic Sodium hydroxide
Dibasic acid assisted
Lime / slacked lime / hydrated lime
Limestone / dolomitic limestone / calcium carbonate
Magnesium oxide
Soda ash / Sodium bicarbonate / Sodium carbonate / Sodium formate
/ Soda liquid
Trona
Water / Treated wastewater (select only if no other sorbent is used)
Other (specify in SCHEDULE 7)

4. For line 4, Is there any salable byproduct recovery? Enter “Yes” if there is any salable
byproduct recovery. Otherwise, enter “No.”
5. For line 5, What are the annual pond and land fill requirements? Report the annual
pond and land fill requirements in acre feet per year.
6. For line 6a, Is there a sludge pond associated with this unit? Indicate whether there
is a sludge pond associated with this FGD unit.
For line 6b, Is the sludge pond lined? Indicate whether the sludge pond is lined.
7. For line 7, Can flue gas bypass the flue gas desulfurization unit? Indicate whether
the flue gas can bypass the FGD unit.
8. For line 8, What is the design specification for ash when burning coal or petroleum
coke? Enter the design fuel specifications for ash (as burned) to the nearest 0.1 percent
of weight, when burning coal or petroleum coke, if applicable.
9. For line 9, What is the design specification for sulfur when burning coal or
petroleum coke? Enter the design fuel specifications for sulfur (as burned) to the
nearest 0.1 percent of weight, when burning coal or petroleum coke, if applicable.
10. For line 10, What is the total number of flue gas desulfurization unit scrubber trains

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ANNUAL ELECTRIC
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Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

or modules? Enter the total number of flue gas desulfurization unit scrubber trains or
modules operated.
11. For line 11, How many flue gas desulfurization unit scrubber trains or modules are
operated at 100 percent load? Enter how many flue gas desulfurization unit scrubber
trains or modules are operated at 100 percent load.
12. For line 12, What is this unit’s design removal efficiency for sulfur dioxide when
operating at 100 percent load? Report the design removal efficiency to nearest 0.1
percent by weight of gases removed from the flue gas when operating at 100 percent
generator load.
13. For line 13, What is the design sulfur dioxide emission rate for this unit when
operating at 100 percent load? Report the design sulfur dioxide emission rate in
pounds per hour when operating at 100 percent generator load.
14. For line 14, What is the flue gas exit rate for this unit? Report the flue gas exit rate in
actual cubic feet per minute when operating at 100 percent generator load.
15. For line 15, What is this unit’s flue gas exit temperature? Report the flue gas exit
temperature in degrees Fahrenheit when operating at 100 percent generator load.
16. For line 16, What percentage of flue gas enters the flue gas desulfurization unit
when operating at 100 percent load? Enter the percentage of flue gas entering this
FGD unit at a percent of total gas when operating at 100 percent generator load.
17. For line 17, What are the installed or anticipated costs of all FGD structures and
equipment, excluding land? Enter the nominal installed costs for the existing flue gas
desulfurization unit or the anticipated costs, in thousand dollars, to bring a planned flue
gas desulfurization unit into commercial operation. Installed cost should include the cost
of all major modifications. A major modification is any physical change which results in a
change in the amount of air or water pollutants or which results in a different pollutant
being emitted.
18. For line 18, What are the installed costs of the sludge transport and disposal
system? Enter the nominal installed costs for the sludge transport and disposal system,
or the anticipated costs, in thousand dollars, to bring a planned sludge transport and
disposal system into commercial operation. Installed cost should include the cost of all
major modifications. A major modification is any physical change which results in a
change in the amount of air or water pollutants or which results in a different pollutant
being emitted.
19. For line 19, What other installed costs are there pertaining to the installation of the
FGD unit? Enter any other nominal installed costs, in thousand dollars, pertaining to the
installation of the flue gas desulfurization unit, or any other costs related to bringing a
planned flue gas desulfurization unit into commercial operation. Installed cost should
include the cost of all major modifications. A major modification is any physical change
which results in a change in the amount of air or water pollutants or which results in a
different pollutant being emitted.
20. For 20, What are the total installed costs of the FGD unit? Enter the total nominal
installed cost, in thousand dollars, for the existing flue gas desulfurization unit or the total
anticipated costs to bring a planned flue gas desulfurization unit into commercial
operation. Installed cost should include the cost of all major modifications. A major

FORM EIA-860
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ANNUAL ELECTRIC
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modification is any physical change which results in a change in the amount of air or
water pollutants or which results in a different pollutant being emitted. This total will be
the sum of lines 17, 18, and 19.

SCHEDULE 6, PART G. STACK AND FLUE INFORMATION – DESIGN PARAMETERS
Complete SCHEDULE 6, Part G for plants where the sum of the nameplate capacity of the
steam-electric generators, including duct fired steam components of combined cycle units,
sum to 100 MW or more.
NOTE: A stack is defined as a vertical structure containing one or more flues used to
discharge products of combustion into the atmosphere. A flue is defined as an enclosed
passageway within a stack for directing products of combustion to the atmosphere. If the
stack has a single flue, use the stack identification for the flue identification
Complete one SCHEDULE 6 PART G for each Stack ID or Flue ID reported on SCHEDULE
6 PART A, Line 1, Row 8.
1. For line 1, What is this stack or flue equipment’s identification code? Enter the
identification code for each stack or flue as entered on SCHEDULE 6 PART A, Line 1,
Row 8.
2. For line 2, What is the actual or projected in-service date for this stack or flue?
Enter either the date on which the stack or flue began commercial operation or the date
(MM/YYYY) on which the stack or flue are expected to begin commercial operation.
3. For line 3, What was the status of this stack or flue as of December 31 of the
reporting year? Select one from the following equipment status codes from Table 27.
Table 27. Stack Status Codes and Description
Stack
Status Code
CN
CO
OP
OS
PL
RE
SB
SC
TS

Stack Status Code Description
Cancelled (previously reported as “planned”)
New unit under construction
Operating (in commercial service or out of service within 365
days)
Out of service (365 days or longer)
Planned (on order or expected to go into commercial service
within 10 years)
Retired (no longer in service and not expected to be returned to
service)
Standby (or inactive reserve, i.e., not normally used, but
available for service)
Cold Standby (Reserve); deactivated. Usually requires 3 to 6
months to reactivate
Operating under test conditions (not in commercial service).

4. For line 4, What is this stack’s height at the top, as measured from the ground?

FORM EIA-860
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ANNUAL ELECTRIC
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Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Enter the height of the stack in feet as measured from the ground by the plant.
5. For line 5, What is the cross-sectional area at the top of this stack? Enter the crosssectional area at the top of the stack as measured in square feet.
6. For line 6, What is the design flue gas exit rate at the top of the stack at 100 percent
load? Enter the design flue gas exit rate at the top of the stack when operating at 100
percent load as measured in actual cubic feet per minute. The rate should be
approximately equal to the cross-sectional area of the flue multiplied by the velocity and
then multiplied by 60.
7. For line 7, What is the design flue gas exit rate at the top of the stack at 50 percent
load? Enter the design flue gas exit rate at the top of the stack when operating at 50
percent load as measured in actual cubic feet per minute. The rate should be
approximately equal to the cross-sectional area of the flue multiplied by the velocity and
then multiplied by 60.
8. For line 8, What is the design flue gas exit temperature at the top of the stack at 100
percent load? Enter the design flue gas exit temperature in degrees Fahrenheit at the
top of the stack when operating at 100 percent load.
9. For line 9, What is the design flue gas exit temperature at the top of the stack at 50
percent load? Enter the design flue gas exit temperature in degrees Fahrenheit at the
top of the stack when operating at 50 percent load.
10. For line 10, What is the design flue gas velocity at the top of the stack at 100
percent load? Enter the design flue gas exit velocity in feet per second at the top of the
stack when operating at 100 percent load.
11. For line 11, What is the design flue gas velocity at the top of the stack at 50 percent
load? Enter the design flue gas exit velocity in feet per second at the top of the stack
when operating at 50 percent load.
12. For line 12, What is the average flue gas exit temperature for the summer season?
Enter the seasonal average flue gas exit temperature in degrees Fahrenheit, based on
the arithmetic mean of measurements during operating hours. Summer season includes
June, July, and August.
13. For line 13, What is the average flue gas exit temperature for the winter season?
Enter the seasonal average flue gas exit temperature in degrees Fahrenheit, based on
the arithmetic mean of measurements during operating hours. Winter season includes
December, January, and February (for example, when reporting for year 2013, use
December 2012, January 2013 and February 2013).
14. For line 14, Were the average flue gas exit temperatures measures or estimated?
Indicate whether the flue gas exit temperatures used to calculate the mean values
reported on Lines 13 and 14 were measured or estimated.

SCHEDULE 7. COMMENTS
This schedule provides additional space for comments. Please identify schedule, part, and

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

question and include identifying information (e.g., plant code, boiler id, generator id) for each
comment. Use additional pages, if necessary.

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Table 28. Energy Source Codes and Heat Content
Fuel Type

Coal

Petroleum
Products

Natural
Gas and
Other
Gases

Solid
Renewable
Fuels

Higher Heating
Value Range
MMBtu
MMBtu
Lower
Upper
Fossil Fuels
22
28
20
29
10
14.5
0.2
0.3
15
20

Energy
Source
Code

Unit
Label

ANT
BIT
LIG
SGC
SUB

Tons
Tons
Tons
Mcf
Tons

tons

6.5

tons

DFO

barrels

5.5

6.2

JF
KER
PC

barrels
barrels
tons

5
5.6
24

6
6.1
30

Anthracite Coal
Bituminous Coal
Lignite Coal
Coal-Derived Synthesis Gas
Subbituminous Coal
Waste/Other Coal (incl. anthracite
culm, bituminous gob, fine coal,
lignite waste, waste coal)
Refined Coal
Distillate Fuel Oil (including
diesel, No. 1, No. 2, and No. 4
fuel oils)
Jet Fuel
Kerosene
Petroleum Coke

Mcf

2.5

2.75

Gaseous Propane

RFO

barrels

5.8

6.8

SGP

Mcf

0.2

1.1

barrels

3.0

5.8

BFG
NG
H2

Mcf
Mcf
Mcf

0.07
0.8
0.3

0.12
1.1
0.4

Mcf

0.32

3.3

AB
MSW

tons
tons

OBS

tons

WDS

tons

Renewable Fuels
7
18
9
12

Energy Source Description

Residual Fuel Oil (incl. Nos. 5 & 6
fuel oils, and bunker C fuel oil)
Synthesis Gas from Petroleum
Coke
Waste/Other Oil (including crude
oil, liquid butane, liquid propane,
naphtha, oil waste, re-refined
motor oil, sludge oil, tar oil, or
other petroleum-based liquid
wastes)
Blast Furnace Gas
Natural Gas
Hydrogen
Other Gas (specify in
SCHEDULE 7)
Agricultural By-Products
Municipal Solid Waste
Other Biomass Solids (specify in
SCHEDULE 7)
Wood/Wood Waste Solids (incl.
paper pellets, railroad ties, utility
poles, wood chips, bark, and
wood waste solids)

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Fuel Type

Liquid
Renewable
(Biomass)
Fuels

Gaseous
Renewable
(Biomass)
Fuels

All Other
Renewable
Fuels

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Higher Heating
Value Range
MMBtu
MMBtu
Lower
Upper
Renewable Fuels

Energy
Source
Code

Unit
Label

OBL

barrels

3.5

SLW
BLQ

tons
tons

10
10

16
14

WDL

barrels

LFG

Mcf

0.3

0.6

OBG

Mcf

0.36

1.6

SUN
WND
GEO

N/A
N/A
N/A

WAT

N/A

All Other Fuels

All Other
Energy
Sources

WAT

MWh

N/A

NUC

N/A

PUR

N/A

TDF
MWH

Tons
MWh

16
N/A

32
N/A

OTH

N/A

Energy Source Description

Other Biomass Liquids (specify
in SCHEDULE 7)
Sludge Waste
Black Liquor
Wood Waste Liquids excluding
Black Liquor (including red
liquor, sludge wood, spent
sulfite liquor, and other woodbased liquids)
Landfill Gas
Other Biomass Gas (including
digester gas, methane, and
other biomass gases; specify in
SCHEDULE 7)
Solar
Wind
Geothermal
Water at a Conventional
Hydroelectric Turbine, and water
used in Wave Buoy Hydrokinetic
Technology, Current
Hydrokinetic Technology, and
Tidal Hydrokinetic Technology
Pumping Energy for Reversible
(Pumped Storage) Hydroelectric
Turbine
Nuclear (including Uranium,
Plutonium, and Thorium)
Purchased Steam
Waste heat not directly
attributed to a fuel source (WH
should only be reported when
the fuel source is undetermined,
and for combined cycle steam
turbines that do not have
supplemental firing.)
Tire-derived Fuels
Electricity used for energy
storage
Specify in SCHEDULE 7

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Table 29. Commonly Used North American Industry Classification System (NAICS)
Codes
111
112
113
114
115

Agriculture, Forestry, Fishing and Hunting
Crop Production
Animal Production and Aquaculture
Forestry and Logging
Fishing, Hunting and Trapping
Support Activities for Agriculture and Forestry

211
2121
2122
2123

Mining, Quarrying, and Oil and Gas Extraction
Oil and Gas Extraction
Coal Mining
Metal Ore Mining
Nonmetallic Mineral Mining and Quarrying

22
2212
22131
22132
22133

Utilities
Electric Power Generation, Transmission and Distribution (other than 2212,
2213, 22131, 22132 or 22133)
Natural Gas Distribution
Water Supply and Irrigation Systems
Sewage Treatment Facilities
Steam and Air-Conditioning Supply

Construction
Construction

311
312
313
314
315
316
321
322
322122
32213
323
324
32411
325
32511
32512

Manufacturing
Food Manufacturing
Beverage and Tobacco Product Manufacturing
Textile Mills (Fiber, Yarn, Thread, Fabric, and Textiles)
Textile Product Mills
Apparel Manufacturing
Leather and Allied Product Manufacturing
Wood Product Manufacturing
Paper Manufacturing (other than 322122 or 32213)
Newsprint Mills
Paperboard Mills
Printing and Related Support Activities
Petroleum and Coal Products Manufacturing (other than 32411)
Petroleum Refineries
Chemical Manufacturing (other than 32511, 32512, 325193, 3252 325211, 3253
or 325311)
Petrochemical Manufacturing
Industrial Gas Manufacturing

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT
325188
325193

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

3253
325311
326
327
32731
331
3311
3313
332
333
334
335
336
337
339

Industrial Inorganic Chemicals
Ethyl Alcohol Manufacturing (including Ethanol)
Resin, Synthetic Rubber, and Artificial Synthetic Fibers and Filaments
Manufacturing (other than 325211)
Plastics Material and Resin Manufacturing
Pesticide, Fertilizer, and Other Agricultural Chemical Manufacturing (other than
325311)
Nitrogenous Fertilizer Manufacturing
Plastics and Rubber Products Manufacturing
Nonmetallic Mineral Product Manufacturing (other than 32731)
Cement Manufacturing
Primary Metal Manufacturing (other than 3311 or 3313)
Iron and Steel Mills and Ferroalloy Manufacturing
Alumina and Aluminum Production and Processing
Fabricated Metal Product Manufacturing
Machinery Manufacturing
Computer and Electronic Product Manufacturing
Electrical Equipment, Appliance, and Component Manufacturing
Transportation Equipment Manufacturing
Furniture and Related Product Manufacturing
Miscellaneous Manufacturing

421

Wholesale Trade

441

Retail Trade

481
482
483
484
485
486
487
488
4881
4882
4883
4884
491
492
493

Transportation and Warehousing
Air Transportation
Rail Transportation
Water Transportation
Truck Transportation
Transit and Ground Passenger Transportation
Pipeline Transportation
Scenic and Sightseeing Transportation
Support Activities for Transportation (other than 4881, 4882, 4883 or 4884)
Support Activities for Air Transportation (including Airports)
Support Activities for Rail Transportation (including Rail Stations)
Support Activities for Water Transportation (including Marinas)
Support Activities for Road Transportation
Postal Service
Couriers and Messengers
Warehousing and Storage

511
512

Information
Publishing Industries (except Internet)
Motion Picture and Sound Recording Industries

3252
325211

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

515
517
518
519

Broadcasting (except Internet)
Telecommunications
Data Processing, Hosting, and Related Services
Other Information Services

521

Finance and Insurance

Real Estate and Rental and Leasing (including Convention Centers and
Office Buildings)

541

Professional, Scientific, and Technical Services

Management of Companies and Enterprises

561
562
562212
562213

Administrative and Support and Waste Management and Remediation
Services
Administrative and Support Services
Waste Management and Remediation Services (other than 562212 or 562213)
Solid Waste Landfill
Solid Waste Combustors and Incinerators

611

Educational Services

621
622
623
624

Health Care and Social Assistance
Ambulatory Health Care Services
Hospitals
Nursing and Residential Care Facilities
Social Assistance

711
712
713

Arts, Entertainment, and Recreation
Performing Arts, Spectator Sports, and Related Industries
Museums, Historical Sites, and Similar Institutions
Amusement, Gambling, and Recreation Industries

721
722

Accommodation and Food Services
Accommodation
Food Services and Drinking Places

811
812
813
814

Other Services (except Public Administration)
Repair and Maintenance
Personal and Laundry Services
Religious, Grantmaking, Civic, Professional, and Similar Organizations
Private Households

92
921

Public Administration (other than 921, 922, 92214 or 928)
Executive, Legislative, and Other General Government Services

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT
922
92214
928

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

Justice, Public Order and Safety Activities (other than 92214)
Correctional Facilities
National Security and International Affairs (including Military Bases)

GLOSSARY

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

The glossary for this form is available online at the following URL:
http://www.eia.gov/glossary/index.html
SANCTIONS
The timely submission of Form EIA-860 by those required to report is mandatory under 15
U.S.C. §772(b), as amended. Failure to respond may result in a civil penalty of not more than
$10,633 each day for each violation. The government may bring a civil action to prohibit
reporting violations which may result in a temporary restraining order or a preliminary or
permanent injunction without bond. In such civil action, the court may also issue mandatory
injunctions commanding any person to comply with these reporting requirements.
REPORTING BURDEN
Public reporting burden for this collection of information is estimated to average 7.6 hours per
response for respondents without environmental information and 16.0 hours per response for
respondents with environmental information, including the time for reviewing instructions,
searching existing data sources, gathering and maintaining the data needed, and completing and
reviewing the collection of information. Send comments regarding this burden estimate or any
other aspect of this collection of information, including suggestions for reducing this burden, to
the U.S. Energy Information Administration, Office of Survey Development and Statistical
Integration, EI-21 Forrestal Building, 1000 Independence Avenue SW, Washington, DC 205850670; and to the Office of Information and Regulatory Affairs, Office of Management and
Budget, Washington, D.C. 20503. A person is not required to respond to the collection of
information unless the form displays a valid OMB number.
DISCLOSURE OF INFORMATION
The following information reported on this survey will be protected and not disclosed to the
extent that it satisfies the criteria for exemption under the Freedom of Information Act (FOIA), 5
U.S.C. §552, the Department of Energy (DOE) regulations, 10 C.F.R. §1004.11, implementing
the FOIA, and the Trade Secrets Act, 18 U.S.C. §1905:
•All information associated with the “Survey Contact” and the “Supervisor of Contact
Person for Survey” on SCHEDULE 1.
•Information reported for the data element “Tested Heat Rate” on SCHEDULE 3, PART
B, GENERATOR INFORMATION – EXISTING GENERATORS
•All data reported on Parts A and B of SCHEDULE 5, GENERATOR COST
INFORMATION

FORM EIA-860
INSTRUCTIONS
ANNUAL ELECTRIC
GENERATOR REPORT

Approval: OMB No. 1905-0129
Approval Expires: xx/xx/xxxx
Burden: 16.0 Hours

All other information reported on Form EIA-860 will be treated as non-sensitive and may be
publicly released in identifiable form.
The Federal Energy Administration Act requires EIA to provide company-specific data to other
Federal agencies when requested for official use. The information reported on this form may
also be made available, upon request, to another component of the Department of Energy (DOE),
to any Committee of Congress, the Government Accountability Office, or other Federal agencies
authorized by law to receive such information. A court of competent jurisdiction may obtain this
information in response to an order. The information may be used for any nonstatistical
purposes such as administrative, regulatory, law enforcement, or adjudicatory purposes.
With the exception of data on the costs of constructing power plants, data protection methods are
not applied to the aggregate statistical data published from this survey. There may be some
statistics that are based on data from fewer than three respondents, or that are dominated by data
from one or two large respondents. In these cases, it may be possible for a knowledgeable person
to closely estimate the information reported by a specific respondent.

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Author	Robert Rutchik
File Modified	2022-11-14
File Created	2022-05-23