Source: https://www.federalregister.gov/documents/2000/02/03/00-2366/revision-of-annual-charges-assessed-to-public-utilities
Timestamp: 2018-02-19 20:21:34
Document Index: 398018495

Matched Legal Cases: ['art 382', 'art 382', 'art 382', 'art 382', '§\u2009382', '§\u2009382', 'art 382', '§\u200931', '§\u200931', '§\u200961', '§\u200961', 'arts 300', 'art 292']

Federal Register :: Revision of Annual Charges Assessed to Public Utilities
A Proposed Rule by the Federal Energy Regulatory Commission on 02/03/2000
Comments on the proposed rulemaking are due on or before April 3, 2000..
65 FR 5289
5289-5295 (7 pages)
00-2366
2. PMA's
3. QF's
B. Proposed Apportionment
The Commission established two separate categories because:
2. Standards for Waiving All or Part of an Annual Charge
https://www.federalregister.gov/d/00-2366 https://www.federalregister.gov/d/00-2366
The Federal Energy Regulatory Commission (Commission) proposes to amend its regulations to establish a new methodology for the assessment of annual charges to public utilities. The Commission proposes that annual charges would be assessed to public utilities based on the volume of electricity transmitted by the public utilities.
File comments on the notice of proposed rulemaking with the Office of the Secretary, Federal Energy Regulatory Commission, 888 First Street, N.E., Washington, D.C. 20426. Comments should reference Docket No. RM00-7-000
Herman Dalgetty (Technical Information), Chief, Accounts Receivable and Assessment Branch, Office of Finance, Accounting and Operations, 888 First Street, N.E., Washington, D.C. 20426, (202) 219-2918
Jennifer Lokenvitz Schwitzer (Legal Information), Office of the General Counsel, 888 First Street, N.E., Start Printed Page 5290Washington, D.C. 20426, (202) 219-4471
In addition to publishing the full text of this document in the Federal Register, the Commission also provides all interested persons an opportunity to view and/or print the contents of this document via the Internet through FERC's Home Page (http://ferc.fed.us) and in FERC's Public Reference Room during normal business hours (8:30 a.m. to 5:00 p.m. Eastern time) at 888 First Street, N.E., Room 2A, Washington, DC 20426.
—CIPS can be accessed using the CIPS link or the Energy Information Online icon. The full text of this document will be available on IPS in ASCII and WordPerfect 8.0 format for viewing, printing and/or downloading.
The Federal Energy Regulatory Commission (Commission) proposes to amend its regulations to establish a new methodology for the assessment of annual charges to public utilities. The Commission proposes that annual charges would be assessed to public utilities based on the volume of electricity transmitted by the public utilities. [1]
The Commission is required by section 3401 of the Omnibus Budget Reconciliation Act of 1986 (Budget Act) [2] to “assess and collect fees and annual charges in any fiscal year in amounts equal to all of the costs incurred * * * in that fiscal year.” [3] The annual charges must be computed based on methods which the Commission determines to be “fair and equitable.” [4] The Conference Report accompanying the Budget Act provides the Commission with the following guidance as to this phrase's meaning:
[A]nnual charges assessed during a fiscal year on any person may be reasonably based on the following factors: (1) The type of Commission regulation which applies to such person such as a gas pipeline or electric utility regulation; (2) the total direct and indirect costs of that type of Commission regulation incurred during such year; [5] (3) the amount of energy—electricity, natural gas, or oil—transported or sold subject to Commission regulation by such person during such year; and (4) the total volume of all energy transported or sold subject to Commission regulation by all similarly situated persons during such year.[6]
The Commission may assess these charges by making estimates based upon data available to it at the time of the assessment. [7]
The annual charges do not enable the Commission to collect amounts in excess of its expenses, but merely serve as a vehicle to reimburse the United States Treasury for the Commission's expenses.[8]
As required by the Budget Act, the Commission's regulations provide for the payment of annual charges by public utilities. [9] The Commission intends that these electric annual charges in any fiscal year will recover the Commission's estimated electric regulatory program costs (other than the costs of regulating Federal Power Marketing Agencies and electric regulatory program costs recovered through electric filing fees) for that fiscal year. In the next fiscal year, the Commission adjusts its annual charges up or down, as appropriate, both to eliminate any over-or under-recovery of the Commission's actual costs and to eliminate any over-or under-charging of any particular person.[10]
In calculating annual charges, the Commission first determines the total costs of its electric regulatory program and subtracts all Federal Power Marketing Agency-related and electric filing fee collections to determine total collectible electric regulatory program costs. It then uses the data submitted under FERC Reporting Requirement No. 582 (FERC-582) to determine the total volumes of long-term firm sales and transmission, and short-term sales and transmission and exchanges for all assessable public utilities. The Commission divides those transaction volumes into its collectible electric regulatory program costs to determine the unit charge per megawatt-hour for each category of long-term and short-term transactions. Finally, the Start Printed Page 5291Commission multiplies the transaction volume in each category for each public utility by the relevant unit charge per megawatt-hour to determine the annual charges for all assessable public utilities.[11]
Public utilities subject to these annual charges must submit FERC-582 to the Office of the Secretary by April 30 of each year. [12] The Commission issues bills for annual charges, and public utilities then must pay the charges within 45 days of the date on which the Commission issues the bills.[13]
Since the issuance of Order No. 472, the industry has undergone sweeping changes, including: The Commission's establishment of open access transmission as a foundation for competitive wholesale power markets; [14] a movement by many states to develop retail competition; the growing divestiture of generation assets by traditional public utilities; the entry of new market participants in the industry in the form of independent and affiliated power marketers and stand-alone merchant plant generators; and the establishment of Independent System Operators (ISOs), the expected establishment of transmission companies (transcos), and the establishment of power exchanges as managers of transmission systems and power markets, respectively.
As the landscape of the industry has changed and continues to change, the nature of the work of the Commission likewise has changed. The purpose of this rule is to change the way in which the Commission assesses annual charges to recover its electric regulatory program costs to reflect these changes, by assessing annual charges to public utilities based on the volumes of electric energy transmitted.
We note at the outset that this proposed rule is only for the determination of annual charges to recover the costs of the Commission's electric regulatory program.
Therefore, how to apportion the costs among the Commission's different regulatory programs is not before the Commission.
Below, we will discuss the types of companies to be billed, the proposed apportionment of our electric regulatory program costs among such companies, and other matters related to the proposed changes to the Commission's regulation on annual charges.
The Commission's electric regulatory program includes administering the provisions of Parts II and III of the Federal Power Act (FPA) [15] as they apply to the activities of public utilities (traditionally, principally investor-owned utilities); [16] discharging its responsibilities under various statues involving the Federal Power Marketing Agencies (PMAs); and implementing various provisions of the Public Utility Regulatory Policies Act of 1987 (PURPA) [17] involving qualifying cogenerators and small power producers (QFs).
Pursuant to section 205 of the FPA, [18] the Commission regulates the rates, terms and conditions of service of public utilities making sales for resale or transmitting electric energy in interstate commerce. All jurisdictional rates, terms and conditions must be on file with the Commission, and may be approved by the Commission only if they are just and reasonable and not unduly discriminatory or preferential. Under section 206 of the FPA, [19] the Commission may change any rates, terms or conditions that it finds to be unjust, unreasonable, or unduly discriminatory or preferential.
The Commission also regulates certain accounting and corporate activities of public utilities pursuant to the FPA. Examples include the following: Under section 203, [20] the Commission reviews applications filed by public utilities seeking to merge or to dispose of jurisdictional facilities. Pursuant to section 204, [21] the Commission reviews the proposed securities issuances of public utilities whose securities issuances are not regulated by a state commission within the meaning of section 204(f). Under sections 301 and 302, [22] the Commission has authority over a public utility's accounting and its depreciation.
The Commission reviews the rates established by the Department of Energy for the federally-owned PMAs (Bonneville Power Administration (BPA), Alaska Power Administration, Southeastern Power Administration, Southwestern Power Administration, and Western Power Administration). While regulation of public utility rates is guided by the FPA, regulation of the PMAs' rates is subject to the standards enumerated in a number of other statutes. [23] Essentially, the statutes require that the rates established by the PMAs must be devised with regard for the recovery of the cost of generation and transmission of electric energy, the encouragement of the most widespread use of the power, the provision of the lowest possible rates to customers consistent with sound business principles, and the protection of the interests of the United States in amortizing its investment in the projects within a reasonable period of time. The Commission is also authorized, Start Printed Page 5292pursuant to the Northwest Power Act, to review the Average System Cost methodology used to determine rates for exchange sales by utilities to BPA.
Section 210 of PURPA [24] requires the Commission to prescribe rules to encourage cogeneration and small power production of electricity. In particular, the section directs the Commission to adopt rules requiring utilities to purchase power from and sell power to qualifying cogeneration and small power production facilities. The Commission reviews applications filed by cogenerators and small power producers requesting QF certification, and either grants or rejects such applications based on criteria set forth in the Commission's regulations.[25]
The Commission proposes to assess annual charges to public utilities involved in the transmission of electric energy in interstate commerce. The Commission will continue unchanged its existing policy with regard to its assessment of annual charges to PMAs. [26]
The Commission also will continue to excuse qualifying cogenerators and small power producers from annual charges. For the most part, these entities do not provide interstate transmission of electric energy. The Commission believes that any amounts which might be assessed as annual charges to the few entities that may provide such transmission do not justify the risk of discouraging the fullest development of cogeneration and small power production by such entities. Therefore, the Commission will continue to not assess annual charges to these entities.[27]
The Commission proposes to continue its existing policy that municipals and rural electric cooperative utility systems that are financed by the Rural Utilities Service will not be required to pay annual charges. While these entities may be transmitting utilities subject to our authority under sections 211, 212 and 213 of the FPA, they are not public utilities under the FPA.[28]
The Commission proposes to continue its practice of not assessing annual charges to utilities operating in Alaska or Hawaii because they are not public utilities under the FPA, because they do not make wholesale sales or transmit electric energy in interstate commerce.
Lastly, the Commission proposes to not assess annual charges to foreign electric utilities to the extent that their transactions are in foreign commerce or wholly within another country.[29]
The Commission is proposing to change the way in which it apportions annual charges among the entities it regulates. As previously stated, the Commission first determines the total costs of its electric regulatory program and subtracts all Federal Power Marketing Agency-related costs and electric filing fee collections to determine the total collectible electric regulatory program costs. It then uses the data submitted under FERC-582 to determine the total volumes of long-term firm sales and transmission, and short-term sales and transmission [30] and exchanges for all assessable public utilities. The Commission divides those transaction volumes into its collectible electric regulatory program costs to determine the unit charge per megawatt-hour for each category of transactions. Finally, the Commission multiplies the transaction volume in each category for each public utility by the relevant unit charge per megawatt-hour to determine the annual charges for each assessable public utility.[31]
Rates for long-term coordination and transmission sales usually require greater use of Commission resources than those for sales which have a duration of less than five years. Long-term sales contracts tend to be based upon fully distributed costs and require cost projections (test year data) which must be reasonable. Rates for short-term coordination or transmission sales, on the other hand, are not necessarily exclusively cost-based, but may be made for many non-cost reasons as well. [32]
This methodology for assessing annual charges worked well for the industry structure that existed at the time the rule was issued. However, because there has been such dramatic changes in the industry, this classification no longer serves its purpose.
With open-access transmission, functional unbundling and the rapid movement to market-based power sales rates brought about by, inter alia, Commission Order No. 888,[33] state retail unbundling efforts, and the recently issued Order No. 2000,[34] the time and effort of our electric regulatory program is now increasingly devoted to assuring open and equal access to public utilities' transmission systems. In contrast, the time and effort of our electric regulatory program that had been devoted to reviewing cost-based power sales rates has been decreasing, and with open access transmission, power sales rates are now increasingly being disciplined by competitive market forces and less by the Commission directly. As a consequence, we believe it appropriate to assess our electric regulatory program costs solely on the MWh of electric energy transmitted in interstate commerce by public utilities,[35] rather than, as in the past, on both jurisdictional power sales and transmission volumes. We further note that, as described below, sellers of electric energy typically must use public utility transmission systems to transmit their electric energy and therefore will, in fact, pay annual charges, albeit indirectly.
The Commission believes that this approach of directly charging only those public utilities that provide interstate transmission service is both fair and equitable because, in turn, all parties involved in the generation and sale of electric energy rely on the transmission system to move their product. Thus, the Commission believes that power sellers will, in fact, be contributing to the Commission's recovery of its electric regulatory program costs in that they will be using the transmission system and, in the cost-based rates that they will pay for transmission service, will pay, albeit indirectly, a fair and equitable share of the Commission's costs.
Specifically, therefore, the Commission is proposing to assess annual charges to public utilities based on their transmission of electric energy Start Printed Page 5293in interstate commerce, as measured by: (1) unbundled wholesale transmission, (2) unbundled retail transmission,[36] and (3) bundled wholesale power sales which, by definition, include a transmission component, where the transmission component is not separately reported as unbundled transmission.[37]
As to ISOs, and potential Regional Transmission Organizations (RTOs), that have members that retain ownership of transmission facilities, the Commission is concerned that the assessment of annual charges to them could result in a “double counting” of transactions “ by counting a single transaction both to the transmission-owning public utility and to the ISO or RTO public utility. We believe that there are at least two ways to address this issue, and are inviting comments on these and any other solutions to this problem. One way would be not to charge the ISO or RTO itself, but instead charge each transmission-owning public utility based on the MWh of transmission service provided on their lines. The transmission-owning public utility would include the annual charges, as a cost element, in its revenue requirement, which, in turn, is recovered by the ISO or RTO through the ISO's or RTO's open access transmission tariff rates. Another way would be to allow the ISO or RTO to act as an agent for all of the individual transmission owners and have the ISO or RTO pay the annual charges rather than the individual transmission owners. Either of these approaches may be acceptable. The Commission is soliciting comments on these approaches, as well as any other approach that will allow the Commission to collect annual charges on these MWh of transmission service, in the most administratively efficient manner.
The Commission is proposing a change in its reporting requirements for annual charges. Currently, a public utility has to submit the total long-term firm sales for resale and transmission megawatt-hours and the total short-term sales, transmission, and exchange megawatt-hours. With the elimination of the distinction between long-term and short-term transactions, such distinctions in the reporting requirement are likewise no longer needed. The Commission proposes, therefore, that public utilities will report only total volumes of electric energy transmitted in interstate commerce (as defined above to include all unbundled transmission and all bundled wholesale power sales), in MWh, by April 30th of each year.
Finally, we note that any corrections to FERC-582 will need to be made by the end of the calendar year in which the FERC-582 was filed.
The Commission is not proposing to change the standards applicable for waiving all or part of an annual charge. Thus, the Commission is proposing to continue to apply to annual charges the stringent standards for waiver currently applicable to filing fees, with a filing period for waiver petitions of 15 days after the issuance of the annual charges bill.
We anticipate that we will begin assessing annual charges under this new methodology starting with bills to be paid in calendar year 2002, based on data reported on FERC-582 in calendar year 2002 (for transactions that occurred in calendar year 2001, the first full year after adoption of changes in the regulation).[38]
Likewise we anticipate that we will make the change discussed above with respect to corrections to FERC-582 effective beginning with the data reported in FERC-582 in calendar year 2002 (for transactions that occurred in calendar year 2001); thus such corrections will need to be submitted on or before December 31, 2002.
The Commission excludes certain actions not having a significant effect on the human environment from the requirement to prepare an environmental assessment or an environmental impact statement. [39] The promulgation of a rule that is procedural or that does not substantially change the effect of legislation or regulations amended raises no environmental considerations.[40] This proposed rule amends Part 382 of the Commission's regulations to establish a new methodology for the assessment of annual charges to public utilities and does not substantially change the effect of the underlying legislation or the regulations being revised. Accordingly, no environmental consideration is necessary.
Overall, the Commission does not believe that this rule will have a significant direct impact on small entities. Specifically, most, if not all, public utilities that would be assessed annual charges under this rule do not fall within the RFA's definition of a small entity because most public utilities subject to this rule are too large to be considered “small entities.” [41] Therefore, the Commission certifies that this rule will not have a “significant economic impact on a substantial number of small entities.”
The collection of information contained in this proposed rule is being submitted to the Office of Management and Budget (OMB) for review under Section 3507(d) of the Paperwork Reduction Act of 1995. FERC identifies the information provided under Part 382 as FERC-582.
Comments are solicited on the Commission's need for this information, whether the information will have Start Printed Page 5294practical utility, the accuracy of the provided burden estimates, ways to enhance the quality, utility, and clarity of the information to be collected, and any suggested methods for minimizing respondents' burden, including the use of automated information techniques.
The burden estimate for complying with this proposed rule is as follows:
FER-582 242 1 4 968
Total Annual Hours for Collection (reporting + recordkeeping, (if appropriate)) = 968.
Information Collection Costs: The Commission seeks comments on the costs to comply with these requirements. It has projected the average annualized cost for all respondents to be: Annualized Capital/Startup Costs − Annualized Costs (Operations & Maintenance) − $51,911 (968 hours ÷ 2080 hours per year × $111,545 = $51,911). The cost per respondent is equal to $215.
The OMB regulations require OMB to approve certain information collection requirements imposed by agency rule. [42] Accordingly, pursuant to OMB regulations, the Commission is providing notice of its proposed information collections to OMB.
Necessity of Information: The proposed rule revises the requirements contained in 18 CFR Part 382 to revise the method for determining the assessment of annual charges.
The Commission is seeking to make its assessments for annual charges compatible with the current regulatory environment and the creation of competitive wholesale markets. The Commission has the authority under the Omnibus Budget Reconciliation of 1986 (42 U.S.C. 7178) to “assess and collect fees and annual charges in any fiscal year in amounts equal to all of the costs incurred * * * in that fiscal year.” The Act gives the Commission the flexibility to arrive at a reasonable approximation of its program costs. The costs are determined by a summation of all electric regulatory program costs and then subtracting all electric regulatory program filing fee collections in order to determine the total collectible costs for the electric regulatory program. Information submitted under FERC-582 is the basis for the calculation of annual charges, and presently includes total volumes of long-term firm sales and transmission and short-term sales and transmission plus exchanges for all public utilities, including power marketers. The proposed rule changes the basis for the calculation of annual charges to the total volumes of electricity transmitted by public utilities.
Internal Review: The Commission has assured itself, by means of internal review, that there is specific, objective support for the burden estimates associated with the information requirements. The Commission's Office of Finance, Accounting and Operations will use the data submitted under FERC-582 in order to serve as a billing determinant to recover costs for administering its electric regulatory program, including administering the provisions of Parts II and III of the Federal Power Act and the provisions of the Public Utility Regulatory Policies Act of 1987.
Interested persons may obtain information on the reporting requirements by contacting the following: Federal Energy Regulatory Commission, 888 First Street, N.E., Washington, D.C. 20426 [Attention: Michael Miller, Capital Planning and Policy Group, Phone: (202) 208-1415, Fax: (202) 208-2425, E-Mail: mike.miller@ferc.fed.us].
For submitting comments concerning the collection of information(s) and associated burden estimate(s), please send your comments to the contact listed above and to the Office of Management and Budget, Office of Information and Regulatory Affairs, Washington, D.C. 20503 [Attention: Desk Officer for the Federal Energy Regulatory Commission, Phone: (202) 395-3087, Fax: (202) 395-7285].
Prior to taking final action on this proposed rulemaking, we are inviting interested persons to submit written comments on the changes to the regulations proposed in this notice to be adopted. All comments in response to this notice should be submitted to the Office of the Secretary, Federal Energy Regulatory Commission, 888 First Street, N.E., Washington, D.C. 20426, and should refer to Docket No. RM00-7-000. An original and fourteen (14) copies of such comments should be filed with the Commission on or before April 3, 2000.
In addition to filing paper copies, the Commission encourages the filing of comments either on computer diskette or via Internet E-Mail. Comments maybe filed in the following formats: WordPerfect 8.0 or lower version, MS Word Office 97 or lower version, or ASCII format.
For diskette filing, include the following information on the diskette label: Docket No. RM00-7-000; the name of the filing entity; the software and version used to create the file; and the name and telephone number of a contact person.
For Internet E-Mail submittal, comments should be submitted to “comment.rm@ferc.fed.us” in the following format. On the subject line, specify Docket No. RM00-7-000. In the body of the E-Mail message, include the name of the filing entity; the software and version used to create the file, and the name and telephone number of the contact person. Attach the comments to the E-Mail in one of the formats specified above. The Commission will send an automatic acknowledgment to the sender's E-Mail address upon receipt. Questions on electronic filing should be directed to Brooks Carter at: 202-501-8145, E-Mail address: brooks.carter@ferc.fed.us.
Commenters should take notice that, until the Commission amends its rules and regulations, the paper copy of the filing remains the official copy of the document submitted. Therefore, any discrepancies between the paper filing and the electronic filing or the diskette will be resolved by reference to the paper filing.
All written comments will be placed in the Commission's public files and will be available for inspection in the Commission's Public Reference room at 888 First Street, N.E., Washington, D.C. 20426, during regular business hours. Start Printed Page 5295Additionally, comments may be viewed, printed or downloaded remotely via the Internet through FERC's Homepage, using the RIMS or CIPS link. RIMS contains all comments but only those comments submitted in electronic format are available on CIPS. User assistance is available at 202-208-2222, or by E-Mail to rimsmaster@ferc.fed.us.
By direction of the Commission. Commissioner Bailey did not participate in this decision.
In consideration of the foregoing, the Commission proposes to amend Part 382, Chapter I, Title 18 of the Code of Federal Regulations, as set forth below.
§ 382.102
2. In section 382.102 paragraphs (h), (i), (j) and (k) are removed and paragraphs (l), (m), (n), (o) and (p) are redesignated as (h), (i), (j), (k) and (l), respectively.
(a) Determination of costs to be assessed to public utilities. The adjusted costs of administration of the electric regulatory program, excluding the costs of regulating the Power Marketing Agencies, will be assessed to public utilities.
(b) Determination of annual charges to be assessed to public utilities. The costs determined under paragraph (a) of this section will be assessed as annual charges to each public utility based on the proportion of the megawatt-hours of transmission of electric energy in interstate commerce of each public utility in the immediately preceding reporting year (either a calendar year or fiscal year, depending on which accounting convention is used by the public utility to be charged) to the sum of the megawatt-hours of transmission of electric energy in interstate commerce in the immediately preceding reporting year of all public utilities being assessed annual charges.
(c) Reporting requirement. (1) For purposes of computing annual charges, as of January 1, 2002, a public utility, as defined in § 382.102(b), must submit under oath to the Office of the Secretary by April 30 of each year an original and conformed copies of the following information (designated as FERC Reporting Requirement No. 582 (FERC-582)): the total megawatt-hours of transmission of electric energy in interstate commerce, which for purposes of computing the annual charges and for purposes of this reporting requirement, will be measured by the sum of the megawatt-hours of all unbundled transmission (including MWh received in wheeling transactions and MWh delivered in exchange transactions) and the megawatt-hours of all bundled wholesale power sales (to the extent the megawatt-hours were not separately reported as unbundled transmission). This information should be reported to 3 decimal places; e.g., 3,105 KWh will be reported as 3.105 MWh.
(2) Corrections to the information reported on FERC-582, as of January 1, 2002, must be submitted under oath to the Office of the Secretary on or before the end of each calendar year in which the information was originally reported (i.e., on or before the last day of the year that the Commission is open to accept such filings, e.g., on or before December 31, 2002, etc.)
1. On August 12, 1998, the Commission received a petition for rulemaking from Automated Power Exchange, Citizens Power, Coral Power, L.L.C., Electric Clearinghouse, Inc., Enron Power Marketing, Inc., Koch Energy Trading, Inc., NP Energy Inc., Sonat Power Marketing, L.P., and Williams Energy Services in Docket No. RM98-14-000. The parties petitioned the Commission to initiate a rulemaking to modify its methodology for assessing annual charges. The Commission notes that the instant rulemaking on annual charges moots the petition. Therefore, the Commission plans to terminate Docket No. RM98-14-000 in the final rule. Petitioners are free to file timely comments in response to the instant rulemaking and we will address them in the final rule.
2. 42 U.S.C. 7178.
3. This authority is in addition to that granted to the Commission in sections 10(e) and 30(e) of the Federal Power Act (FPA). 16 U.S.C. 803(e), 823a(e).
5. The Commission is required to collect not only all its direct costs but also all its indirect expenses such as hearing costs and indirect personnel costs. See H.R. Conf. Rep. No. 99-1012 at 238 (1986), reprinted in 1986 U.S.C.C.A.N. 3868, 3883 (Conference Report); see also, S. Rep. No. 99-348 at 56, 66 and 68 (1986).
6. See Conference Report at 238.
7. 42 U.S.C. 7178(c).
8. Id. at 7178(f). Congress approves the Commission's budget through annual and supplemental appropriations.
9. 18 CFR Part 382; see Annual Charges Under the Omnibus Budget Reconciliation Act of 1986, Order No. 472, 52 FR 21263 and 24153 (June 5 and 29, 1987), FERC Stats. & Regs., Regulations Preambles 1986-1990 ¶ 30,746 (1987), clarified, Order No. 472-A, 52 FR 23650 (June 24, 1987), FERC Stats. & Regs., Regulations Preambles 1986-1990 ¶ 30,750, order on reh'g, Order No. 472-B, 52 FR 36013 (Sept. 25, 1987), FERC Stats. & Regs., Regulations Preambles 1986-1990 ¶ 30,767 (1987), order on reh'g, Order No. 472-C, 53 FR 1728 (Jan. 22, 1988), 42 FERC ¶ 61,013 (1988).
10. 18 CFR 382.201; see Order No. 472, 52 FR 21263 and 24153, FERC Stats. & Regs., Regulations Preambles 1986-1990 at 30,612-18; accord Annual Charges Under the Omnibus Budget Reconciliation Act of 1986, Order No. 507, 53 FR 46445 (Nov. 17, 1985), FERC Stats. & Regs., Regulations Preambles 1986-1990 ¶ 30,839 at 31,263-64 (1988); Texas Utilities Electric Company, 45 FERC ¶ 61,007 at 61,027 (1988) (Texas Utilities).
11. 18 CFR 382.201; see Annual Charges Under the Omnibus Budget Reconciliation Act of 1986 (Phibro Inc.), 81 FERC ¶ 61,308 at 62,424-25 (1997).
12. 18 CFR 382.201(b)(4).
13. See Texas Utilities, 45 FERC at 61,026.
14. See Promoting Wholesale Competition Through Open Access Non-discriminatory Transmission Services by Public Utilities and Recovery of Stranded Costs by Public Utilities and Transmitting Utilities, 61 FR 21540 (May 10, 1996), FERC Stats. & Regs. § 31,036 (1996) (Order No. 888), order on reh'g, Order No. 888-A, 62 FR 12274 (March 14, 1997), FERC Stats. & Regs. § 31,048 (1997), order on reh'g, Order No. 888-B, 62 FR 64688 (March 14, 1997), 81 FERC § 61,248 (1997), order on reh'g, Order No. 888-C, 82 FERC § 61,046 (1998), appeal docketed, Transmission Access Policy Study Group, et al. v. FERC, No. 97-1715 et al. (D.C. Cir.).
15. 16 U.S.C. 824-825r.
16. Under sections 211, 212 and 213 of the FPA, 16 U.S.C. 824j-l, the Commission also has authority over transmitting utilities that are not public utilities. Compare 16 U.S.C. 796(23) with 16 U.S.C. 824(b), (e).
17. 16 U.S.C. 2601-2645.
18. 16 U.S.C. 824d(a).
19. 16 U.S.C. 824e.
20. 16 U.S.C. 824b.
21. 16 U.S.C. 824c.
22. 16 U.S.C. 825, 825a.
23. Flood Control Act of 1944, 16 U.S.C. 825s; Federal Columbia River Transmission System Act, 16 U.S.C. 838g; Pacific Northwest Power Preference Act, 16 U.S.C. 837; Pacific Northwest Electric Power Planning and Conservation Act of 1980, 16 U.S.C. 839; the Bonneville Project Act, 16 U.S.C. 832f (Northwest Power Act); and the Reclamation Act of 1939, 43 U.S.C. 485h; the Department of Energy Organization Act, 42 U.S.C. 7101; see also DOE Delegation Order No. 0204-108, 48 FR 55664 (Dec. 14, 1983); 18 CFR Parts 300 and 301.
24. 16 U.S.C. 824a-3(a).
25. 18 CFR Part 292.
26. See 18 CFR 382.201(c).
27. 18 CFR 382.102(b); see Order No. 472, FERC Stats. & Regs., Regulations Preambles 1986-1990 at 30,637.
28. 18 CFR 382.102(b); see 16 U.S.C. 284; South Carolina Public Service Authority, 75 FERC 61,209 at 61,696 (1996); Dairyland Power Corporation, 37 FPC 12, 15 (1967); accord, Salt River Project Agricultural Improvement and Power District v. FPC, 391 F.2d 470, 474 (D.C. Cir.), cert. denied, 393 U.S. 857 (1968).
29. E.g., British Columbia Power Exchange Corporation, 80 FERC 61,343 at 62,137, 62,141 (1997) (sales in foreign commerce or within another country are excluded from annual charges calculations).
30. Long-term firm sales and transmission activities and short-term sales and transmission activities are defined in 18 CFR 382.102.
31. The Commission also carries over any over-or under-charge from the prior year as a credit or debit on the current year's annual charge bill.
32. Order 472-B at 30,830.
34. Regional Transmission Organizations, Order No. 2000, 65 FR 810 (Jan. 6, 2000), FERC Stats. & Regs. ¶ 31,089 (1999).
35. This approach is essentially the same as how annual charges are assessed against gas pipelines.
36. The Commission is proposing that annual charges will be assessed based on all interstate transmission by public utilities, with no distinction made between so-called unbundled retail and unbundled wholesale transmission. This transmission would include MWh received in wheeling transactions and the MWh delivered in exchange transactions.
37. If the bundled wholesale power sale involves only the use of non-affiliated, third-party transmission systems, the transmission component would be picked up through the non-affiliated, third-party transmission providers' reporting of the MWhs of transmission service they provided. Similarly, if the bundled wholesale power sale involves the use of the power seller's or its affiliate's transmission system, the transmission component may be separately reported as unbundled transmission. If, however, neither of these were the case, the MWhs would need to be reported as a bundled wholesale power sale.
38. Our existing regulations will remain effective until these changes become effective.
39. 18 CFR 380.4.
40. 18 CFR 380.4(a)(2)(ii).
41. 5 U.S.C. 601(6).
[FR Doc. 00-2366 Filed 2-2-00; 8:45 am]