Petroleum Supply Reporting System

U.S. DEPARTMENT OF ENERGY
ENERGY IN FORMATION ADMINISTRATION
Washington, D.C. 20585

OMB No. 1905-0165
Expiration Date: 12/31/09
(Revised 2006)

EIA-810
MONTHLY REFINERY REPORT
INSTRUCTIONS
interactively, import data from your own database,
validate your data online, and transmit the encrypted data
electronically to EIA via the Internet or a dial-up modem. If
you are interested in receiving this free software, contact
the Electronic Data Collection Support Staff at
(202) 586-659.

QUESTIONS
If you have any questions about Form EIA-810 after reading the
instructions, please contact the Form Manager at
(202) 586-6281.

PURPOSE
The Energy Information Administration (EIA) Form EIA-810,
"Monthly Refinery Report," is used to collect data on the
operations of all petroleum refineries located in the 50 States,
District of Columbia, Puerto Rico, the Virgin Islands, Guam, and
other U.S. possessions. The data appear on EIA’s website at
www.eia.doe.gov and in numerous government publications.

COPIES OF SURVEY FORMS, INSTRUCTIONS
AND DEFINITIONS
Copies in portable document format (PDF) and spreadsheet
format (XLS) are available on EIA's website at:
www.eia.doe.gov/oil_gas/petroleum/survey_forms/pet_survey_forms.html

You may also access the materials by following the steps
below:

WHO MUST SUBMIT
Form EIA-810 is mandatory pursuant to Section 13(b) of the
Federal Energy Administration Act of 1974 (Public Law 93-275)
and must be completed by the operators of all operating and
idle petroleum refineries located in the 50 States, District of
Columbia, Puerto Rico, the Virgin Islands, Guam, and other U.S.
possessions.

•
•
•
•

Go to EIA’s website at www.eia.doe.gov
Click on Petroleum
Click on Petroleum Survey Forms located in the
References box on the right side of the page
Select the materials you want.

Files must be saved to your personal computer. Data cannot
be entered interactively on the website.

WHEN TO SUBMIT
Form EIA-810 must be received by the EIA by the 20th
calendar day following the end of the report period (e.g., the
Form EIA-810 covering the January 2007 report period must
be received by February 20, 2007).

HOW TO SUBMIT

GENERAL INSTRUCTIONS
Definitions of petroleum products and other terms are available
on our website. Refer to the above for details on accessing
our website. Please refer to these definitions before
completing the survey form.

Instructions on how to report via fax, secure file transfer, or
e-mail are printed on PART 2 of Form EIA-810.

PART 1. RESPONDENT IDENTIFICATION DATA

•

•

Enter the year and month on each page. The monthly
report period begins at 12:01 a.m. EST on the first day of
the month and ends midnight of the last day of the month.

•

Enter the 10-digit EIA ID Number. If you do not have a
number, submit your report leaving this field blank. EIA will
advise you of the number.

•

Enter the name and mailing address of the reporting
company. If there has been a change since the last report,
enter an “X” in the block provided.

•

Enter the refinery site name.

•

Secure File Transfer: This form may be submitted to the
EIA by fax, e-mail, or secure file transfer. Should you
choose to submit your data via e-mail or facsimile, we
must advise you that e-mail and facsimile are insecure
means of transmission because the data are not
encrypted, and there is some possibility that your data
could be compromised. You can also send your Excel files
to EIA using a secure method of transmission: HTTPS.
This is an industry standard method to send information
over the web using secure, encrypted processes. (It is
the same method that commercial companies use to
communicate with customers when transacting business
on the web.) To use this service, we recommend the use
of Microsoft Internet Explorer 5.5 or later or Netscape 4.77
or later. Send your surveys using this secure method to:
https://idc.eia.doe.gov/upload/noticeoog.jsp.
Electronic Filing Option: The PC Electronic Data
Reporting Option (PEDRO) is a Windows-based
application that will enable you to enter data

•

Enter the name, telephone number, fax number, and
e-mail address of the person to contact concerning
information shown on the report. The person listed
should be the person most knowledgeable of the specific
data reported. Check the box provided if the contact
information is different from the prior month.

EIA-810, Monthly Refinery Report

Page 1

than the atmospheric crude oil distillation units (e.g.,
cracking units) from Code 990.

PART 2. SUBMISSION/RESUBMISSION INFORMATON
Refer to “How to Submit” section for more details or methods
for submitting data.
Resubmission
A resubmission is required whenever an error greater than
5 percent of a previously reported value is discovered by a
respondent or if requested by the EIA.
Enter "X" in the resubmission box if you are correcting
information previously reported.
Enter only those data cells which are affected by the changes.
You are not required to file a complete form when you resubmit.

SPECIFIC INSTRUCTIONS

Operable Capacity of Atmospheric Crude Oil Distillation
Units on the First Day of the Month
Report in barrels per calendar day the Operating, Idle, and
Total Operable Capacities in the appropriate spaces. The
capacity for an individual unit must be either idle or operating
on the first day of the month. Do not report percentages of
capacity based on monthly inputs.
• Operating Capacity (Code 399) - Report the component of
Total Operable Capacity that is in operation on the first day
of the month.

PART 3. REFINERY INPUT AND CAPACITY
Refinery Input
Gross Input to Atmospheric Crude Oil Distillation Units
(Code 990) - Report the sum of the various components of
refinery input to atmospheric crude oil distillation units. Do not
include inputs to downstream units such as vacuum distillation
units, catalytic cracking units, and coking units. Any
processing equipment upstream of the actual atmospheric
distillation tower/furnace, such as preflash drums/towers,
prefractionators and outboard flash towers, should be
considered part of the atmospheric distillation unit for capacity
reporting purposes. Fresh feed inputs to selected downstream
units are reported in codes 491, 492, and 493. The following
components of refinery input to atmospheric crude oil distillation
units should be included in Code 990:
• Crude Oil - Report the total amount of crude oil (including
lease condensate and liquid hydrocarbons produced from
tar sands, gilsonite, and oil shale) of both foreign and
domestic origin that is charged to the atmospheric crude oil
distillation units. Exclude crude oil charged to units other
than the atmospheric crude oil distillation units (e.g., coking
unit) from Code 990.
• Products of Natural Gas Processing Plants - Report all
quantities of natural gas plant liquids (i.e., ethane, propane,
normal butane, isobutane, and pentanes plus) charged to
the atmospheric crude oil distillation units. Include inputs of
unfractionated streams and mixtures of liquefied petroleum
gases. Exclude products of natural gas plants blended or
charged to units other than the atmospheric crude oil
distillation units from Code 990.
• Unfinished Oils - Report all unfinished oils charged to the
atmospheric crude oil distillation units (e.g., unfinished
naphthas, gas oil, virgin naphtha, topped crude, cracking
stocks, and slop oil). Exclude unfinished oils charged to
units other than the atmospheric crude oil distillation units
(e.g., cracking units) from Code 990.
• All Other Oils - Report any finished petroleum products
(e.g., distillate fuel oil and residual fuel oil) charged to the
atmospheric crude oil distillation units for further processing.
Include raw materials such as coal tar derivatives,
hydrogen, and gilsonite. Exclude oils charged to units other
Page 2

Fresh Feed Input to Downstream Processing Units (Codes
491, 492, and 493) - Report the fresh feed liquid (adjusted for
standard temperature and pressure) input to catalytic
cracking units, catalytic hydrocracking units, and delayed and
fluid coking units. Exclude recycled feeds, steam, and
hydrogen gas. For Code 493, include fresh feed input to
flexicoking units.

• Idle Capacity (Code 400) - Report the component of Total
Operable Capacity that is not in operation and not under
active repair, but capable of being placed in operation within
30 days; and capacity not in operation but under active
repair that can be placed in operation within 90 days.
• Total Operable Capacity (Code 401) - Report the amount
of capacity that on the first day of the month, is either in
operation; not in operation, and not under active repair but
capable of being placed in operation within 30 days; or not
in operation but under active repair that can be placed in
operation within 90 days. Total Operable Capacity is the
sum of the Operating and Idle Capacity Code 399 and Code
400).
Barrels per calendar day is defined as the amount of input that
a distillation facility can process under usual operating
conditions on an average day. Calendar day capacity is less
than the stream day capacity which is a measure of maximum
processing capacity under ideal operating conditions.
Calendar day capacity is expressed in terms of capacity
during a 24-hour period and reduces the maximum processing
capability of all units at the facility under continuous operation
to account for the following limitations that may delay, interrupt,
or slow down production:
•

The capability of downstream processing units to absorb
the output of crude oil processing facilities of a given
refinery. No reduction is necessary for intermediate
streams that are distributed to other than downstream
facilities as part of a refinery’s normal operation;

•

The types and grades of inputs to be processed;

•

The types and
manufactured;

•

The environmental constraints associated with refinery
operations;

•

The annualized reduction of capacity for scheduled
downtime due to such conditions as routine inspection,
maintenance, repairs, and turnaround; and

EIA-810, Monthly Refinery Report

grade

of

products

expected

to

•

The annualized reduction of capacity for unscheduled
downtime due to such conditions as mechanical
problems, repairs and slowdowns.

PART 4. SULFUR CONTENT AND API GRAVITY OF
CRUDE OIL

•

Report stocks as of midnight of the last day of the report
o
month, corrected to 60 F less basic sediment and water
(BS&W).

•

Report all domestic and foreign stocks held at refineries
and in transit thereto, except crude oil in transit by water
from Alaska or any crude oil or product in transit by
pipeline. Crude oil in transit by pipeline and Alaskan crude
oil in transit by water are reported on Form EIA-813,
“Monthly Crude Oil Report.” Petroleum products in transit
by pipeline are reported by pipeline operators on Form
EIA-812, “Monthly Product Pipeline Report.” Include
foreign stocks only after entry through Customs. Exclude
stocks of foreign origin held in bond.

Indicate the sulfur content and the API gravity of Crude Oil
(Code 050) reported either as refinery receipts or inputs. Do
not report sulfur content and API gravity for both refinery
receipts and inputs.
Weighted Average Sulfur Content is the percentage of sulfur in
domestic and foreign crude oil. Report to the nearest one
hundredth of one percent.
Weighted Average API Gravity is gravity at 60 degrees
o
Fahrenheit ( F) of domestic and foreign crude oil. Report to the
nearest hundredth of a degree.

For purposes of this report, “after entry through Customs” is
said to occur on:
•

the “entry date” specified on the U.S. Customs Form
CF7501, “Entry Summary;” or

The following is an example of how to calculate and report
weighted average API gravity:

•

the “date of withdrawal conditionally free of duty” specified
on U.S. Customs Form CF 7501, “Entry Summary;” or

Operator inputs 100,000 barrels of 27.5 API gravity oil (at
60oF) and 200,000 barrels of 33.5 API gravity oil (at 60oF).

•

the “import date” specified on the U.S. Customs Form
214, “Application for Foreign Trade Zone Admission
and/or Status Designation;” or

•

the “date of exportation” specific on the U.S. Department
of Commerce Form 7525-V, “Shipper’s Export Declaration,”
for shipments from Puerto Rico to the 50 States and the
District of Columbia.

•

100,000 barrels x 27.5 = 2,750,000
200,000 barrels x 33.5 = 6,700,000
300,000 barrels
9,450,000

•

9,450,000 divided by 300,000 = 31.50

•

The weighted average API gravity would be
reported as 31.50.

Include stocks in underground storage associated with the
refinery when reporting liquefied petroleum gas and liquefied
refinery gas.

PART 5. REFINERY OPERATIONS
Quantities: Report using the following criteria.
• Report all quantities to the nearest whole number in
thousand barrels (42 U.S. gallons/barrel). Quantities
ending in 499 or less are rounded down, and quantities
ending in 500 or more are rounded up (e.g., 106,499 barrels
are reported as 106 and 106,500 barrels are reported as
107).
• Report data for only those lines which are applicable to
your operation. If there are no data for a specific line, leave
the entire line blank. Shaded cells on the form are those in
which data are not currently required to be reported.
• For each product, report beginning and end-of-month
stocks, receipts, inputs, production, shipments, and refinery
fuel use and losses during the month, except where shaded.
• Most reporting categories must balance across:
Beginning Stocks + Receipts - Inputs + Production Shipments - Fuel Use/Losses must equal Ending
Stocks.
• Report only positive (i.e. greater than requal to zero)
quantities.
Stocks (Beginning and End of Month)
•

Report all stocks in the custody of the refinery regardless
of ownership. Reported stock quantities should represent
actual measured inventories.

Include stocks of oxygenates held at oxygenate production
facilities which are either located within or adjacent to the
refinery complex whose oxygenates are dedicated for use by
this refinery complex. (Captive Oxygenate Plants).
Include stocks of unfinished oils held at terminals offsite of the
refinery that are intended for future processing at the refinery.
Report end-of-month stocks of unfinished oils by degree
Fahrenheit end-point. The following are the degree end-point
categories: Naphthas and Lighter (Code 820), less than 401oF;
Kerosene and Light Gas Oils (Code 830), 401oF to 650oF;
o
o
Heavy Gas Oils (Code 840), 651 F to 1,000 F; and Residuum
o
(Code 850), greater than 1,000 F.
Receipts During Month
Report all receipts at the refinery and in transit thereto, using
the same criteria as those used for reporting stocks. Receipts
of Crude Oil, Domestic (Code 010) include Alaskan Crude Oil
(Code 011).
Crude Oil, Total (Code 050) is the sum of Domestic (Code 010)
and Foreign (Code 020) Crude Oil.
Liquefied gases received at a refinery are reported as receipts
of liquids from natural gas processing plants (Codes 110, 231,
232, 233, 220) if their origin is unknown.
Receipts of Liquefied Refinery Gases (Codes 621, 622, 623,

EIA-810, Monthly Refinery Report

Page 3

and 615) and Still Gas (Code 045) include both fuel use and
petrochemical feedstock use.
Oxygenates received from sources outsides the refinery
(Merchant Plants), as well as, oxygenates produced at the
refinery (Captive Plants) should be reported as receipts of
Other Hydrocarbons, Hydrogen, and Oxygenates (Code 090).
Report Hydrogen received from sources outside the refinery as
well as hydrogen produced at hydrogen plants within the
refinery as receipts and inputs on line 090 and then report as
inputs on line 094. Exclude of natural gas used as a
feedstock to produce hydrogen from refinery receipts. Also
exclude natural gas received at the refinery for use as a fuel.
Inputs During Month
Report the volume of crude oil, unfinished oils, natural gas
liquids, other hydrocarbons, hydrogen, oxygenates, and
liquefied refinery gases input to refinery processing units for the
purpose of producing finished petroleum products.
Report gross refinery input for each item identified on the
survey form except where shaded. Do not “net out” the inputs
by reporting the difference between inputs and production.
Oils that have undergone prior refinery processing should not
be reported as inputs of Crude Oil (Code 050). Such oils
should be reported as inputs of intermediate product (typically,
unfinished oils or motor gasoline blending components) or
finished product. An “Input” of a finished product, such as a
finished motor gasoline or distillate fuel oil, represents a
reclassification of a finished product (see Reclassification of
Inventory on page 5).
Inputs of product used to manufacture finished petrochemicals
should be excluded. Input of natural gas to produce hydrogen
should be excluded. Input of feedstock to manufacture
oxygenates should be excluded. Inputs of finished petroleum
products are explained under “Reclassification of Inventory” on
page 5.
Include oxygenates (e.g., fuel ethanol, ethyl tertiary butyl ether,
methyl tertiary butyl ether, tertiary amyl methyl ether, tertiary
butyl alcohol) in Other Hydrocarbons, Hydrogen, and
Oxygenates (Code 090).
Production During Month
Report gross refinery production during the month for each item
identified on the survey except where shaded.
Do not “net out” the production by reporting the difference
between inputs and production.
Report the volume of petroleum products produced from
processing of crude oil, unfinished oils, liquefied petroleum
gases, other hydrocarbons, hydrogen, and oxygenates. Report
the volume of petroleum products produced from blending
operations of motor gasoline and aviation blending components.
The production of olefins (Codes 631, 632, 633, and 634)
should represent only that portion of liquefied refinery gases
that are shipped from the refinery as a finished refinery product
(e.g., olefins shipped to petrochemical facilities).
Report the production of aromatics (e.g., benzene, toluene, and
xylene) based upon intended use. Aromatics to be used for
Page 4

blending or compounding into finished aviation or motor
gasoline should be reported production of aviation or motor
gasoline blending components. Aromatics used as
petrochemical feedstocks should be reported as production of
o
Naphtha less than 401 F (Code 822).
Non-fuel use production is reported on line 097. Non-fuel
use products include white spirits (distillate intermdeiaries in
the naptha/kerosene range) blended into paint, insecticides,
and other similar products. Elemental Sulfur is also
accounted for on this line. To convert short tons of sulfur to
barrels, multiply the number of short tons by 3.17.
Shipments During Month
Report all shipments, including intracompany shipments to
other refineries, storage facilities, chemical plants or
fractionating facilities. Inputs to onsite petrochemical plants
should be reported as shipments from the refinery.
Refinery Fuel Use and Losses During Month
Report all nonprocessing losses (e.g., spills, fire losses,
contamination, etc.) by product. Include crude oil and
petroleum products used as fuel at the refinery. Exclude
refinery processing gains and losses as well as stock
discrepancies caused by gauging problems. Exclude fuel use
at petrochemical facilities located at the same site as the
refinery.
Gasoline Blending Components
Report naphtha-range hydrocarbons as one of the products
broadly classified as motor gasoline blending components in
cases where the intended end use is for blending or
compounding into finished motor gasoline. Products classified
by EIA as motor gasoline blending components include
Reformulated Blendstock for Oxygenate Blending (RBOB) for
blending with ether (EIA product code 122), RBOB for Blending
with Alcohol (EIA product code 123), Conventional Blendstock
for Oxygenate Blending (CBOB) (EIA product code 139),
reformulated “Gasoline Treated as Blendstock” (GTAB) (EIA
product code 120), conventional GTAB (EIA product code
121), or “all other” motor gasoline blending components (EIA
product code 138). Naphtha-range hydrocarbons intended for
blending or compounding into finished aviation gasoline have a
separate product code (code 112) on EIA reports. Exclude any
naphtha-range hydrocarbons from gasoline blending
components if the intended end use is other than blending or
compounding into finished motor gasoline or finished aviation
gasoline (e.g. naphtha intended for use in solvents or as
petrochemical feedstocks).
Note that “Gasoline Treated as Blendstock” (GTAB) is a
specific category of gasoline intended to provide importers with
flexibility to blend imported gasoline after the gasoline arrives
in the U.S. Classification of gasoline as GTAB requires
compliance with specific regulatory and accounting
requirements established by the U.S. Environmental Protection
Agency. GTAB is not a generic descriptive term for finished
gasoline or gasoline blending components intended for further
blending.
Certain products that may be intended for blending into
gasoline are reported separately and excluded from gasoline
blending components because they have separate EIA product
codes. These products include normal butane (EIA product

EIA-810, Monthly Refinery Report

codes 232 and 623), butylene (EIA product code 633),
isobutane (EIA product codes 233 and 615), isobutylene (EIA
product code 634), pentanes plus (EIA product code 220), fuel
ethanol (EIA product code 141), and Methyl Tertiary Butyl
Ether (MTBE) (EIA product code 144). This applies only to
unblended products. After blending, butanes, pentanes plus,
fuel ethanol, MTBE, and other materials become part of the
volume of gasoline blending components or finished motor
gasoline.
Certain gasoline blending components may be received as
return streams from chemical plants. In this case, it is very
important to maintain consistent classification of product
produced and shipped from the refinery and received and input
at the refinery. For example, a refinery may ship naphtharange petrochemical feedstocks (EIA product 822) to a
chemical plant and then receive a return stream from the
chemical plant that will be used for motor gasoline blending. In
this case, the return stream reported to EIA must be classified
as receipt and input of petrochemical feedstock and then
production of gasoline blending components or finished
gasoline.
Inputs (Gain) or Production (Loss)
Report the net processing gain or loss that occurred during the
refining process. Exclude losses which do not take place
during the refining process (e.g., spills, fire losses, and
contamination during blending, transportation, or storage).
Report those losses by product under the “Refinery Fuel Uses
and Losses” column.
A refinery processing gain represents the volumetric amount by
which total refinery production is greater than input for the
report period. A refinery processing loss represents the
volumetric amount by which total refinery production is less than
input for the report period. These differences are due to the
processing of crude oil and other inputs into products which in
total have less volume or more volume than the inputs
processed. Therefore, the total production of products is
greater or less than input.
Report a processing gain in the “Input” column or a processing
loss in the “Production” column (Code 911). These entries are
always positive numbers and are used to balance the total
input and total production columns for Code 999.

are reported on codes 621, 631, 622, 632, 623, 633, 615, and
634). The volume of LRG for any class (i.e. Ethane) has to
be equal or greater than any breakout volume (i.e. Ethylene).
Lubricants
Report only lubricant base oils produced at the refinery. Do not
include finished lubricants produced at lube plants. Exclude
byproducts of lubricating oil refining such as aromatic extracts
derived from solvent extraction or tars derived from
deasphalting. Reporting categories include:
Paraffinic. Includes all grades of bright stock and neutrals
with a Viscosity Index >75.
Naphthenic. Includes all lubricating oil base stocks with a
Viscosity Index <75.
Note : The criterion for categorizing lubricants is based solely
on the Viscosity Index of the stocks and is independent of crude
sources and type of processing used to produce the oils.
Exceptions: Lubricating oil base stocks that have been
historically classified as naphthenic or paraffinic by a refiner
may continue to be so categorized irrespective of the Viscosity
Index criterion (e.g., Unextracted paraffinic oils that would not
meet the Viscosity Index test).
Oxygenates
Report oxygenates on an individual basis in product codes 141,
142, and 144. All other oxygenates (Code 445) includes other
aliphatic alcohols and ethers (e.g., TAME, TBA) intended for
motor gasoline blending.
Include stocks held at oxygenate production facilities, located
within or adjacent to the refinery complex (captive plants).
Do not report oxygenates as motor gasoline blending
components unless they have been commingled with motor
gasoline blending components.
Report gross inputs of oxygenates. Do not “net out” oxygenate
inputs by reporting the difference between oxygenate inputs and
production.
Petrochemical Feedstocks

Liquefied Gases

Report petrochemical feedstock. Do not report finished
petrochemicals.

Report all mixes of natural gas plant liquids (including
unfractionated streams) and liquefied refinery gases by
individual components as determined by chemical analysis,
(e.g., ethane, propane, normal butane, isobutane, pentanes
plus for gas plant liquids, and ethane/ethylene,
propane/propylene,
normal
butane/butylene,
and
isobutane/isobutylene for liquefied refinery gases).

Deliveries of feedstock to petrochemical units within your
refinery, chemical or rubber manufacturing plants are reported
as shipments. Report return streams of petrochemical
feedstocks as a receipt and input of petrochemical feedstocks
and as a production in the product category of intended use.

Liquefied Petroleum Gases (LPG) extracted from natural gas
liquids streams originating at natural gas processing plants, and
received by the refinery for processing into finished products
are reported by component under codes 110, 231, 232, 233,
and 220.
Liquefied Refinery Gases (LRG) that are fractionated from
crude oil or produced from downstream processes, such as
catalytic cracking, and result in finished LRG (liquefied gases
production that are subsequently stored or shipped as a LRG)

Do not report natural gas liquids (NGL) or liquefied refinery
gases (LRG) as petrochemical feedstock. These products are
reported by component as ethane, ethylene, propane,
propylene, normal butane, butylene, isobutane, isobutylene,
and pentanes plus (Codes 110, 231, 232, 233, 220, 621, 631,
622, 632, 623, 633, 615, and 634).
Pipeline Interface
Pipeline interface consists of petroleum products which have
become mixed during pipeline transport. Pipeline interface is to

EIA-810, Monthly Refinery Report

Page 5

be excluded from volumes reported on the Form EIA-810. The
input of pipeline interface and finished petroleum products
produced from processing of pipeline interface are also
excluded.
Reclassification of Inventory
If a finished product is reclassified as a different finished
product or as an unfinished oil, the quantity of the original
product is reported in the “Input” column and the reclassified
product is reported in the “Production” column.
For example, if you produce 10,000 barrels of kerosene during
January and have it in storage at the end of the month, this
quantity is to be reported as “Production” and “Stocks” of
Kerosene (Code 311) on the January report. If during February
the intended use of the 10,000 barrels of kerosene is changed
to Kerosene-Type Jet Fuel, report this reclassification by
reporting the 10,000 barrels as an “Input” of Kerosene
(Code 311) and as a “Production“ of Kerosene-Type Jet Fuel
(Code 213).

regulatory, law enforcement, or adjudicatory purposes.
Disclosure limitation procedures are not applied to the
statistical data published from this survey's information. Thus,
there may be some statistics that are based on data from fewer
than three respondents, or that are dominated by data from
one or two large respondents. In these cases, it may be
possible for a knowledgeable person to estimate the
information reported by a specific respondent.
Company specific data are also provided to other DOE offices
for the purpose of examining specific petroleum operations in
the context of emergency response planning and actual
emergencies.
The data collected on Form EIA-810, “Monthly Refinery
Report,” is used to report aggregate statistics on and conduct
analyses of the operation of U.S. petroleum refineries.

SANCTIONS

Residual Fuel Oil by Percent of Sulfur Content
Report refinery input and production during the month and end-of-month stocks of residual fuel oil by sulfur content. Product
Codes 508, 509, and 510 must sum to the total for Residual
Fuel Oil (Code 511).
Still Gas
Still gas shipped to petrochemical facilities should be reported
as a shipment in Code 045, less the amount of such streams
returned to the producing refinery. Still gas used as a fuel at
the refinery should be reported as a fuel use/loss.
Report still gas in thousand fuel oil equivalent barrels. The
conversion factor is 6 million BTU’s per fuel oil equivalent barrel
(higher heating value).
Synthetic Hydrocarbons
Report synthetic hydrocarbons such as shale oil, tar sands oils,
etc., with Crude Oil (Codes 050 and 990).

PROVISIONS REGARDING
CONFIDENTIALITY OF INFORMATION
The information reported on this form will be protected and not
disclosed to the public to the extent that it satisfies the criteria
for exemption under the Freedom of Information Act (FOIA), 5
U.S.C. §552, the DOE regulations, 10 C.F.R. §1004.11,
implementing the FOIA, and the Trade Secrets Act, 18 U.S.C.
§1905.

The timely submission of Form EIA-810 by those required to
report is mandatory under Section 13(b) of the Federal Energy
Administration Act of 1974 (Public Law 93-275), as amended.
Failure to respond may result in a civil penalty of not more than
$2,750 each day for each violation, or a fine of not more than
$5,000 for each willful 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.

FILING FORMS WITH THE FEDERAL
GOVERNMENT AND ESTIMATED REPORTING
BURDEN
Respondents are not required to file or reply to any Federal
collection of information unless it has a valid OMB control
number. Public reporting burden for this collection of
information is estimated to average 4 hours and 45 minutes per
response. This includes 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: Energy Information
Administration, Statistics and Methods Group, EI-70, 1000
Independence Avenue, S.W., Washington, D.C. 20585; and to
the Office of Information and Regulatory Affairs, Office of
Management and Budget, Washington, D.C. 20503.

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 General Accounting Office, or
other Federal agencies authorized by law to receive such
information. A court of competent jurisdiction may obtain this
information in response to an order. The information may be
used for any nonstatistical purposes such as administrative,
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EIA-810, Monthly Refinery Report