EIA810ic2023_Instructions

U. S. DEPARTMENT OF ENERGY
ENERGY INFORMATION ADMINISTRATION
Washington, DC 20585

OMB No. XXXX-XXXX
Expiration Date: mm/dd/yyyy
Burden 4.68 hours

EIA-810
MONTHLY REFINERY REPORT
INSTRUCTIONS
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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 www.eia.gov and in numerous government publications.

WHO MUST SUBMIT

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Form EIA-810 is mandatory under 15 U.S.C. §772(b) and must be completed by the operators of all operating and idle petroleum
refineries and non-refinery operators of distillation, reforming, cracking, coking, hydrotreating and similar processes located in the 50
States, District of Columbia, Puerto Rico, the Virgin Islands, Guam, and other U.S. possessions.

WHEN TO SUBMIT

Form EIA-810 must be received by 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).
Form EIA-810, Annual Storage Capacity Supplement, must be received by EIA by the 20th of April for the March report period.

HOW TO SUBMIT

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

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Secure file transmission (HTTPS) must be used 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

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COPIES OF SURVEY FORMS, INSTRUCTIONS, AND DEFINITIONS
Copies in spreadsheet format (XLS) are available on EIA's website. You may access the materials at the following link:
https://www.eia.gov/survey/#eia-810

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

GENERAL INSTRUCTIONS
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.
Quantities: Report using the following criteria:
Report 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 the quantity for a product for which you usually report data
is zero, please enter “0". Shaded cells on the form are those in which data are not currently required to be reported.
Report quantities corrected to 60 degrees Fahrenheit (0F) less basic sediment and water (BS&W).

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PART 1. RESPONDENT IDENTIFICATION DATA
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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.

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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.

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

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Enter the name of the reporting company.

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

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Enter the refinery site name.

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

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Enter the physical address of the reporting company.

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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.)

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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.

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PART 2. SUBMISSION/RESUBMISSION INFORMATION
Submission

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 the true value is discovered by a respondent or if requested
by EIA. Enter "X" in the resubmission box if you are correcting information previously reported.
Comments

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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 page 1. 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 10.

SPECIFIC INSTRUCTIONS

PART 3. REFINERY INPUT AND CAPACITY
Refinery Input

Gross Input to Atmospheric Crude Oil Distillation Units (Product 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 Product codes 490, 491, 492, and 493.
The following components of refinery input to atmospheric crude oil distillation units should be included in Product code 990:
Crude Oil –
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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.

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Exclude crude oil charged to units other than the atmospheric crude oil distillation units (e.g., coking unit) from Product code
990.

Products of Natural Gas Processing Plants –
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Report all quantities of natural gas liquids (i.e., ethane, propane, normal butane, isobutane, and natural gasoline) charged to
the atmospheric crude oil distillation units. Include inputs of unfractionated streams and mixtures of natural gas liquids.
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Exclude natural gas liquids blended or charged to units other than the atmospheric crude oil distillation units from Product
code 990.

Unfinished Oils –
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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).

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Exclude unfinished oils charged to units other than the atmospheric crude oil distillation units (e.g., cracking units) from
Product code 990.

All Other Oils –
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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.

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Exclude oils charged to units other than the atmospheric crude oil distillation units (e.g., cracking units) from Product code
990.

Fresh Feed Input to Downstream Processing Units (Product codes 490, 491, 492, and 493) –
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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.

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

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

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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 (Product code 399) - Report the component of Total Operable Capacity that was in operation on the first day of
the month.

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Idle Capacity (Product 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.

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Total Operable Capacity (Product 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 (Product code 399 and Product code 400).

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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;
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The types and grades of inputs to be processed;

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The types and grade of products expected to manufactured;

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The environmental constraints associated with refinery operations;

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

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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 (Product 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:
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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).
Convert API Gravity to specific gravity:
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141.5/(131.5+27.5) = 0.89

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141.5/(131.5+33.5) = 0.86

Calculate a weighted average of the specific gravity:
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89,000
100,000 barrels x .89 =
200,000 barrels x .86 =
172,000
300,000 barrels
261,000
261,000 divided by 300,000 = .87

Convert specific gravity back to API gravity:
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141.5/.87 – 131.5 = 31.14

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The weighted average API gravity would be reported as 31.14.

PART 5. REFINERY OPERATIONS
Quantities: Report using the following criteria:

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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.
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)

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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.

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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 EIA812, 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:
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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);

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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

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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.

Report stocks in underground storage associated with the refinery when reporting natural gas liquids and refinery olefins.
Report end-of-month stocks of unfinished oils by degree Fahrenheit end-point. The following are the degree end-point categories:
Naphthas and Lighter (Product code 820), less than 401oF; Kerosene and Light Gas Oils (Product code 830), 401oF to 650oF;
Heavy Gas Oils (Product code 840), 651oF to 1,000oF; and Residuum (Product code 850), greater than 1,000oF.
Receipts During Month
Report all receipts at the refinery and in transit thereto by tanker, barge, rail, or truck, using the same criteria as those used for
reporting stocks. Receipts of Crude Oil, Domestic (Product code 010) include Alaskan Crude Oil (Product code 011).
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Crude Oil, Total (Product code 050) is the sum of Domestic (Product code 010) and Foreign (Product code 020) Crude Oil.
Report receipts of Natural Gas Liquids and Refinery Olefins under Product 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 liquids and refinery olefins, other hydrocarbons, and hydrogen input to
refinery processing units for the purpose of producing finished petroleum products. Report inputs of ethanol for blending into motor
gasoline.
Report gross refinery input for each item identified on the survey form except where shaded.
Note: Gross inputs (Product 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 (Product 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).

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Exclude inputs of product used to manufacture finished petrochemicals. Exclude input of natural gas to produce hydrogen. Exclude
input of feedstock to manufacture oxygenates. Inputs of finished petroleum products are explained under “Reclassification of
Inventory” on page 6.
Report Biodiesel B50-B100 (Product code 203) blending 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, natural gas liquids, other
hydrocarbons, and hydrogen.

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Report the volume of petroleum products produced from blending operations of motor gasoline and aviation gasoline blending
components, ethanol and other biofuels.

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Report production of biofuels (fuel ethanol, biodiesel fuel, renewable diesel fuel, and other renewable fuels and intermediate
products) 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, then your report
on Form EIA-810 will show production of fuel ethanol (Product code 141) equal to the volume of RBOB blended with the fuel ethanol as
denaturant.
Exclude from production any biofuels coprocessed with petroleum feedstocks. Production of biofuels 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 renewable diesel fuel (Product code 205). The volume of the receipt and input of
renewable diesel fuel will equal the volume of output from the hydrotreater that is attributed to animal fat.
Report the production of olefins (Product codes 631, 632, 633, and 634) to include only that portion of hydrocarbon gas liquids 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 (Product code 822).
Report Miscellaneous Products for Non-fuel use production using Product 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 Product 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.
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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.
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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 (Product code 911).

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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 (Product code 911).

Hydrogen

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Note: These entries are always positive numbers and are used to balance the total input and total production columns for
Product code 999.

Report receipts, inputs, and fuel use and loss of hydrogen using Product 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 Product 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 EIA-810. Report natural gas feedstock inputs for hydrogen production on
Form EIA-820, Annual Refinery Report.

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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.)

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Report Still gas (Product code 045), Special Naphtha (Product code 051), and Unfinished oils, naphtha and lighter (Product 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
product codes as were used when reporting feedstock shipments to the hydrogen plant.
Natural Gas Liquids and Refinery Olefins

Report all mixes of natural gas liquids (including unfractionated streams) and refinery olefins by individual components as
determined by chemical analysis, (e.g., ethane, propane, normal butane, isobutane, natural gasoline for gas plant liquids, and
ethylene, propylene, normal butylene, and isobutylene for refinery olefins).
Report natural gas liquids (NGL) extracted from natural gas liquids streams originating at natural gas processing plants, and received by
the refinery for processing into finished products by component under Product codes 247, 249, and 220. Also report them under
Product codes 244 and 245.
Report natural gas liquids and refinery olefins that are fractionated from crude oil or produced from downstream processes, such as
catalytic cracking, and result in finished NGL production that are subsequently stored or shipped as a NGL under Product codes 641,
631, 642, 632, 643, 633, 644, and 634). The volume of NGL and refinery olefins for any class (e.g., Ethane/Ethylene) has to be equal
or greater than any breakout volume (e.g., Ethylene). Also report them under Product codes 108, 246, 244 and 245.
Report production of polymer grade or chemical grade propylene as propylene (Product 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 (Product code 642) and propylene (Product 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 (Product code 642).
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Report inputs of natural gas liquids as products of natural gas processing plants (Product 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 Conventional,
Blended with Fuel Ethanol Ed55 and Lower (product code 166).
Report finished motor gasoline blended with fuel ethanol that contains greater than 55% denatured fuel ethanol by volume as
Conventional, Blended with Fuel Ethanol Greater than Ed55 (product code 149). All or most of the gasoline reported in this product
category will be E85.
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 (Product code 118), CBOB (Product code 139), GTAB (Product code 117) and “all other” motor
gasoline blending components (Product 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).

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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 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 (Product
code 117).

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Exclude the following products from motor gasoline blending components.
• normal butane (Product codes 244, 249 and 643),
• butylene (Product code 633),
• isobutane (Product codes 245, 247 and 644),
• isobutylene (Product code 634),
• natural gasoline (Product code 220),
• fuel ethanol (Product code 141)

While these products may be blended into finished motor gasoline, they are reported under separate product product codes. This
applies only to unblended products. After blending, butanes, natural gasoline, fuel ethanol, and other materials become part of the
volume of gasoline blending components or finished motor gasoline.

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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 (Product 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 end-of-month stocks of distillate fuel oil by sulfur content. Product codes
465, 466, and 467 must sum to the total for Distillate Fuel Oil (Product code 411).
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 (Product 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.
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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
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Report petrochemical feedstock. Exclude finished petrochemicals.

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

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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.

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Exclude natural gas liquids or refinery olefins as petrochemical feedstock. These products are reported by component as ethane,
ethylene, propane, propylene, normal butane, butylene, isobutane, isobutylene, and natural gasoline (Product 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).

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Still Gas

Report still gas shipped to petrochemical facilities as a shipment in Product 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

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Report still gas by individual natural gas liquids and refinery olefins product components (ethane, propane, normal butane,
isobutane, natural gasoline, ethylene, propylene, normal butylene, isobutylene) based on chemical analysis when still gas is
fractionated into products whether fractionation happens at the refinery or at a facility downstream of the refinery and the
composition of the still gas stream is known or can be estimated from prior fractionation reports. Report still gas products other than
natural gas liquids and refinery olefins (e.g. methane), and unfractionated natural gas liquids and refinery olefins products on the still
gas line (product code 045).

Transmix

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Report synthetic hydrocarbons (e.g., shale oil and oil from tar sands) as crude oil (Product code 050).

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, this quantity
then report “Production” and “Stocks” of Kerosene (Product 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
“Input” of Kerosene (Product code 311) and “Production“ of Kerosene-Type Jet Fuel (Product code 213).
PART 6. ANNUAL STORAGE CAPACITY SUPPLEMENT
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 once each year with the submission for March. It is unnecessary to report storage capacity for months
other than March.
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
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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.

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Figure 1. Schematic of Tank Storage Capacity and Stocks

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Figure 2. Schematic of Cavern Storage Capacity and Stocks

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.

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•

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 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

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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.
Storage Capacity Temporarily Out of Service

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Storage capacity temporarily out of service 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 tanks and caverns temporarily out of service.
Exclude storage capacity and caverns temporarily out of service when reporting working storage capacity.

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Exclude storage capacity of tanks and caverns that were temporarily out of service at the end of the report month and could not be
placed in operation within 90 days.
Exclude storage capacity of tanks and caverns temporarily out of service 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
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 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(b), the DOE
regulations, 10 C.F.R. §1004.11, implementing the FOIA, and the Trade Secrets Act, 18 U.S.C. §1905.
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The Federal Energy Administration Act requires EIA to provide company-specific data to other Federal agencies when requested for
official use. The information reported on this form may also be made available, upon request, to another component of the Department
of Energy (DOE); to any Committee of Congress, the Government Accountability Office, or other Federal agencies authorized by law to
receive such information. A court of competent jurisdiction may obtain this information in response to an order. The information may be
used for any nonstatistical purposes such as administrative, regulatory, law enforcement, or adjudicatory purposes.
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 15 U.S.C. §772(b), as amended. Failure to
respond may result in a civil penalty of not more than $10,633 each day for each violation. The government may bring a civil action
to prohibit reporting violations which may result in a temporary restraining order or a preliminary or permanent injunction without
bond. In such civil action, the court may also issue mandatory injunctions commanding any person to comply with these reporting
requirements.

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FILING FORMS WITH THE FEDERAL GOVERNMENT AND ESTIMATED REPORTING BURDEN

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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 hours and 12 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, Office of Statistical Methods and
Research, EI-21, 1000 Independence Avenue, S.W., Washington, DC 20585; and to the Office of Information and Regulatory Affairs,
Office of Management and Budget, Washington, DC 20503.

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