Oil and Gas Reserves System Surveys

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

Form Approved
OMB Number: 1905-0057
Expiration Date: xx/xx/20xx

ANNUAL SURVEY OF DOMESTIC OIL AND GAS RESERVES
FORM EIA-23L Field Level Survey Instructions

SURVEY YEAR 2009
Table of Contents
Page

General Instructions ..........................................................................................

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A. Purpose ..................................................................................................................
B. Who Must Submit Form EIA-23L ...........................................................................
C. What Must Be Submitted .......................................................................................
D. When and Where to Submit...................................................................................
E. Record Keeping Requirements..............................................................................
F. Sanctions ...............................................................................................................
G. Disclosure of Information .......................................................................................
H. Reporting Standards ..............................................................................................
1. Proved Reserves .............................................................................................
2. Survey Year Production ...................................................................................
3. Total Operated Basis .......................................................................................
4. States and Geographic Subdivisions...............................................................
5. Field Names and Codes ..................................................................................
6. Reporting Units ................................................................................................
7. Prior Year's Filings ...........................................................................................
a. Properties Were Purchased or Acquired ..................................................
b. Properties Were Sold or Transferred........................................................
c. Gas Type Reclassified ..............................................................................
d. First Time Reporting Reserves .................................................................
8. Schedule Preparation Standards.....................................................................
9. EIA Secure File Transfer Information………………………..............................

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

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I. Cover Page - Operator Identification .....................................................................
J...Schedule A - Operated Proved Reserves, Production, and
Related Data by Field.............................................................................................
K. Schedule B - Footnotes..........................................................................................
L. Definitions ..............................................................................................................
M. Field Naming and Coding Conventions .................................................................
N. Location Codes ......................................................................................................
1. Geographic Codes ...........................................................................................
2. County Codes ..................................................................................................
3. State and Geographic Subdivision Codes.......................................................

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Maps of Selected State Subdivisions ................................................................

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

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GENERAL INSTRUCTIONS
A. PURPOSE

hydrocarbons from wells that they operated on December 31,
2009. The three size categories are as follows:

The Energy Information Administration (EIA) of the
Department of Energy (DOE) seeks, with Form EIA-23L, 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.

Category I Operators: Operators that produced 1.5 million
barrels or more of crude oil and/or 15 billion cubic feet or
more of natural gas, must file:
• Cover Page
• Schedule A - Operated proved reserves, production, and
related data by fields
• Schedule B - Footnotes
Category II Operators: Operators that produced at least
400,000 barrels of crude oil or 2 billion cubic feet of natural
gas but less than Category I operators must file
• Cover Page
• Schedule A - Operated proved reserves (if available),
production, and related data by fields
• Schedule B - Footnotes

B. WHO MUST SUBMIT FORM EIA-23L
Each operator (see Section L Definitions, page 8) selected
must file Form EIA-23L if your total gross operated survey
year production is either 400 thousand barrels (400 MBbls) of
crude oil or 2 billion cubic feet (2,000 MMCF or 2 BCF) of
natural gas. Also, operators of wells in the federal offshore
and/or of coalbed methane wells are required to file Form
EIA-23L regardless of their total survey year production
levels. If you do not meet these annual production levels,
contact the EIA-23 Coordinator 800-879-1470 to obtain Form
EIA-23S and instructions.

Category III Operators: Operators who produced less than
Category II operators, but operate either coalbed methane
gas wells and/or federal offshore wells, must file:
• Cover Page
• Schedule A - Operated proved reserves (if available),
production, and related data by fields
• Schedule B - Footnotes

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

Proved reserves estimates are required only if such data
exists in company records. To the extent that these operators
do not have proved reserves estimates associated with one
or more specific properties, they must report their Survey
Year Production, Schedule A, Column I.

Each operating affiliate of a parent company must file its own
Form EIA-23L. The parent company must file only if it is an
operator itself. If no parent company exercises ultimate
control over your company, please indicate that on the Cover
Page.

D. WHEN AND WHERE TO SUBMIT
The completed 2009 survey forms must be submitted on or
before April 2, 2010. Filing electronically, using Secure File
Transfer or Fax, is encouraged.

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).

Secure File Transfer: See page 5 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

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, 2009 (perhaps a former
operator or solely a working or royalty interest owner), you
should complete and sign the Cover Page and return it to
EIA along with a letter stating when operations ceased and
what became of the wells you previously operated.

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

E. RECORD KEEPING REQUIREMENTS

C. WHAT MUST BE SUBMITTED

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.

Production data and estimates of proved reserves of crude
oil, natural gas, and lease condensate are required of each
operator selected. This survey segregates selected operators
into three categories, according to the annual production of

EIA may perform quality assurance on the data, assessing
the accuracy of the resulting information. Two principal
quality assurance activities are: 1) government personnel will
make or supervise independent reserve estimates on a

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H. REPORTING STANDARDS

selected basis or, 2) a sample of operators will be visited to
review the data submitted.

1. Proved Reserves
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.

F. SANCTIONS
The timely submission of Form EIA-23L by those required to
report is mandatory under Section 13 (b) of the Energy
Information Administration Act of 1974 (FEAA) (Public Law
93-275), as amended. Failure to respond may result in a civil
penalty of not more than $2,750 a day for each violation, or a
fine of not more than $5,000 a day for each willful 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.

Proved reserves of oil and gas as of December 31, 2009 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 L
Definitions, page 8.)

G. DISCLOSURE OF INFORMATION

2. Survey Year Production
Production data are required from all operators. If the actual
production data are not available at the time Form EIA-23L is
prepared, estimate production. Note that amended schedules
are not required to correct preliminary production data.
Production data reported in the prior year survey may have
been subsequently revised or corrected, thereby altering the
end of the prior year reserves. Any change in the end of the
prior year reserves due to this factor should be accounted for
as part of the Revision Increases or Revision Decreases
reported in the current survey.

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 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.

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.

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.

3. 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.

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.

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.

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

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.

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from another field. The resultant increase in proved gas
reserves is considered a Revision Increase for those
volumes that are reasonably expected to be recovered at
some future date. A Schedule B footnote must indicate the
total injected volume and the expected future recoveries.

4. 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, subdivisions, or counties, the
proved reserves data must be subdivided into the
appropriate geographic components. Refer to the Section:
Maps of Selected Sate Subdivisions for the subdivision
boundaries in the States of Alaska, California, Louisiana,
New Mexico, and Texas.

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).

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.

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.

5. Field Names and Codes

e. Negative and Positive Volumes: All data are to be
entered as whole number integers without plus (+) or minus
(-) symbols. By definition, Revision Decreases, Sales, and
Production all constitute reserve decreases and are
entered without the minus symbol.

The EIA 2009 Annual Oil and Gas Field Code Master List
(2009 FCML) contains the appropriate State, county, field
codes, and spelling conventions for field names. It is found
on the enclosed CD-ROM also.

6. Reporting Units

7. Prior Year's Filing

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:

Entries for Total Proved Reserves December 31, 2008,
Schedule A, Column (A) in this year's Form EIA-23L filing
should not differ from those quantities reported as end-ofyear reserves in the prior year's filing.

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.

a. Properties Were Purchased or Acquired
If operations were transferred from another company to the
respondent during the survey year, then these reserves
should be shown in Acquisitions, Schedule A, Column (E).
Reserves and production for the acquired properties should
be reported from the date of purchase. Additionally, a
Schedule B footnote must be provided indicating the name
of the previous operator and the month in which operations
were acquired.

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.
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.

b. Properties Were Sold or Transferred
If operations were transferred to another company during
the survey year, then these reserves should be shown in
Sales, Schedule A Column (D). Reserves and production
for these properties should be reported until the date of
sale. Additionally, a Schedule B footnote must be provided
indicating the name of the new operator and the month in
which operations were transferred. In the event the
respondent no longer operates any properties in this field,
then the Total Proved Reserves December 31, 2009,
Schedule A, Column (J) would be zero.

The EIA obtains data from gas processing plants separately.
Gas volumes reported on Form EIA-23 should 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 the EIA or not, contact the EIA-23
Coordinator at 800-879-1470 to obtain information on those
plants which report.

c. Gas Type Reclassified
In the case where the type of gas was improperly reported
or reclassified from associated-dissolved (AD) to nonassociated (NA), or vice-versa, report the Total Proved
Reserves, December 31, 2008, Schedule A, Column (A)
from prior year’s Schedule A for the previous classification.
Eliminate the reserves of the previous classification by a
Revision Decreases, Schedule A, Column C and create
the reserves of the new classification by an equal Revision
Increases, Schedule A, Column B. Enter zero for Total
Proved Reserves, December 31, 2008, Schedule A,
Column (A) for the new classification. Note the
reclassification of natural gas on Schedule B.

Operators must segregate natural gas data into associateddissolved and nonassociated gas entries (see natural
gas,
associated-dissolved
and
natural
gas,
nonassociated, Section L Definitions, page 8.). For a given
reservoir, the gas type should represent the State
classification as of December 31, of the survey year. This
gas type may differ from the classification reflected in the
prior year's Form EIA-23L filing.
An unusual situation may occur when, for pressure
maintenance, a field is injected with natural gas produced

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d. First Time Reporting Reserves
If a respondent reports reserves estimates in the current
survey but not in the prior year's survey because such
estimates were not available in the company records at that
time, add Survey Year Production, Schedule A, Column
(I), and Total Proved Reserves December 31, 2009,
Schedule A, Column (J). Enter the sum in Total Proved
Reserves December 31, 2008, Schedule A, Column (A).

9. EIA Secure File Transfer (SFT)Information
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.

8. Schedule Preparation Standards
Prior to submission, completed forms must be assembled
and paginated consecutively within each schedule in the
following order:

To use the EIA HTTPS secure file transfer system:
1. Cover Page
1. Click to open the SFT webpage
or type in this URL in your browser:
https://signon.eia.doe.gov/upload/noticeoog.jsp

2. Schedule A: Sort alphabetically by state, then by
subdivision within that state, then by field name within
each subdivision, then by county, and then by type code.
The last Schedule A page is to contain the Company
Totals for all reported fields.

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.

3. Schedule B: In the same sequence as Schedule A.

If you have any trouble transferring your files, please call the
EIA User Services Center 202-586-8959 or email them at
[email protected].

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SPECIFIC INSTRUCTIONS
a responsible officer or the office responsible for regulatory
filings. If filed electronically, there is no requirement to submit
a signed cover page.

I. COVER PAGE - Operator Identification
You are required to enter those items that are incorrect
or missing from the preprinted form.

J. SCHEDULE A - Operated Proved Reserves,
Production, and Related Data By Field

Part I. Identification

All proved reserves, production, and reserve changes data on
Schedule A are to be reported on a Total Operated Basis for
each field in which the respondent operated oil and/or gas
wells on December 31, of the survey year, including
abandonments during the survey year. (See Total Operated
Basis, Section H, Item 3.) If a field overlaps two or more
States, subdivisions, or counties, data pertaining to each
must be separately reported.

EIA Operator ID Code: If this item is missing, contact the
EIA-23 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: 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 1.0: Operator Detailed Data Report
Report the information in this section on each Schedule A
submitted.
Item 1.1: EIA Operator ID Code – This is the same as the
Cover Page EIA Operator ID Code.

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 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.

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.

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 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.

Item 1.4: Amended - Enter an ‘X' if this schedule amends a
previously submitted schedule. Otherwise, leave blank.
Item 1.5: Page – Enter the current page number in this
schedule series.

Part II. Parent Company Identification
SECTION 2.0: Field Data (Operated Basis)
Item 5: Is there a parent company …? Check the
appropriate box. If Box 2 is checked, provide parent company
information in Items 6 through 10.

Production data and/or estimates of proved reserves of crude
oil, natural gas, and lease condensate are required of each
operator selected. Production refers to the total survey year
production from all domestic oil and/or gas wells you
operated on December 31, of that survey year, including
wells abandoned during the survey year.

Item 6: Parent Company Name. Enter the legal name and
address of the parent company, if any that exercises ultimate
control over the respondent.
Example: You are Company A, which takes direction
from Company B, which in turn takes direction from
Company C. Report Company C as the parent company,
rather than Company B.

Production data and proved reserve estimates are required
by field from all Category I operators. Production data are
required by field from all Category II operators and proved
reserves estimates are required only if such data exist in
company records.

Items 7-10: Address, City, State, and Zip Code. Enter the
address, City, State, and Zip Code of the parent company.

If it would make your forms preparation easier, a new State or
State subdivision may be started in the first field data block of
a new Schedule A page. In all other cases, utilize all threefield data blocks on each Schedule A. When completing more
than one page of Schedule A, do not renumber items 2.1
through 2.3 on successive pages. However, be certain to

Part III. Approval
Items 11 thru 14: 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

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enter the correct, consecutive page numbers on each page in
item 1.5.

define the wells, properties, and/or leases to which data
entered in this block pertains. Prospect name is generally
utilized prior to the assignment of an official field name by the
state or other jurisdictional agency.

Subitem 1: State Code - Enter the two-character alphabetic
abbreviation of the State that data reported for this field
pertains. For State offshore fields, use the abbreviation of the
adjacent state. (See Geographic Codes, page 12.)

Type of Hydrocarbons:
Subitem 12: Crude Oil (MBbls)

Subitem 2: Subdivision Code - Enter the two-digit code of
the appropriate geographic subdivision to which data reported
for this field pertain. Leave blank if not applicable. (See
Geographic Codes, page 12.)

Subitem 13: Associated-Dissolved Gas (MMCF)
Subitem 14:Non-associated Gas (MMCF)

Subitem 3: County Code - Enter the three-digit numeric
code for the county or parish in which the field is located
according to the 2009 FCML. If the field is located in more
than one county and there is a question about where the
reserves are located, enter the county code that contains the
largest lease acreage of proved reserves

Subitem 15: Lease Condensate (MBbls)
Column (A): Total Proved Reserves, December 31, 2008
Enter the volumes of total proved reserves as of December
31, 2008. This number should equal the ending reserves
previously reported to EIA for December 31, 2008. (See
Proved Reserves of Crude Oil; Proved Reserves of Lease
Condensate; and Proved Reserves of Natural Gas, Wet
after Lease Separation; Section L Definitions, page 8.)

Subitem 4: Field Code - Enter the six-digit field code as it
appears in the 2009 FCML. If field name is Wildcat, enter
999001 for the field code. If you cannot locate the field name
on the list or there is doubt that a field identified on the list is
the same field that you are reporting, insert 999002 for the
field code. If there are multiple unknown fields in a county,
report them as one field with a field code of 999002. Please
use Schedule B - Footnotes for clarifying data.

Column (B): Revision Increases - Enter the total of upward
revisions made in the field during the survey year. Explain
any revision increase in excess of 2,500 MBbls of liquid or
15,000 MMCF of gas in a Schedule B footnote and check
Subitem 8. To the extent that reserves are revised upward
due to implementation of secondary or tertiary recovery
techniques, such revisions should be indicated by volume
and by recovery method in a Schedule B footnote. Also,
indicate in a Schedule B footnote the volume of any upward
revisions due to the transfer of unproved reserves to proved
status. (See Revisions, Section L Definitions, page 8.)

Subitem 5: Type Code - Enter the alpha code to recognize
the volumes of field production and proved reserves from
conventional reservoirs, and designated unconventional
reservoirs. These alpha codes are C for conventional
reservoirs, CB for coal bed reservoirs, SH for shale
reservoirs, CH for chalk reservoirs and LP for other low
permeability reservoirs. Low permeability reservoirs are those
with values of 0.1 millidarcy or less.

Column (C): Revision Decreases - Enter the total of
downward revisions made in the field during the survey year.
Do not enter a minus sign as entries in this column are
assumed to be negative. Explain any revision decrease in
excess of 2,500 MBbls of liquid or 15,000 MMCF of gas in a
footnote on Schedule B and check subitem 8. (See
Revisions, Section L Definitions, page 8.)

Subitem 6: Field Name - Enter the name of the field. Do not
include reservoir names. (See Field Naming Conventions,
Section M, page 12.)
Subitem 7: Proved Nonproducing Reserves. - Enter the
estimated volumes of proved reserves in the field which were
in nonproducing status at the end of the survey year. This
includes proved developed nonproducing and proved
undeveloped reserves. (See Nonproducing Reserves
Section L Definitions, page 8.)

Column (D): Sales - If operations were transferred to
another company during the survey year, then these reserves
should be reported as Sales. Enter the reserves for these
properties until the date of sale. Additionally, a Schedule B
footnote must be provided indicating the name of the new
operator and the month in which operations were transferred.
In the event the respondent no longer operates any
properties in this field, then Total Proved Reserves
December 31, 2009 Schedule A, Column (J) will be zero.
(See Sales, Section L Definitions, page 8.)

Subitem 8: Footnote - For Schedule B, Footnotes, enter an
‘X’. Leave blank if there is no footnote information.
Subitem 9: Water Depth - For an offshore field, enter the
average depth of water (from mean sea level to seabed) over
the field, in feet. Leave blank if an onshore field.

Column (E) Acquisitions - If operations were transferred
from another company to the respondent during the survey
year, then these reserves should be reported as Acquisitions.
Enter the reserves for the acquired properties from the date
of purchase or transfer. Additionally, a Schedule B footnote
must be provided indicating the name of the previous
operator and the month in which operations were acquired.
(See Acquisitions, Section L Definitions, page 8.)

Subitem 10: Field Discovery Year - The survey year in
which a field was first recognized as containing economically
recoverable accumulations of oil and/or gas. Field discovery
year may be found in the 2009 FCML. If a new discovery,
footnote on Schedule B and check Subitem 8, Footnote.
Subitem 11: Prospect Name (Optional) - Respondent may
enter the prospect name used by the respondent company to

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Footnote Data: Use all lines on each Schedule B page
before using additional pages. Columns (a) thru (e) must be
filled in only for the first line of each footnote.

Column (F) Extensions - If this is an old field, enter the
increases to the field’s reserves attributable to extensions,
including increased density and recompleted wells, during the
survey year. (See Extensions, Section L Definitions, page
8.)

Column (A) State Code - Enter the state abbreviation from
Schedule A referenced by this footnote.

Column (G) New Field Discoveries - If the field was
discovered during the survey year, enter the estimated initial
volumes of proved reserves attributable thereto (before
reducing it by production during the survey year, if any). (See
New Field Discoveries, Section L Definitions, page 8.)

Column (B) Subdivision Code - Enter the Subdivision Code
from Schedule A referenced by this footnote.
Column (C) County Code - Enter the county code from
Schedule A referenced by this footnote.

Column (H) New Reservoir Discoveries in Old Fields - If
this is an old field and any new reservoir discoveries were
made in it during the survey year, enter the estimated initial
volumes attributable thereto, (before reducing by production
during the survey year, if any). (See New Field and Old
Field, Section L Definitions, page 8.)

Column (D) Field Code - Enter the field code from Schedule
A referenced by this footnote.
Column (E) Type Code - Enter the type code from Schedule
A referenced by this footnote.
Column (F) Hydrocarbon Type - Enter the number for the
type of hydrocarbon shown in Schedule A referenced by this
footnote. For example, use 12 for crude oil, 13 for associated
dissolved gas, 14 for non-associated gas, and 15 for lease
condensate. Use 7 for footnote references to proved nonproducing reserves regardless of the type of hydrocarbon.

Column (I) Survey Year Production - Enter the volumes
produced from the field during the survey year. (See
Production, Crude Oil; Production, Lease Condensate;
and Production, Natural Gas, Wet After Lease Separation,
Section l Definitions, page 8.)
Column (J) Total Proved Reserves, December 31, 2009
Enter the volumes of total proved reserves as of December
31, 2009. This item should be the algebraic sum of Columns
(a) + (b) + (e) + (f) + (g) + (h), less Columns (c), (d), and (i).
This value includes producing and non-producing reserves
and therefore should always be equal to or greater than the
values shown in Subitem 7.

Column (G) Column - Enter the alphabetic column
designation (A through J) from Schedule A referenced by the
footnote.
Column (H) Footnotes - Enter the text of the footnote, using
as many lines as necessary.

Company Totals

L. DEFINITIONS

Company totals for each of the volumetric data elements
reported are required. Enter these company totals in the next
available Field Data (Operated Basis) block. Enter ‘ZZ’ in
State Code and Company Totals in the Field Name to identify
these data as company totals.

These definitions have been formulated with reference to the
particular purposes of Form EIA-23L. 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-23L.
Acquisitions: The volumes of proved reserves of crude oil,
natural gas, and/or lease condensate associated with
properties that were purchased and/or transferred from
another company to the respondent’s operatorship during the
survey year.

K. SCHEDULE B - Footnotes
Submit footnotes in clarification of reported data items. This
includes revisions, sales, or acquisitions of properties during
the survey year. Additionally, you may footnote any other
reported item if this will enhance its clarity.
Item 1.1 EIA Operator ID Code - This is the same as the
Cover Page EIA Operator ID Code.

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

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.

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)

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.

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

Item 1.4 Amended - Enter an ‘X' if this schedule amends a
previously submitted schedule. Otherwise, leave blank.
Item 1.5 Page - Enter the current page number in this
schedule series.

8

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:
• small amounts of hydrocarbons that exist in gaseous
phase in natural underground reservoirs but are liquid at
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.
When a State regulatory agency specifies a definition of
crude oil which differs from that above, the State definition is
to be followed and its use footnoted on Schedule B of Form
EIA-23L.

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.
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.
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.

Extensions: The reserves credited to a reservoir because of
enlargement of its proved area. Normally, the ultimate size of
newly discovered fields or newly discovered reservoirs in old
fields is determined by wells drilled in years subsequent to
discovery. When such wells add to the proved area of a
previously discovered reservoir, the increase in proved
reserves is classified as an extension. This would also
include increased density wells and recompletions that
extend the drainage area of the field beyond the existing
wells.

Field Area: A geographic area encompassing two or more
pools that have a common gathering and metering system,
the reserves of which are reported as a single unit. This
concept applies primarily to the Appalachian region. (See
Pool)

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. 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.

Field Discovery Year: The survey year in which a field was
first recognized as containing economically recoverable
accumulations of oil and/or gas. The official dates may be
found in the 2009 FCML.

Associated-dissolved natural gas: Natural gas that
occurs in crude oil reservoirs either as free gas
(associated) or as gas in solution with crude oil
(casinghead gas).

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)

Non-associated natural gas: Natural gas that is not in
contact with significant quantities of crude oil in the
reservoir.

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})

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).

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 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

Field: An area consisting of a single reservoir or multiple
reservoirs all grouped on, or related to, the same individual
geological structural feature and/or stratigraphic condition.
There may be two or more reservoirs in a field that are
separated vertically by intervening impervious strata or
laterally by local geologic barriers or by both.

9

• net differences between opening and closing lease
inventories
• basic sediment and water
• Crude oil used on the lease is considered production.

quality of the natural gas stream to be marketed. Cycling
plants are classified as natural gas processing plants.
New Field: A field discovered during the survey year.

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)

New Field Discoveries: The volumes of proved reserves of
crude oil, natural gas, and/or lease condensate discovered in
new fields during the survey year.
New Reservoir: A reservoir discovered during the survey
year.

Production, Natural Gas: The volume of natural gas
withdrawn from reservoirs during the survey year less:
New Reservoir Discoveries in Old Fields: The volumes of • the volume returned to such reservoirs in cycling,
proved reserves of crude oil, natural gas, and/or natural gas
repressuring of oil reservoirs and conservation operations
liquids discovered during the survey year in new reservoir(s) • the shrinkage resulting from the removal of lease
located in old fields.
condensate
• non-hydrocarbon gases where they occur in sufficient
Non-producing Reserves: Quantities of proved liquid or
quantity to render the gas unmarketable.
gaseous hydrocarbon reserves that have been identified, but Lease use and flared and vented gas are considered
which did not produce during the last survey year regardless production and should be included in the volumes reported.
of the availability and/or operation of production, gathering or Volumes of gas withdrawn from gas storage reservoirs and
transportation facilities. This includes both proved native gas, which has been transferred to the storage
category, are not considered production.
undeveloped and proved developed non-producing reserves.
Prospect: An area of exploration or development in which
hydrocarbons have been predicted to exist in economic
quantity. A prospect is commonly an anomaly, such as a
geologic structure or a seismic amplitude anomaly, which is
recommended by exploration personnel for drilling a well. A
single drilling location may also be called a prospect but the
term is more properly used in the context of exploration.

Old Reservoir: A reservoir discovered prior to the survey
year.
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, 2009. 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 2009 are
also to be considered operated as of December 31, 2009.
(See Person, Proved Reserves of Crude Oil, Proved
Reserves of Natural Gas, Proved Reserves of Lease
Condensate, Survey Year, and Reservoir)

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.
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.
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.

Ownership: (See Gross Working Interest Ownership
Basis)
Parent Company: A firm that directly or indirectly controls
another entity. (See Affiliated {Associated} Company and
Control)
Person: An individual, a corporation, a partnership, an
association, a joint-stock company, a business trust or an
unincorporated organization.
Pool: In general, a reservoir. In certain situations a pool may
consist of more than one reservoir. (See Field Area)

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

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:

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.

10

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)
• 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.

Revisions: Changes to prior year-end proved reserves
estimates, either positive or negative, resulting from new
information other than an increase in proved acreage
(extension). Revisions include increases of proved reserves
associated with the installation of improved recovery
techniques or equipment. They also include correction of
prior survey year arithmetical or clerical errors and
adjustments to prior year-end production volumes to the
extent that these alter previous reserves estimates.
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, 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)

Sales: The volumes of proved reserves of crude oil, natural
gas, and/or lease condensate associated with properties that
were sold and/or transferred during the survey year from the
respondent’s operatorship to that of another company.

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)

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.
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.

Survey Year: The year to which data reported on this form
pertains.
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.

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.

M. FIELD NAMING AND
CODING CONVENTIONS
The 2009 FCML is included on the RIGS CD and on the EIA
Website. Please consult it for the appropriate State, county,
field codes, and spelling conventions for field names.

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.

1. Field Naming Conventions

Reserves: (See Proved Reserves)
Field naming conventions are used to provide a standard
nomenclature for each geologic field that is recognizable to
both the personnel working with Form EIA-23L and the
computer system and fits into 26 characters. In most
instances, field names should reflect the conventions
imposed by State oil and gas regulatory agencies. (See 2009

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.

11

• Special attention should be given to reporting field names
in Michigan. Most fields have the section, township, and
range after the field name. For example: Kalkaska 1227N-7W. Operators should report field name as indicated.
• If a field that has been reported in the previous survey
year is changed or aliased to another field according to
the field code publication, report the data under the new
field name. For example, Mud Spring is an alias of Four
Mile Creek. All data that was previously reported under
Mud Spring should now be reported under and combined
with any previous Four Mile Creek data.
• Lease names are not acceptable in lieu of geologic field
names. To determine the field name for a particular lease,
contact the EIA-23 Field Coordinator 1-800-879-1470, the
state geologic survey, or conservation commission. If a
field name cannot be determined, report the field name as
unknown.

FCML, Table 1.) List of Authorities for Naming Oil and Gas
Fields) Field names that have come into general acceptance
in an area may be used, unless they have been specifically
altered or replaced by the appropriate naming authority. Also,
field names used strictly by one company must give
precedence to the State recognized name.
Exceptions occur for names of fields located in Texas and
New Mexico, in which States the regulatory agencies
consider geologic reservoirs to be fields. For example, in
Texas, Parker (Pennsylvanian) and Parker (Wolfcamp) are
considered separate fields by the State. In actuality, Parker is
the name of the geologic field and Pennsylvanian and
Wolfcamp are reservoir names of the geologic reservoirs in
the field (by Texas Railroad Commission convention, the
geologic reservoir name appears in parentheses after the
geologic field name). For the purpose of reporting names on
Schedule A of form EIA-23L, only the geologic field name
should be used. In the example above, PARKER would be
entered as the field name, subitem 6, in the field data block of
Schedule A. Some specific conventions include the following:

2. Field Coding Conventions
Field codes are to be entered on Schedule A for all fields
reported. The field names and corresponding six-digit code
are contained in the 2009 FCML. If the field you are reporting
does not appear in the 2009 FCML, enter 999002 for the field
code, but if the field is a Wildcat, enter 999001 for the field
code. Enter the field name and location information.

• Offshore field names usually (but not always) consist of a
basic offshore area name and block number specified by
the U.S. Minerals Management Service. Example: East
Cameron South addition Block 265. If offshore area
names must be abbreviated to fit within 26 characters
allowed, the following standard abbreviations should be
used:

N. LOCATION CODES
The following codes are those specified in the 2009 FCML.

Name

Code

Name

Code

1. Geographic Codes
NORTH
SOUTH
EAST
WEST
BLOCK
ISLAND

N
S
E
W
BLK
IS

NORTH ADDITION
SOUTH ADDITION
EAST ADDITION
WEST ADDITION
SOUTH EXTENSION
EAST EXTENSION

NA
SA
EA
WA
SX
EX

State and geographic codes are to be entered on Schedule A
for all fields reported by respondents and Schedule B if there
is a footnote. The State and geographic subdivision names
and corresponding codes are contained in the 2009 FCML.

2. County Codes
For example, High Island East Addition South Extension
Block A-375 would be HIGH IS EA SX BLK A-375.

County codes are to be entered for all fields reported by
respondents. The county names and corresponding threedigit code are contained in 2009 FCML There are no counties
in Alaska. Census Divisions have been used to locate oil and
gas fields.

Such abbreviations should not be applied to names of
onshore fields (except for non-cardinal compass points such
as NW for northwest or SE for southeast). If an onshore field
name is too long to fit in the allotted space, truncate it on the
right and provide the full name on Schedule B.
• Compass point words used in field names are to be
placed at the end of the field name (i.e. Three Mile Creek
North). Exceptions are made for geographic places, such
as East Texas field of East Texas or East Branch, a field
named for East Branch, Pennsylvania.

12

State and Geographic Subdivision Codes
___________________________________________________________________________________________________
State
Subdivision
State
Subdivision
State
Name and Geographic Subdivisions1
Code
Code
State Name and Geographic Subdivisions1
Code
Code
_______________________________________________________________________________________________________________________________

Michigan.......................................................
MI
Blank
Alaska - South State Offshore2 ...................
AK
05
Minnesota .................................................... MN
Blank
Alaska - South Onshore ..............................
AK
10
Missouri........................................................ MO
Blank
Alaska - North Onshore and Offshore3 .......
AK
50
Mississippi - Onshore .................................. MS
Blank
Alabama - Onshore .....................................
AL
Blank
Mississippi - State Offshore2 ....................... MS
05
Alabama - State Offshore2 ..........................
AL
05
Montana ....................................................... MT
Blank
Arkansas .....................................................
AR
Blank
North Carolina.............................................. NC
Blank
Arizona ........................................................
AZ
Blank
North Dakota................................................ ND
Blank
California - State Offshore2 .........................
CA
05
Nebraska...................................................... NE
Blank
California - San Joaquin Basin Onshore......
CA
10
New Hampshire............................................ NH
Blank
California - Coastal Region Onshore ...........
CA
50
New Jersey .................................................. NJ
Blank
California - Los Angeles Basin Onshore......
CA
90
New Mexico - East ....................................... NM
10
Colorado......................................................
CO
Blank
New Mexico - West ...................................... NM
50
Connecticut .................................................
CT
Blank
Nevada......................................................... NV
Blank
District of Columbia .....................................
DC
Blank
New York ..................................................... NY
Blank
Delaware .....................................................
DE
Blank
Ohio ............................................................ OH
Blank
Federal Offshore - Atlantic...........................
AC
00
Oklahoma..................................................... OK
Blank
Federal Offshore - Gulf of Mexico
Oregon ......................................................... OR
Blank
(Alabama) ...........................................
AL
00
Pennsylvania................................................ PA
Blank
Federal Offshore - Gulf of Mexico
Rhode Island ...............................................
RI
Blank
(Florida) ..............................................
FL
00
South Carolina ............................................. SC
Blank
Federal Offshore - Gulf of Mexico
South Dakota ............................................... SD
Blank
(Louisiana) ..........................................
LA
00
Tennessee ................................................... TN
Blank
Federal Offshore - Gulf of Mexico
Texas - State Offshore2 ............................... TX
05
(Mississippi) ........................................
MS
00
Texas - Railroad Commission District 1 ....... TX
10
Federal Offshore - Gulf of Mexico
Texas - Railroad Commission District 2
(Other Gulf)......................................... OG
00
Onshore .............................................. TX
20
Federal Offshore - Gulf of Mexico
Texas - Railroad Commission District 3
(Texas)................................................
TX
00
Onshore .............................................. TX
30
Federal Offshore - Pacific (Alaska)..............
AK
00
Texas - Railroad Commission District 4
Federal Offshore - Pacific (California) .........
CA
00
Onshore............................................... TX
40
Federal Offshore - Pacific (Oregon).............
OR
00
Texas - Railroad Commission District 5 ....... TX
50
Federal Offshore - Pacific (Washington)...... WA
00
Texas - Railroad Commission District 6 ....... TX
60
Florida - Onshore ........................................
FL
Blank
Texas - Railroad Commission District 7B..... TX
70
Florida - State Offshore2 .............................
FL
05
Texas - Railroad Commission District 7C..... TX
75
Georgia........................................................
GA
Blank
Texas - Railroad Commission District 8 ....... TX
80
Hawaii..........................................................
HI
Blank
Texas - Railroad Commission District 8A..... TX
85
Iowa ............................................................
IA
Blank
Texas - Railroad Commission District 9 ....... TX
90
Idaho ...........................................................
ID
Blank
Texas - Railroad Commission District 10 ..... TX
95
Illinois ..........................................................
IL
Blank
Utah ............................................................ UT
Blank
Indiana.........................................................
IN
Blank
Virginia ......................................................... VA
Blank
Kansas ........................................................
KS
Blank
Vermont ....................................................... VT
Blank
Kentucky......................................................
KY
Blank
Washington .................................................. WA
Blank
Louisiana - South State Offshore2...............
LA
05
Wisconsin..................................................... WI
Blank
Louisiana - South Onshore..........................
LA
10
West Virginia................................................ WV
Blank
Louisiana - North .........................................
LA
50
Massachusetts ............................................
MA
Blank
Wyoming ...................................................... WY
Blank
Maryland...................................................... MD
Blank
Maine...........................................................
ME
Blank
Company Totals ......................................... ZZ
ZZ
___________________________________________________________________________________________________
1Refer to maps for subdivision boundaries in these States: Alaska, California, Louisiana, New Mexico, and Texas.
2If you are not certain whether an offshore field lies in the Federal or the State domain, assume that it lies in the State domain
and indicate this in a footnote in Schedule B.

3Alaska North Onshore and Offshore includes both State and Federal domain.

13

MAPS OF SELECTED STATE SUBDIVISIONS

Alaska Subdivisions and U.S. Geological Survey Quadrangles

Source: After U.S. Geological Survey

14

Subdivisions of California

Source: Energy Information Administration, Office of Oil and Gas.

15

Subdivisions of Louisiana

Source: Energy Information Administration, Office of Oil and Gas

16

Subdivisions of New Mexico

Source: Energy Information Administration, Office of Oil and Gas

17

Subdivisions of Texas

Source: Energy Information Administration, Office of Oil and Gas

18

Western Planning Area, Gulf of Mexico Outer Continental Shelf Region

Source: After Minerals Management Service, U.S. Department of the Interior

19

Central Planning Area, Gulf of Mexico Outer Continental Shelf Region

Source: After Minerals Management Service, U.S. Department of the Interior

20

Eastern Planning Area, Gulf of Mexico Outer Continental Shelf Region

Source: After Minerals Management Service, U.S. Department of the Interior.

21