18 Cfr 260.2

Pt. 260

18 CFR Ch. I (4–1–16 Edition)

the specifications and format contained in Form No. 592, which can be
obtained at the Federal Energy Regulatory Commission, Public Reference
and Files Maintenance Branch, Washington, DC 20426.
(e) Penalty for failure to comply. (1)
Any person who transports gas for others pursuant to Subparts B or G of Part
284 of this chapter and who knowingly
violates the requirements of §§ 358.4 and
358.5, § 250.16, or § 284.13 of this chapter
will be subject, pursuant to sections
311(c), 501, and 504(b)(6) of the Natural
Gas Policy Act of 1978, to a civil penalty, which the Commission may assess, of not more than $5,000 for any
one violation.
(2) For purposes of this paragraph, in
the case of a continuing violation, each
day of the violation will constitute a
separate violation.
[Order 566, 59 FR 32898, June 27, 1994, as
amended by Order 566–A, 59 FR 52904, Oct. 20,
1994; Order 581, 60 FR 53071, Oct. 11, 1996; 61
FR 39068, July 26, 1996; Order 637, 65 FR 10220,
Feb. 25, 2000; Order 2004, 68 FR 69157, Dec. 11,
2003]

PART 260—STATEMENTS AND
REPORTS (SCHEDULES)
Sec.
260.1 FERC Form No. 2, Annual report for
Major natural gas companies.
260.2 FERC Form No. 2–A, Annual report for
Nonmajor natural gas companies.
260.4–260.7 [Reserved]
260.8 System flow diagrams: Format No.
FERC 567.
260.9 Reports by natural gas pipeline companies on service interruptions and damage to facilities.
260.11–260.15 [Reserved]
260.200 Original cost statement of utility
property.
260.300 FERC Form No. 3–Q, Quarterly financial report of electric utilities, licensees, and natural gas companies.
260.400 Cash management programs.
260.401 FERC Form No. 552, Annual Report
of Natural Gas Transactions.

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AUTHORITY: 15 U.S.C. 717–717w, 3301–3432; 42
U.S.C. 7101–7352.
EDITORIAL NOTE: For FEDERAL REGISTER citations affecting forms listed in part 260, see
the List of CFR Sections Affected, which appears in the Finding Aids section of the
printed volume and at www.fdsys.gov.

§ 260.1 FERC Form No. 2, Annual report for Major natural gas companies.
(a) Prescription. The form of Annual
Report of Natural Gas Companies
(Class A and Class B), designated herein as FERC Form No. 2, is prescribed.
(b) Filing requirements. Each natural
gas company, as defined by the Natural
Gas Act (15 U.S.C. 717, et seq.) which is
a major company (a natural gas company whose combined gas transported
or stored for a fee exceed 50 million
Dth in each of the three previous calendar years) must prepare and file with
the Commission, as follows:
(1) The annual report for the year
ending December 2004 must be filed on
April 25, 2005.
(2) The annual report for each year
thereafter must be filed on April 18 of
the subsequent year.
(3) Newly established entities must
use projected data to determine whether FERC Form No. 2 must be filed.
(4) The form must be filed in electronic format only, as indicated in the
general instructions set out in that
form. The format for the electronic filing can be obtained at the Federal Energy Regulatory Commission, Division
of Information Services, Public Reference and Files Maintenance Branch,
Washington, DC 20426. One copy of the
report must be retained by the respondent in its files.
[Order 121, 46 FR 6887, Jan. 22, 1981, as amended by Order 390, 49 FR 32527, Aug. 14, 1984;
Order 493, 53 FR 15030, Apr. 27, 1988; Order 581,
60 FR 53071, Oct. 11, 1995; Order 628, 68 FR 269,
Jan. 3, 2003; 69 FR 9044, Feb. 26, 2004]

§ 260.2 FERC Form No. 2–A, Annual report for Nonmajor natural gas companies.
(a) Prescription. The form of Annual
Report for Nonmajor Natural Gas Companies, designated herein as FERC
Form No. 2—A, is prescribed.
(b) Filing requirements. Each natural
gas company, as defined by the Natural
Gas Act, not meeting the filing threshold for FERC Form No. 2, but having
total gas sales or volume transactions
exceeding 200,000 Dth in each of the
three previous calendar years, must
prepare and file with the Commission,
as follows:

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Federal Energy Regulatory Commission
(1) The annual report for the year
ending December 2004 must be filed on
April 25, 2005.
(2) The annual report for each year
thereafter must be filed on April 18 of
the subsequent year.
(3) Newly established entities must
use projected data to determine whether FERC Form No. 2–A must be filed.
(4) The form must be filed in electronic format only, as indicated in the
General Instructions set out in that
form. The format for the electronic filing can be obtained at the Federal Energy Regulatory Commission, Division
of Information Services, Public Reference and Files Maintenance Branch,
Washington, DC 20426. One copy of the
report must be retained by the respondent in its files.
(Natural Gas Act, as amended, 15 U.S.C. 717–
717w; Natural Gas Policy Act of 1978, 15
U.S.C. 3301–3432; Federal Power Act, as
amended, 16 U.S.C. 792–828c; Department of
Energy Organization Act, 42 U.S.C. 7101–7352;
E.O. 12009, 3 CFR part 142 (1978))
[Order 101, 45 FR 60900, Sept. 15, 1980, as
amended by Order 390, 49 FR 32527, Aug. 14,
1984; Order 493, 53 FR 15031, Apr. 27, 1988;
Order 581, 60 FR 53071, Oct. 11, 1995; Order 628,
68 FR 269, Jan. 3, 2003; 69 FR 9044, Feb. 26,
2004]

§§ 260.4–260.7

[Reserved]

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§ 260.8 System flow diagrams: Format
No. FERC 567.
(a) Each Major natural gas pipeline
company, having a system delivery capacity in excess of 100,000 Mcf per day
(measured at 14.73 p.s.i.a. and 60 °F),
shall file with the Commission by June
1 of each year five (5) copies of a diagram or diagrams reflecting operating
conditions on its main transmission
system during the previous twelve
months ended December 31. For purposes of system peak deliveries, the
heating season overlapping the year’s
end shall be used. Facilities shall be
those installed and in operation on December 31 of the reporting year. All
volumes shall be reported on a uniform
stated pressure and temperature base.
Receipt and delivery point information
required in various exhibits must be labeled with a location point name and
code in accordance with the location
name and code adopted by the pipeline

§ 260.8
in accordance with § 284.13(f) of this
chapter.
(b) The diagram or diagrams shall include the following items of information:
(1) Nominal diameter (inches) of each
pipeline.
(2) Miles of pipeline (to nearest 0.1
mile) between points of intake, delivery, river crossings, storage fields,
crossovers, compressor stations and
connections with other pipeline companies.
(3) Direction of flow in the pipelines.
If direction of flow can be reversed at
compressor stations, so indicate.
(4) Maximum permissible operating
pressure for each pipeline at discharge
side of each compressor station or
other critical point, determined by the
Department of Transportation’s safety
standards.
(5) Total horsepower of compressor
engines installed at each compressor
station.
(6) Designed suction pressure for each
compressor station, p.s.i.g.
(7) Designed discharge pressure for
each station, p.s.i.g.
(8) Maximum volume, Mcf per day
that can be compressed at each compressor station under conditions of suction and discharge set forth in paragraphs (b) (6) and (7) of this section. If
direction of flow affects these factors
provide the information for each direction of flow.
(9) The fuel requirement at each compressor station under conditions described in paragraph (b)(8) of this section.
(10) Pressure in the pipeline at points
of emergency interconnection with
other pipeline companies which can
normally be expected to exist, and the
volume which could be delivered or received at such emergency interconnection points at such pressures. Give the
name of the interconnecting company.
(11) For each storage field, connected
to the system and operated by the respondent pipeline company, the maximum dependable daily and seasonal
withdrawal volumes available under
normal conditions of operation.
(12) Volumes delivered: (i) The average daily volumes delivered at each
takeoff point, (ii) the volumes delivered at each takeoff point on the day of

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