15 U.S.C. 717-717w, 3301-3432; 42 U.S.C. 7101-7352.
When cancelling an entire tariff or an entire rate schedule, the notice of cancellation as set forth below must be filed as a revised tariff sheet superseding the first tariff sheet in the sequence of tariff sheets containing the tariff or part of the tariff being cancelled. When cancelling an individual tariff sheet, the tariff sheet should be designated as reserved for future use.
Notice is hereby given that effective __________ (date) FERC Gas Tariff of __________ (Name of Company) is to be cancelled.
Notice is hereby given that effective __________ (date) Rate Schedule __________ constituting __________ Sheet(s) No.(s) __________ of the FERC Gas Tariff of __________ (Name of Company) is to be cancelled.
Notice is hereby given that effective the _____ day of __________, ___, the contract with __________, (Name of customer or customers) dated __________ and relating to service under rate schedules(s) __________ (Here identify the rate schedule(s), giving sheet numbers in the Tariff) is to be __________ (Specify whether it automatically terminates by its terms or is to be canceled by action of the parties)
1. Name of applicant (indicate whether individual, corporation or municipality).
2. Address.
3. Name, title, mailing address, and telephone number of person to be contacted concerning the application.
4. Name of natural gas company from whom service is desired.
5. Are you now rendering gas service? If so, briefly describe operations.
6. Nature of service sought, giving a brief description of proposal, including location of community, population, number of residences and kind of service sought and to be rendered, showing:
(a) Is this an initial connection with the pipe line, or is it an extension or improvement of existing facilities?
(b) Estimate of maximum day requirements for residential, commercial and industrial customers for each of the first three years of proposed operations (Mcf at 14.73 psia), and how the estimates were derived;
(c) Estimate of annual requirements for residential, commercial and industrial customers for each of the first three years of proposed operations (Mcf at 14.73 psia), and how the estimates were derived.
7. Do you have or do you need a franchise to render the proposed service? If you have filed an application for such a franchise, with whom was it filed and what action has been taken on it?
8. Do you have or do you need a state certificate approving the proposed distribution system project? If you have filed an application for such a certificate, with whom was it filed and what action has been taken on it?
9. When do you propose to start construction and when do you estimate it will be completed? When do you propose to start selling gas?
10. How much are the facilities expected to cost? Show separately the estimated cost of the distribution system, the connecting supply lines, legal fees, financing fees and engineering fees, and briefly state how the estimates were derived.
11. Have you used the services of an engineering consultant? If so, the consultant should state his experience in the design of distribution systems, cost data of systems now in service compared with his initial estimates, and the actual rate at which new customers were attached in the new distribution systems.
12. How do you propose to finance the proposed facilities? Submit evidence that the money will be available. (This evidence need not be submitted if you have a state certificate for your project.)
13. For each of the first three years of operation of the proposed facilities, show (a) the estimated gross annual revenues for the natural gas estimated to be sold to residential, commercial and industrial customers as shown in item 6(c) and the rates you propose to charge, and (b) the cost of gas purchased by you (state the rate to be paid to the pipeline supplier and the pipeline's rate schedule under which you will purchase said gas), other operating and maintenance expenses and operating revenue deductions, and (c) the net operating revenues. If you have received a certificate of public convenience and necessity issued by a local regulatory commission, it may be submitted in lieu of this requirement.
14. Municipalities should submit a bond amortization and interest schedule for the life of the bond issue related to the project and computation of the average debt service coverage ratio over the life of the issue. State briefly how all estimates were derived. Exhibits to be furnished:
(a) Location, length and size of your transmission lines;
(b) Location and size (related horsepower) of your transmission compressor stations (if any);
(c) Location and designation of each point of connection of your proposed transmission facilities with proposed pipeline supplier;
(d) And if known, location, length and size of facilities to be installed by the proposed supplier.
(a)
(b)
(1) The procedures used to address and resolve complaints by shippers and potential shippers including a provision that the pipeline will respond within 48 hours and in writing within 30 days to such complaints.
(2) [Reserved]
(c)
(2) The current log of allocation data for marketing affiliates must be posted on the pipeline's Internet Web site, operated pursuant to § 284.12 of this chapter. The posting must conform with the requirements of § 284.12 of this chapter and the pipeline's tariff requirements relating to Internet Web sites. Access to the information must be provided using the same protocols and procedures used for the pipeline's Internet Web site.
(3) The log of affiliate and non-affiliate information must be provided to the Commission upon request and must be made available to the public under Subpart D of Part 385 of this chapter. When requested by the Commission, the information must be provided, within a reasonable time, according to 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.
(d)
(2) The discount information must be made available to the Commission upon request and to the public under Subpart D of Part 385 of this chapter. When requested by the Commission, the information must be provided, within a reasonable time, according to 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)
(2) For purposes of this paragraph, in the case of a continuing violation, each
15 U.S.C. 717-717w, 3301-3432; 42 U.S.C. 7101-7352.
For
(a)
(b)
(a)
(b)
(a) This form, which is applicable to natural gas companies designated herein, is designed to obtain on a quarterly basis monthly information concerning selected revenues and associated quantities.
(b)(1)
(2)
(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.
(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 maximum coincidental delivery, and
(13) The average daily volume received at each intake point to the transmission pipeline system.
(14) The volume received into the transmission pipeline system at each intake point on the day of maximum coincidental delivery.
(15) The information required by paragraphs (b)(12), (13) and (14), of this section may be furnished in tabular form, or by reference to FERC Form No. 2, providing, that the information is suitably keyed to the diagram by appropriate identifying symbol or number.
(a) Every natural gas pipeline company shall report to the Federal Energy Regulatory Commission (Commission) serious interruptions of service to any wholesale customer involving facilities operated under certificate authorization from the Commission. Such serious interruptions of service shall include interruptions of service to communities, major Government installations and large industrial plants outside of communities or any other interruptions which are significant in the judgment of the pipeline company. Interruptible service interrupted in accordance with the provisions of filed tariffs, interruptions of service resulting from planned maintenance or construction and interruptions of service of less than 3-hours duration need not be reported.
(b) Natural gas pipeline companies must report such interruptions to service by any electronic means, including facsimile transmission or telegraph, to the Director, Division of Pipeline Certificates, Office of Energy Projects, Federal Energy Regulatory Commission, Washington, DC 20426 (FAX: (202) 208-2853), at the earliest feasible time following such interruption to service, and must state briefly:
(1) The location of the interruption,
(2) The time of the interruption,
(3) The customers affected by the interruption, and
(4) Emergency actions taken to maintain service.
(c) If so directed by the Commission or the Director, Division of Pipeline Certificates, the company must provide any supplemental information so as to provide a full report of the circumstances surrounding the occurrence.
(d) Natural gas pipeline companies shall furnish to the Commission within 20 days of each interruption to service involving failure of facilities on any part of the pipeline system operated under certificate authorization from the Commission a copy of such failure reports as required by the Department of Transportation reporting requirement under the Natural Gas Pipeline Safety Act of 1968.
(e) Copies of the telegraphic or facsimile report on interruption of service must be sent to the State commission in those States where service has been or might be affected.
Any natural gas company becoming subject to the jurisdiction of the Commission shall file, insofar as applicable, the following statements properly sworn to by the officer in responsible charge of their compilation:
Statement A showing the origin and development of the company, including, particularly, a description (giving names of parties and dates) of each consolidation and merger to which the company, or a predecessor, was a party and each acquisition of a gas operating unit or system. Any affiliation existing between the parties shall be stated.
Statement B showing for each acquisition of a gas operating unit or system by the reporting company or any of its predecessors:
If the depreciation, retirement, or amortization reserve was adjusted as of the date of acquisition and in connection therewith, a full disclosure of the pertinent facts shall be made.
The amount to be included in account 114, Gas Plant Acquisition Adjustments, shall be subdivided so as to show the amounts applicable to (a) gas plant in service, (b) gas plant leased to others, and (c) gas plant held for future use.
The procedure followed in determining the original cost of the gas plant acquired as operating units or systems shall be described in sufficient detail so as to permit a clear understanding of the nature of the investigations and analyses which were made for that purpose.
Where estimates are used in arriving at original cost or the amount to be included in account 114, a full disclosure of the method and underlying facts shall be given. The proportion of the original cost of each acquisition which has been determined from actual recorded costs and the proportion estimated shall be shown for each functional class of plant. In addition there shall be furnished in respect to each predecessor or vendor company for which complete construction costs are not available, a description of such plant records as are available, including the years covered thereby.
Statement C showing any amounts arrived at by appraisals in the gas plant accounts (and not eliminated) in lieu of cost to the reporting company. This statement should describe the appraisal and give the complete journal entry at the time the appraisal was originally recorded. If the entry had the effect of appreciating or writing up the gas plant account, the amount of the appreciation or writeup should be traced, by proper description and explanation of changes, from the date recorded through the end of the calendar year prior to the year in which the filing is made.
Statement D showing in detail gas plant as classified in the books of account immediately prior to reclassification in accordance with the Uniform System of Accounts, including, under appropriate descriptive headings, any unclassified amounts applicable jointly to the gas department and other departments of the utility.
Statement E showing the adjustments necessary to state accounts 101, 103-107, 114, and 116, and amount of common utility plant includible in account 118, as prescribed in the Uniform System of Accounts.
Statement F showing gas plant classified according to the accounts prescribed in the Uniform System of Accounts, and showing also the amount includible in account 116, Other Gas Plant Adjustments, and the amount of common utility plant includible in account 118, Other Utility Plant.
Statement G showing a comparative balance sheet reflecting the accounts and amounts appearing in the books before the adjusting entries have been made and after such entries shall have been made. The balance sheet shall be classified by the accounts set forth in the Uniform System of Accounts Prescribed for Natural Gas Companies.
Statement H giving a suggested plan for depreciating, amortizing, or otherwise disposing of, in whole or in part, the amounts includible in account 114, Gas Plant Acquisition Adjustments, and account 116, Other Gas Plant Adjustments.
Statement I furnishing the following statistical information relative to gas plant:
Show separately for each producing plant the name and location of plant, date of original construction, type of plant (whether coal gas, coke ovens, water gas, etc.), rated 24-hour capacity in Mcf of each unit and of the total plant, and date of installation of each unit installed after original construction. Show also the original cost according to the System of Accounts for each plant, by accounts 304 to 319, inclusive.
For each “field” includible in account 101, Gas Plant in Service, furnish the number of acres each of gas producing lands owned, of gas producing lands leased by the company, and of land on which gas rights only are owned, as included in accounts 325.1, 325.2,
For each “field” state number of feet of each size pipe used in field gathering lines.
For each “field” state number of wells included in accounts 330 and 331 segregated to show the number of wells on each type of producing lands classified under accounts 325.1, 325.2, 325.3.
When pumping or compressing plants exist within the production plant, include the same information as that requested for compressor stations under transmission plant.
State type and character of purification equipment and residual refining equipment included in accounts 336 and 337, respectively.
Show the original cost according to the System of Accounts for natural gas production plant by each “field” and by accounts 325.1 to 340.
Show separately for each location the name of plant, date of construction, type and total capacity (Mcf) of each gas holder. State also the original cost according to the System of Accounts for each location, by accounts 350.1 to 351, inclusive.
If depleted gas fields are being repressured, the statements furnished shall reflect the number of acres involved and the original cost according to the System of Accounts (accounts 350.1 to 351, inclusive).
State the number of feet of each size of main.
State separately for each compressor boosting station the name of plant, location, date of original construction, rated capacity, type and character of power unit, and rated capacity and type of compressor units. Also state the capacity, type, and date of installation of each additional power or compressor unit. Show for each station the original cost according to the System of Accounts by accounts 365.1, 365.2, 366, 368, and 369.
State number of feet of each size of main and the number of active meters, house regulators, and services. Give a general description of the district regulators and number, by sizes.
Where pumping or compressor stations exist within the distribution plant, include the same information requested for similar stations under transmission plant.
Describe the principal structures and improvements.
State the number and type of transportation vehicles and appurtenant equipment.
Give a description of store, shop, and laboratory equipment and miscellaneous equipment.
Furnish maps, drawn to scale, upon which indicate transmission mains, location of production plants (artificial and natural), producing and nonproducing leaseholds (indicating thereon producing wells, dry holes and depleted wells), gathering systems, booster and compressor stations, communities served (noting as to wholesale or retail), and large industrial consumers. Where gas is purchased from or sold to other gas utilities, indicate location of measuring stations or gates. If scale maps are not available, furnish sketch maps upon which should be indicated approximate distances between the locations above specified.