Natural Gas Data Collection Program Package

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

Form Approved
OMB No. 1905-XXXX
Expiration Date: 12/31/20XX

ANNUAL REPORT OF NATURAL AND SUPPLEMENTAL GAS SUPPLY AND DISPOSITION
FORM EIA-176
INSTRUCTIONS
PURPOSE

HOW TO REPORT

The Energy Information Administration (EIA) Form EIA-176,
“Annual Report of Natural and Supplemental Gas Supply and
Disposition,” is designed to collect data on natural, synthetic, and
other supplemental gas supplies, disposition, and certain revenues
by State. The data appear in the EIA publications, Monthly Energy
Review, Natural Gas Annual, and Natural Gas Monthly.

Instructions on where to report via mail, fax, secure file transfer, or
email are printed on Part 2 of Form EIA-176.

REPORTING REQUIREMENT

You may file electronically using Electronic Filing System (EFS)
for Form EIA-176 that can be installed on a personal computer
(PC). If you have any questions, please contact the Electronic Data
Collection Staff on (202) 586-9659.

COPIES OF THE
INSTRUCTIONS

Report must be completed by:
(1)
(2)
(3)
(4)
(5)
(6)

Interstate natural gas pipeline companies,
Intrastate natural gas pipeline companies,
Natural gas distribution companies,
Underground natural gas storage operators,
Synthetic natural gas plant operators,
Field, well, or processing plant operators that deliver natural
gas directly to consumers (including their own industrial
facilities) other than for lease or plant use or processing,
(7) Field, well, or processing plant operators that transport gas to,
across, or from a State border through field or gathering
facilities,
(8) Liquefied natural gas (LNG) storage operators, both peaking
facilities and marine terminals.
A separate report must be completed for each State in which your
company is engaged in one or more of the following activities:
(1) Gas (natural, commingled natural and supplemental gas, or
LNG) was transported utilizing respondent-operated facilities
other than field or gathering lines,
(2) Gas was transported to, from, or across a State border utilizing
respondent-operated field or gathering lines,
(3) Gas was delivered directly to consumers utilizing respondent
operated facilities other than field, well, or plant operators
delivering solely for lease and plant use or processing,
(4) Gas was stored in respondent-operated underground storage
reservoirs, or LNG storage facilities, and/or
(5) Synthetic natural gas was produced in respondent-operated
facilities.
This report is mandatory. A separate report should be filed by, or
for, each company subsidiary or affiliate meeting the filing
requirements that operated separate systems within a State.
However, approval to report on a consolidated basis for a State may
be granted upon request to the EIA at (877) 800-5261.
A State, for the purpose of this report, includes adjacent offshore
Federal Domain areas.

WHEN TO REPORT
st

Form EIA-176 is due March 1 . If an extension is needed call
(877) 800-5261.

SURVEY

FORM

AND

Copies in portable document format (PDF) and spreadsheet format
(XLS) are available on EIA's website at:
www.eia.gov/oil_gas/natural_gas/survey_forms/nat_survey_forms.
html
You can also access the materials by following these steps:
• Go to EIA's website at www.eia.gov.
• Click on the Natural Gas category (this takes you to EIA's
natural gas information page).
• Click on the Survey Forms link located in the reference box in
the lower right corner.
• Select the materials you want.
Files must be saved to your personal computer. Data cannot be
entered interactively on the web site.

SECURE FILE TRANSFER
Forms may be submitted through the Secure File Transfer System.
The secure hypertext transfer protocol (HTTPS) is an industry
standard method to send information over the web using a secure,
encrypted process. All information is protected by 128-bit
encryption to maintain the privacy and confidentiality of
transmitted data. The Secure File Transfer System may be
accessed
through
the
following
web
address:
https://signon.eia.doe.gov/upload/noticeoog.jsp.

GENERAL INSTRUCTIONS
Complete only those Parts and data elements applicable to your
operations. Leave all other spaces blank. No data are to be entered
in the shaded areas or spaces.
All information is to be reported on a calendar year basis. Volumes
are to refer to natural gas physically in your possession (custody
basis).
Revised reports are not required unless actual or corrected data
vary more than plus (+) or minus (-) 4 percent from the data
previously reported.
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SPECIFIC INSTRUCTIONS
PART 1: RESPONDENT IDENTIFICATION
Please provide up-to-date company information.
EIA ID Number: Complete the 10-digit identification number
assigned by EIA. Companies operating in more than one State
should note that a unique number has been assigned for operations
in each State. In the event an identification number has not been
assigned, leave the space blank and contact the EIA at (877) 8005261, a number will then be assigned by the EIA.
Resubmission: Check the box if report is a revised report.
Otherwise, if the report is an original, leave this space blank.
Company Name: Enter the company name.
Operations in (State): Enter the name of the State covered by the
report. A separate report must be submitted for each State for
which your company is required to file.
Contact Information: Enter the current contact information.
PART 3: COMPANY CHARACTERISTICS
Provides information for the four options available for submitting
your completed Form EIA-176: (1) mail; (2) fax; (3) email; and (4)
Secure File Transfer.
A. Type of Operations (Check all that apply). Check all of the
boxes that describe your company’s overall gas operations. This
information will be used to provide aggregates of the data collected
in the survey by type of company. For a description of gas
operations, please reference the “Definitions” section included in
these instructions.
B. Vehicles Powered by Alternative Fuels. Indicate whether your
company fleet includes vehicles that are powered by alternative
fuels. If your company fleet includes vehicles powered by
alternative fuels, enter the number of vehicles that are powered by
alternative fuels. For a list of alternative fuels, please reference the
“Definitions” section included in these instructions.
C. Customer Choice Program. Indicate if your company actively
allows residential and/or commercial customers, regardless of size,
to purchase fuel from an alternative supplier. If yes, indicate the
number of customers in your service territory eligible for such
programs at the end of the calendar year, as well as the number
currently participating at the end of the year. The number of
participants may not necessarily equal the number of transportation
customers listed in Part VI, Line 11, due to measurements taken at
different points in time.
D. Sales/Acquisitions. Indicate whether your company’s service
territory changed due to purchase or sale of any system or part
thereof. For instance, if a municipal system was acquired, indicate
“yes” and identify the name in the comments area and the
transaction date.
PART 4: NATURAL AND SUPPLEMENTAL GAS SUPPLY
FOR THE REPORT STATE
Report the total volumes of natural and supplemental gas physically
produced or received and taken into company-operated storage,
company-operated transportation or company-operated distribution
facilities located in the report State. Volumes are to be reported on
a physical possession basis regardless of ownership.

1.0 If you are a producer, report production within the report
State of
1.1 Natural gas: Report gross production, after lease
separation, (including royalty and overriding royalty interest)
taken directly into your system at the wellhead, field or
tailgate of a processing plant, whether produced from wells
operated by your company or by others.
Please report vented & flared volumes and extraction loss
volumes on Line 18.4.
1.2 Synthetic natural gas (SNG): Report the volume of
synthetic natural gas produced in the plant or plants operated
by your company. Synthetic natural gas, also referred to as
substitute natural gas, is a manufactured product, chemically
similar in most respects to natural gas, resulting from the
conversion or reforming of coal or petroleum hydrocarbons
which may easily be substituted for, or interchanged with,
pipeline quality natural gas.
2.0 If you are a storage operator, report operations within
the report State: Report the total volume, regardless of
ownership, of underground storage withdrawals (2.1), liquefied
natural gas (LNG) storage withdrawals (2.2), and above ground
storage withdrawals (2.3).
For data reported on Line 2.1, include a corresponding entry on
Part 6 (disposition), most likely on Line 18.2, so that the net
value of your storage activity’s supply and disposition is zero.
Please note, for Line 2.2 LNG storage withdrawals – LNG import
and export marine terminals should not report withdrawals of
natural gas during the course of routine operations for handling
imports and not held in storage for future use.
Please see the section of these instructions titled “LNG Marine
Terminals Reporting” for further guidance.
3.0 If you are an interstate pipeline company or other company
receiving physical custody at State lines or U.S. borders, report
receipts: Report the name of the company, the adjacent State or
Country from which the gas was received, and the volume of gas
received at the State line or U.S. border. For liquefied natural gas
(LNG) received by ship, rail, barge, or truck, consider the receiving
terminal as a point on the State line or U.S. border, report the name of
the State or Country from which the LNG was shipped, and describe
the transaction by footnote on Part 7.
4.0 If you are a distributor, report receipts at city gates within
the report State: Report gas volumes received at the city gate for
delivery to end-use customers.
5.0 Report any other receipts of natural gas within the report
State: Report the volume of other receipts within the report State if
the gas was delivered to a point on your company’s system and not
previously reported in questions 1.0 through 4.0 above. Include
volumes of both natural gas, liquefied natural gas, and synthetic
natural gas.
6.0 Supplemental gaseous fuel supplies (Specify type): Report
sources of supplemental gas supply received or introduced into
your system and the volume(s) of each. Supplemental gas includes
any gaseous substance introduced into or commingled with natural
gas that increases the volume available for disposition. Such
substances include, but are not limited to, propane-air, refinery gas,
coke oven gas, still gas, manufactured gas, biomass gas, or air or
inerts added for Btu stabilization.

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PART 5: LIQUEFIED NATURAL GAS (LNG) STORAGE
INVENTORY
8.0 Inventory of LNG (gaseous equivalent) in storage as of
December 31 of report year. Report inventory of LNG
(gaseous equivalent) in storage as of December 31 of the report
year.

PART 6: NATURAL AND SUPPLEMENTAL
DISPOSITION FOR THE REPORT STATE

GAS

Report in Part 6, the total volumes of and where indicated, the
revenue (including taxes) from natural and supplemental gas
delivered to others, consumed, or stored in company-operated
facilities, or otherwise disposed of within the State or delivered to
bordering States or to foreign countries.
The type of disposition (delivered, consumed, stored, etc.) is to be
determined based upon the physical possession of the gas within
your company-operated production, transportation, storage, or
distribution facilities at the point of disposition.
Revenue information is to be reported only for volumes sold and
delivered directly to the end-use customers and is to be gross
revenues including any and all demand charges, commodity
charges, taxes, surcharges, adjustments or other charges billed for
gas delivered. Any gains or losses associated with financial hedges
are to be included. Please indicate by footnote if taxes are not
included in revenue figures. All revenue values are to be rounded to
the nearest whole number of dollars.
The average number of consumers during the year, for the purpose
of this report, is the sum of the number of consumers attached to
your system at the end of each month divided by twelve.
Each dwelling, building, plant, establishment, or location is to be
counted as a separate consumer, for the purpose of this report,
whether or not centrally billed and whether or not provided with
more than one type of service, e.g., firm and interruptible service.
Consumers should be classified by category in accordance with the
definitions provided below.
Multiple-use or combination
consumers such as apartment buildings with commercial
establishments, retail stores with attached dwellings, or industrial
plants with on-site office space or buildings served from a common
meter are to be classified based upon the predominate volumetric
usage. If certain categories, e.g., residential and commercial, are
carried on a combined basis in your accounts, please provide your
best estimate of the information for each category separately. If you
have no reasonable basis for categorizing the estimates, enter the
information as “Other” and describe in a footnote in Part 7.
Deliveries directly to end-use consumers are to be reported based
upon the following definitions:
Residential: An energy-consuming sector that consists of living
quarters for private households. Common uses of energy associated
with this sector include space heating, water heating, and cooking.
The residential sector includes mobile homes and apartment
buildings [whether privately owned or publicly subsidized] and
excludes institutional living quarters.
Commercial: An energy-consuming sector that consists of serviceproviding facilities and equipment of businesses; Federal, State,
and local governments; and other private and public organizations,
such as religious, social, or fraternal groups. The commercial sector
includes institutional living quarters. Common uses of energy
associated with this sector include space heating, water heating,
cooking, and running a wide variety of other equipment. Note: This

sector includes generators that produce electricity and/or useful
thermal output primarily to support the activities of the abovementioned commercial establishments. Vehicle fuel and company
use are not to be included in the commercial sector.
Industrial: An energy-consuming sector that consists of all
facilities and equipment used for producing, processing, or
assembling goods. The industrial sector encompasses the following
types of activity: manufacturing; agriculture, forestry, and fisheries;
mining, including oil and gas extraction; and construction. Overall
energy use in this sector is largely for process heat and powering
machinery, with lesser amounts used for facility heating. Natural
gas is also used as raw material inputs to manufactured products.
Note: This sector includes generators that produce electricity and/or
useful thermal output primarily to support the above-mentioned
industrial activities.
Electric power: An energy-consuming sector that consists of
electricity-only plants and combined heat and power (CHP) plants,
whose primary business is to sell electricity, or electricity and heat,
to the public.
Vehicle fuel: Natural gas, either compressed (CNG) or liquefied
(LNG), that is consumed by motor vehicles.
Other (not included in above categories) Specify type: This
category is only to be used for service provided directly to
consumers for which you are uncertain of the correct category from
among residential, commercial, industrial, and electric power.
Please use the space provided to specify the type of delivery you
report here.
9.0 Heat content of gas delivered to consumers (Btu/cf): The
average heat content (Btu) should be computed by summing the
total Btu delivered each month (volume delivered directly to
consumers multiplied by average Btu content per unit volume) and
dividing by the total volume delivered directly to consumers during
that month. The average Btu content for each month should be that
used for billing purposes whether billing was on a therm (100,000
Btu) or decatherm (1,000,000 Btu) basis. The value for heat content
is expected to be in the range of 900 to 1200 Btu/cu. ft.
If billing was on a volumetric basis and your company did not
measure the Btu content, contact your supplier for the information.
If the Btu content was not measured at any point, enter a "U" for
Unknown.
10.0 Deliveries of natural gas that you own to end-use
consumers within the report State: Report the average number
of consumers served directly from your facilities during the year,
the volumes sold and delivered to such consumers, and the
revenues received in the appropriate category. Include deliveries
directly to your company-owned commercial, industrial or electric
power facilities.
How to Report on Type of Consumer on Form EIA-176
Master-metered apartments
Residential
Mobile homes
Residential
Multi-family dwellings, individually metered
Residential
Single-family dwellings
Residential
Churches and hospitals
Commercial
Government (local, State and Federal) agencies Commercial
Hotels
Commercial
Non-manufacturing military installations
Commercial
Restaurants
Commercial
Retail stores
Commercial
Schools and universities
Commercial
Wholesale stores
Commercial
Agriculture, forestry and fisheries
Industrial
Mining (including oil and gas extraction)
Industrial
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Manufacturing
Regulated electric utilities
Nonregulated electricity generators

Industrial
Electric
Power
Electric
Power

The size of an operation does not affect consumer classification:
1.
2.

Large commercial operations should be classified as
commercial, not industrial.
Small industrial operations should be classified as industrial,
not commercial.

11.0 Deliveries of natural gas that you do not own to end-use
consumers within the report State: Report the average number of
consumers served directly from your facilities, volumes delivered
to and revenues received for transportation of natural gas to those
consumers for each end-use consumer category.
Note: Pipeline companies are not required to provide revenue data
for deliveries of gas that they do not own.

17.0 Losses from leaks, damage, accidents, migration and/or
blow down within the report State: Report known volumes as a
result of losses from leaks, damage, accidents, migration and/or
blow down within the report State these events took place. Indicate
known and estimated losses from leaks encountered as a natural
consequence of distribution activites. Volume may represent your
best estimate.
18.0 Other disposition within report State (not included above):
Report any disposition of gas not included in lines 10.1 through
17.0. Report disposition to distribution companies (18.1), other
pipelines, (18.2), storage operators (18.3), and other (specify type)
(18.4) within the report State. Please provide estimates of the
volume involved, if not measured. If insufficient space is provided,
continue on Part 7.
20.0 Difference between Supply (+) or Disposition (-) (Part 4
line 7.0 and Part 6 line 19.0): A positive entry indicates supply in
excess of accounted for disposition and a negative entry (denoted
by a minus sign preceding the entry) indicates accounted for
disposition in excess of supply reported.

12.0 Natural gas consumed in your operations: Report the
volume of gas consumed as fuel in your company's operations:
Space heat of your own facilities (12.1), new pipeline fill (12.2),
pipeline distribution or storage compressor use (12.3), and other
(specify type) (12.4) within the report State. Volume may represent
your best estimate. Interdepartmental volumes used to fuel
company-owned generation facilities should be classified as
electric power.

PART 7: FOOTNOTES

13.0 If you are a storage operator, report operations within
the State: Report the total volume added, regardless of
ownership, to underground storage (including new fields) (13.1),
liquefied natural gas (LNG) storage additions (13.2), and above
ground storage additions (13.3) operated by your company within
the report State.

Liquefied natural gas (LNG) terminals should report the origin of
natural gas imported, along with its ultimate destination, whether it
is delivered to another pipeline, held in inventory, exported to a
foreign country, or consumed during operations.

For data reported on Line 13.1, include a corresponding entry on
Part 4 (supply), most likely on Line 5.0, so that the net value of
your storage activity’s supply and disposition is zero.
Please note, for Line 13.2 LNG storage injections - LNG import
and export marine terminals should not report injections of LNG
during the course of routine operations for handling imports and
not held in storage for future use.

The Part 7 footnotes sheet is to be used, if needed, to provide
explanatory notes for data reported on Parts 1 through 6. The
footnotes will become a permanent part of the computer data file
and thereby serve as an integral part of your report.

LNG MARINE TERMINALS REPORTING

It is expected that volumes will be reported by LNG terminals on
Lines 3.0 (imports), 7.0 (total supply), 8.0 (inventory), 12.0
(volumes consumed in operations), 14.0 (exports to other countries
or interstate pipelines), 18.0 (deliveries within the State), 19.0 (total
supply) and 20.0 (unaccounted for gas). See Figure 1 below for a
graphic depiction showing specifically where gas should be
recorded on the Form EIA-176.
Imports
Line 3.0

Please see the guide for LNG marine terminals for further
guidance.
14.0 If you are an interstate pipeline company or other
company moving gas across or to State lines or U.S. borders,
report volumes transported: Report the name of the company,
the adjacent State or Country to which the gas was delivered, and
the volume of gas delivered at the State line or U.S. border. For
liquefied natural gas sales shipped by ship, truck, rail, or barge,
consider the loading terminal a point on the State line or U.S.
border. Report the name of the State or Country to which the LNG
was delivered, and describe the transaction by footnote in Part 7.
15.0 If you are a producer, report lease use: Report total volume
of gas used in your company’s well, field, and/or lease operations.
16.0 Returned to oil and/or gas reservoirs, used for
repressuring, reinjection (Reported by producers only): Report
the volume of gas delivered directly from your system to oil or gas
fields located within the report State for repressuring, pressure
maintenance, and/or cycling operations.

Distributed
within the
State
Line 18.0

NG Facility Gas consumed
during operations
(space heat,
compressor use,
etc.)
Line 12.0

Year-end
Storage
Inventory
Line 8.0

Figure 1
LNG Reporting

Page 4

Exports
Line 14.0

Reported LNG Inventory:

Marine terminal: Point of import or export for tankers carrying
liquefied natural gas (LNG).

Line 8.0 Volume = Line 8.0 Volume + Line 3.0 Volume
(Current Year)

Line 14.0 Volume
(Current Year)

(Prior Year)

Line 18.0 Volume
(Current Year)

(Current Year)

Mcf: 1,000 cubic feet.

Line 12.0 Volume
(Current Year)

DEFINITIONS
Alternative fuel: Alternative fuels, for transportation applications
such as hybrids, include the following: methanol, denatured
ethanol, and other alcohols, fuel mixtures containing 85 percent or
more by volume of methanol, denatured ethanol, and other alcohols
with gasoline or other fuels -- natural gas, liquefied petroleum gas
(propane), hydrogen, coal-derived liquid fuels, fuels (other than
alcohol) derived from biological materials (biofuels such as soy
diesel fuel), electricity (including electricity from solar energy.)
The term "alternative fuel" does not include alcohol or other
blended portions of primarily petroleum-based fuels used as
oxygenates or extenders, i.e., MTBE, ETBE, other ethers, and the
10-percent ethanol portion of gasohol.

Natural Gas: A gaseous mixture of hydrocarbon compounds, the
primary one being methane. Also see Dry Natural Gas and Wet
Natural Gas.
Offshore: That geographic area that lies seaward of the coastline.
In general, the coastline is the line of ordinary low water along with
that portion of the coast that is in direct contact with the open sea or
the line marking the seaward limit of inland water. If a state agency
uses a different basis for classifying onshore and offshore areas, the
state classification should be used (e.g., Cook Inlet in Alaska is
classified as offshore; for Louisiana, the coastline is defined as the
Chapman Line, as modified by subsequent adjudication).
Operator: The company responsible for the management and dayto-day operations of natural gas production, gathering, treating,
processing, transportation, storage, distribution facilities, and/or a
synthetic natural gas plant.

Consumer: Any individually-metered dwelling, building,
establishment, or location using natural gas, synthetic natural gas,
and/or mixtures of natural and supplemental gas for feedstock or as
fuel for any purpose other than in oil or gas lease operations;
natural gas treating or processing plants; or pipeline, distribution, or
storage compressors.

Pipeline: A continuous pipe conduit, complete with such
equipment as valves, compressor stations, communication systems,
and meters for transporting natural and/or supplemental gas from
one point to another, usually from a point on or beyond the
producing field or processing plant to another pipeline or to points
of utilization. Also refers to a company operating such facilities.

Customer choice: The right of customers to purchase energy from
a supplier other than their traditional supplier or from more than
one seller in the retail market.

Producer: A company engaged in the production and sale of
natural gas from gas or oil wells with delivery generally at a point
at or near the wellhead, the field, or the tailgate of a gas processing
plant. For the purpose of company classification, a company
primarily engaged in the exploration for, development of, and/or
production of oil and/or natural gas.

Delivered: The physical transfer of natural, synthetic, and/or
supplemental gas from facilities operated by the responding
company to facilities operated by others or to consumers.
Disposition: The removal of natural, synthetic, and/or
supplemental gas, or any components or gaseous mixtures
contained therein, from the responding company's facilities within
the report State by any means or for any purpose including the
transportation of such gas out of the report State.
Dry natural gas: Natural gas which remains after: 1) the
liquefiable hydrocarbon portion has been removed from the gas
stream (i.e., gas after lease, field, and/or plant separation); and 2)
any volumes of nonhydrocarbon gases have been removed where
they occur in sufficient quantity to render the gas unmarketable.
Note: Dry natural gas is also known as consumer-grade natural gas.
The parameters for measurement are cubic feet at 60 degrees
Fahrenheit and 14.73 pounds per square inch absolute.
Gatherer: A company primarily engaged in the gathering of natural
gas from well or field lines for delivery, for a fee, to a natural gas
processing plant or central point. Gathering companies may also
provide compression, dehydration, and/or treating services.
Lease Operations: Any well, lease, or field operations related to
the exploration for or production of natural gas prior to delivery for
processing or transportation out of the field. Gas used in lease
operations includes usage such as drilling operations, heaters,
dehydrators, field compressors, and net used for gas lift.
Liquefied Natural Gas (LNG): Natural gas (primarily methane)
that has been liquefied by reducing its temperature to –260º
Fahrenheit at atmospheric pressure.

Received: Gas physically transferred into the responding
company’s transportation, storage, and/or distribution facilities.
Supplemental Gas: Any gaseous substance introduced into or
commingled with natural gas that increases the volume available
for disposition. Such substances include, but are not limited to,
propane-air, refinery gas, coke oven gas, still gas, manufactured
gas, biomass gas, or air or inerts added for Btu stabilization.
Supply: Natural, synthetic, and supplemental gas produced within,
introduced into, and/or received into facilities operated by the
responding company within the report State for disposition during
the report year.
Synthetic Natural Gas (SNG) (Also referred to as substitute
natural gas): A manufactured product, chemically similar in most
respects to natural gas, resulting from the conversion or reforming
of hydrocarbons that may easily be substituted for or interchanged
with pipeline-quality natural gas.
Underground Storage: The storage of natural gas in underground
reservoirs at a different location from which it was produced.
Wet natural gas: A mixture of hydrocarbon compounds and small
quantities of various nonhydrocarbons 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
nonhydrocarbon gases that may be present in reservoir natural gas are
water vapor, carbon dioxide, hydrogen sulfide, nitrogen and trace

Page 5

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.

DISCLOSURE OF INFORMATION
Information reported on Form EIA-176 is considered public
information and may be publicly released in company or
individually identifiable form.

SANCTIONS
The timely submission of Form EIA-176 by those required to
report is mandatory under Section 13(b) of the Federal Energy
Administration Act of 1974 (FEA ACT) (Public Law 93 275), as
amended. Failure to respond may result in a civil penalty of not
more than $2,750 each day for each violation, or a fine of not more
than $5,000 each day for each willful violation. The government
may bring a civil action to prohibit reporting violations, which may

result in a temporary restraining order or a preliminary or
permanent injunction without bond. In such civil action, the court
may also issue mandatory injunction commanding any person to
comply with these reporting requirements.

FILING FORMS WITH FEDERAL
GOVERNMENT AND ESTIMATED
REPORTING BURDEN
Respondents are not required to file or reply to any Federal collection
of information unless it has a valid OMB control number. Public
reporting burden for this collection of information is estimated to
average 12 hours per response, including the time of reviewing
instructions, searching existing data sources, gathering and maintaining
the data needed, and completing and reviewing the collection of
information. Send comments regarding this burden estimate or any
other aspect of this collection of information including suggestions for
reducing this burden to: Energy Information Administration, Office of
Survey Development and Statistical Integration, EI-21, 1000
Independence Avenue, S.W., Washington, DC 20585; and to the Office
of Information and Regulatory Affairs, Office of Management and
Budget, Washington, DC 20503.

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