Download:
pdf |
pdfU.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
PURPOSE
Form EIA-923 collects information from electric power plants and combined heat and power (CHP) plants
in the United States (see Required Respondents immediately below). Data collected on this form include
electric power generation, fuel consumption, fossil fuel stocks, delivered fossil fuel cost, combustion
byproducts, operational cooling water data, and operational data for NOx, SO2, and particulate matter
control equipment. These data are used to monitor the status and trends of the electric power industry and
appear in many U.S. 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.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 generator nameplate capacity (sum for generators at a single site) of 1
megawatt (MW) or greater; and 2) where the generator(s), or the facility in which the generator(s) resides,
is connected to the local or regional electric power grid and has the ability to draw power from the grid or
deliver power to the 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.
Facilities that do not generate electricity but serve either as a transfer terminal or offsite storage facility for
fossil fuel stocks for generating stations may be required to report on the Form EIA-923.
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.
Supplemental responses (monthly respondent’s filings of Schedule 6 through Schedule 8) must be filed no
later than 45 days after the form opens for data entry – typically around March 31 following the end of the
reporting year.
Annual respondents are required to file the form approximately 45 calendar days after the form opens for data
entry – typically around March 31 following the end of the reporting year. (Schedules 3A, 5A, and 8D require
monthly level data for the calendar year. All other schedules collect aggregated annual data for the calendar
year.)
See instructions for each schedule for more specific filing requirements.
METHODS OF
FILING RESPONSE
Submit your data electronically using EIA’s secure e-file system. This system uses security protocols to
protect information against unauthorized access during transmission.
If you have not registered with the e-file Single Sign-On (SSO) system, send an email requesting
assistance to: [email protected].
If you have registered with SSO, log on at: https://signon.eia.gov/ssoserver/login
If you are having a technical problem with logging into or using the e-file system, contact the Help Desk at:
Email: [email protected] or 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.
1
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
CONTACTS
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
E-file System Questions: For questions related to the e-file system, see the help contact information
immediately above.
Data Questions: For questions about the data requested on the Form EIA-923, contact:
Schedules 1 & 4:
Chris Cassar
[email protected]
202-586-5448
Schedule 2:
Rebecca Peterson
[email protected]
202-586-4509
Schedules 3 & 5:
Ron Hankey
[email protected]
202-586-2630
[email protected]
202-586-5356
Schedules 6, 7, & 8: Channele Wirman
EIA-923 Fax:
EIA-923 Mailbox:
GENERAL
INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
202-287-1959 or 202-287-1960
[email protected]
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 e-file 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 e-file system because the monthly data file has been
closed, please email 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 prepopulated information: For e-file users, much of the information on the form is
prepopulated by EIA. Verify the administrative information and make corrections to the contact name,
phone numbers, addresses, or email addresses. Please note that PLANT NAME, PLANT CODE, and
COMPANY NAME cannot be changed. Contact the survey manager if these items are incorrect.
Correcting errors: For e-file users, data that fail our edits will be amassed into an edit log. Upon hitting
the “Submit” button, the system will notify you if there are failed edits in the log. You will be directed to the
log and given the opportunity to either revise the data in question or override it. When an edit is
overridden, the system will ask for a comment/explanation. Each explanation is reviewed by EIA and, if it
does not sufficiently explain the anomaly, you will be contacted for a more detailed clarification.
Revising data: If you report via facsimile or email, 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. If you report via the e-file system, send an email to the
survey manager indicating the 4 items listed above.
Schedule 9 is provided for respondents to provide comments. Use it to explain anomalies with data or to
provide any further details that are pertinent to the data and plant.
2
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
ITEM-BY-ITEM
INSTRUCTIONS
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
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 email address. The Survey Contact and Supervisor cannot be
the same person.
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 twocharacter U.S. Postal Service abbreviations. These fields cannot be revised online. Contact the EIA923 survey manager if corrections are needed.
4.
Regulatory Status: Verify that the check correctly identifies your plant as either regulated or
unregulated. Contact the EIA-923 survey manager if a correction is needed.
5.
CHP Checkbox: Verify that the check correctly indicates whether or not this facility is a combined
heat and power plant, regardless of its utility/nonutility status. Contact the EIA-923 survey manager if
a correction is needed.
6.
CHP Plant Efficiency: If the CHP checkbox is “YES”, enter the efficiency of the combined heat and
power plant. To calculate the total plant efficiency, divide the sum of the energy outputs (in British
thermal units (Btu)), including net generation and useful thermal output by the sum of the energy
inputs (fuels converted to Btu). Report the annual average total CHP plant efficiency.
SCHEDULE 2. COST AND QUALITY OF FUEL PURCHASES – 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 or the combined production of electric power and useful thermal output
must complete the appropriate data on Schedule 2, Cost and Quality of Fuel Receipts.
All fuel purchases should be reported at the plant level. However, for fuel received at transfer terminals or
storage facilities that CANNOT be allocated to individual plants or vendor information for cost and quality of
the fuel at a terminal is not available to the plant, the terminal or storage facility must report the fuel
purchases, including cost and quality data. Terminals and storage facilities must list the plants where the fuel
will be utilized on Schedule 9, Comments.
In order to avoid duplicate data, report purchases at either the storage site or at the plant, but not both.
Purchases reported by a storage site and then transferred to the plant should not be reported at the plant
level. Instead, designate such transfers in Schedule 4 as a negative adjustment to stocks at the storage
site and a positive adjustment to stocks at the plant, including appropriate comments.
ANNUAL RESPONDENTS: Report Schedule 2 by aggregating receipts for the entire year in the manner
specified in the instructions for Schedule 2, Page 1 below.
Plant Name, Plant ID, State, Reporting Month and Year: For e-file users, verify the prepopulated
information for these items at the top of this (and all) page(s).
If no fuel was purchased during the reporting period, place a check in the “No Receipts” box, and go to
Schedule 3.
3
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
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. Report all other data. 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. For e-file users, this
check will carry over into subsequent months. If the agreement expires, contact the survey manager to
have the check removed.
SCHEDULE 2. PAGE 1. CONTRACT INFORMATION, RECEIPTS, AND COSTS.
1. Fuel Supplier Name:
Coal Purchases: Report data by supplier and mine source. (Purchased coal or petroleum coke
which will be converted to synthesis gas should be reported as it is received, i.e. as coal or petroleum
coke.)
Monthly Respondents: Coal received from spot-market purchases and from contract purchases must
be reported separately. Data on coal received under each purchase order or contract from the same
supplier must be reported separately. Coal purchases can be aggregated when supplier, purchase
type, contract date, coal rank, transportation mode, costs, fuel quality, and all mine information are
identical. If coal received under a purchase order or contract originates in more than one
State/county/mine and the mines are known as well as the amount received from each mine, split the
amount received accordingly between the number of different mines and report identical quality and
prices (unless the actual quality and prices are known). Mine information is reported on Page 3 of
Schedule 2. If the mine or group of mines is not available on the list of mines provided for data entry on
the e-filing system, contact EIA immediately (see contacts on Page 1 of the form or instructions). EIA will
add appropriate choices for purchases from multiple sources to the drop down list.
Annual Respondents: Coal received from spot market purchases and from contract purchases must
be reported separately. Aggregation of coal shipments is allowed ONLY IF shipments are identical in
purchase type, coal rank, mine name, mine type, Mine Safety and Health Administration (MSHA) ID,
State of origin, county of origin, and supplier. For aggregated purchases, report the weighted average
cost and quality of the fuel. If the mine or group of mines is not available on the list of mines provided for
data entry on the e-filing system, contact EIA immediately (see contacts on Page 1 of the form or
instructions).
Petroleum Purchases: Report data by fuel type, supplier or broker, or refinery and, if applicable, port
of entry.
Monthly Respondents: Oil received from spot-market purchases and from contract purchases must be
reported separately. Report individual shipments as separate line items.
Annual Respondents: Oil received from spot-market purchases and from contract purchases must be
reported separately. Aggregation for the entire year is allowed by fuel type and supplier. If
aggregated, report the weighted average cost and quality of the fuel.
Gas Purchases (monthly and annual respondents): Report data by fuel type and supplier.
Aggregation of gas deliveries from various suppliers is allowed only if 1) the deliveries are spot
purchases, 2) the type of gas is the same (either NG, OG, or PG), and 3) the transportation contracts
are identical (either firm or interruptible). For aggregated deliveries, report the pipeline or distributor in
the supplier column and the weighted average cost and quality of the fuel. Contract purchases must
be reported as separate line items and should never be aggregated. For gas produced by the plant
(e.g., BFG), list the suppler as “self-produced,” which is one of the choices in the drop-down list of
suppliers. Do not report land fill gas (LFG) in the category of other gases (OG) on Schedule 2
because LFG is not a fossil fuel. Do not report gas injected into storage. Report it when it is delivered
to the plant. Do not report any costs associated with storage.
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. Contracts with a shorter term are considered spot purchases. (See below.)
4
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
NC – New Contract or Renegotiated Contract Purchase – Fuel received under a purchase order or
contract with 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 with 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 “1112” for a November “2012” expiration date. This column should be left blank if
Contract Type contains an “S” for spot-market purchase.
Purchases
4.
Energy Source: Identify purchased fossil fuels (including start-up and flame stabilization fuel) using
the energy source codes listed in Table 8 for coal, petroleum products, petroleum coke, and natural
gas and other gases.
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. Fuel purchases reported should pertain to the fuel
that will ultimately be used only in the electric power plant for the generation of electricity and at
combined heat and power plants for useful thermal output (process steam, district heating/cooling,
space heating, or steam delivered to other end users). As far as possible, do not include fuel that will
be used in boilers with no connection to an electric power generator and are not part of the electric
power station. If these fuels cannot be separated, please provide a comment on Schedule 9,
Comments. Start-up and flame-stabilization fuels should be reported. When fuel is purchased by and
received at the plant and is resold, report the total receipts minus the amount sold. See the below
instruction regarding how to report the costs.
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 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. If fuel
received at the plant is resold, report the commodity cost and the total delivered cost as the cents per
MMBtu paid for the original receipt. Do not discount the costs by the revenue received for the sale of
the fuel.
7.
For natural gas, include the following pipeline charges: fuel losses, transportation reservation
charges, balancing costs, and distribution system costs outside of the plant. Because these types of
fees can skew the cost of the fuel per MMBtu, please provide an explanation in an edit log override
comment, e.g. “This price includes a reservation fee of x dollars.”
8.
Commodity Cost (Coal, Petroleum Coke, and Natural Gas Only): The commodity cost is the price
of that fuel (in cents per million Btu) at the point of first loading (free on board mine/transportation
pipeline (FOB)) including taxes and any quality-related charges or credits. The commodity cost does
not include: loading and unloading charges, dust proofing, freeze conditioning, switching charges,
diesel fuel surcharges, pipeline charges, or any other charges relating to the movement of the fuel to
the point of use. In the case of natural gas this is typically the price of the gas FOB the transmission
pipeline.
9.
For fuel purchased via a hedging contract, report the actual fuel supplier, not the hedge contract.
Report the cost net of gains/losses as a result of the contract.
5
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
SCHEDULE 2. PAGE 2. QUALITY OF FUEL AND TRANSPORTATION INFORMATION
Quality of Fuel
Fuel Supplier Name, Contract Type, Quantity Purchased, and Energy Source is prepopulated for efile users based on the data entered on page 1 of SCHEDULE 2.
1.
Heat Content: Enter the actual (not contractual) average Btu content for each fuel purchase in terms
of million (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. Refer to Table 8 for approximate ranges.
2.
Sulfur Content: For all coal types, petroleum coke, residual fuel oil, and waste oil, enter the sulfur
content of the fuel in terms of percent sulfur by weight. Show to the nearest 0.01 percent. Refer to
Table 1 for approximate ranges.
3.
Ash Content: For coal and petroleum coke, enter the ash content of the fuel in terms of percent ash
by weight. Show to the nearest 0.1 percent. Enter a comment in Schedule 9 if the reported ash
content for coal is an estimate. Refer to Table 1 for approximate ranges.
4.
Mercury Content: For coal only, enter the mercury content in parts per million (ppm). Show to the
nearest 0.001 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. Refer to Table 1 for approximate
ranges. If mercury content is unknown, enter 9.
Table 1
Fuel
BIT
% Sulfur
0.4 – 6.0
% Ash
4.0 – 30.0
Mercury
(ppm)
0.020 -- 0.500
LIG
0.4 – 3.0
5.0 – 35.0
0.020 -- 0.500
SUB
0.2 – 1.5
3.0 – 15.0
0.020 -- 0.200
ANT
0.4 – 6.0
4.0 – 30.0
0.020 -- 0.500
RC
0.2 – 6.0
3.0 – 30.0
0.020 -- 0.500
WC
0.3 – 6.0
5.0 – 50.0
0.020 -- 1.200
PC
1.0 – 7.0
0.1 -- 1.2
RFO
0.2 – 4.5
WO
0.0 – 4.5
Fuel Transportation
5.
Natural Gas: Use the following codes for natural gas transportation service:
F – Firm – Gas transportation service provided on a firm basis, i.e. 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 provided under schedules or contracts which anticipate
and permit interruption on short notice, such as in peak-load seasons, by reason of the claim of firm
service customers and higher priority users.
(Note: Natural Gas received under firm contracts must be reported separately from interruptible
contracts.)
6
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
6.
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.
7.
Secondary Mode: If more than one method of transportation is used in a single shipment, the
Secondary Mode of transportation is the second longest method used to transport the fuel to
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 plant used to
move coal from the plant storage pile to the plant).
For minemouth 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
WT – Water: Shipments of fuel moved to consumers by other waterways.
TR – Truck: Shipments of fuel moved to consumers by truck. Not included is fuel hauled to or away from
7
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
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.
SCHEDULE 2. PAGE 3. COAL MINE INFORMATION
Fuel Supplier Name, Contract Type, Quantity Purchased, and Energy Source will be prepopulated for
e-file users based on the data entered on page 1 of SCHEDULE 2.
1.
State or Country of Origin: Choose the two-letter U.S. Postal Service abbreviation or country code
from the drop down list of coal producing states (countries). For imported coal, insert the two-letter
country code shown here.
AS – Australia; CN – Canada; CL – Colombia; IS – Indonesia; PL – Poland;
RS – Russia; VZ – Venezuela; OT – Other (specify the country in Schedule 9).
The State of Origin is mandatory. If purchases originate from a broker, barge site or other third party,
you must contact the broker, barge site or other party and find out the State(s) where the coal
originates. If the broker or supplier is not forthcoming with State of Origin information or Mine Information,
provide the name and telephone number of the supplier on Schedule 9, Comments.
If coal purchased under a purchase order or contract originates in more than one State, determine from
the supplier the most dominant or probable State(s) of origin for the coal. Contact EIA to have the
supplier and State(s) added to the drop down list of choices for State of Origin and Mine Information on
Schedule 2 Page 3. If the amount of coal from each State/Mine is known, allocate the purchase among
multiple States, or report the State where the majority of the coal originates and report identical quality
and cost data (unless the actual quality and costs are known).
Contact EIA immediately (see contacts on Page 1 of the form or instructions) for assistance in reporting
coal State of Origin or Mine Information. EIA will add appropriate choices for purchases from multiple
sources to the drop down list.
2.
Mine Information: Choose from the drop down list the mine of origin. The list will display only those
mines located in the State/country of origin. The displayed information includes the mine operating
company for informational purposes to aid in identifying the mine of origin. Upon choosing a mine, the
MSHA ID, Mine Name, Mine Type and Mine County will automatically be populated.
Mine Information is mandatory. Determine from the supplier the most dominant or probable mine(s) of
origin for the coal. List the mines on Schedule 9, Comments. If the broker or supplier is not forthcoming
with State of Origin information or Mine Information, provide the name and telephone number of the
supplier on Schedule 9, Comments.
In cases where coal originates from multiple mines or the specific mine information cannot be
determined, list the tipple/loading point or dock on Schedule 9, Comments. EIA will add appropriate
choices to the drop down list of Mine Information to accommodate multiple mines or undetermined mine
sources. Use Schedule 9, Comments, to provide detailed explanations of mine origin data, including
names of multiple mines for a specific supplier/broker or dock, or the most probable origin of the coal
(county/State) if not specifically known.
Contact EIA immediately (see contacts on Page 1 of the form or instructions) for assistance in reporting
coal State of Origin or Mine Information. EIA will add appropriate choices for purchases from multiple
sources to the drop down list.
8
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
SCHEDULE 3. PART A. BOILER-LEVEL 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. If no fuel is consumed, for example in
combined cycle steam units (HRSG) without supplementary firing, report zero. Do not leave the field
blank. Report fuels consumed in gas turbines, including the gas turbines at combined-cycle plants, and IC
engines on SCHEDULE 3 PART B.
For combined heat and power plants, 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.
For those plants that report annually, Schedules 3A and 5A must be reported for each month.
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. For a complete list of prime mover codes, please refer to Table 7.
Prime Mover Code: Prime mover codes are shown in Table 7. Only CA and ST can be used in Schedule
3. Part A. For e-file users, the code will be prepopulated. If the prepopulated code is incorrect, delete the
code and choose the correct prime mover code from the drop-down list.
Boiler ID: The boiler ID is prepopulated. For an ID not prepopulated, choose the ID from the drop down list
of boiler IDs that were reported for your plant on the Form EIA-860. If the boiler ID is not on the list, contact
EIA immediately to have the ID added to your form. Boiler IDs must match those reported on the Form
EIA-860.
Boiler Status: Enter one of the codes listed below:
Table 2
Code
Boiler Status
OP
Operating (in commercial service or out of service less than 365 days)
OS
Out of service (365 days or longer)
RE
Retired (no longer in service and not expected to be returned to service)
SB
Standby (or inactive reserve); i.e., not normally used, but available for service
SC
Cold Standby (Reserve); deactivated (usually requires 3 to 6 months to reactivate)
TS
Operating under test conditions (not in commercial service)
Energy Source: Use the fuel codes in Table 8. For bituminous and subbituminous coal that is blended,
where possible report each coal rank consumed separately. If no allocation can be determined, report the
fuel that is predominant in quantity. An estimated allocation between coal ranks is acceptable.
Quantity Consumed: For each month, report the amount of fuel consumed for electric power generation
and, at combined heat and power stations, for useful thermal output. Combined-cycle units should
report only the auxiliary firing fuel associated with the HRSG. Do not report the fuel consumed in the
combustion turbine portion of the combined-cycle unit on Schedule 3A. CT consumption must be reported
on Schedule 3B.
9
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
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 to the nearest 0.001
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 8 for approximate ranges of
heat content of specific energy sources.
Sulfur Content (petroleum, petroleum coke, and coal): For each month, enter sulfur content to nearest
0.01 percent. Sulfur content should be reported for the following fuel codes: ANT, BIT, LIG, RC, SUB,
WC, PC, RFO, and WO. Refer to Table 1 for approximate ranges.
Ash Content (coal and petroleum coke only): For each month, enter ash content to the nearest 0.1
percent. Ash content should be reported for the following fuel codes: ANT, BIT, LIG, SUB, WC, RC, and
PC. Refer to Table 1 for approximate ranges.
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 gas turbines, including the combustion turbine part
of combined-cycle plants, internal combustion engines, steam-electric plants under 10 megawatts, fuel
cells, and electric power input to pumped-storage hydroelectric plants, compressed air units, and other
miscellaneous energy storage technologies. Excluded from this schedule are conventional hydroelectric
plants and all other plants that are not required to report energy consumed (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 total steamelectric capacity is less than 10 MW. All steam-electric plants and supplementary-fired HRSGs at combined
cycle plants with a total steam electric nameplate of 10 MW and above must report fuel consumption at the
boiler level 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.
For combined heat and power plants, 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 Code: Prime mover codes are shown in Table 7. Only CA, CE, CS, CT, FC, GT, IC, PS,
ST, and OT can be used in Schedule 3. Part B. For e-file users, the code is prepopulated. If the
prepopulated code is incorrect, choose the correct code from the drop-down list. Each prime mover type on
Schedule 3B must have a corresponding entry on Schedule 5B for electric power generation.
10
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Report actual values. If necessary, report estimated values and state that the value is an estimate on
SCHEDULE 9.
Energy Source: Use the fuel codes in Table 8. For bituminous and subbituminous coal that is blended,
where possible report each coal rank consumed separately. If no allocation can be determined, report the
fuel that is predominant in quantity. An estimated allocation between coal ranks is acceptable.
Quantity Consumed: For each month, report the amount of fuel consumed for electric power generation
and, at combined heat and power stations, for useful thermal output. Include start-up and flamestabilization fuels. Pumped storage hydroelectric plants and compressed air plants report the megawatthours
of energy input for pumping water or compressing air for energy storage. Combined cycle plants with no
supplementary firing must report the CA unit on Schedule 3B with ZERO for fuel consumed. Each prime
mover type on Schedule 3B must have a corresponding entry on Schedule 5B for electric power generation.
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)
Pumped storage hydro and compressed air -- Megawatthours
Average Heat Content: For each month, report the heat content of the fuels burned to the nearest
.001 MMBtu (million Btu) per physical unit (MMBtu per ton/barrel/thousand cubit feet). 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 8 for approximate
ranges of heat content for specific fuels. Heat content can be blank if fuel consumed is zero and for
pumped storage and compressed air plants.
SCHEDULE 4. FOSSIL FUEL STOCKS AT THE END OF THE REPORTING PERIOD
AND DATA BALANCE
Required Respondents: Schedule 4 regarding 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,
PETROLEUM COKE, and for plants 50 MW and above, NATURAL GAS. Although there are no stocks for
natural gas, the energy balance (between receipts and consumed fuel) and comments should be
completed for natural gas plants that have a total nameplate capacity of 50 MW and more (and have
completed Schedule 2).
Report fuel stocks ONLY for the following fuels:
−
Coal: Report all stocks of coal for use by this power plant. Include 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. Do not report waste
coal stocks.
−
Residual oil (No. 5 and No. 6 fuel oils)
−
Distillate-type oils (including diesel oil, No. 2 oil, jet fuel, and kerosene)
−
Petroleum coke
11
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Include back-up fuels and start-up and flame-stabilization fuels. Do not report stocks for waste coal,
natural gas, or wood and wood waste or other biomass fuels. All fuel stocks should be reported at the
plant level where possible. Stocks data should be reported by a transfer terminal or storage facility only if
inventory cannot be attributed to individual plants.
To avoid duplication, do not report receipts in Schedule 2 at the plant level that have already been reported by
a transfer terminal or storage facility and then transferred to a plant(s). Designate such transfers in Schedule
4 as negative adjustments to stocks at the transfer terminal or storage facility and positive adjustments to
stocks at the plant, including appropriate comments. Depending on the required data at transfer terminals or
storage sites and associated plants, the energy balance may require an explanatory comment. ENTER ZERO
in the Ending Stocks column if a plant has no stocks. Do not leave the field blank.
Energy Source: Add the energy source code from Table 8. For e-file users the code is prepopulated. If
the code is incorrect, choose the correct code from the drop-down list.
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 populated into the schedule from the
previous reporting period.
2.
Current Month’s Purchases: These data have been reported (above in SCHEDULE 2) and the
sum by energy source is automatically populated.
3.
Current Month’s Consumption: These data have been reported (in SCHEDULE 3A and 3B) and
the sum by energy source is automatically populated.
4.
Ending Stocks: Report this month’s ending stocks. Include all on-site stocks held for eventual use
in the electric power plant regardless of actual ownership of the fuel.
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 an explanation for the adjustment in the section
provided on Schedule 4.
6.
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 Purchases minus Current Month’s
Consumption plus (or minus) Adjustment to Stocks [(4) = (1) + (2) - (3) + (5)]. If the balance is a nonzero value, please review the data entered for stocks, receipts, consumption, and adjustments. Enter
a comment in the box on Schedule 4 for Balance comments to explain any discrepancy. Fuel receipts
that are not used for the production of electricity but for other purposes at the plant (e.g. as a feed
material to produce chemical byproducts such as fertilizers, etc.) may cause an imbalance in the
equation. Likewise, fuel that is sold during the month may cause an imbalance. Enter an
adjustment to balance the equation and enter an explanation for the adjustment or other situation
that result in an imbalance. Note that there are separate areas on Schedule 4 for adjustment
explanations and explanations for balances not equal to zero.
12
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
SCHEDULE 5. PART A. GENERATOR INFORMATION FOR STEAM-ELECTRIC
ORGANIC-FUELED PLANTS
Required Respondents: This schedule will be completed ONLY for generators at steam-electric organicfueled plants with a total steam turbine capacity of 10 megawatts and above, including the steam turbine
generation from combined cycle units. Report generation for all other types of prime movers (combustion
turbines, IC engines, wind, and hydraulic turbines), and steam turbine capacity of less than 10 megawatts
and all plants fueled by nuclear, solar, geothermal, or other energy sources on SCHEDULE 5. PARTS B or
C. Generation reported on Schedule 5. Part A. corresponds to the fuel consumption reported on Schedule
3. Part A.
For those plants that report annually, Schedules 3.A. and 5.A. must be reported for each month.
Prime Mover Code: Prime mover codes are shown in Table 7. Only CA and ST can be used in Schedule
5. Part A. For e-file users, the code is prepopulated. If the prepopulated code is incorrect, choose the
correct prime mover code from the drop-down list.
Generator ID: The generator ID is prepopulated. For an ID not prepopulated, choose the ID from the drop
down list of generator IDs that were reported for your plant on the Form EIA-860. If the generator ID is not
on the list, contact EIA immediately to have the ID added to your form. Generator IDs must match those
reported on the Form EIA-860.
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.
Generator Status: Enter one of the codes listed in Table 3 for generator status.
Table 3
Status Status Code Description
Code
OP
Operating - in service (commercial operation) and producing some electricity. Includes
peaking units that are run on an as needed (intermittent or seasonal) basis.
SB
Standby/Backup - available for service but not normally used (has little or no generation
during the year) for this reporting period
OA
Out of service – was not used for some or all of the reporting period but was either returned to
service on December 31 or will be returned to service in the next calendar year.
OS
Out of service – was not used for some or all of the reporting period and is NOT expected to
be returned to service in the next calendar year.
RE
Retired - no longer in service and not expected to be returned to service
Gross Generation: Enter 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: Enter the net generation (gross generation minus the parasitic station load, i.e. station
use). If the monthly station service load exceeded the monthly gross electrical generation, report negative
net generation with a minus sign. Do not use parentheses. For each month, enter that amount in MWh.
Combined heat and power plants in the industrial and commercial sectors may choose to leave net
generation blank in cases where net generation cannot be determined. Please note that net generation is
not defined as electric power sold to the grid (net of direct use), but as gross minus station use. If station
use is not separable from direct use at combined heat and power plants, report only gross generation and
leave net generation blank.
13
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
SCHEDULE 5. PART B. PRIME MOVER LEVEL GENERATION
Required Respondents: This schedule will be completed by: 1) steam-electric organic-fueled plants with
a total steam turbine capacity less than 10 megawatts, 2) combined-cycle plants whose steam portion of
the operation is under 10 MW and 3) all IC engines, combustion turbines, compressed air units, pumpedstorage hydroelectric turbines, and other miscellaneous energy storage technologies. Generation reported
on this schedule corresponds to the fuel consumption reported on Schedule 3. Part B.
Prime Mover Code: Prime mover codes are shown in Table 7. Only CA, CE, CS, CT, FC, GT, IC, PS,
ST, and OT can be used in Schedule 5. Part B. For e-file users, the code is prepopulated. If the
prepopulated code is incorrect, choose the correct prime mover code from the drop-down list. Each prime
mover type on Schedule 5B must have a corresponding entry on Schedule 3B for fuel consumption. Note
that for prime mover type CA, the entry on Schedule 3B (fuel consumed) is ZERO.
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: Enter 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: Enter the net generation (gross generation minus the parasitic station load, i.e. station
use). If the monthly station service load exceeded the monthly gross electrical generation, report negative
net generation with a minus sign. Do not use parentheses. For each month, enter that amount in MWh.
Combined heat and power plants in the industrial and commercial sectors may choose to leave net
generation blank in cases where net generation cannot be determined. Please note that net generation is
not defined as electric power sold to the grid (net of direct use), but as gross minus station use. If station
use is not separable from direct use at combined heat and power plants, report only gross generation and
leave net generation blank.
SCHEDULE 5. PART C. GENERATION FROM NUCLEAR AND
OTHER NONCOMBUSTIBLE ENERGY SOURCES
Required Respondents: This schedule will be completed by all nuclear plants and by all wind, solar,
geothermal, conventional hydroelectric or other plants where the energy source is not required to be
reported on Schedules 3A or 3B, such as purchased steam or waste heat. No fuel consumption data is
required for these types of plants. Report generation by energy source for nuclear, wind, solar, geothermal,
conventional hydroelectric and miscellaneous sources such as purchased steam or waste heat. Report
nuclear data by generating unit. For all other plant types, ignore the unit column. Do not report generation
at a combined-cycle plant. All combined-cycle generation is reported on SCHEDULE 5. PARTS A or B,
even though the fuel consumption for non-supplementary fired HRSG units is zero (reported on Schedule
3A or 3B with a zero for fuel).
Prime Mover Code: Prime mover codes are shown in Table 7. Only HY, HA, HB, HK, BT, PV, ST, WT,
and OT can be used in Schedule 5. Part C. For e-file users, the code is prepopulated. If the prepopulated
code is incorrect, choose the correct prime mover code from the drop-down list.
Energy Source: Enter one of the fuel codes listed in Table 8.
Unit Code: The nuclear unit code is prepopulated. Contact EIA if it is incorrect. All other plants ignore this
field.
Gross Generation: Enter 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: Enter the net generation (gross generation minus the parasitic station load, i.e. station
use). If the monthly station service load exceeded the monthly gross electrical generation, report negative
net generation with a minus sign. Do not use parentheses. For each month, enter that amount in MWh.
Combined heat and power plants in the industrial and commercial sectors may choose to leave net
14
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
generation blank in cases where net generation cannot be determined. Please note that net generation is
not defined as electric power sold to the grid (net of direct use), but as gross minus station use. If station
use is not separable from direct use at combined heat and power plants, report only gross generation and
leave net generation blank.
SCHEDULE 6. NONUTILITY ANNUAL SOURCE AND DISPOSITION OF ELECTRICITY
Required Respondents: Nonutility plants report annual calendar year data for the source and disposition
of electricity.
•
If you file the EIA-923 monthly,, this schedule is completed on the Form EIA-923 Supplemental Form
and is filed annually.
•
If you file the EIA-923 annually, this schedule is completed on the Form EIA-923 Annual.
Report all generation in MWh rounded to a whole number.
Source of Electricity
1.
Gross Generation (Annual): Report the total gross generation from all prime movers at the plant.
Note that for monthly respondents this should equal the sum of the gross generation reported each
month on Schedules 5A, 5B, and 5C.
2.
Other Incoming Electricity: 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, which is the
electricity used in the operation and maintenance of the facility (e.g., parasitic loads from auxiliary
equipment and onsite heating and lighting loads), 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 pumpedstorage plant), nor direct use (see below) of electricity by an industrial or commercial CHP plant.
5.
Direct Use (Industrial and Commercial Sector Plants, both CHP and non-CHP): 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. (Plants that
cannot separate Station Use and Direct Use may enter zero in Station Use and the sum of Station
Use and Direct Use in the Direct Use field. Provide a comment on SCHEDULE 9. )
6.
Total Facility Use: Report the total sum of station use and direct use.
7.
Retail Sales to Ultimate Customers: Report the amount of electricity sold directly to retail (end-use)
customers (power that is not re-sold or distributed by another entity). 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 file the Form EIA-861 “Annual
Electric Power Industry Report,” for more detailed information on the nature of the retail sales.
8.
Sales for Resale: Report the amount of electricity sold for resale (wholesale sales in MWh). 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).
15
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
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, power marketers, or other entities for resale to end-use consumers. This excludes
energy supplied under tolling agreements that is intended for resale to end use customers. Report energy
supplied under tolling agreements in “Other Outgoing Electricity.” Report all revenue from Sales for
Resale in thousand dollars to the nearest whole number.
SCHEDULE 8. ANNUAL ENVIRONMENTAL INFORMATION
Required Respondents: SCHEDULE 8 is filed annually and must be reported by steam-electric organicfueled power plants and combined cycle plants with a total steam turbine capacity of 10 megawatts and
above (that is the set of plants that reported boiler-level consumption on SCHEDULE 3. Part A.). Parts A
through F are required for plants 100 MW and above, and only Parts C, E and F are required for plants from
10 megawatts to less than 100 MW.
•
If you file the EIA-923 monthly, this schedule is completed on the Form EIA-923 Supplemental and is
filed annually.
•
If you file the EIA-923 annually, this schedule is completed on the Form EIA-923 Annual.
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. 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.
3.
Do not include byproducts sold under “Used On-Site.”
4.
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.
5.
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.
6.
Fly ash from FBC units includes fly ash from 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.
Bottom (bed) ash from FBC units includes bottom (bed) ash from fluidized bed combustion (FBC) units.
9.
FGD Gypsum is defined as byproducts that are greater than 75 percent CaS04●2H20 by weight.
10. Other FGD byproducts includes all FGD byproducts not reported in Fly ash from units with dry
FGD units; Fly ash from FBC units; Bottom ash from standard boiler units; Bottom (bed) ash
from FBC units; and FGD gypsum along with additives used to stabilize the FGD byproducts.
11. Ash from coal gasification (IGCC) units includes slag or solids extracted from the bottom of the
gasifier as well as fly ash removed downstream of the gasifier.
12. Other: Enter amount of other by-products. Specify the by-product on Schedule 9, Comments.
16
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
13. Steam sales must be reported in million Btu (MMBtu).
SCHEDULE 8. PART B. FINANCIAL INFORMATION RELATED TO COMBUSTION BYPRODUCTS
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 costs
including equipment operation and maintenance costs (such as particulate collectors, conveyors,
hoppers, etc.) associated with the collection and disposal of the byproducts. Record expenditures for
IGCC slag or fly ash collection/disposal in Column (1) or Column (2), respectively.
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.
17
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
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. 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.
No NOx Controls: Place a check in this box if the plant has no NOx control equipment or processes.
2.
Boiler ID: The boiler ID must match and correspond to the boiler ID and associated information
reported on the EIA-860. The boiler ID is prepopulated for e-file users. If it is not prepopulated, choose
the boiler ID from the drop down list. If the boiler ID is not on the list, contact EIA.
3.
NOx Control In-Service (hours): Enter the total hours the nitrogen oxide control was in service during
the reporting period (to the nearest hour).
4.
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.
5.
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. MONTHLY COOLING SYSTEM OPERATIONS
NOTE: All steam-electric plants of 100 MW nameplate capacity or greater, including combined cycle and
nuclear energy plants, must respond to this schedule. A separate page must be completed for each
month.
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 Cooling Water
Temperature sections.
3.
Cooling System ID or PLANT: The cooling system ID must match and correspond to the data
reported on the EIA-860. The ID is prepopulated for e-file users. If the ID is not prepopulated, choose
the ID from the drop down list. If the cooling system ID is not on the list, contact EIA to have new IDs
added. If the data to be reported are for the entire plant (because the data cannot be broken down by
separate cooling systems), choose “PLANT” from the drop-down list.
4.
Cooling System Status: Select from the equipment status codes on Table 4.
18
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
PRIME MOVER
CODES AND
DESCRIPTION
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Table 4
Code
5.
System Status
OP
Operating (in commercial service or out of service less than 365 days)
OS
Out of service (365 days or longer)
RE
Retired (no longer in service and not expected to be returned to service)
SB
Standby (or inactive reserve); i.e., not normally used, but available for
service)
SC
Cold Standby (Reserve); deactivated (usually requires 3 to 6 months to
reactivate)
TS
Operating under test conditions (not in commercial service)
Hours in Service: Enter the hours each cooling system was in service for the reporting
period..
6.
Monthly 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. Report amount of chlorine to
the nearest whole number in thousand pounds.
7.
Average Monthly Rate of Cooling Water data should be the rate of flow reported in cubic feet per
second (to the nearest 0.1 ft3 ). Diversion is the water moved from a watercourse without immediate
beneficial use, for purposes such as filling a cooling pond or adding water to a lake from which
thermoelectric power water withdrawals can occur. Withdrawal is the water removed from a water
body for beneficial use such as cooling water, boiler make-up water, ash sluicing, and dust
suppression. Discharge is the water returned to a water body, not necessarily the same water body
as the withdrawal. (Do not include water discharged to a recirculation pond that will be re-used at this
power plant.) Consumption is the water that is withdrawn from a water body and not returned
(discharged), because of evaporation losses and onsite consumption such as for dust control and flue
gas desulfurization.
8.
For Measured or Estimated, if all data reported under either the Average Monthly Rate of Cooling
Water section or the Intake or Discharge Temperature section have been measured, choose one of
the choices for “Measured” from the drop-down list. If one or more entries have been estimated in a
particular section choose one of the estimation methodologies given in the drop-down list for that
section. If “Other” is chosen, provide details of the estimation method on Schedule 9.
9.
For the Cooling Water Temperature sections, report the Average Monthly Temperature and the
Maximum Temperature for the Month in degrees Fahrenheit to the nearest whole number, measured
at the withdrawal point from the natural body of water or cooling pond in the case where water s first
divertedand discharge into the natural body of water.
SCHEDULE 8. PART E. FLUE GAS PARTICULATE COLLECTOR INFORMATION
1.
Flue Gas Particulate Collector ID: The flue gas particulate collector ID must match and correspond
to the data reported on the Form EIA-860. The ID is prepopulated for e-file users. For an ID not
prepopulated, choose the ID from the drop down list. If the ID is not on the list, contact EIA.
2.
FGP Collector Status: Select from the equipment status codes in Table 5.
19
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
ENERGY SOURCE
CODES AND HEAT
CONTENT
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Table 5
Code
Status
CN
Cancelled (previously reported as “planned”)
CO
New unit under construction
OP
Operating (in commercial service or out of service within 365 days)
OS
Out of service (365 days or longer)
PL
Planned (on order or expected to go into commercial service within 5 years)
RE
Retired (no longer in service and not expected to be returned to service)
SC
Cold Standby (Reserve); deactivated (usually requires 3 – 6 months to reactivate)
TS
Operating under test conditions (not in commercial service)
3.
Hours in Service: Enter the hours each collector was in service for the reporting period.
4.
For Typical Particulate Emissions Rate, enter the particulate emission rate based on the annual
operating factor (to nearest 0.01 pound per million Btu).
5.
For Removal Efficiency of Particulate Matter at Annual Operating Factor and At 100-Percent
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.
6.
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.
7.
For 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 comment on
SCHEDULE 9. If no test has been conducted, ENTER ZERO in the column and leave the test date
blank. Test results should not be reported if there was no test date.
8.
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.
Flue Gas Desulfurization Unit ID: The flue gas desulfurization unit ID must match and correspond to
the data reported on the Form EIA-860. The ID is prepopulated for e-file users. For an ID not
prepopulated, choose the ID from the drop down list. If the ID is not on the list, contact EIA.
2.
Flue Gas Desulfurization Unit Status, as of January 1 following the end of the reporting year. Select
from the equipment status codes listed in Table 6.
20
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Table 6
Code
Status
CN
Cancelled (previously reported as “planned”)
CO
New unit under construction
Operating (in commercial service or out of service less than
365 days)
Out of service (365 days or longer)
OP
OS
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 service); i.e. not normally used, but
available for service
Cold Standby (Reserve); deactivated (usually requires 3 – 6
months to reactivate
Operating under test conditions (not in commercial service)
PL
RE
SB
SC
TS
3.
For Hours in Service, enter the total number of hours one or more trains (or modules) were in
operation; do not report for individual trains.
4.
Quantity of FGD Sorbent Used: Enter the quantity of FGD sorbent used during the reporting period
(to the nearest 0.1 thousand tons).
5.
Electrical Energy Consumption: Enter the Electrical Energy Consumed by this Unit during the
reporting period (in megawatthours).
6.
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.
7.
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 per year. If actual
data are unavailable, provide estimates based on equipment design performance specifications.
8.
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 comment on SCHEDULE 9. If no test was conducted, enter zero for the
efficiency and leave the test data blank. Test results should not be given without a test date.
9.
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 purchaser’s name, a telephone number (if available), and date of sale.
21
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Table 7
Prime Mover Code
Prime Mover Description
BT
Turbines Used in a Binary Cycle (such as used for geothermal applications)
CA
Combined-Cycle – Steam Part
CE
Compressed Air Energy Storage
CP
Energy Storage, Concentrated Solar Power
CS
Combined-Cycle Single-Shaft Combustion turbine and steam turbine
share a single generator
CT
Combined-Cycle Combustion Turbine Part
FC
Fuel Cell
GT
Combustion (Gas) Turbine (including jet engine design)
HA
Hydrokinetic, Axial Flow Turbine
HB
Hydrokinetic, Wave Buoy
HK
Hydrokinetic, Other
HY
Hydraulic Turbine (including turbines associated with delivery of water by
pipeline)
IC
Internal Combustion (diesel, piston) Engine
OT
Other – Specify on SCHEDULE 9.
PS
Hydraulic Turbine – Reversible (pumped storage)
PV
Photovoltaic
ST
Steam Turbine (including nuclear, geothermal and solar steam, excluding
combined-cycle)
WT
Wind Turbine
22
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Table 8
“Higher Heating Value”
Range
Energy
Source
Code
Unit
Label
MMBtu
Lower
Energy Source Description
MMBtu
Upper
Fossil Fuels
Coal
Petroleum
Products
Natural Gas
and Other
Gases
ANT
tons
22
28
Anthracite Coal
BIT
tons
20
29
Bituminous Coal
LIG
tons
10
14.5
SUB
tons
15
20
Subbituminous Coal
WC
tons
6.5
16
Waste/Other Coal (including anthracite culm,
bituminous gob, fine coal, lignite waste, waste coal)
RC
tons
20
29
Refined Coal
DFO
barrels
5.5
6.2
Distillate Fuel Oil (including diesel, No. 1, No. 2, and
No. 4 fuel oils.
JF
barrels
5
6
KER
barrels
5.6
6.1
Kerosene
PC
tons
24
30
Petroleum Coke
RFO
barrels
5.8
6.8
WO
barrels
3.0
5.8
BFG
Mcf
0.07
0.12
Blast Furnace Gas
NG
Mcf
0.8
1.1
Natural Gas
OG
Mcf
0.32
3.3
Other Gas (specify in Comment Section of
SCHEDULE 9)
PG
Mcf
2.5
2.75
Gaseous Propane
SG
Mcf
0.2
1.1
Synthetic Gas
SGC
Mcf
0.2
0.3
Coal-Derived Synthetic Gas
Lignite Coal
Jet Fuel
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)
Renewable Fuels
Solid
Renewable
Fuels
AB
tons
7
18
MSW
tons
9
12
OBS
tons
8
25
WDS
tons
7
18
23
Agricultural By-Products
Municipal Solid Waste
Other Biomass Solids (specify
in Comment Section of
SCHEDULE 9)
Wood/Wood Waste Solids (including paper
pellets, railroad ties, utility poles, wood chips,
bark, and wood waste solids)
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Table 8 Continued
Energy
Source
Code
“Higher Heating
Value” Range
Unit
Label
Energy Source Description
MMBtu
Lower
MMBtu
Upper
Renewable Fuels (cont.)
OBL
Liquid
Renewable
(Biomass)
Fuels
Gaseous
Renewable
(Biomass)
Fuels
All Other
Renewable
Fuels
barrels
3.5
4
Other Biomass Liquids (specify in Comment
Section of SCHEDULE 9)
SLW
tons
10
16
Sludge Waste
BLQ
tons
10
14
Black Liquor
WDL
barrels
8
14
Wood Waste Liquids excluding Black Liquor
(includes red liquor, sludge wood, spent sulfite
liquor, and other wood-based liquids)
LFG
Mcf
0.3
0.6
Landfill Gas
OBG
Mcf
0.36
1.6
Other Biomass Gas (includes digester gas,
methane, and other biomass gasses)
(specify in Comment Section of SCHEDULE 9)
SUN
WND
GEO
N/A
N/A
N/A
0
0
0
0
0
0
WV
N/A
0
0
CUR
TID
N/A
N/A
0
0
0
0
WAT
N/A
0
0
Solar
Wind
Geothermal
Water used in Wave Buoy Hydrokinetic
Technology
Water used in Current Hydrokinetic Technology
Water used in Tidal Hydrokinetic Technology
Water at a Conventional
Hydroelectric Turbine
All Other Fuels
Pumping Energy for Reversible (Pumped
Storage) Hydroelectric Turbine
WAT
MWh
0
0
N/A
MWh
0
0
NUC
N/A
0
0
PUR
N/A
0
0
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.)
All Other
Fuels
Compressed Air
Nuclear Uranium, Plutonium, Thorium
WH
N/A
0
0
TDF
tons
16
32
Tire-derived Fuels
OTH
N/A
0
0
Specify in Comment Section of SCHEDULE 9.
24
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-923 (2011)
POWER PLANT OPERATIONS
REPORT INSTRUCTIONS
Form Approval
OMB No. 1905-0129
Approval Expires: 12/31/2013
Burden: 2.8 Hours
Plant Name: ____________________________________________________________________
Plant ID: _________________________________
State: ______
Reporting Month/Year: ____________________
GLOSSARY
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-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.
REPORTING
BURDEN
DISCLOSURE
OF INFORMATION
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. The weighted average burden for the Form EIA-923 is 2.8 hours per response. 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.
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 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 other information reported on Form EIA-923 is
considered public information and may be publicly released in company identifiable form.
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 protected 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.
25
| File Type | application/pdf |
| File Title | Appendix C |
| Author | Grace Sutherland |
| File Modified | 2010-09-30 |
| File Created | 2010-09-30 |