Annual Survey of Domestic Oil and Gas Reserves Summary Report

U.S. DEPARTMENT OF ENERGY
Energy Information Administration
Office of Oil and Gas
Washington, DC 20585

OMB Number: 1905-0057
Expiration Date: x/xx/xxxx
Product No.: 2019.01
Burden: 8 hours

ANNUAL REPORT OF DOMESTIC OIL AND GAS RESERVES
FORM EIA-23S
Summary Level Report Instructions

SURVEY YEAR 2019
Table of Contents
Page

General Instructions .........................................................................................
A.
B.
C.
D.
E.
F.
G.

2

Purpose ..................................................................................................................
Who Must Submit Form EIA-23S ...........................................................................
When and Where to Submit ...................................................................................
Record Keeping Requirements ..............................................................................
Sanctions................................................................................................................
Disclosure of Information .......................................................................................
Reporting Standards ..............................................................................................
1. Proved Reserves .............................................................................................
2. Survey Year Production ...................................................................................
3. Total Operated Basis .......................................................................................
4. States and Geographic Subdivisions ...............................................................
5. Reporting Units ................................................................................................
6. EIA Secure File Transfer Information……………………….. ............................

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2
2
2
2
2
3
3
3
3
3
3
4

Specific Instructions .........................................................................................

5

H. Cover Page - Operator Identification .....................................................................
I. Summary Report ....................................................................................................
J. Definitions...............................................................................................................

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5
6

For Information, Assistance, or Additional Forms
Contact the EIA-23 Coordinator 800-879-1470
8:00 a.m. – 4:30 p. m. Central Time

2019 EIA-23S Annual Report of Domestic Oil and Gas Reserves, Summary Level

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GENERAL INSTRUCTIONS
A. PURPOSE

C. WHEN AND WHERE TO SUBMIT

The Energy Information Administration (EIA) of the
Department of Energy (DOE) seeks, with Form EIA-23S, to
gather and summarize credible and timely data regarding
proved reserves and production of crude oil, natural gas, lease
condensate, and other related matters. The Government will
use the resulting information to develop national and regional
estimates of proved reserves of domestic crude oil, natural
gas, and natural gas liquids and to facilitate national energy
policy decisions.

The completed 2019 survey forms must be submitted on
or before June 15, 2020. Filing electronically, using Secure
File Transfer or Fax, is encouraged.
Secure File Transfer: See page 4 for information
Fax completed forms to: 202 586-1076
Mail completed paper forms to:
Oil and Gas Surveys
U. S. Department of Energy, EIA
Ben Franklin Station
PO Box 279
Washington DC 20044-0279

B. WHO MUST SUBMIT FORM EIA-23S
Each operator (Section J Definitions, page 6) of domestic oil
and/or gas wells as of December 31, 2019 that has
been selected must file either a Form EIA-23S or a Form
EIA-23L.

When entering responses on hard copies, type or print in black
ink using all capital letters. EIA-23S forms and instructions are
available on the EIA website.

Filing requirements are based on operator category or
size, which is determined by the total or gross (8/8ths)
annual operated production rate. Production refers to
the total calendar year production from all domestic oil and/
or gas wells operated on December 31, 2019, including
wells abandoned during the year.

For information concerning requests for extension of time to
file or for exception from filing Form EIA-23S, contact the EIA23 Coordinator 800-879-1470 from 8:00 a.m. to 4:30 p.m.
Central Time.

If you have received the EIA-23S Summary Level
Report form, but your total gross operated production
exceeds 400 thousand barrels (400 MBbls) of crude oil
or 2 billion cubic feet (2,000 MMCF or 2 BCF) of natural
gas, or you operate wells in the federal offshore or
coalbed methane gas wells, contact the EIA-23
Coordinator 800-879-1470 to obtain
the
EIA-23L
County Level Report form and instructions.

D. RECORD KEEPING REQUIREMENTS
All records necessary to reconstruct the data on this form must
be retained and available for a period of three (3) years from
the filing due date.

E. SANCTIONS
The timely submission of Form EIA-23L by those required to
report is mandatory under Section 657 of Public Law 95-91
(42 USC 7267). Failure to respond may result in a civil penalty
of $10,366 a day for each violation. The government may
bring a civil action to prohibit reporting violations that 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.

Note that as defined, day-to-day physical operation of a
well or wells does not alone qualify a person as the
operator. Physical operation may occasionally be
divorced from operatorship, such as in the instance of
manipulation of swing wells by a gas pipeline company
representative or the manipulation and maintenance of
wells located on an offshore platform by the platform
manager. While the operator's own personnel usually
perform such duties, the key factor is that the operator is
the person who makes management decisions regarding the
well(s) in question on behalf of the owner(s).

F. DISCLOSURE OF INFORMATION

If you are not certain whether you are the operator,
contact the EIA-23 Coordinator 800-879-1470 for
assistance in making this determination. If you are not
the operator of oil and/or gas wells on December 31,
2019 (perhaps a former operator or solely a working or
royalty interest owner), you should complete and sign the
Cover Page only and return it to EIA along with a letter
stating when operations ceased and what became of the
wells you previously operated.

The annual production of crude oil, lease condensate, and
natural gas reported on Form EIA-23 are considered public
information. These data elements may be released in
company-identifiable form and will not be protected from
disclosure in identifiable form when releasing statistical
aggregate information. All other information reported on Form
EIA-23 will be protected and not disclosed to the public to the

2019 EIA-23S Annual Report of Domestic Oil and Gas Reserves, Summary Level

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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.

Examples:
Of the total 8/8ths interest, respondent's share is 50 percent
and the associated royalty share is 6.25 percent. Respondent
operates property. Respondent reports 100 percent of proved
reserves and production.

The Federal Energy Administration Act requires the EIA to
provide company-specific data to other Federal agencies
when requested for official use. The information reported on
this form may also be made available, upon request, to
another component of the Department of Energy (DOE); to
any Committee of Congress, the Government Accountability
Office, or other Federal agencies authorized by law to receive
such information. A court of competent jurisdiction may obtain
this information in response to an order. The information may
be used for any non-statistical purposes such as
administrative, regulatory, law enforcement, or adjudicatory
purposes.

Of the total 8/8ths interest, respondent's share is zero but it
operates the property (i.e., a contract operator). Respondent
reports 100 percent of proved reserves and production.

3. States and Geographic Subdivisions
To determination in which state or geographic subdivision to
report proved reserves and production data is based on the
location of the field(s) containing the oil and/or gas. If a field
overlaps two or more states or subdivisions, the proved
reserves data must be subdivided into the appropriate
geographic components.

Disclosure limitation procedures are applied to the protected
statistical data published from EIA-23 survey information to
ensure that the risk of disclosure of identifiable information is
very small.

For a State in which you operated but not listed on the form,
specify the two-letter postal code in the line labeled "Other
States". Enter the production and reserves in Columns A
through I.

Confidential information collected on Form EIA-23 will be
provided to United States Department of Interior offices (the
Bureau of Ocean Energy Management and the United States
Geological Survey) for statistical purposes only, in conducting
their resource estimation activities.

Offshore proved reserves data are required separately for the
State and Federal domains. If an offshore field lies on or
between disputed boundaries, include all data in the State
offshore area.

G. REPORTING STANDARDS
1. Proved Reserves

4. Reporting Units

EIA recognizes that the judgment of geologists and petroleum
engineers is required in the reserve estimation process, and
that as a result, proved reserves are estimates rather than
precise quantitative measurements.

Volumes must be reported in whole numbers and not contain
decimals. All volumes are to be reported in the appropriate
reporting units as shown below:
a. Crude Oil: All crude oil volumes are to be reported in
thousands of barrels (MBbls) (42 U.S. gallons per barrel
at atmospheric pressure corrected to 60° Fahrenheit) and
excluding basic sediment and water.

Proved reserves of oil and gas as of December 31, 2019
are the estimated quantities of oil and/or gas, which
geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from
known reservoirs under existing economic and operating
conditions. (See Proved Reserves, Crude Oil; Proved
Reserves, Natural Gas; and Proved Reserves, Lease
Condensate, Section I Definitions, page 9.)

b. Natural Gas: All natural gas volumes are to be reported
in millions of cubic feet (MMCF) at 14.73 psia and 60°
Fahrenheit, wet after lease separation.

2. Survey Year Production

It is recognized that the operator in many instances has no
knowledge of the ultimate reduction of the gas stream
produced from his properties, which may result from further
downstream processing. The operator is requested to report
volumes of natural gas, which remain after processing through
lease and field separation facilities. Lease use and flared
and vented gas are also considered production and
should be included in the volumes reported.
EIA obtains data from gas processing plants separately. Gas
volumes reported on Form EIA-23S must not be corrected for
liquids removed by these plants. If you do not know if a field
facility through which your gas is processed is currently
reporting data to EIA or not, contact the EIA-23 Coordinator to
obtain information on those plants which report.

Production data are required from all operators. If the actual
production data are not available at the time Form EIA-23S is
prepared, estimate production.
If any properties were acquired during the survey year,
production data from the acquired properties should be
reported from the date of purchase. If any properties were sold
during the survey year, production data should be reported
until the date of sale.

Total Operated Basis
All data on Schedule A (reserves and related data by field) are
to be reported on an 8/8ths or Total Operated Basis. When
reporting on this basis, production and reserves data for any
properties on which operations were acquired during the
survey year should be reported from the date of transfer or
purchase. If any properties were sold or transferred to a new
operator during the survey year, production and reserves data
should be reported until the date of sale or transfer.

2019 EIA-23S Annual Report of Domestic Oil and Gas Reserves, Summary Level

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5. EIA Secure File Transfer Information

c. Lease Condensate: All lease condensate volumes are
to be reported in thousands of barrels (MBbls) (42 U.S.
gallons per barrel, at atmospheric pressure corrected to 60°
Fahrenheit).

EIA is ensuring the security of your transactions by using the
latest Internet security technology. The technology being used
to protect your data is encryption which is the scrambling of
data into a code that is unreadable to anyone who does not
have the key that deciphers it. The secure hypertext transfer
protocol (https) is a communications protocol designed to
transfer this encrypted information between computers over
the World Wide Web. All information is protected by 128-bit
encryption to maintain the privacy and confidentiality of your
data. The only thing you need to take advantage of strong
encryption technology is a secure browser, one that supports
128-bit encryption.

d. Rounding: Round liquid volumes 500 barrels and above
up to ‘1’ MBbls, and less than 500 barrels down to ‘0’
MBbls. Round gas volumes 500 MCF and above up to ‘1’
MMCF, and less than 500 MCF down to ‘0’ MMCF.
e. Negative and Positive Volumes: All data are to be
entered as whole number integers without plus (+) or minus
(-) symbols.

To use the EIA https secure file transfer system:
1. Click to open the SFT webpage
or type in the URL in your browser:
https://signon.eia.doe.gov/upload/noticeoog.jsp
The EIA SFT Notice to Users page appears.
2. Read and then click the Accept button.
The Secure File Transfer System page appears.
At the bottom of this page, in blue text, click on
Instructions for Secure File Transfer.
If you have any trouble transferring your files, please call the
EIA User Services Center 202-586-8959 or email them at
[email protected].

2019 EIA-23S Annual Report of Domestic Oil and Gas Reserves, Summary Level

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SPECIFIC INSTRUCTIONS
H. COVER PAGE - Operator Identification

I. SUMMARY REPORT

You are required to enter those items that are incorrect or
missing from the preprinted form.

SECTION 1.0: Operator Detailed Data Report
Item 1.1: EIA Operator ID Code – This is the same as the
Cover Page EIA Operator ID Code.

Part I. Identification

Item 1.2: Operator Name - This is the same operator name
on the Cover Page. Enter the first 35 characters of the operator
name. If the name exceeds 35 characters, do not abbreviate,
but simply truncate the extra characters from the right.

EIA Operator ID Code: If this item is missing, contact the EIA23 coordinator.
Operator Name, Address, City, State, Zip Code. Enter the
legal name and address of the operator. If a foreign address,
enter city, local equivalent of State name (e.g., province), and
country.

Item 1.3: Original - Enter an ‘X' in the box if this is the first
submission of this schedule for the survey year. Otherwise
leave blank.
Item 1.4: Amended - Enter an ‘X' if this schedule amends a
previously submitted schedule. Otherwise, leave blank.

Item 1: Contact Information. Name, telephone number, fax
number, and e-mail address of the person most
knowledgeable about the reported data. This person should
be familiar with the data provided, and will be the person to
whom inquiries will be directed, if necessary.

SECTION 2.0: Reserves and Production Data
Provide data in Columns A through I for each State or
geographic subdivision in which you were an operator of
oil and/or gas wells as of December 31, 2019. Proved
reserves and production for 2019 are to be reported
on a Total Operated Basis. (See Section G, Reporting
Standards)

Item 2: Was your company an oil and gas field
operator ...? Check the appropriate box and follow the
instructions for completing the rest of the form.
Item 3: Company Status, Name, and/or Address Change
or Correction. If there was a change to the company name or
address, or if the company was sold, merged with another
company or the company went out of business, check the
appropriate box and complete Item 4.

You are not required to complete entries with zeros for
states or subdivisions in which you do not operate wells.
Leave these entries blank.

Item 4: Note Change Company Name, Address, and/or
Contact Information. If any box in Item 3 was checked, enter
the new or correct company name, address, or contact person
here.

2019 Reserves Data

REPORTING INSTRUCTIONS

December 31, 2019 Proved Reserves Data - Enter
estimates of total proved reserves for operated properties
if estimates are available. The estimates should be based
on your most recent evaluations, adjusted for production
through December 31, 2019, and for any other relevant
factors. If reserves were depleted during 2019, enter zero.
The resulting estimates for reserves should be consistent
with the definitions of proved reserves. (See Section J,
Definitions, page 6)

Part II. Approval
Items 5 thru 8: Approval - Enter the name and title of the
individual designated by the respondent company to review
and approve the accuracy of this submission and the date of
the signing. This report should be reviewed and approved by
a responsible officer or the office responsible for regulatory
filings. If filed electronically, there is no requirement to submit
a signed cover page.

Column A: Crude Oil Reserves
Column D: Natural Gas Reserves
Column G: Lease Condensate Reserves
Note: If no proved reserves estimates are available, enter
"NA" in Column(s) A, D, and/or G.

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2019 Production Data

atmospheric pressure after being recovered from oil well
(casinghead) gas in lease separators and are
subsequently commingled with the crude stream without
being separately measured
• small amounts of non-hydrocarbons produced with the oil,
such as sulfur and various metals.

December 31, 2019 Production Data are required from
all operators. If the actual survey year production data are
not available at the time the Form EIA-23S is prepared,
estimate production. Lease use and flared and vented gas
are also considered production and should be
included in the volumes reported.

When a State regulatory agency specifies a definition of crude
oil which differs from that above, the State definition is to be
followed.

Production
from
Properties
With
Reserves
Estimated: Enter the 2019 production for those operated
properties with proved reserves data that were reported in
Columns A, D, or G in the corresponding Columns B, E, or
H.
Column B: Crude Oil Production
Column E: Natural Gas Production
Column H: Lease Condensate Production

Field Separation Facility: A surface installation designed to
recover lease condensate from a produced natural gas stream
usually originating from more than one lease, and managed
by the operator of one or more of these leases. (See Lease
Condensate)
Gross Working Interest Ownership Basis: Gross working
interest ownership is the respondent's working interest in a
given property plus the proportionate share of any royalty
interest, including overriding royalty interest, associated with
the working interest. (See Working Interest and Royalty
Interest {Including Overriding Royalty})

Production from Properties for Which Reserves
Were NOT Estimated: Enter the 2019 production for those
operated properties for which proved reserves estimates
are NOT available in existing company records and were
therefore NOT reported in Columns A, D or G.
Column C: Crude Oil Production
Column F: Natural Gas Production
Column I: Lease Condensate Production

Lease Condensate: A mixture consisting primarily of
pentanes and heavier hydrocarbons which is recovered as a
liquid from natural gas in lease or field separation facilities.
This category excludes natural gas plant liquids, such as
butane and propane, which are recovered at downstream
natural gas processing plants or facilities. The output of natural
gas processing plants is reported on Form EIA-64A, Annual
Report of the Origin of Natural Gas Liquids Production and
Form EIA-816, Monthly Natural Gas Liquids Report.

U.S. TOTALS: Sum the entries in each column and enter the
totals on the last line of page 2, U.S. Totals.

J. DEFINITIONS
These definitions have been formulated with reference to the
particular purposes of Form EIA-23S. They are not necessarily
synonymous with the same or similar terms used in DOE
regulations, and are not to be construed as definitions
applicable for any purposes other than the collection and
reporting of data on Form EIA-23S.

Lease Separator: A facility installed at the surface for the
purpose of separating gases from:
• produced crude oil and water at the temperature and
pressure conditions of the separator, and/or
• that portion of the produced natural gas stream, which
liquefies at the temperature and pressure conditions of
the separator.

Affiliated (Associated) Company: An entity that is directly or
indirectly owned, operated, or controlled by another entity.
(See Person and Control)

Natural Gas: A gaseous mixture of hydrocarbon compounds,
the primary one being methane. The parameters for
measurement are cubic feet at 60 degrees Fahrenheit and
14.73 pounds per square inch absolute (psia). The Energy
Information Administration measures wet natural gas and its
sources of production, associated/dissolved natural gas
and non-associated natural gas, and dry natural gas, which
are produced from wet natural gas. This EIA survey does not
include landfill gas (biomass gas), synthetic natural gas, coke
oven gas, or manufactured gas.

Control: The term control (including the terms controlling,
controlled by, and under common control with) means the
possession, direct or indirect, of the power to direct or cause
the direction of the management and policies of a person,
whether through the ownership of voting shares, by contract
or otherwise. (See Person)
Crude Oil (excluding Lease Condensate): A mixture of
hydrocarbons that exists primarily in the liquid phase in natural
underground reservoirs and remains liquid at atmospheric
pressure after passing through surface separating facilities.
Such hydrocarbons as lease condensate and natural gasoline
recovered as liquids from natural gas wells in lease or field
separation facilities and later mixed into the crude stream are
excluded. Depending upon the characteristics of the crude
stream, it may also include:

Wet natural gas: A mixture of hydrocarbon compounds
and small quantities of various non-hydrocarbons existing
in the gaseous phase or in solution with crude oil in
porous rock formations at reservoir conditions. The
principal hydrocarbons normally contained in the mixture
are methane, ethane, propane, butane, and pentane.
Typical non-hydrocarbon gases that may be present in
reservoir natural gas are water vapor, carbon dioxide,
hydrogen sulfide, nitrogen and trace amounts of helium.

• small amounts of hydrocarbons that exist in gaseous
phase in natural underground reservoirs but are liquid at

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Production, Lease Condensate: The volume of lease
condensate produced during the survey year. Lease
condensate volumes include only those volumes recovered
from lease or field separation facilities. (See Lease
Condensate)

Under reservoir conditions, natural gas and its associated
liquefiable portions occur either in a single gaseous phase
in the reservoir or in solution with crude oil and are not
distinguishable at the time as separate substances. Note:
The Securities and Exchange Commission and The
Financial Accounting Standards Board refer to this product
as natural gas.

Production, Natural Gas: The volume of natural gas
withdrawn from reservoirs during the survey year less:

Dry natural gas: Natural gas that remains after:
• the liquefiable hydrocarbon portion has been
removed from the gas stream (i.e., gas after lease,
field and/or plant separation)
• any volumes of non-hydrocarbon gases have been
removed where they occur in sufficient quantity to
reduce the gas quality below minimum pipeline
specifications (rendering it unmarketable).

• the volume returned to such reservoirs in cycling,
repressuring of oil reservoirs and conservation operations
• the shrinkage resulting from the removal of lease
condensate
• non-hydrocarbon gases where they occur in sufficient
quantity to render the gas unmarketable.
Lease use and flared and vented gas are considered
production and should be included in the volumes reported.
Volumes of gas withdrawn from gas storage reservoirs and
native gas, which has been transferred to the storage
category, are not considered production.

Natural Gas Processing Plant: Facilities designed to recover
natural gas liquids from a stream of natural gas that may or
may not have passed through lease separators and/or field
separation facilities. These facilities also control the quality of
the natural gas stream to be marketed. Cycling plants are
classified as natural gas processing plants.

Proved Reserves, Crude Oil: Proved reserves of crude oil as
of December 31 of the survey year are the estimated volumes
of all liquids defined as crude oil, which geological and
engineering data demonstrate with reasonable certainty to be
recoverable in future years from known reservoirs under
existing economic and operating conditions.

Operator: The person responsible for the management and
day-to-day operation of one or more crude oil and/or
natural gas wells as of December 31, 2019. The operator is
generally a working interest owner or a company under
contract to the working interest owner(s). Wells included
are those, which have proved reserves of crude oil,
natural gas, and/or lease condensate in the reservoirs
associated with them, whether or not they are producing.
Wells abandoned during 2019 are also to be considered
operated as of December 31, 2019. (See Person, Proved
Reserves of Crude Oil, Proved Reserves of Natural
Gas, Proved Reserves of Lease Condensate, Survey
Year, and Reservoir)

Reservoirs are considered proved if economic producibility is
supported by actual production or conclusive formation test
(drill stem or wire line), or if economic producibility is supported
by core analyses and/or electric or other log interpretations.
The area of an oil reservoir considered proved includes:
• that portion delineated by drilling and defined by gas-oil
and/or oil-water contacts, if any
• the immediately adjoining portions not yet drilled, but
which can be reasonably judged as economically
productive on the basis of available geological and
engineering data.

Ownership: (See Gross Working Interest
Ownership Basis)

In the absence of information on fluid contacts, the lowest
known structural occurrence of hydrocarbons is considered to
be the lower proved limit of the reservoir.

Parent Company: A firm that directly or indirectly
controls another entity. (See Affiliated {Associated}
Company and Control)

Volumes of crude oil placed in underground storage are not
considered proved reserves.

Person: An individual, a corporation, a partnership,
an association, a joint-stock company, a business trust
or an unincorporated organization.

Reserves of crude oil which can be produced economically
through application of improved recovery techniques (such as
fluid injection) are included in the proved classification when
successful testing by a pilot project, or the operation of an
installed program in the reservoir, provides support for the
engineering analysis on which the project or program was
based.

Pool: In general, a reservoir. In certain situations a pool
may consist of more than one reservoir. (See Field Area)
Production, Crude Oil: The volumes of crude oil that
was extracted from oil reservoirs during the survey year.
These volumes are determined through measurement of the
volumes delivered from lease storage tanks or at the point
of custody transfer, with adjustment for:
• net differences between opening and closing lease
inventories
• basic sediment and water
• Crude oil used on the lease is considered production.

Estimates of proved crude oil reserves do not include the
following:
• oil that may become available from known reservoirs in
the future
• natural gas liquids (including lease condensate)

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• oil, the recovery of which is subject to reasonable doubt
because of uncertainty as to geology, reservoir
characteristics, or economic factors
• oil that may occur in undrilled prospects
• oil that may be recovered from oil shales, coal, Gilsonite
and other such sources.
•
It is not necessary that production, gathering or transportation
facilities are installed or operative for a reservoir to be
considered proved.

It is not necessary that production, gathering or transportation
facilities are installed or operative for a reservoir to be
considered proved. It is to be assumed that compression will
be initiated if and when economically justified.
Reserves: (See Proved Reserves)
Reservoir: A porous and permeable underground formation
containing an individual and separate natural accumulation of
producible hydrocarbons (oil and/or gas) which is confined by
impermeable rock or water barriers and is characterized by a
single natural pressure system.

Proved Reserves, Lease Condensate: Proved reserves of
lease condensate as of December 31 of the survey year are
the estimated volumes expected to be recovered in future
years in conjunction with the production of proved reserves of
natural gas based on the recovery efficiency of lease and/or
field separation facilities currently installed. (See Lease
Condensate and Proved Reserves of Natural Gas)

Royalty Interests (Including Overriding Royalty): Rights
that entitle their owner(s) to a share of the mineral production
from a property or to a share of the proceeds from a property.
They do not contain the rights and obligations of operating the
property and normally do not bear any of the costs of
exploration, development, and operation of the property.

Proved Reserves, Natural Gas: Proved reserves of natural
gas as of December 31 of the survey year are the estimated
volumes which analysis of geologic and engineering data
demonstrates with reasonable certainty to be recoverable in
future years from known reservoirs under existing economic
and operating conditions. Reservoirs are considered proved if
economic producibility is supported by actual production or
conclusive formation test (drill stem or wire line), or if economic
producibility is supported by core analyses and/or electric or
other log interpretations.

Subdivision: A prescribed portion of a given State or other
geographical region defined in this publication for statistical
reporting purposes.
Subsidiary Company: A company which is controlled through
the ownership of voting stock or a corporate joint venture in
which a corporation is owned by a small group of businesses
as a separate and specific business or project for the mutual
benefit of the members of the group. (See Control)
Survey Year: The year to which data reported on this form
pertains.

The area of a gas reservoir considered proved includes:
• that portion delineated by drilling and defined by gas-oil
and/or gas-water contacts, if any
• the immediately adjoining portions not yet drilled, but
which can be reasonably judged as economically
productive on the basis of available geological and
engineering data.

Total Operated Basis: The total reserves or production
associated with the wells operated by an individual operator.
This is also commonly known as the gross operated or 8/8ths
basis.
Working Interest: Rights that permits the owner(s) to explore,
develop, and operate a property. The working interest
owner(s) bear(s) the costs of exploration, development, and
operation of the property. In return for these investments, the
owner(s) is (are) entitled to a share of the mineral production
from the property or to a share of the proceeds from the
property.

In the absence of information on fluid contacts, the lowest
known structural occurrence of hydrocarbons is considered to
be the lower proved limit of the reservoir.
Volumes of natural gas placed in underground storage are not
considered proved reserves.
For natural gas reserves, wet after lease separation, an
appropriate reduction in the reservoir gas volume must be
made to cover the removal of the liquefiable portions of the
gas in lease and/or field separation facilities and the exclusion
of nonhydrocarbon gases where they occur in sufficient
quantity to render the gas unmarketable.

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State and Federal Subdivision Codes
State Name and Geographic Subdivision1

Code

State Name and Geographic Subdivision1

Alabama Onshore ...............................................
Alabama – State Offshore ...................................
Alaska - North Onshore.......................................
Alaska – North State Offshore……………………
Alaska - South Onshore ......................................
Alaska - South State Offshore .............................
Arizona ................................................................
Arkansas .............................................................
California – Onshore, Los Angeles Basin............
California – Onshore, Coastal Region .................
California – Onshore, San Joaquin Basin ...........
California – State Offshore ..................................
Colorado .............................................................
Connecticut .........................................................
Delaware .............................................................
District of Columbia .............................................
Florida – Onshore………………………………….
Florida - State Offshore .......................................
Georgia ...............................................................
Hawaii .................................................................
Idaho ...................................................................
Illinois ..................................................................
Indiana ................................................................
Iowa ....................................................................
Kansas ................................................................
Kentucky .............................................................
Louisiana – North
(Monroe & Shreveport Districts) .......
Louisiana – South (Lafayette District) .................
Louisiana – State Offshore ..................................
Maine ..................................................................
Maryland .............................................................
Massachusetts ....................................................
Michigan ..............................................................
Minnesota ...........................................................
Mississippi – Onshore .........................................
Mississippi – State Offshore ................................
Missouri ...............................................................
Montana ..............................................................
Nebraska .............................................................
Nevada ................................................................
New Hampshire...................................................
New Jersey .........................................................

AL
AL99
AKN
AK88
AKS
AK99
AZ
AR
CA1
CA2
CA3
CA99
CO
CT
DE
DC
FL
FL99
GA
HI
ID
IL
IN
IA
KS
KY

New Mexico – East .......................................................... NME
New Mexico - West .......................................................... NMW
New York .........................................................................
NY
North Carolina..................................................................
NC
North Dakota....................................................................
ND
Ohio .................................................................................
OH
Oklahoma ........................................................................
OK
Oregon .............................................................................
OR
Pennsylvania ...................................................................
PA
Rhode Island....................................................................
RI
South Carolina .................................................................
SC
South Dakota ...................................................................
SD
Tennessee .......................................................................
TN
Texas - Railroad Commission District 1 ........................... TX1
Texas - Railroad Commission District 2 Onshore ............ TX2
Texas - Railroad Commission District 3 Onshore ............ TX3
Texas - Railroad Commission District 4 Onshore ............ TX4
Texas - Railroad Commission District 5 ........................... TX5
Texas - Railroad Commission District 6 ........................... TX6
Texas - Railroad Commission District 7B......................... TX7B
Texas - Railroad Commission District 7C ........................ TX7C
Texas - Railroad Commission District 8 ........................... TX8
Texas - Railroad Commission District 8A......................... TX8A
Texas - Railroad Commission District 9 ........................... TX9
Texas - Railroad Commission District 10 ......................... TX10
Texas - State Offshore ..................................................... TX99
Utah .................................................................................
UT
Vermont ...........................................................................
VT
Virginia .............................................................................
VA
Washington ...................................................................... WA
West Virginia.................................................................... WV
Wisconsin ........................................................................
WI
Wyoming .......................................................................... WY
Federal Offshore – Atlantic (Lower 48 East Coast)..……. FAEC
Federal Offshore – Alaska Arctic (North of Bering Strait
Chuckchi and Beaufort Seas)
…AKAA
Federal Offshore – Alaska Pacific (South of Bering Strait
.
Bering Sea and Pacific)
...AKPA
Federal Offshore – Gulf of Mex (East Planning Area)...…. FGEP
Federal Offshore – Gulf of Mex (Central Planning Area)... FGCP
Federal Offshore – Gulf of Mex (West Planning Area)…. FGWP
Federal Offshore – Pacific (Lower 48 West Coast)…..……FPWC

LAN
LAS
LA99
ME
MD
MA
MI
MN
MS
MS99
M0
MT
NE
NV
NH
NJ

Code

___________________________________
Reference maps that illustrate state and federal subdivisions and their codes for boundaries in the States of Alaska, California, Louisiana, New
Mexico, Texas and the Gulf of Mexico can be found at this web link: www.eia.gov need link.
.

2019 EIA-23S Annual Report of Domestic Oil and Gas Reserves, Summary Level

9

MAPS OF SELECTED STATE SUBDIVISIONS

Alaska Subdivisions and U.S. Geological Report Quadrangles
2019 EIA-23S Annual Report of Domestic Oil and Gas Reserves, Summary Level

10

Source: U.S. Energy Information Administration, Office of Oil, Gas, and Coal Supply Statistics

Subdivisions of California

Source: U.S. Energy Information Administration, Office of Oil, Gas, and Coal Supply Statistics

Subdivisions of Louisiana

Source: U.S. Energy Information Administration, Office of Oil, Gas, and Coal Supply Statistics

Subdivisions of New Mexico

Subdivisions of Texas

Western Planning Area, Gulf of Mexico Outer Continental Shelf Region

Source: U.S. Department of the Interior

Central Planning Area, Gulf of Mexico Outer Continental Shelf Region

Source: U.S. Department of the Interior

Eastern Planning Area, Gulf of Mexico Outer Continental Shelf Region

Source: U.S. Department of the Interior.

Energy Information Administration
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