Compilation of Rules and Regulations of the State of Georgia › Department 515 - RULES OF GEORGIA PUBLIC SERVICE COMMISSION › Chapter 515-7 - GAS UTILITIES › Subject 515-7-2 - GAS SUPPLY PLANS AND GAS COST ADJUSTMENT FACTORS › Rule 515-7-2-.04 - Minimum Filing Requirements

Current through Rules and Regulations filed through June 27, 2024
(1) On or before August 1 of each year, each
				Utility shall file with the Commission its Gas Supply Plan for the following
				Recovery Year. Such filing shall be in addition to any compliance filing the
				Commission may require for the current Recovery Year. The Utility shall include
				with such filing the Adjustment Factors it proposes for recovering its
				Purchased Gas Costs during such following Recovery Year, together with the
				calculation that produced such factors.
(2) As part of its annual gas Supply Plan and
				Adjustment Factor filing, each Utility shall include the following as minimum
				filing requirements:
(a) A five year
				forecast. This forecast need not be in the same detail as the Recovery Year
				forecast. Nevertheless, there must be sufficient information in this forecast
				to enable the Commission to evaluate the reasonableness of the Utility's
				long-term contracts and the effectiveness of any IRP applicable to the
				Utility.
(b) A summary of the
				impact of any IRP on the Supply Plan. In view of the relative importance of
				capacity costs to the Utility's Adjustment Factor, the emphasis of this section
				of the Supply Plan shall reflect the success of reducing peak load requirements
				and improving load factors.
(c) The
				Utility's most recent 12-month actual data pertaining to requirements and gas
				supply costs, together with an explanation of how such data support the
				reasonableness of the Utility's forecast for the Recovery Year.
Actual data shall include the following:
1. Actual firm and interruptible sales and
				transportation volumes by rate schedule or customer class.
2. For the Utility's most recent peak day, a
				summary of:
(i) The gas supply, storage, and
				transportation options in the applicable Supply Plan that were available and
				utilized; and
(ii) The actual
				throughput to firm and interruptible customers, which in the case of firm
				customers shall be broken down by rate schedule or customer type, and in the
				case of interruptible customers shall be broken down by sales and
				transportation volumes.
3. A complete history of the Utility's
				capacity release and acquisition activity during the historic period, including
				for each transaction:
(i) The applicable
				pipeline, quantity, price, release period, and revenues or costs;
(ii) The maximum lawful rate for capacity
				release on the pipeline;
(iii)
				Whether recall conditions were placed on the release and whether the capacity
				was recalled prior to the expiration of the release period;
(iv) Whether the capacity release had been
				prearranged at a price other than the maximum lawful price and had not been
				subject to bid; and
(v) Whether the
				capacity release had been listed on the pipeline's bulletin board.
4. The utilization of all firm
				capacity and all contracted supply the Utility purchased from pipelines
				individually and well-head purchases in the aggregate. The pipeline information
				shall include data separately stated for all firm transportation and storage
				contracts.
5. End-of-month storage
				level by storage service.
(d) A Gas Supply Plan and Adjustment Factor
				for the Recovery Year, which shall consist of at least the following:
1. For the Utility's Gas Supply Plan design
				day, monthly and annual requirements:
(i)
				Detailed description of forecast methodology(ies);
(ii) Level of projected requirements of firm
				and interruptible customers, which in the case of firm customers shall be
				broken down by rate schedule or customer class, and in the case of
				interruptible customers shall be broken down by sales and transportation
				volumes;
(iii) Supply options
				selected to meet requirements; and
(iv) Projected utilization of supply options
				selected to meet requirements.
2. Summary of all individual contracts with
				interstate pipelines, gas suppliers, or any other party whose contract, or
				purchase agreement, affects the Utility's Gas Supply Plan and Adjustment
				Factor. At a minimum, summaries will include: parties, terms, volumes (annual,
				seasonal, daily and minimum purchases requirement), prices and rates, and
				description of all services provided. Summaries of storage services shall
				include a description of the method of transportation to and from storage, and
				whether transportation services are included in the contracts with the storage
				services.
Exceptions to this filing requirement are:
(i) Short term (
31
days or
				less) gas supply contracts; and
(ii) Contracts that contain "Trade Secret"
				documents.
(iii) With respect to
				the "Trade Secret" contracts, the Utility must state the number of "Trade
				Secret" contracts, state reasons why they are "Trade Secret" documents, provide
				a summary of these contracts in aggregate form, and flow the Commission Staff
				(or Staff representatives subject to appropriate confidentiality agreements) to
				review these contracts as part of the Supply Plan review. With respect to the
				short term contracts, the Utility must state the number of short term contracts
				and provide a summary of these contracts in aggregate form.
3. The proposed utilization of all
				projected capacity and gas supply the Utility will purchase from pipelines and
				producers. This information will be provided on a contract-by-contract basis.
				"Trade Secret" contract information can be provided in aggregate.
4. An explanation of how the Utility
				determined any estimated Gas Supply Realignment (GSR) and transition costs,
				including the levels of such costs, the outstanding balance at the commencement
				of the Recovery Year and the expected outstanding balance at the end of the
				Recovery Year.
5. Projected
				end-of-month storage levels by storage service.
6. A disaggregation of the commodity and
				demand charges reflected in the Adjustment Factors. At a minimum, the actual
				pipeline rates for each service shall be shown, and commodity costs shall be
				stated separately for projected gas costs, variable pipeline costs and fuel
				rates. Pipeline fuel costs should be shown as they are projected to be
				incurred, either as gas delivered in kind or as the dollar amount expected to
				be paid by the Utility to the pipeline.
(e) The requirements of O.C.G.A. §
										46-2-25 shall not apply to filings
				made pursuant to O.C.G.A. §
										46-2-26.5 and this Rule.