Electric Power Surveys

U.S. Department of Energy
Energy Information Administration
Form EIA-923

POWER PLANT OPERATIONS
REPORT INSTRUCTIONS

Form Approval
OMB No. 1905-0129
Approval Expires:

PURPOSE

Form EIA-923 collects information from all electric power plants and combined heat and power
(CHP) plants in the United States. Data collected on this form include electric power generation,
fuel consumption, fossil fuel stocks, and delivered fossil fuel cost and quality. These data are
used to monitor the status and trends of the electric power industry and appear in many Energy
Information Administration (EIA) publications including: Electric Power Monthly, Electric Power
Annual, Monthly Energy Review, Annual Energy Review, Natural Gas Monthly, Natural Gas
Annual, Cost and Quality of Fuels, Quarterly Coal Report, and the Renewable Energy Annual.
Further information can be found at http://www.eia.doe.gov/fuelelectric.html. The “Stocks at End
of Reporting Period” information (SCHEDULE 4), Nonutility “Total Delivered Cost,” information
(SCHEDULE 2), and “Commodity Cost” information (SCHEDULE 2) reported on this form are
protected information.

REQUIRED
RESPONDENTS

The Form EIA-923 is a mandatory report for all electric power plants and CHP plants that meet the
following criteria: 1) have a total generating capacity of 1 megawatt (MW) or more and 2) are
connected to the electric grid. To lessen the reporting burden, a sample of plants is collected on a
monthly basis. Plants that are not selected to respond monthly must respond annually for the
calendar year. See instructions for each schedule for more specific filing requirements.

RESPONSE DUE
DATE

Monthly respondents are required to file SCHEDULE 1 through SCHEDULE 5 and SCHEDULE
9 of this form with EIA by the last day of the month following the reporting period. For example, if
reporting for July, survey data are due on August 31. SCHEDULE 6 through SCHEDULE 8 must
be filed by March 30 following the end of the reporting year.
Annual respondents are required to file the form with EIA by March 30 following the close of the
reporting year.

METHODS OF
FILING RESPONSE

Submit your data electronically using EIA’s secure Internet Data Collection (IDC) system. This
system uses security protocols to protect information against unauthorized access during
transmission.
•

If you have not registered with the IDC Single Sign-On (SSO) system, send an e-mail
requesting assistance to: [email protected].

•

If you have registered with SSO, log on at: https://signon.eia.doe.gov/ssoserver/login

•

If you are having a technical problem with logging into or using the IDC system, contact
the IDC Help Desk at:
E-mail: [email protected]
Phone: 202-586-9595

•

If you need an alternate means of filing your response, contact the Help Desk.

Retain a completed copy of this form for your files.
CONTACTS

Internet System Questions: For questions related to the IDC system, see the help contact
information immediately above.
Data Questions: For questions about the data requested on the Form EIA-923, contact the
Survey Manager:
Name: TBD
Telephone: (202) 586-XXXX
FAX: (202) 287-XXXX
E-mail: [email protected]

1

U.S. Department of Energy
Energy Information Administration
Form EIA-923
GENERAL
INSTRUCTIONS

POWER PLANT OPERATIONS
REPORT INSTRUCTIONS

Form Approval
OMB No. 1905-0129
Approval Expires:

Revision Policy: Submit revisions to data previously reported as soon as possible after the
error or omission is discovered. Do not wait to revise data until the next reporting month's form
is due. Revisions or adjustments to data should be made only to the survey month(s) to which
they pertain. (Do not adjust the current month to reflect a revision or adjustment to a prior
month submission.)
•
•

Log on to the IDC system, re-key revised data, indicate in SCHEDULE 9 the nature and
date of the revision, and resubmit the data.
Remember to save and RESUBMIT (click on the SUBMIT button).

If you are unable to make a revision through the IDC system because the monthly data file
has been closed, please e-mail your changes to [email protected], and indicate ‘Revision’
in subject line. Be sure to include your Plant ID, the specific revision, and the month that is
being revised.
Correcting Preprinted Information. Much of the information on the form is preprinted by
EIA. If you need to correct or add to the administrative information, e.g., contact name or email address, click on the CHANGE CONTACT Tab on SCHEDULE 1 and enter the changes.
Please note that PLANT NAME, PLANT CODE, and COMPANY NAME cannot be changed.
Contact the survey manager if these items are incorrect.
If you report via Internet Secure File Transfer, facsimile, or e-mail, you may send a
corrected copy of the form, but be sure to indicate in SCHEDULE 9: (1) that it is a
revision, (2) the month that is being revised, (3) what has been revised, and (4) the date
of the revision.
ITEM-BY-ITEM
INSTRUCTIONS

SCHEDULE 1. IDENTIFICATION
1. Survey Contact: Verify contact name, title, address, telephone number, Fax number, and email address.
2. Supervisor of Contact Person for Survey: Verify the contact’s supervisor’s name, title,
address, telephone number, Fax number and e-mail address.
If any of the above information is incorrect, revise the incorrect entry and provide the correct
information. Provide any missing information.
3. Report For: Verify all information, including company name, plant name, plant identification
number, plant State and county, and month or year for which data are being reported. State
codes are two-character U.S. Postal Service abbreviations. These fields cannot be revised
online. Contact the EIA-923 survey manager if corrections are needed.
SCHEDULE 2. COST AND QUALITY OF FUEL RECEIPTS – PLANT-LEVEL
REQUIRED RESPONDENTS: Plants with a total nameplate capacity of 50 MW and above
that use fossil fuels (coal, petroleum products, petroleum coke, natural gas, and other
gases (including blast furnace gas)) for the generation of electric power must complete the
appropriate data on Schedule 2, Cost and Quality of Fuel Receipts.
Plant Name, Plant ID, State, Reporting Month and Year: Verify the preprinted information for
those items at the top of this (and all) page(s).
If no fuel was received during the reporting period, place a check in the “No Receipts” box, and go
to Schedule 3.
If this plant has a tolling agreement and the toller will not divulge the cost of the fuel, you may
leave both the commodity and delivered prices blank. Be sure to indicate that there is a tolling
agreement currently in place by entering a check in the box at the center of the page.
2

U.S. Department of Energy
Energy Information Administration
Form EIA-923

Form Approval
OMB No. 1905-0129
Approval Expires:
Contract Information

POWER PLANT OPERATIONS
REPORT INSTRUCTIONS

1. Fuel Supplier Name: For all fossil fuel receipts, enter the name of the company or broker from
whom the fuel was purchased. For natural gas receipts, DO NOT provide the name of the
company providing the transportation service.
Electric generating plants should report all deliveries of fossil fuels received that will ultimately
be used for electric power generation. Combined heat and power plants should report all fuel
received for both electric power generation and useful thermal output. Fuel purchased but sent
to an off-site storage plant should not be reported until it is actually delivered to the plant.
Examples include:

a. Coal that is purchased and sent to a river dock for storage before final
shipment to the plant. This coal should not be reported until it is actually delivered
to the plant. The filing to EIA should show as the source of the coal the originating
mine(s) or county if information can be obtained from inventory accounting or
estimated; otherwise, the dock should be shown as the origin source.

b. Natural gas that is purchased and injected into storage. This gas should not be
reported until it is actually delivered to the plant.
Coal: Report data by supplier. Data on coal received under each purchase order or contract
with a supplier should be reported separately. Aggregation of coal receipt data into a single
line item is allowed if the coal is received under the same purchase order or contract and the
purchase type, coal type, mine type, Mine Safety and Health Administration (MSHA) ID, State
of origin, county of origin, and supplier are identical for each delivery. For example, 10
trainloads of contract, surface-mined subbituminous coal from the Black Thunder mine in
Campbell County, Wyoming may be reported as one line item. The reported quality and cost
data would then be a weighted average of the aggregated deliveries.
Coal received from spot-market purchases and from contract purchases should never
be aggregated and reported as one line item. If coal received under a purchase order or
contract originates in more than one county and a county-level breakdown is not available,
report estimates for each county. If estimates are not available, report the origin as the county
where the majority of the coal originates.
Petroleum and Gas: Report data by supplier, or aggregate by pipeline or distributor.
Aggregation of fuel deliveries from various suppliers is allowed only if the purchase type and
fuel are identical. The reported cost and quality data would be the weighted average of the
aggregated deliveries. Contract or spot-market purchases must be reported as separate line
items and should never be aggregated and reported as one delivery.
2. Contract Type: Use the following codes for coal, petroleum and natural gas purchases:
C – Contract Purchase – Fuel received under a purchase order or contract with a term of one
year or longer.
NC – New Contract or Renegotiated Contract Purchase – Fuel received under a purchase
order or contract with a duration of one year or longer, under which deliveries were first made
during the reporting month.
S – Spot-Market Purchase – Fuel received under a purchase order or contract that has a
duration of less than one year.
3. Contract Expiration Date: Enter the month and the year the purchase order or contract
expires. For example, report “1108” for a November 2008 expiration date. This column should
be left blank if Contract Type contains an “S” for spot-market purchase.
3

U.S. Department of Energy
Energy Information Administration
Form EIA-923

POWER PLANT OPERATIONS
REPORT INSTRUCTIONS

Form Approval
OMB No. 1905-0129
Approval Expires:

Receipts
4. Energy Source: Identify purchased fossil fuels (including start-up and flame stabilization fuel)
using the following abbreviations:

Fuel Type

Coal and
Syncoal

Petroleum
Products

Natural
Gas
and Other
Gases

Table 1
“Higher Heating
Value” Range
(Million Btu per
unit of Fuel)
Low
High
Value
Value
20
29
10
14.5

Energy
Source
Code

Units

BIT
LIG

tons
tons

SC

tons

10

35

SUB

tons

15

20

WC

tons

6.5

16

DFO

barrels

5.5

6.2

JF
KER
PC

barrels
barrels
tons

5
5.6
24

6
6.1
30

RFO

barrels

5.8

6.8

WO

barrels

3.0

5.8

BFG
NG

Mcf
Mcf

0.07
0.8

0.12
1.1

OG

Mcf

0.32

3.3

SG
SGC

Mcf
Mcf

0.2
0.2

1.1
0.3

Energy Source Description

Anthracite Coal, Bituminous Coal
Lignite Coal
Coal-based Synfuel (including
briquettes, pellets, or extrusions, which
are formed by binding materials or
processes that recycle materials)
Subbituminous Coal
Waste/Other Coal (including anthracite
culms, bituminous gob, fine coal, lignite
waste, waste coal)
Distillate Fuel Oil (including all diesel
and No. 1, No. 2, and No. 4 fuel oils.
Jet Fuel
Kerosene
Petroleum Coke
Residual Fuel Oil (including No. 5 and
No. 6 fuel oils and bunker C fuel oil)
Waste/Other Oil (including crude oil,
liquid butane, liquid propane, oil waste,
re-refined motor oil, sludge oil, tar oil, or
other petroleum-based liquid wastes)
Blast Furnace Gas
Natural Gas
Other Gas Includes manufactured gas,
coke-oven gas, and refinery gas
Synthetic Gas
Coal-derived Synthetic Gas

5. Quantity Received: Enter quantities in tons for coal and other solid fuels, barrels for oil and
other liquid fuels, and thousands of cubic feet for gas. The receipts reported should pertain to
the fuel that will ultimately be used for electric power generation and thermal energy
associated with the production of electricity. Include fuel receipts for use in a cogeneration
system, such as fuel used for process steam, direct heating, space heating/cooling, or steam
delivered to other end users.
Cost of Fuel
6. Total Delivered Cost (all fuels): Enter the delivered cost of the fuel in cents per million Btu
to the nearest 0.1 cent. This cost should include all costs incurred in the purchase and
delivery of the fuel to the plant. It should not include unloading costs. Do not include
adjustments associated with prior months’ fuel costs. The delivered price for fuel shipped
4

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
under contract should include any penalties/premiums paid or expected to be paid on the fuel
delivered during the month. These adjustments should be made only by revising the
appropriate prior months’ submissions. The current month fuel costs should reflect only
costs associated with the current month fuel deliveries.
7. Commodity Cost (Coal and Natural Gas): The FOB (free on board) price paid by the plant
for the fuel, exclusive of any charges for moving the fuel to the plant. In the case of coal this is
typically the cost of coal FOB railcar, barge, or truck. In the case of natural gas this is typically
the price of the gas FOB the transmission pipeline.
Quality of Fuel as Received
8. Heat Content: Enter the average Btu content for each fuel in terms of million Btu (MMBtu) per
ton for solid fuel, MMBtu per barrel for liquid fuel, and MMBtu per thousand cubic feet for gas.
Show to the nearest 0.001 MMBtu.
9. Sulfur Content: For all fuels except gas, enter the sulfur content of the fuel in terms of
percent sulfur by weight. Show to the nearest 0.01 percent.
10. Ash Content: For coal only, enter the ash content of the fuel in terms of percent ash by
weight. Show to the nearest 0.1 percent. Comment if the reported ash content for coal is an
estimate.
11. Mercury Content: For coal only, enter the mercury content in parts per million (ppm). If lab
tests of the coal receipts do not include the mercury content, enter the amount specified in the
contract with the supplier.
Fuel Transportation
12. Natural Gas: Use the following codes for natural gas transportation service:
F – Firm – Gas transportation service provided on a firm basis using facilities that were
designed, installed, and dedicated to a certified quantity of service. The contract with the gas
transportation company anticipates no interruption of gas transportation service. Firm
transportation service takes priority over interruptible service.
I – Interruptible – Gas transportation service (usually low-priority service) provided under
schedules or contracts which anticipate and permit interruption on short notice, generally in
peak-load seasons, by reason of the claim of firm service customers and higher priority users.
13. Predominant Mode: The method used to transport the fuel over the longest distance from
point of origin to consumer. If the shipment involves only one mode of transportation, that is
the Predominant Mode. If the shipment involves more than one mode of transportation, see
Secondary Mode below.
14. Secondary Mode: If more than one method of transportation is used in a single shipment, the
Secondary Mode of transportation is the method used to transport the fuel over the second
longest distance from point of origin to consumer. If two methods are used to transport a
shipment and both distances are equal, then the Predominant Mode is the method used to
transport the fuel from the source and the Secondary Mode is the method used to deliver the
fuel to the consumer. If more than two methods are used in a single shipment, only the
Predominant and Secondary Modes should be reported.
Do not report “truck” as a transportation mode if trucks are used to transport coal exclusively
on private roads between the mine and rail load-out or barge terminal.
Do not report the transportation modes used entirely within a mine, terminal, or power plant
(e.g., trucks used to move coal from a mine pit to the mine load-out; conveyors at a power
5

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
plant used to move coal from the plant storage pile to the plant).
For mine mouth coal plants, report “Conveyor” as the Predominant Mode if the conveyor
feeding coal to the plant site originates at the mine. Otherwise report the Predominant Mode
(typically truck or rail) used to move the coal to the plant site.
Report Transportation Modes using the following codes:
RR – Rail: Shipments of fuel moved to consumers by rail (private or public/commercial).
Included is coal hauled to or away from a railroad siding by truck if the truck did not
use public roads.
RV – River: Shipments of fuel moved to consumers via river by barge. Not included are
shipments to Great Lakes coal loading docks, tidewater piers, or coastal ports.
GL – Great Lakes: Shipments of coal moved to consumers via the Great Lakes. These
shipments are moved via the Great Lakes coal loading docks, which are identified by
name and location as follows:
Conneaut Coal Storage & Transfer, Conneaut, Ohio
NS Coal Dock (Ashtabula Coal Dock), Ashtabula, Ohio
Sandusky Coal Pier, Sandusky, Ohio
Toledo Docks, Toledo, Ohio
KCBX Terminals Inc., Chicago, Illinois
Superior Midwest Energy Terminal, Superior, Wisconsin
TP – Tidewater Piers and Coastal Ports: Shipments of coal moved to Tidewater Piers
and Coastal Ports for further shipments to consumers via coastal water or ocean. The
Tidewater Piers and Coastal Ports are identified by name and location as follows:
Dominion Terminal Associates, Newport News, Virginia
McDuffie Coal Terminal, Mobile, Alabama
IC Railmarine Terminal, Convent, Louisiana
International Marine Terminals, Myrtle Grove, Louisiana
Cooper/T. Smith Stevedoring Co. Inc., Darrow, Louisiana
Seward Terminal Inc., Seward, Alaska
Los Angeles Export Terminal, Inc., Los Angeles, California
Levin-Richmond Terminal Corp., Richmond, California
Baltimore Terminal, Baltimore, Maryland
Norfolk Southern Lamberts Point P-6, Norfolk, Virginia
Chesapeake Bay Piers, Baltimore, Maryland
Pier IX Terminal Company, Newport News, Virginia
Electro-Coal Transport Corp., Davant, Louisiana
TR – Truck: Shipments of fuel moved to consumers by truck. Not included is fuel hauled
to or away from a railroad siding by truck on non-public roads.
TC – Tramway/Conveyor: Shipments of fuel moved to consumers by tramway or
conveyor.
SP – Slurry Pipeline: Shipments of coal moved to consumers by slurry pipeline.
PL – Pipeline: Shipments of fuel moved to consumers by pipeline.
WT – Water: Shipments of fuel moved to consumers by other waterways.
Coal Mine and Type
15. Mine Safety and Health Administration (MSHA) ID Number: Enter the MSHA ID number.
The MSHA ID should match the ID located at the top of most MSHA forms.
6

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
16. Name of Mine or Tipple: Insert the name of the mine or tipple.
17. Mine Type: Insert “S” for surface-mined or “U” for underground-mined. If the coal received is
a blend of surface and underground, use “S/U” or “U/S.” This notation will result in a 0.67/0.33
allocation. Do not combine separate deliveries of surface-mined coal and underground-mined
coal using the designation of “S/U” or “U/S.” These must be reported using the corresponding
“S” or “U” mine type.
18. State or Country of Origin: Use the two-letter U.S. Postal Service abbreviation to show the
State in which the coal was mined. Do not report the location of the preparation plants or
transfer facilities, but rather the location of the mine(s). Verify the State of origin with the
supplier. If the origin cannot be determined, report on SCHEDULE 9, the State of origin based
on the most likely probability.
For imported coal, insert the two-letter country code shown here, in combination with IMP in
the county code field.
AS – Australia; CN – Canada; CL – Colombia; ID – Indonesia; PL – Poland;
RS– Russia; VZ – Venezuela; OT – Other.
19. County: Insert the three-digit Federal Information Processing Standards (FIPS) County Code,
http://www.itl.nist.gov/fipspubs/co-codes/states.htm, to show the county in which the coal was
mined. (For IDC users, a dropdown list is provided for your convenience. Double click on the
county code box to access the dropdown list.) Do not report the location of the transfer
facilities, shipping facilities, preparation plants, or mining company headquarters. Use only
the mine location to determine the county of origin. If the coal from the supplier originates
from more than one county, use separate lines to show county of origin and appropriate
quantity, quality, and cost data. For imported coal, IMP should be entered.
SCHEDULE 3. PART A. BOILER INFORMATION
FOR STEAM-ELECTRIC ORGANIC-FUELED PLANTS – FUEL CONSUMPTION
Required Respondents: Complete this schedule for fuels consumed in the boilers at plants with
steam turbines that have a total nameplate capacity of 10 MW and above and burn organic fuels.
This does not include steam turbines where the energy source is nuclear, geothermal, or solar, or
plants that have less than 10 MW total steam turbine nameplate capacity. Also report on this
schedule, fuels consumed at combined-cycle plants for supplementary firing of heat recovery
steam generator (HRSG) units that have a total steam turbine nameplate capacity of 10 MW and
above. For fuels consumed by gas turbines, including the gas turbines at combined-cycle plants,
IC engines, or pumped-storage hydroelectric plants, report fuel consumption on SCHEDULE 3.
PART B.
Boiler ID: Identification information should be a code commonly used by plant management for
that equipment (e.g., “2,” “A101,” “7B,” etc.). Select a code for each piece of equipment and use it
for that equipment when reporting on EIA forms, specifically the Forms EIA-860 and EIA-923. The
code should be a maximum of six characters long and should conform to codes reported for the
same equipment (especially generators) on other EIA forms. Do not use blanks in the code.
If any of the boilers produced steam for purposes other than electric power generation during this
reporting period please place a check in the box on the form.
Energy Source: Report all fuels consumed for all purposes. Use the fuel codes in Table 3 on
pages 17 through 19.
Quantity Consumed: For each month, report the amount of fuel consumed for electric power
generation and thermal energy associated with the production of electricity. Include all fuel used
in a cogeneration system, such as fuel used for process steam, direct heating, space heating, or
thermal output delivered to other end users. Combined-cycle units should report only the auxiliary
7

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
firing fuel associated with the HRSG. Do no repost the fuel associated with the combustion
turbine portion of the combined-cycle unit.
Type of Physical Units: Fuel consumption must be reported in the following units:
•
Solids – Tons
•
Liquids – Barrels (one barrel equals 42 U.S. gallons)
•
Gases – Thousands of cubic feet (Mcf)
Average Heat Content: For each month, report the heat content of the fuels burned in million Btu
(MMBtu) per physical unit. The heat content of the fuel should be reported as the gross or “higher
heating value” (rather than the net or lower heating value). The higher heating value exceeds the
lower heating value by the latent heat of vaporization of the water. The heating value of fuels
generally used and reported in a fuel analysis, unless otherwise specified, is the higher heating
value. If the fuel heat content cannot be reported “as burned,” data may be obtained from the fuel
supplier on an “as received” basis. If this is the case, indicate on SCHEDULE 9 that the fuel heat
content data are “as received.” Report the value in the following units: solids in million Btu
(MMBtu) per ton; liquids in MMBtu per barrel; and gases in MMBtu per thousand cubic feet (Mcf).
Refer to Table 3 on pages 17 through 19 for approximate ranges of Heat Content of specific
energy sources.
Sulfur Content (petroleum, petroleum coke, and coal): For each month, enter sulfur content in
column (d) to nearest 0.01 percent. Sulfur content should be reported for the following fuel codes:
BIT, LIG, SUB, WC, PC, SC, DFO, JF, KER, RFO, and WO.
Ash Content (coal only): For each month, enter ash content in column (e) to the nearest 0.01
percent. Ash content should be reported for the following fuel codes: BIT, LIG, SUB, WC, and SC.
Report actual values. If necessary, report estimated values and state that the value is an
estimate on SCHEDULE 9.
ENTER ZERO when an energy source was not consumed for the reporting period. Do not leave
blank.
SCHEDULE 3. PART B. FUEL CONSUMPTION – PRIME MOVER-LEVEL
Required Respondents: Report fuel consumed in all combustion turbines, internal combustion
engines, steam-electric plants under 10 megawatts, and pumped-storage hydroelectric plants.
Excluded from this schedule are conventional hydroelectric plants and all other plants that do not
consume a combustible energy source (e.g., wind, solar, geothermal, and nuclear). Do not report
for each individual unit. For example, report natural gas consumed in all combustion turbines at
the plant as one value and report distillate fuel oil consumed by all IC engines as one value.
Combined-cycle plants should report the fuel consumed by the combustion turbines on this
schedule. Report supplementary fuel consumed by the HRSG on this schedule only if the steam
turbine is less than 10 MW. Supplementary-fired HRSGs 10 MW and above must report on
Schedule 3A.
Prime movers are devices that convert one energy form (such as heat from fuels or the motion of
water or wind) into mechanical energy. Examples include steam turbines, combustion turbines,
reciprocating engines, and water turbines.
If steam was produced for purposes other than electric power generation during this reporting
period, please place a check in the box on the form.
Prime Mover Type: If the preprinted prime mover code is incorrect, delete the code and choose
the correct prime mover code from this prime mover table.
Prime Mover Type _Prime Mover Description
8

U.S. Department of Energy
Energy Information Administration
Form EIA-923
CA
CE
CS
CT
FC
GT
HY
IC
PS
BT
PV
ST
WT
OT

POWER PLANT OPERATIONS
REPORT INSTRUCTIONS

Form Approval
OMB No. 1905-0129
Approval Expires:

Combined-Cycle – Steam Part
Compressed Air Energy Storage
Combined-Cycle Single Shaft – Combustion turbine and steam turbine
share a single generator
Combined-Cycle Combustion – Turbine Part
Fuel Cell
Combustion (Gas) Turbine (including jet engine design)
Hydraulic Turbine (including turbines associated with delivery of water by
pipeline)
Internal Combustion (diesel, piston) Engine
Hydraulic Turbine – Reversible (pumped storage)
Turbines Used in a Binary Cycle (such as used for geothermal applications)
Photovoltaic
Steam Turbine (including nuclear, geothermal and solar steam, excluding
combined-cycle)
Wind Turbine
Other – Specify on SCHEDULE 9.

Report actual values. If necessary, report estimated values and state that the value is an
estimate on SCHEDULE 9.
Energy Source: Report all fuels consumed for all purposes. Use the fuel codes in Table 3 on
pages 17 through 19.
Quantity Consumed: For each month, report the amount of fuel consumed for electric power
generation and thermal energy associated with the production of electricity. Include all fuel used
in a cogeneration system, such as fuel used for process steam, direct heating, space heating, or
thermal output delivered to other end users. If you cannot report your fuel using the specified
units of measure (below), specify the units you are using on SCHEDULE 9.
Include start-up and flame-stabilization fuels.
Type of Physical Units: Fuel consumption must be reported in the following units:
• Solids – Tons
• Liquids – Barrels (one barrel equals 42 U.S. gallons)
• Gases – Thousands of cubic feet (Mcf)
Average Heat Content: For each month, report the heat content of the fuels burned in million Btu
(MMBtu) per physical unit. The heat content of the fuel should be reported as the gross or “higher
heating value” (rather than the net or lower heating value). The higher heating value exceeds the
lower heating value by the latent heat of vaporization of the water. The heating value of fuels
generally used and reported in a fuel analysis, unless otherwise specified, is the higher heating
value. If the fuel heat content cannot be reported “as burned,” data may be obtained from the fuel
supplier on an “as received” basis. If this is the case, indicate on SCHEDULE 9 that the fuel heat
content data are “as received.” Report the value in the following units: solids in MMBtu per ton;
liquids in MMBtu per barrel; and gases in MMBtu per thousand cubic feet (Mcf). Refer to Table 3
on pages 17 through 19 for approximate ranges of heat content for specific fuels.
SCHEDULE 4. FOSSIL FUEL STOCKS AT THE END OF THE REPORTING PERIOD AND
DATA BALANCE
Required Respondents: Schedule 4 (stocks) must be completed by all plants that burn fossil
fuels: COAL, DISTILLATE FUEL OILS (NO. 2, 4), RESIDUAL FUEL OIL (NO. 6), JET FUEL,
KEROSENE, AND PETROLEUM COKE. Stocks are not required for natural gas; however, the
energy balance (between receipts and consumed fuel) and comments should be completed for
NG plants that have a total nameplate capacity of 50 MW and more (and have completed
Schedule 2).
9

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
Report fuel stocks ONLY for the following fuels:
- Coal: Report all stocks of coal for use by this power plant. This includes both stocks
held on site and stocks held off site whether owned by your plant or by an affiliated
company. If the stocks are held for the plant by an affiliated company and the amount
is unknown, please provide EIA the name of the company. EIA will contact them to
obtain the stocks number.
- Residual oil (No. 5 and No. 6 fuel oils)
- Distillate-type oils (including diesel oil, No. 2 oil, jet fuel, and kerosene)
- Petroleum coke
Include back-up fuels and start-up and flame-stabilization fuels. Do not report stocks for waste
coal, natural gas, or wood waste. Stocks held off-site that cannot be assigned to an individual
plant are to be reported as stocks held at a central storage site. Each central storage site must be
reported separately. New sites should be indicated on SCHEDULE 9 of the form.
ENTER ZERO in the Ending Stocks column if a plant has no stocks.
Energy Source: If a fuel that you stock is not preprinted, add the energy source code from Table
1.
Type of Physical Units: Report coal and petroleum coke in tons and distillate and residual oils in
barrels.
1.

Previous Month’s Ending Stocks: This is automatically loaded into the schedule.

2.

Current Month’s Receipts: These data have been reported (above in SCHEDULE 2) and
will also automatically appear.

3.

Current Month’s Consumption: These data also have been reported (in SCHEDULE 3) and
will automatically appear. For plants with steam-electric turbines of 10 MW or greater, these
are the data reported in SCHEDULE 3. PART A. Otherwise, these are the data reported in
SCHEDULE 3. PART B.

4.

Ending Stocks: Report this month’s ending stocks.

5.

Adjustment to Stocks: Report adjustments to end-of-month stocks. Adjustments may
include stocks transferred or sold offsite and revisions to account for adjustments to previous
months’ stocks. Adjustments can be positive or negative. Enter the reason for the
adjustment in a comment in SCHEDULE 9.

Balance: The data balance verifies the quality of the data. The balance is the difference between
Reported Ending Stocks (4) and an expected value for ending stocks calculated by the following
equation: Previous Month’s Ending Stocks plus Current Month’s Receipts minus Current Month’s
Consumption plus (or minus) Adjustment to Stocks [(4) = (1) + (2) - (3) + (5)]. If the balance is a
non-zero value, please review the data entered for stocks, receipts, consumption, and
adjustments. Enter a comment to explain any discrepancy.

SCHEDULE 5. PART A. GENERATOR INFORMATION FOR STEAM-ELECTRIC ORGANICFUELED PLANTS
Required Respondents: Plants with a steam-electric nameplate capacity of 10 MW and above
that burn organic fuels must report generation by generating unit on SCHEDULE 5, PART A for
the steam turbines only. For generation produced by combustion turbines, IC engines, and all
other types of prime movers, use SCHEDULE 5. PART B. Combined-cycle plants should report
all generation on SCHEDULE 5, PART B. for both the combustion turbines and steam turbines.
Plant Code Generator ID: Identification information should be a code commonly used by plant
10

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
management for that equipment (e.g., “2,” “A101,” “7B,” etc.). Select a code for each piece of
equipment and use it for that equipment throughout this form. The code should be a maximum of
six characters long and should conform to codes reported for the same equipment (especially
generators on Form EIA-860) on other EIA forms. Do not use blanks in the code.
Data must be reported in megawatthours (MWh), rounded to whole numbers, no decimals.
If no generation occurred, report ZERO. Please do not leave fields blank.
Gross Generation: is the total amount of electric energy produced by generating units and
measured at the generating terminal. For each month, enter that amount in MWh.
Net Generation: is the gross generation minus the electric energy consumed at the generating
station for pumps, fans, and auxiliary equipment. If the monthly station service load exceeded the
monthly gross electrical generation, report negative electrical net generation with a minus sign.
Do not use parentheses. For each month, enter that amount in MWh.
SCHEDULE 5. PART B. GENERATION – PRIME MOVER-LEVEL
Required Respondents: Report generation at the prime mover level (sum of generation by prime
mover type) for steam turbines under 10 MW, steam turbines using nuclear, solar, geothermal or
other noncombustible energy sources, combustion turbines, hydraulic turbines, wind turbines, or
other prime movers. Steam turbines with a total nameplate capacity of 10 MW and above which
burn organic fuels must report on SCHEDULE 5. PART A. Industrial and commercial CHP
facilities (those with NAIC codes that are NOT 22) may report only gross generation, if net
generation is not measured.
Prime Mover Type: If the preprinted prime mover code is incorrect, delete the code and choose
the correct prime mover code from the prime mover table on pages 8 through 9.
If no generation occurred, report zero. Do not leave fields blank.
Data must be reported in MWh, rounded to whole numbers, with no decimals.
Gross Generation: is the total amount of electric energy produced by generating units and
measured at the generating terminal. For each month, enter in the MWh generated.
Net Generation: is the gross generation minus the electric energy consumed at the generating
station for pumps, fans, and auxiliary equipment. If the monthly station service load exceeded the
monthly gross electrical generation, report negative net electrical generation with a minus sign.
Do not use parentheses. For each month, enter the net generation in MWh.
SCHEDULE 6. NONUTILITY ANNUAL SOURCE AND DISPOSITION OF ELECTRICITY
Required Respondents: Nonutility plants report annual (no monthly detail) source and
disposition of electricity. Annual data on SCHEDULE 6 are due by March 30 following the
reporting year.
• If you file the EIA-923 monthly, you should complete this schedule between January and
the March 30 due date following the reporting year.
• If you file the EIA-923 annually, fill out this schedule when you submit your other data due
by March 30 of the year following the reporting year.
Report all generation in MWh rounded to a whole number.
Sources of Electricity
1. Gross Generation (Annual):

•

Report the total gross generation from all prime movers at the plant.
11

U.S. Department of Energy
POWER PLANT OPERATIONS
Energy Information Administration
REPORT INSTRUCTIONS
Form EIA-923
2. Other Incoming Electricity:

Form Approval
OMB No. 1905-0129
Approval Expires:

Report all incoming electricity to the facility, whether from purchases, tolling agreements,
transfers, exchanges, or other arrangements.
3. Total Sources:
•

Enter the sum of the total gross electricity generated plus the total incoming
electricity. This entry must equal Total Disposition (see below).

Disposition of Electricity
4. Station Use:

•

Station Use is electricity that is used to operate an electric generating plant, including
electricity used in the operation, maintenance, or repair of the facility (e.g., for
heating, lighting, and office facilities), regardless of whether the electricity is produced
at the plant or comes from another source. Station use does not include any
electricity converted and stored at an energy storage plant (such as electricity used
for pumping at a hydroelectric pumped-storage plant), nor direct use (see below) of
electricity by an industrial or commercial CHP plant.

5. Direct Use (CHP Plants):
•

Report the amount of electricity generated by the plant and consumed onsite for
processes such as manufacturing, district heating/cooling, and uses other than power
plant station use.

6. Total Facility Use: Report the total sum of station use and direct use. If station use and
direct use cannot be reported separately, report total facility use and leave station use and
direct use blank. Provide a comment on SCHEDULE 9.
7. Retail Sales to Ultimate Customers: Report the amount of electricity sold, or otherwise
provided, to retail (end-use) customers. Include unbilled electricity provided to affiliated and
non-affiliated entities, excluding power provided as part of a tolling agreement. By entering a
value in this cell, you will be required to also file Form EIA-861 “Annual Electric Power Industry
Report.”
8. Sales for Resale: Report the amount of electricity sold for resale (wholesale sales). If data
are entered for this item, you must complete SCHEDULE 7.
9. Other Outgoing Electricity: Report all other outgoing electricity from the facility, such as
tolling agreements, transfers, and exchanges.
10. Total Disposition: Report the sum of station use, direct use, retail sales, sales for resale,
and other outgoing electricity. This entry must equal Total Sources (see above).
SCHEDULE 7. ANNUAL REVENUES FROM SALES FOR RESALE
Required Respondents: To be completed by respondents who report a positive value on
SCHEDULE 6, Disposition of Electricity, Item 8, Sales for Resale.
“Sales for Resale” is energy supplied to other electric utilities, cooperatives, municipalities, Federal
and State electric agencies, or other entities for resale to end-use consumers.
Report all revenue from Sales for Resale in thousand dollars to the nearest whole number.
SCHEDULE 8. ANNUAL ENVIRONMENTAL INFORMATION

12

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
Required Respondents: Steam-electric organic-fueled plants with a total steam-electric
nameplate capacity rating of 10 MW and above must complete applicable sections of SCHEDULE
8, PARTS A through F ANNUALLY. Annual data are due by March 30 following the reporting
year.
SCHEDULE 8. PART A. ANNUAL BYPRODUCT DISPOSITION
1. If no byproduct was produced, place a check in the checkbox labeled NO BYPRODUCTS.
2. If a byproduct is disposed of at no cost, enter the quantity of the byproduct under the
appropriate column and make a footnote entry on SCHEDULE 9 stating that no money was
exchanged for the quantity indicated. If there was a cost for disposal, make sure there is a
corresponding entry on SCHEDULE 8, PART B, for collection and/or disposal costs. Costs for
gypsum disposal should be reported on SCHEDULE 8, PART B, column 5, under “Disposal,”
with a footnote entry on SCHEDULE 9.
3. Entries on SCHEDULE 8, PART A, in the Sold column, must be compatible with entries on
SCHEDULE 8, PART B, columns 11 through 16, Byproduct Sales Revenue. If the
byproduct was distributed in several different ways (for example, the byproduct was placed in
a landfill and then later sold), report the end disposition of the byproduct and provide a
comment on SCHEDULE 9 explaining all previous dispositions.
4. Do not include byproducts sold under “Used On-Site.”
5. Fly ash from standard boiler/primary particulate collection device (PCD) units includes those
with no flue gas desulfurization (FGD) system or with FGD systems located downstream of the
PCD.
6. Fly ash from units with dry FGD includes spray dryer or duct injection systems where Fly Ash
and FGD byproducts are collected in the same PCD. It does not include Fluidized Bed
Combustion (FBC) units.
7. Bottom ash from standard boiler units includes boiler slag from slagging combustors. It does
not include Bottom (Bed) Ash from FBC units or slag from coal gasification units.
8. FGD Gypsum is defined as byproducts that are greater than 75 percent CaS04●2H20 by
weight.
9. Other FGD byproducts includes all FGD byproducts not reported on lines Fly ash from units
with dry FGD units, Fly ash from FBC units, Bottom (bed) ash from FBC units, and FGD
gypsum along with additives used to stabilize the FGD byproducts.
10. Report sales of steam in million Btu (MMBtu).
SCHEDULE 8. PART B. FINANCIAL INFORMATION
1. All entries should be reported in thousand dollars to the nearest whole number.
2. For all Operation and Maintenance (O&M) Expenditures During Year, costs should be
provided for both collection and disposal of the indicated byproducts. If the collection and
disposal costs cannot be separated, place the total cost under Collection, and provide a
comment on SCHEDULE 9 indicating that the costs cannot be separated. All operation and
maintenance expenditures should exclude depreciation expense, cost of electricity
consumed, and fuel differential expense (i.e., extra costs of cleaner, thus more expensive
fuel). Include all contract and self-service pollution abatement operation and maintenance
expenditures for each line item.
3. For column 1, Fly Ash, and column 2, Bottom Ash, expenditures cover all material and labor
13

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
costs including equipment operation and maintenance costs (such as particulate collectors,
conveyors, hoppers, etc.) associated with the collection and disposal of the byproducts.
4. For column 3, Flue Gas Desulfurization, expenditures cover all material and labor costs
including equipment operation and maintenance costs associated with the collection and
disposal of the sulfur byproduct.
5. For column 4, Water Pollution Abatement, expenditures cover all operation and
maintenance costs for material and/or supplies and labor costs including equipment operation
and maintenance (pumps, pipes, settling ponds, monitoring equipment, etc.), chemicals, and
contracted disposal costs. Collection costs include any expenditure incurred once the water
that is used at the plant is drawn from its source. Begin calculating expenditures at the point
of the water intake. Disposal costs include any expenditure incurred once the water that is
used at the plant is discharged. Begin calculating disposal expenditures at the water outlet
(i.e., cooling costs).
6. For column 5, Other Pollution Abatement, operation and maintenance expenditures are
those not allocated to one particular expenditure (e.g., expenditures to operate an
environmental protection office or lab). Include expenses for conducting environmental
studies for expansion or reduction of operation. Exclude all expenses for health, safety,
employee comfort (OSHA), environmental aesthetics, research and development, taxes,
fines, permits, legal fees, Superfund taxes, and contributions. Define other pollution
abatement(s) in a comment on SCHEDULE 9.
7. For Capital Expenditures for New Structures and Equipment during Year, Excluding
Land and Interest Expense, report all pollution abatement capital expenditures for new
structures and/or equipment made during the reporting year regardless of the date they may
become operational. Columns 7, 8, 9, and 10 should not be left blank. ENTER ZERO if the
item is not applicable or an estimate is not available, and enter a comment in SCHEDULE 9.
Specify the nature of the expenditures for these items in a comment on SCHEDULE 9.
8. For column 7, Air Pollution Abatement, report new structures and/or equipment purchased
to reduce, monitor, or eliminate airborne pollutants, including particulate matter (dust, smoke,
fly ash, dirt, etc.), sulfur dioxides, nitrogen oxides, carbon monoxide, hydrocarbons, odors,
and other pollutants. Examples of air pollution abatement structures/equipment include flue
gas particulate collectors, FGD units, continuous emissions monitoring equipment (CEMs),
and nitrogen oxide control devices. Specify new structures/equipment in a comment on
SCHEDULE 9.
9. For column 8, Water Pollution Abatement, report new structures and/or equipment
purchased to reduce, monitor, or eliminate waterborne pollutants, including chlorine,
phosphates, acids, bases, hydrocarbons, sewage, and other pollutants. Examples include
structures/equipment used to treat thermal pollution; cooling, boiler, and cooling tower
blowdown water; coal pile runoff; and fly ash waste water. Water pollution abatement
excludes expenditures for treatment of water prior to use at the plant. Specify new
structures/equipment in a comment on SCHEDULE 9.
10. For column 9, Solid/Contained Waste, report new structures/equipment purchased to collect
and dispose of objectionable solids or contained liquids. Examples include purchases of
storage facilities, trucks, etc., to collect, store, and dispose of solid/contained waste. Include
equipment used for handling solid/contained waste generated as a result of air and water
pollution abatement. Specify new structures/equipment in a comment on SCHEDULE 9.
11. For column 10, Other Pollution Abatement, report amortizable expenses and purchases of
new structures and or equipment when such purchases are not allocated to a particular unit
or item. Examples include charges for the purchases of facilities to control hazardous waste,
radiation, and noise pollution. Exclude all equipment purchased for aesthetics purposes.
14

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
Specify new structures/equipment in a comment on SCHEDULE 9.
12. If Byproduct Sales Revenue During Year items are not applicable, ENTER ZERO in Total,
column 16, only. Report the revenue, if any, for each listed byproduct. Specify “other”
revenue in a comment on SCHEDULE 9. Entries must be compatible with the entries on
SCHEDULE 8, PART A, “Sold” column. If the revenue for a byproduct is less than $500, but
more than zero dollars, enter a zero and enter a comment on SCHEDULE 9 with the actual
dollar amount. Revenue for gypsum should be reported on SCHEDULE 8, PART B, column
14, with a comment on SCHEDULE 9. Report the total revenue for the sale of byproducts in
column 16. If the revenue reported was for the sale of stockpiled byproducts from previous
years, make a comment on SCHEDULE 9.
SCHEDULE 8. PART C. BOILER INFORMATION
NITROGEN OXIDE EMISSION CONTROLS
1. For Entire Year, enter the controlled nitrogen oxide emission rate, in pounds per million Btu
of the fuel, based on data from the continuous emission monitoring system (CEMS) where
possible. Where CEMS data are not available, report the controlled nitrogen oxide emission
rate based on the method used to report emissions data to environmental authorities.
2. For May through September Only, enter the controlled nitrogen oxide emission rate, in
pounds per million Btu of the fuel, based on data from CEMS where possible. Where CEMS
data are not available, report controlled nitrogen oxide rates based on the method used to
report emissions data to environmental authorities. The summer emission rate may be
assumed to be equivalent to the annual emission rate where identical nitrogen oxide controls
are used year round.
SCHEDULE 8. PART D. COOLING SYSTEM INFORMATION
ANNUAL OPERATIONS
1. If actual data are not available, provide an estimated value.
2. If the source of cooling water is a well or municipal water system, do not complete the
Maximum Cooling Water Temperature sections.
3. Annual Amount of Chlorine Added to Cooling Water pertains solely to elemental chlorine.
If a compound is used, determine the amount of chlorine in the compound. If the amount of
chlorine added to the cooling water is known for the entire plant but not for each cooling
system, enter the information under the first cooling system ID in column (a), and ENTER
ZERO in the rest of the columns as necessary, and indicate in a comment on SCHEDULE 9
that the information is for the entire plant. Report amount of chlorine to the nearest whole
number in thousand pounds.
4. For Annual Rate of Cooling Water Discharge, if the system is a closed, zero-discharge
system, report “0,” complete consumption and intake temperatures, but skip discharge
temperatures.
5. If the Average Annual Flow Rate of Cooling Water is known for the entire plant but not for
each cooling system, enter the information in Consumption under the first cooling system ID,
column (a), ENTER ZERO in the rest of the columns as necessary, and indicate in a
comment on SCHEDULE 9 that the information is for the entire plant.
6. For the Maximum Cooling Water Temperature sections, the “Peak Load Month” refers to
the month of greatest plant electrical generation during the winter heating season (OctoberMarch) and summer cooling season (April-September), respectively. Report temperature in
degrees Fahrenheit to the nearest whole number.
SCHEDULE 8. PART E. FLUE GAS PARTICULATE COLLECTOR INFORMATION
15

U.S. Department of Energy
Energy Information Administration
Form EIA-923

POWER PLANT OPERATIONS
REPORT INSTRUCTIONS

Form Approval
OMB No. 1905-0129
Approval Expires:

1. For Typical Particulate Emissions Rate at Annual Operating Rate, enter the particulate
emission rate based on the annual operating factor (to nearest 0.01 pound per million Btu).
2. For Removal Efficiency of Particulate Matter at Annual Operating Factor and At 100Percent Load or Tested Efficiency, if the collector has a combination of components (i.e., a
baghouse and an electrostatic precipitator) enter both components as one unit in one column.
If the particulate collector also removes sulfur dioxide, enter the particulate scrubbing process
in this section and the desulfurization process on SCHEDULE 8, PART F, FLUE GAS
DESULFURIZATION UNIT INFORMATION ANNUAL OPERATIONS.
3. For Removal Efficiency of Particulate Matter at Annual Operating Factor, enter removal
efficiency based on the annual operating factor. Annual operating factor is defined as annual
fuel consumption divided by the product of design firing rate and hours of operation per year.
If actual data are unavailable, provide estimates based on equipment design performance
specifications.
4. For At 100-Percent Load or Tested Efficiency, if the test was conducted, but not at 100percent load, enter the efficiency and provide the load at which the test was conducted in a
comment on SCHEDULE 9. If no test has been conducted, ENTER ZERO in the column and
in the test date column. Test results should not be noted if there was no test date.
5. For Date of Most Recent Efficiency Test, enter test date. If an efficiency test has never
been performed, enter “NA” and enter a comment on SCHEDULE 9.
SCHEDULE 8. PART F. FLUE GAS DESULFURIZATION UNIT INFORMATION
ANNUAL OPERATIONS
1. The Flue Gas Desulfurization Unit Status, as of January 1 following the end of the
reporting year. Select from the following equipment status codes:

Code
CN
CO
OP
OS
PL
RE
SB
SC
TS

Table 2
Status
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 (on order and expected to go into commercial service within 5 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)

If the code selected is “OP,” complete SCHEDULE 8. PART F; otherwise do not complete.
2. For Hours In Service During Year, enter the total number of hours one or more trains (or
modules) were in operation; do not report for individual trains.
3. For Estimated Removal Efficiency for Sulfur Dioxide at Annual Operating Factor and At
100 Percent Load or Tested Efficiency, if the FGD unit also removes particulate matter,
enter the desulfurization process in this section and the particulate scrubbing process on
SCHEDULE 8. PART E, FLUE GAS PARTICULATE COLLECTOR INFORMATION.
4. For Estimated Removal Efficiency for Sulfur Dioxide at Annual Operating Factor, enter
removal efficiency based on the annual operating factor. Annual operating factor is defined
as annual fuel consumption divided by the product of design firing rate and hours of operation
16

U.S. Department of Energy
Form Approval
POWER PLANT OPERATIONS
Energy Information Administration
OMB No. 1905-0129
REPORT INSTRUCTIONS
Form EIA-923
Approval Expires:
per year. If actual data are unavailable, provide estimates based on equipment design
performance specifications.
5. For Estimated Removal Efficiency for Sulfur Dioxide at 100-Percent Load or Tested
Efficiency, if the test was conducted, but not at 100-percent load, enter the efficiency, and
provide the load at which the test was conducted in a footnote on SCHEDULE 9. If no test
was conducted, input “NA” in the final two lines. Test results should not be given without a
test date.
6. Report the Operation and Maintenance Expenditures during the Year, excluding
electricity in thousand dollars.
SCHEDULE 9. COMMENTS
This schedule provides additional space for comments. Please identify schedule, item, and
identifying information (e.g., plant code, boiler ID, generator ID, prime mover) for each comment.
If plant is sold, provide purchasers name, a telephone number (if available), and date of sale.
ENERGY SOURCE
CODES AND HEAT
CONTENT

Table 3
Energy
Source
Code

Unit
Label

“Higher Heating Value” Range
Energy Source Description
MMBtu Lower

MMBtu Upper
Fossil Fuels

BIT

tons

20

29

LIG

tons

10

14.5

SC

tons

10

35

SUB

tons

15

20

WC

tons

6.5

16

DFO

barrels

5.5

6.2

JF
KER
PC

barrels
barrels
tons

5
5.6
24

6
6.1
30

RFO

barrels

5.8

6.8

WO

barrels

3.0

5.8

BFG

Mcf

0.07

0.12

Coal and
Syncoal

Petroleum
Products

Natural
17

Anthracite Coal and
Bituminous Coal
Lignite Coal
Coal-based Synfuel (including
briquettes, pellets, or
extrusions, which are formed
by binding materials or
processes that recycle
materials)
Subbituminous Coal
Waste/Other Coal (including
anthracite culm, bituminous
gob, fine coal, lignite waste,
waste coal)
Distillate Fuel Oil (including
diesel, No. 1, No. 2, and No.
4 fuel oils.
Jet Fuel
Kerosene
Petroleum Coke
Residual Fuel Oil (including
No. 5 and No. 6 fuel oils,
and bunker C fuel oil.
Waste/Other Oil (including
crude oil, liquid butane, liquid
propane, oil waste, re-refined
motor oil, sludge oil, tar oil, or
other petroleum-based liquid
wastes)
Blast Furnace Gas

U.S. Department of Energy
Energy Information Administration
Form EIA-923
Gas
and Other
Gases

Solid
Renewable
Fuels

Liquid
Renewable
(Biomass)
Fuels

Gaseous
Renewable
(Biomass)
Fuels
All Other
Renewable
Fuels

Form Approval
OMB No. 1905-0129
Approval Expires:
Other Gas (specify in
3.3
Comment Section of
SCHEDULE 9)
2.75
Gaseous Propane
1.1
Synthetic Gas
0.3
Coal-Derived Synthetic Gas
Renewable Fuels
Agricultural Crop
18
Byproducts/Straw/Energy
Crops
12
Municipal Solid Waste
Other Biomass Solids (specify
25
in Comment Section of
SCHEDULE 9)
Wood/Wood Waste Solids
(including paper pellets,
18
railroad ties, utility poles,
wood chips, bark, and wood
waste solids)
Other Biomass Liquids
(specify in Comment Section
4
of SCHEDULE 9)
16
Sludge Waste
14
Black Liquor
Wood Waste Liquids
excluding Black Liquor
(includes red liquor, sludge
14
wood, spent sulfite liquor,
and other wood-based
liquids)
0.6
Landfill Gas
Other Biomass Gas (includes
digester gas, methane, and
1.6
other biomass gasses)
(specify in Comment Section
of SCHEDULE 9)
0
Solar
0
Wind
0
Geothermal
Water at a Conventional
0
Hydroelectric Turbine

POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
OG

Mcf

0.32

PG
SG
SGC

Mcf
Mcf
Mcf

2.5
0.2
0.2

AB

tons

9

MSW

tons

9

OBS

tons

8

WDS

tons

7

OBL

barrels

3.5

SLW
BLQ

tons
tons

10
10

WDL

barrels

8

LFG

Mcf

0.3

OBG

Mcf

0.36

SUN
WND
GEO

N/A
N/A
N/A

0
0
0

WAT

N/A

0

All Other Fuels

All Other
Fuels

PUR

N/A

0

0

WH

N/A

0

0

TDF

tons

16

32

OTH

N/A

0

0

18

Purchased Steam
Waste heat not directly
attributed to a fuel source
(WH should only be reported
where the fuel source for the
waste heat is undetermined,
and for combined cycle steam
turbines that do not have
supplemental firing)
Tire-derived Fuels
Specify in Comment Section
of SCHEDULE 9.

U.S. Department of Energy
Energy Information Administration
Form EIA-923

POWER PLANT OPERATIONS
REPORT INSTRUCTIONS

Form Approval
OMB No. 1905-0129
Approval Expires:

GLOSSARY

The glossary for this form is available online at the following URL:
http://www.eia.doe.gov/glossary/index.html

SANCTIONS

The timely submission of Form EIA-923 by those required to report is mandatory under Section
13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Public Law 93-275), as amended.
Failure to respond may result in a penalty of not more than $2,750 per day for each civil violation,
or a fine of not more than $5,000 per day for each criminal 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. Title
18 U.S.C. 1001 makes it a criminal offense for any person knowingly and willingly to make to any
Agency or Department of the United States any false, fictitious, or fraudulent statements as to any
matter within its jurisdiction.
Public reporting burden for this collection of information is estimated to average 2.7 hours per
response for monthly respondents, 3.2 hours per response for annual respondents, and 3.4 hours
per response for annual respondents with boiler-level data, 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 EIA, Statistics and Methods Group, EI-70, 1000 Independence Avenue S.W.,
Forrestal Building, Washington, D.C. 20585-0670; 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.
Information reported on Form EIA-923 will be treated as non-sensitive and may be publicly
released in identifiable form except as noted below.

REPORTING
BURDEN

PROVISIONS
REGARDING
CONFIDENTIALITY
OF INFORMATION

The “Total Delivered Cost” of coal, natural gas, and petroleum received at nonutility power plants
and “Commodity Cost” information for all plants in SCHEDULE 2 and “Previous Month’s Ending
Stocks” and “Stocks at End of Reporting Period” information reported on SCHEDULE 4 will be
treated as sensitive and protected 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.
The Federal Energy Administration Act requires the 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 non-statistical purposes
such as administrative, regulatory, law enforcement, or adjudicatory purposes.
Disclosure limitation procedures are applied to the sensitive statistical data published from
SCHEDULES 2 and 4 on Form EIA-923 to ensure that the risk of disclosure of identifiable
information is very small.

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