Monthly Refinery Report

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

OMB No. 1905-0165
Expiration Date: 8/31/19
Burden: 5.2 hours

EIA-810
MONTHLY REFINERY REPORT
INSTRUCTIONS
................................................................................................................................................................
QUESTIONS
If you have any questions about Form EIA-810 after reading the
instructions, please contact the Survey 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. A summary of the data appear on EIA’s
website at https://www.eia.gov and in numerous government
publications.

encrypted, and there is some possibility that your data could be
compromised.

COPIES OF SURVEY FORMS, INSTRUCTIONS
AND DEFINITIONS
Copies in portable document format (PDF) and spreadsheet
format (XLS) are available on EIA's website. You may access
the materials at the following link:
http://www.eia.gov/survey/#eia-810
Files must be saved to your personal computer. Data cannot be
entered interactively on the website.

WHO MUST SUBMIT

GENERAL INSTRUCTIONS

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.

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

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 report period must be received by
February 20).

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.

•

If there has been a change since the last report, enter an “X”
in the block provided.

•

Enter the name of the reporting company.

•

Enter the Doing Business As “DBA” name if appropriate.

Form EIA-810 Semi Annual Storage Capacity Supplement
must be received by the EIA by the 20th of April for the March
report period and by the 20th of October for the September
report period.

HOW TO SUBMIT

PART 1. RESPONDENT IDENTIFICATION DATA

•

Enter the refinery site name.

Instructions on how to report are printed on PART 2 of Form
EIA-810.

•

We recommend secure file transmission (HTTPS) for companies
to use when sending this form to EIA. Secure transmission is an
industry standard method to send information over the internet
using encrypted processes. Access the EIA secure transmission
site at: https://signon.eia.doe.gov/upload/noticeoog.jsp.

Enter the Terminal Control Number (TCN) used for
identification of terminals and other facilities in the IRS
ExSTARS system.

•

Enter the physical address of the reporting company.

•

Enter the mailing address of the Contact. (Note: If the
physical address and mailing address are the same,
provide the information only for the physical address.)

•

Enter the name, telephone number, facsimile 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.

Other methods of sending this form to EIA include the PC
Electronic Data Reporting Option (PEDRO), mail, and facsimile.
PEDRO is a Windows-based application that enables you to enter
data interactively, import data from your own database, validate
your data online, and transmit the encrypted data electronically to
EIA via the Internet. If you are interested in receiving this free
software, contact the Electronic Data Collection Support Staff at
(202) 586-9659.
Email may be used for sending PDF forms, but EIA cannot
accept Excel files sent by email. Should you choose to submit
your PDF data by email, we must advise you that e-mail is an
insecure means of transmission because the data are not
Page 1

PART 2. SUBMISSION/RESUBMISSION INFORMATION
Submission
Refer to “How to Submit” section for more details or methods

EIA-810, Monthly Refinery Report

Unfinished Oils –

for submitting data.
Resubmission
A resubmission is required whenever an error greater than
5 percent of the true 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.
Identify only those data cells and lines which are affected by
the changes. You are not required to file a complete form
when you resubmit, but be sure to complete the EIA ID
number, the report period for which you are resubmitting and
contact information.

•

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

Comments
Report any unusual aspects of your operations during the
current reporting period in the Comments section at the
bottom of the form below Part 4 on the cover page. Comments
will be used in the validation process and should address any
data anomalies that could raise questions requiring contact by
survey staff for clarification. Comments will be protected in the
same manner as other information reported on this form as
described in detail in “Provisions Regarding Confidentiality of
Information” following Part 6 of these instructions on Page 7.

Fresh Feed Input to Downstream Processing Units (Codes
490, 491, 492, and 493) –
•

Report the fresh feed liquid (adjusted for standard
temperature and pressure) input to catalytic reforming units,
catalytic cracking units, catalytic hydrocracking units, and
fluid and delayed coking units.

•

Exclude recycled feeds, steam, and hydrogen gas. For
Code 493, include fresh feed input to flexicoking units.

SPECIFIC INSTRUCTIONS
PART 3. REFINERY INPUT AND CAPACITY
Refinery Input

Operable Capacity of Atmospheric Crude Oil Distillation
Units on the First Day of the Month

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. Exclude
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 490, 491, 492, and 493.

Report in barrels per calendar day (see definition below) 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 was in operation on the first day
of the month.

•

Idle Capacity (Code 400) - Report the component of Total
Operable Capacity that was 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, was 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).

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 natural gas plant liquids blended or charged to
units other than the atmospheric crude oil distillation
units from Code 990.

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

EIA-810, Monthly Refinery Report

Page 2

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 grade of products expected to 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

•

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 the sulfur content and the API gravity of Crude Oil
(Code 050) either as refinery receipts or inputs, but not both.
Weighted Average Sulfur Content is the percentage of sulfur in
domestic and foreign crude oil. Report to the nearest one
hundredth of one percent (two decimal places).
Weighted Average API Gravity is gravity at 60 degrees
Fahrenheit (oF) of domestic and foreign crude oil. Report to the
nearest hundredth of a degree (two decimal places).
The following example illustrates how to calculate and report
weighted average API gravity:
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).

Report for each product, beginning and end-of-month stocks,
receipts, inputs, production, shipments, and refinery fuel use
and losses during the month, except where shaded.
Report only positive (i.e. greater than or equal to zero)
quantities.
Most reporting categories must balance across:
Beginning Stocks + Receipts - Inputs + Production Shipments - Fuel Use/Losses must equal Ending
Stocks.
Stocks (Beginning and End of Month)
Report beginning stocks as of midnight of the last day of the
month prior to the current report month. Report ending stocks
as of midnight of the last day of the current report month. All
stocks should be corrected to 60oF less basic sediment and
water (BS&W).
Report all stocks in the custody of the refinery regardless of
ownership. Reported stock quantities should represent actual
measured inventories.
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.
For purposes of this report, “after entry through Customs” is
said to occur on:
•

the “entry date” specified in block 7 on the U.S. Customs
and Border Protection CBP Form 7501, “Entry Summary;”
(The entry date for a warehouse withdrawal is the date of
withdrawal). or

•

the “import date” specified in block 5 on the U.S. Customs
and Border Protection CBP Form 214A (Statistical Copy),
“Application for Foreign Trade Zone Admission and/or
Status Designation;” or

•

the “export date” specified in block 4 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.

Convert API Gravity to specific gravity:
•

141.5/(131.5+27.5) = 0.89

•

141.5/(131.5+33.5) = 0.86

Calculate a weighted average of the specific gravity:
•
•

100,000 barrels x .89 =
89,000
200,000 barrels x .86 =
172,000
300,000 barrels
261,000
261,000 divided by 300,000 = .87

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

Convert specific gravity back to API gravity:
•

141.5/.87 – 131.5 = 31.14

•

The weighted average API gravity would be reported as
31.14.

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.
Page 3

Report 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).
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;
Heavy Gas Oils (Code 840), 651oF to 1,000oF; and Residuum
(Code 850), greater than 1,000oF.
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

EIA-810, Monthly Refinery Report

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.
Oxygenates (excluding Fuel Ethanol), TOTAL (Code 446) is
the sum of oxygenates received from sources outside the
refinery (Merchant Plants), and oxygenates produced at the
refinery (Captive Plants).
Report receipts of Natural Gas Plant Liquids and Liquefied
Refinery Gases (including olefins and derivatives) under Codes
108, 246, 244, 245 and 220. Include both fuel use and
petrochemical feedstock use.
Exclude 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
plant 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.
Note: Gross inputs (Code 990 from Part 3) are typically greater
than crude oil inputs since gross inputs include materials other
than crude oil as well as any re-runs of the same barrels through
the atmospheric crude oil distillation unit.
Exclude from input of Crude Oil (Code 050) any oils that have
undergone prior refinery processing. 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
6).
Exclude inputs of product used to manufacture finished
petrochemicals. 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 6.
Report Biodiesel B21-B100 (Code 203) as inputs during the
month. Also report stocks at the end of the month.
Production During Month
Report gross refinery production during the month for each item
identified on the survey except where shaded.
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.
Report production of renewable fuels (fuel ethanol, biomassbased diesel fuel, other renewable diesel fuel, and other
renewable fuels) when the volume of these fuels is increased

by blending of petroleum barrels. For example, if a cargo of
undenatured fuel ethanol was delivered to your refinery and
then denatured at the refinery with RBOB for blending with fuel
ethanol (Code 141), then your report on Form EIA-810 will show
production of fuel ethanol equal to the volume of RBOB blended
with the fuel ethanol as denaturant.
Exclude from production any renewable fuels coprocessed with
petroleum feedstocks. Production of renewable fuels from
coprocessing with petroleum should be reported as receipts and
inputs. For example, renewable diesel fuel production from animal
fat processed through a diesel hydrotreater should be reported as
receipts and inputs of other renewable diesel fuel (Code 205). The
volume of the receipt and input of other renewable diesel fuel will
equal the volume of output from the hydrotreater that is attributed to
animal fat.
Report the production of olefins (Codes 631, 632, 633, and
634) to include 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
blending or compounding into finished aviation or motor
gasoline should be reported as production of aviation or motor
gasoline blending components.
Report aromatics used as petrochemical feedstocks as
production of Naphtha less than 401oF (Code 822).
Report Miscellaneous Products for Non-fuel use production
using Code 097. These products include white spirits (distillate
intermediaries in the naphtha/kerosene range) blended into
paint, insecticides, and other similar products. Elemental
Sulfur is also reported as Code 097. To convert short tons of
sulfur to barrels, multiply the number of short tons of sulfur by
3.17.
Shipments During Month
Report all shipments, including intracompany shipments to
other refineries, storage facilities, chemical plants or
fractionating facilities. Input to onsite petrochemical plants
should be reported as shipments from the refinery.
Refinery Fuel Use and Losses During Month
Report crude oil and petroleum products used as fuel at the
refinery. Include all nonprocessing losses (e.g., spills, fire
losses, contamination, etc.) by product.
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.
Inputs (Gain) or Production (Loss)
Report the net processing gain or loss that occurred during the
refining process. These differences are due to the processing
of crude oil and other inputs into products which in total have
more volume or less volume than the inputs processed.
Therefore, the total production of products is greater or less
than input.
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 “Fuel Uses and Losses During Month”
column.

EIA-810, Monthly Refinery Report

Page 4

•

A refinery processing gain represents the volumetric amount
by which total refinery production is greater than input for
the report period.
Report a processing gain in the “Input” column (Code 911).

•

A refinery processing loss represents the volumetric amount
by which total refinery production is less than input for the
report period.
Report a processing loss in the “Production” column (Code
911).
Note: These entries are always positive numbers and are
used to balance the total input and total production columns
for Code 999.

isobutane/isobutylene for liquefied refinery gases).
Report Liquefied Petroleum Gases (LPG) extracted from natural
gas liquids streams originating at natural gas processing plants
(NGPL’s), and received by the refinery for processing into
finished products by component under Codes 247, 249, and
220. Also report them under Codes 244 and 245.
Report 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)
under Codes 641, 631, 642, 632, 643, 633, 644, and 634). The
volume of LRG for any class (e.g. Ethane) has to be equal or
greater than any breakout volume (e.g. Ethylene). Also report
them under Codes 108, 246, 244 and 245.

Hydrogen
Report receipts, inputs, and fuel use and loss of hydrogen using
Code 091. Quantities reported by refiners include hydrogen
produced from hydrogen plants located at refineries and hydrogen
purchased from third-party suppliers.
Exclude hydrogen produced from catalytic reformers from
quantities reported for Code 091 to avoid double counting inputs.
Hydrogen input from refinery reformer units is counted indirectly
as input of crude oil and unfinished oils.
Exclude feedstock inputs for hydrogen production on Form EIA810. Report natural gas feedstock inputs for hydrogen
production on Form EIA-820 “Annual Refinery Report.”
Convert standard cubic feet of hydrogen to barrels by using the
conversion factor 19,426 standard cubic feet per barrel of fuel oil
equivalent. (Simply divide the number of standard cubic feet of
hydrogen by 19,426 to convert to barrels.)
Report Still gas (Code 045), Special Naphtha (Code 051), and
Unfinished oils, naphtha, and lighter (Code 820) as shipments to
a hydrogen plant when these products are used as hydrogen
feedstock. Report any feedstock return streams from a
hydrogen plant as receipts from the hydrogen plant and inputs at
the refinery. Report receipts of return streams using the same
product codes as were used when reporting feedstock shipments
to the hydrogen plant.

Report production of polymer grade or chemical grade
propylene as propylene (code 632). Production volumes reported
as propylene will include propylene and up to 8% propane. This
is based on a definition of chemical grade propylene made up of
at least 92% propylene and up to 8% propane.
Report production of mixed propane and propylene streams that
do not meet the specification for polymer grade or chemical
grade propylene (including refinery grade propylene) separately
as propane (code 642) and propylene (code 632), as determined
by chemical analysis, except in cases when you are reasonably
certain the mixed propane and propylene stream will be sold as
fuel, in which case report the entire mixed stream as propane
(code 642).
Report inputs of liquefied petroleum gases as products of
natural gas processing plants (Codes 249 and 247) when their
origin is unknown.
Finished Motor Gasoline
Report finished motor gasoline blended with fuel ethanol that
contains 55% denatured fuel ethanol or less by volume as
Ed55 and Lower (code 166).
Report finished motor gasoline blended with fuel ethanol that
contains greater than 55% denatured fuel ethanol by volume as
Greater than Ed55 (code 149). All or most of the gasoline
reported in this product category will be E85.

Oxygenates
Report oxygenates on an individual basis in product Codes 142
and 144. All other oxygenates (Code 445) includes other
aliphatic alcohols and ethers (e.g., TAME, TBA) intended for
motor gasoline blending.
Report stocks held at oxygenate production facilities, located
within or adjacent to the refinery complex (captive plants).
Report gross inputs of oxygenates. Do not “net out” oxygenate
inputs by reporting the difference between oxygenate inputs and
production.
Exclude oxygenates as motor gasoline blending components
unless they have been commingled with motor gasoline blending
components.
Liquefied Gases
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
Page 5

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 RBOB
(Code 118), CBOB (Code 139), GTAB (Code 117) and “all other”
motor gasoline blending components (Code 138).
Report naphtha-range hydrocarbons intended for blending or
compounding into finished aviation gasoline in product Code
112.
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: “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

EIA-810, Monthly Refinery Report

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. All GTAB is to be reported as
Conventional (Code 117).
Exclude the following products from motor gasoline blending
components.
• normal butane (Codes 244, 249 and 643),
• butylene (Code 633),
• isobutane (Codes 245, 247 and 644),
• isobutylene (Code 634),
• pentanes plus (Code 220),
• fuel ethanol (Code 141), and
• MTBE (Code 144).
While these products may be blended into finished motor
gasoline, they are reported under separate product codes. 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.
Note: 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 naphtha-range petrochemical feedstocks (Code
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.
Distillate Fuel Oil by Percent of Sulfur Content
Report refinery input and production during the month and endof-month stocks of distillate fuel oil by sulfur content. Product
Codes 465, 466, and 467 must sum to the total for Distillate
Fuel Oil (Code 411).
Residual Fuel Oil by Percent of Sulfur Content
Report refinery input and production during the month and endof-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).
Lubricants
Report only lubricant base oils produced at the refinery. Exclude
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).

Petrochemical Feedstocks
•

Report petrochemical feedstock. Exclude finished
petrochemicals.

•

Report deliveries of feedstock to petrochemical units within
your refinery, chemical or rubber manufacturing plants 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.

•

Exclude 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 108, 641, 631, 246, 642, 632,
244, 249, 643, 633, 245, 247, 644, 634, and 220).

Petroleum Coke
Report marketable petroleum coke in barrels. There are 5
barrels per short ton.
Report catalyst coke in fuel oil equivalent barrels. The
conversion factor is 6.287 million BTU’s per fuel oil equivalent
barrel (higher heating value).
Still Gas
Report still gas shipped to petrochemical facilities 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.
Note: report still gas in thousand fuel oil equivalent barrels.
The conversion factor is 6.287 million BTU’s per fuel oil
equivalent barrel (higher heating value).
Synthetic Hydrocarbons
Report synthetic hydrocarbons (e.g. shale oil and oil from tar
sands) as crude oil (Code 050).
Transmix
Transmix is created when two different petroleum products (e.g.
motor gasoline and distillate fuel oil) become commingled during
pipeline transport. Exclude transmix from all quantities reported
on Form EIA-810.
Reclassification of Inventory
Report a finished product that is reclassified as a different
finished product or as an unfinished oil as follows: 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, then
report “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

EIA-810, Monthly Refinery Report

Page 6

TOTAL SHELL CAPACITY

Report storage capacity 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 storage capacity twice each year with submissions for
March 31 and September 30. It is unnecessary to report
storage capacity for months other than March and September.

CRUDE OIL
OR LIQUID
PRODUCT

GROUND
LEVEL
BRINE STRING

PART 6. SEMI ANNUAL STORAGE CAPACITY
SUPPLEMENT

WORKING STORAGE
CAPACITY

Figure 2. Schematic of Cavern Storage Capacity and Stocks

NET AVAILABLE SHELL CAPACITY

barrels as “Input” of Kerosene (Code 311) and “Production“
of Kerosene-Type Jet Fuel (Code 213).

CRITICAL
CAVERN
DEPTH

CONTINGENCY
SPACE

BRINE

UNAVAILABLE
SPACE (BRINE
SUMP)

Report underground and above ground storage capacity
operated by your company.
Exclude leased storage capacity located at facilities operated by
other companies. This storage capacity will be reported by the
companies operating those facilities.
Exclude storage capacity in trucks, rail cars, barges, and
tankers.
Report working storage capacity and net available shell storage
capacity as described in figure 1 for tanks or figure 2 for caverns.
Figures 1 and 2 are based in part on schematics developed by
the National Petroleum Council and U.S. Strategic Petroleum
Reserve.

Terms used in Figures 1 and 2 are defined as follows.
•

Contingency Space (Tank): Available space that is above
the maximum operating inventory level. This storage space
remains empty during normal operations, but it is available if
needed. It allows flexibility to exceed working storage
capacity without reaching an inventory level that might
create safety hazards or disrupt operations. Storage space
above the top of this level is unavailable.

•

Contingency Space (Cavern): Available space that is
below the critical cavern depth but still above unavailable
space. This storage space remains filled with brine during
normal operations, but it is available if needed. It allows
flexibility to exceed working storage capacity without
reaching an inventory level that might create hazards or
disrupt operations.

•

Net Available Shell Storage Capacity (Tank): Total
available space including tank bottoms, working storage
capacity, and contingency space.

•

Net Available Shell Storage Capacity (Cavern): Total
available space including working storage capacity, and
contingency space.

•

Tank Bottoms: Inventory that is below the normal suction
line of a storage tank. In floating roof tanks, this is at least
the volume required to remain in a storage tank in order to
keep the roof from touching the bottom of a storage tank.

•

Total Shell Capacity: Total storage space including
unavailable space and net available shell storage capacity.

•

Unavailable Space (Tank): Storage space that is required
as part of the design of a tank but cannot be used. Includes
tank tops, safety allowance, and any other space that is
included by design but cannot be used.

•

Unavailable Space (Cavern): Storage space that is
required as part of the design of an underground storage
facility but cannot be used. Includes the brine sump and
any other space that is included by design but cannot be
used.

•

Working Storage Capacity (Tank): Available capacity for
storing crude oil or liquid products that is above tank

Figure 1. Schematic of Tank Storage Capacity and Stocks

TANK BOTTOMS

Page 7

INVENTORY
LEVEL

TOTAL SHELL CAPACITY

WORKING
STORAGE
CAPACITY

MAXIMUM OPERATING
INVENTORY

CONTINGENCY
SPACE

NET AVAILABLE SHELL CAPACITY

UNAVAILABLE
SPACE

EIA-810, Monthly Refinery Report

bottoms and below contingency space. When filled to this
capacity, inventory of crude oil or liquid products stands at
the maximum operating inventory level.
•

Working Storage Capacity (Cavern): Available capacity
for storing crude oil or liquid products that is above
contingency space.

Storage Capacity in Operation
Storage capacity in operation includes capacity of tanks and
caverns that were available and able to be used to hold stocks
on the report date. Tanks and caverns in operation may hold
stocks, they may hold only tank bottoms, or they may be empty,
but they must have been able to be placed in operation on the
report date.
Report working storage capacity of tanks and caverns that were
in operation on the report date.
Report net available shell storage capacity of tanks and caverns
that were in operation on the report date.
Net available shell storage capacity of tanks in operation must
always be greater than or equal to working storage capacity of
tanks and caverns in operation.
Idle Storage Capacity
Idle storage capacity includes capacity of tanks and caverns that
were not usable for holding stocks on the report date but could
be placed in operation within 90 days of the report date after
maintenance or repair. When assessing whether or not a tank
can be placed in service within 90 days, it is acceptable to use a
current planned or scheduled return to service date. It is
unnecessary to try to account for possible contingencies (e.g.
maintenance delays caused by weather) unless these were
incorporated into the planned or scheduled in operation date.
Report net available shell storage capacity of idle tanks and
caverns.
Exclude storage capacity of idle tanks and caverns when
reporting working storage capacity.
Exclude storage capacity of idle tanks and caverns that were
idle at the end of the report month and could not be placed in
operation within 90 days.
Exclude storage capacity of idle tanks and caverns where there
is no scheduled date when the capacity will be placed in service.
Exclude storage capacity of tanks and caverns under
construction even when construction is scheduled for completion
within 90 days. Storage capacity of tanks and caverns under
construction is reported as capacity in operation only after new
tanks and caverns are placed in service.

New Storage Capacity

tankers are reported as stocks in Part 5 but the storage capacity
is excluded from Part 6.

PROVISIONS REGARDING
CONFIDENTIALITY OF INFORMATION
Information on operable atmospheric crude oil distillation
capacity reported on Form EIA-810 is not considered confidential
and may be publicly released in identifiable form. All other
information reported on Form EIA-810 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 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 nonstatistical purposes such as administrative,
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,”
are used to report aggregate statistics on and conduct analyses
of the operation of U.S. petroleum refineries.

SANCTIONS
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.

Report new storage capacity beginning with the first storage
capacity report period after the new capacity was placed in
operation.
Exclude new capacity while it is under construction even when
the scheduled completion date was within 90 days of a storage
capacity report date.
Comparison of Stocks and Storage Capacity
In most cases, stocks reported in Part 5 of Form EIA-810 will be
less than total shell storage capacity. There may be exceptions
in cases where barrels stored in trucks, rail cars, barges, or
EIA-810, Monthly Refinery Report

Page 8

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 5.2 hours 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, Office of
Survey Development and Statistical Integration, EI-21, 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.

Page 9

EIA-810, Monthly Refinery Report