2007 Wholesale Power Rate Adjustment Proceeding; Public Hearings, and Opportunities for Public Review and Comment, 67685-67697 [05-22233]

Download as PDF Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices VIII. Other Information Electronic Access to This Document: You may view this document, as well as all other documents of this Department published in the Federal Register, in text or Adobe Portable Document Format (PDF) on the Internet at the following site: www.ed.gov/news/ fedregister. To use PDF you must have Adobe Acrobat Reader, which is available free at this site. If you have questions about using PDF, call the U.S. Government Printing Office (GPO), toll free, at 1– 888–293–6498; or in the Washington, DC, area at (202) 512–1530. Note: The official version of this document is the document published in the Federal Register. Free Internet access to the official edition of the Federal Register and the Code of Federal Regulations is available on GPO Access at: http://www.gpoaccess.gov/nara/ index.html. Dated: November 3, 2005. John H. Hager, Assistant Secretary for Special Education and Rehabilitative Services. [FR Doc. 05–22258 Filed 11–7–05; 8:45 am] BILLING CODE 4000–01–P DEPARTMENT OF ENERGY Albany Research Center; Notice of Intent To Grant Exclusive or Partially Exclusive Patent License Department of Energy (DOE), Albany Research Center (ALRC). ACTION: Notice. AGENCY: SUMMARY: Notice is hereby given of an intent to grant to Harbison-Walker Refractories Co. at Moon Township, Pennsylvania, an exclusive or partially exclusive license to practice the invention described in the U.S. patent number 6,815,386 titled, ‘‘Use of Phosphates to Reduce Slag Penetration in Cr2O3-Based Refractories.’’ The invention is owned by the United States of America, as represented by the Department of Energy (DOE). The proposed license will be exclusive or partially exclusive, subject to a license and other rights retained by the U.S. Government, and other terms and conditions to be negotiated. DOE intends to grant the license, upon a final determination in accordance with 35 U.S.C. 209(c), unless within 15 days of publication of this Notice the Research Marketing Specialist, Department of Energy, Albany Research Center, 1450 Queen Avenue, SW., Albany, OR 97321–2198, receives in writing any of the following, together with the supporting documents: VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 (i) A statement from any person setting forth reasons why it would not be in the best interest of the United States to grant the proposed license; or (ii) An application for a nonexclusive license to the invention, in which applicant states that it already has brought the invention to practical application or is likely to bring the invention to practical application expeditiously. DATES: Written comments or nonexclusive license applications are to be received at the address listed below no later than fifteen (15) days after the date of this published Notice. ADDRESSES: Paula Turner, Research Marketing Specialist, U.S. Department of Energy, Albany Research Center, 1450 Queen Avenue SW., Albany, OR 97321– 2198. FOR FURTHER INFORMATION: Paula Turner, Research Marketing Specialist, U.S. Department of Energy, Albany Research Center, 1450 Queen Avenue SW., Albany, OR 97321–2198; Telephone (541) 967–5966; E-mail: @turnerp@alrc.doe.gov. SUPPLEMENTARY INFORMATION: 35 U.S.C. 209(c) provides the DOE with authority to grant exclusive or partially exclusive licenses in Department-owned inventions, where a determination can be made, among other things, that the desired practical application of the invention has not been achieved, or is not likely expeditiously to be achieved, under a nonexclusive license. The statute and implementing regulations (37 CFR part 404) require that the necessary determinations be made after public notice and opportunity for filing written objections. Harbison-Walker Refractories, a business located at Moon Township, Pennsylvania, has applied for an exclusive or partially exclusive license to practice the invention and has a plan for commercialization of the invention. The proposed license will be exclusive or partially exclusive, subject to a license and other rights retained by the U.S. Government, and subject to a negotiated royalty. The Department will review all timely written responses to this notice, and will grant the license if, after expiration of the 15-day notice period, and after consideration of written responses to this notice, a determination is made, in accordance with 35 U.S.C. 209(c), that the license grant is in the public interest. Dated: October 18, 2005. George J. Dooley, Research Director, Albany Research Center. [FR Doc. 05–22232 Filed 11–7–05; 8:45 am] BILLING CODE 6450–01–P PO 00000 Frm 00028 Fmt 4703 Sfmt 4703 67685 DEPARTMENT OF ENERGY Bonneville Power Administration [BPA File No.: WP–07] 2007 Wholesale Power Rate Adjustment Proceeding; Public Hearings, and Opportunities for Public Review and Comment Bonneville Power Administration (BPA), Department of Energy (DOE). ACTION: Notice of proposed wholesale power rates. AGENCY: SUMMARY: The Pacific Northwest Electric Power Planning and Conservation Act (Northwest Power Act), 16 U.S.C. 839, provides that BPA must establish and periodically review and revise its rates so that they are adequate to recover, in accordance with sound business principles, the costs associated with the acquisition, conservation and transmission of electric power, and to recover the Federal investment in the Federal Columbia River Power System (FCRPS) and other costs incurred by BPA. ADDRESSES: 1. Persons wishing to become formal parties to the proceeding must file a petition to intervene notifying BPA in writing of their intention to do so in conformance with the requirements stated in this notice. Petitions to intervene should be directed to Jennifer Sanders, Hearing Clerk, LP– 7, Bonneville Power Administration, 905 NE 11th Avenue, Portland, OR 97232 or may be e-mailed to the following e-mail address: jsanders@bpa.gov, and must be received no later than 5 p.m., Pacific Standard Time, on November 17, 2005. In addition, a copy of the petition must be served concurrently on BPA’s General Counsel and directed to Peter J. Burger, LP–7, Office of General Counsel, Bonneville Power Administration, 905 NE 11th Avenue, Portland, OR 97232 or be e-mailed to the following e-mail address: http://www.pjburger@bpa.gov. (See Part III (A) for more information.) 2. Non-party participants may submit written comments between November 21, 2005, and February 13, 2006. Comments must be received no later than 5 p.m., Pacific Standard Time, on February 13, 2006, in order to be considered in the draft Record of Decision (ROD). Written comments may be made as follows: in person at the field hearings (see schedule and locations in Part I of this Notice), online at BPA’s Web site: www.bpa.gov/ comment, or by mail to: BPA Communications, DKP–7, P.O. Box 14428, Portland, OR 97293–4428. Please E:\FR\FM\08NON1.SGM 08NON1 67686 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices identify written or electronic comments as ‘‘FY 07–09 Power Rate Case.’’ BPA will consider and address the comments received in the draft ROD. 3. The rate adjustment proceeding will begin with a prehearing conference at 9 a.m., Pacific Standard Time on November 21, 2005, held in the BPA Rates Hearing Room, 2nd Floor, 911 NE 11th Avenue, Portland, OR. BPA will release its 2007 Wholesale Power Rate Case Initial Proposal (WP–07 Initial Proposal) and supporting documents at this prehearing conference. Compact discs (CDs) containing the WP–07 Initial Proposal documents, in PDF format, will be provided to the parties at the prehearing conference. The WP–07 Initial Proposal documents will also be available on BPA’s Web site www.bpa.gov/power/rates. Due to increased security, attendees should allow additional time to enter the building and sign in at the security desk where photo identification will be required for entry. FOR FURTHER INFORMATION CONTACT: Ms. Jamae Hilliard Creecy, Public Affairs Specialist, Public Affairs Office, DKP–7, P.O. Box 14428, Portland, OR 97293– 4428. Interested persons may also call (503) 230–4328 or 1–800–622–4519 (toll-free). Information also may be obtained from: Ms. Kimberly Leathley, Manager, Financial Management, Rates, and Planning—PF–6, P.O. Box 3621, Portland, OR 97208. Ms. Elizabeth Evans, Acting Rates Manager—PFR–6, P.O. Box 3621, Portland, OR 97208. Mr. Garry Thompson, Hub Manager, Mr. Ken Hustad, Senior Customer Account Executive, or Ms. Carol Hustad, Customer Account Executive, Eastern Power Business Area-PSE, 707 W. Main, Suite 500, Spokane, WA 99201. Mr. John Lebens, Hub Manager, Western Power Business Area—PSW–6, P.O. Box 3621, Portland, OR 97208. Mr. Larry King, Customer Account Executive, 2700 Overland, Burley, ID 83318. Mr. C. T. Beede, Customer Account Executive, P.O. Box 40, Big Arm, MT 59910. Mr. Dan Bloyer, Customer Account Executive, 1011 SW Emkay Drive, Suite 211, Bend, OR 97702. Mr. Edward Brost, Senior Customer Account Executive, Kootenai Building, Room 215, N. Power Plant Loop, Richland, WA 99352–0968. Mr. Stuart Clarke, Senior Customer Account Executive, Mr. George Reich, Senior Customer Account Executive, or Ms. R. Kirsten Watts, Customer VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 Account Executive, 909 First Avenue, Suite 380, Seattle, WA 98104–3636. Responsible Official: Ms. Elizabeth Evans, Acting Rates Manager, is the official responsible for the development of BPA’s wholesale power rates. SUPPLEMENTARY INFORMATION: Table of Contents I. Introduction and Procedural Background II. Purpose and Scope of Hearing III. Public Participation IV. Major Studies and Summary of Proposal V. 2007 Wholesale Power Rate Case Schedules and General Rate Schedule Provisions Part I—Introduction and Procedural Background Section 7(i) of the Northwest Power Act, 16 U.S.C. 839e(i), requires that BPA’s rates be established according to certain procedures. These procedures include, among other things, publication of this notice of the proposed rates in the Federal Register (Notice); one or more hearings conducted as expeditiously as practicable by a Hearing Officer; public opportunity to provide both oral and written views; data requests and responses and argument related to the proposed rates; and a decision by the Administrator based on the record. This proceeding is governed by § 1010, et seq., of BPA’s Rules of Procedure Governing Rate Hearings, 51 FR 7611 (1986) (BPA Hearing Procedures). These procedures implement the statutory Section 7(i) requirements. Section 1010.7 of the BPA Hearing Procedures prohibits ex parte communications. The ex parte rule applies to all BPA and all DOE employees. Except as provided below, any outside communications with BPA and/or DOE personnel regarding BPA’s rate case by other Executive Branch agencies, Congress, existing or potential BPA customers (including tribes), and nonprofit or public interest groups are all considered outside communications and are subject to the ex parte rule. The general rule does not apply to communications relating to (1) Matters of procedure only (the status of the rate case, for example); (2) exchanges of data in the course of business or under the Freedom of Information Act; (3) requests for factual information; (4) matters for which BPA is responsible under statutes other than the ratemaking provisions; or (5) matters which all parties agree may be made on an ex parte basis. The ex parte rule remains in effect until the Administrator’s final ROD is issued, which is scheduled to occur on July 7, 2006. The Bonneville Project Act, 16 U.S.C. 832, the Flood Control Act of 1944, 16 PO 00000 Frm 00029 Fmt 4703 Sfmt 4703 U.S.C. 825s, the Federal Columbia River Transmission System Act, 16 U.S.C. 838, and the Northwest Power Act, 16 U.S.C. 839, provide guidance regarding BPA ratemaking. The Northwest Power Act requires BPA to set rates that are sufficient to recover, in accordance with sound business principles, the cost of acquiring, conserving and transmitting electric power, including amortization of the Federal investment in the FCRPS over a reasonable period of years, and certain other costs and expenses incurred by the Administrator. BPA’s initial proposed 2007 Wholesale Power Rate Schedules and General Rate Schedule Provisions (GRSPs) are available for viewing and downloading on PBL’s Web site at http://www.bpa.gov/power/ratecase as discussed in Part V of this Notice. The studies addressing the factors used to develop these rates are listed in Part IV and will be available for examination on November 21, 2005, at BPA’s Public Information Center, BPA Headquarters Building, 1st Floor, 905 NE 11th Avenue, Portland, Oregon, and will be provided to parties at the prehearing conference to be held on November 21, 2005, beginning at 9:00 am, Pacific Standard Time, Room 223, 911 NE 11th Avenue, Portland, Oregon. You may download copies of the studies and documentation from BPA’s Web site at http://www.bpa.gov/power/ ratecase or request them (on a CD or hard copy) by calling BPA’s document request line toll-free at: 1–800–622– 4519. BPA will release its WP–07 Initial Proposal and supporting documents on November 21, 2005, and expects to publish a final ROD on July 7, 2006. BPA will be conducting a formal evidentiary rate hearing attended by rate case parties. Interested parties must file petitions to intervene in order to take part in the formal hearing. A proposed schedule for the formal hearing is stated below. A final schedule will be established by the Hearing Officer at the prehearing conference. November 21, 2005; BPA files Direct Case/Prehearing Conference December 5–9, 2005; Clarification December 9, 2005; Data Request Deadline December 9, 2005; Motions to Strike December 15, 2005; Data Response Deadline December 15, 2005; Answers to Motions to Strike January 6, 2006; Parties file Direct Cases January 17–20, 2006; Clarification January 24, 2006; Data Request Deadline January 24, 2006; Motions to Strike January 30, 2006; Data Response Deadline E:\FR\FM\08NON1.SGM 08NON1 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices January 30, 2006; Answers to Motions to Strike February 13, 2006; Close of Participant Comments February 13, 2006; Litigants File Rebuttal Testimony February 16–17, 2006; Clarification February 17, 2006; Data Request Deadline February 17, 2006; Motions to Strike February 23, 2006; Data Response Deadline February 23, 2006; Answers to Motions to Strike March 6–17, 2006; Cross-Examination April 14, 2006; Initial Briefs Filed April 26–27, 2006; Oral Argument before Administrator May 26, 2006; Draft ROD issued June 9, 2006; Briefs on Exceptions July 7, 2006; Final ROD—Final Studies BPA will also be conducting six public field hearings in cities throughout the Pacific Northwest. Public field hearings are an opportunity for persons who are not parties in the formal rate hearing to have their views included in the official record. Written transcripts will be made at all of the field hearings. The field hearings have been scheduled to take place at the locations, dates, and times specified below. The hearing dates also will be posted on the rate case Web site (www.bpa.gov/power/rates) and through announcements in local newspapers. Any changes to the scheduled public hearings will be available on the rate case Web site. The BPA Public Affairs Office also may be contacted for this information at the telephone number previously listed. Public Field Hearings Schedule November 29, 2005; Springfield, Oregon November 30, 2005; Kalispell, Montana December 1, 2005; Spokane, Washington December 5, 2005; Idaho Falls, Idaho December 6, 2005; Tacoma, Washington December 7, 2005; Portland, Oregon Part II—Purpose and Scope of Hearing A. The Overview and Background to this Rate Filing The WP–07 rate proceeding is designed to establish rates to replace existing rate schedules and GRSPs. One existing rate schedule, the Firm Power Products and Services rate schedule, was established for 10 years in the 1996 Wholesale Power Rate and Transmission Rate Adjustment Proceeding (WP–96/TR–96) and amended in the 1996 Firm Power Products and Services Rate Schedule Correction Proceeding (FPS–96R). The remaining power rate schedules and VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 GRSPs were established in BPA’s 2002 Wholesale Power Rate Adjustment Proceeding (WP–02). All of BPA’s power rate schedules expire on September 30, 2006. Accordingly, BPA must conduct a rate case, pursuant to the 7(i) process, in order to comply with its statutory obligations to establish rates to market the power of the FCRPS. The General Transfer Agreement (GTA) Delivery Charge, was established in the 2006 Transmission Rate Case (TR–06) for the period of October 1, 2005, through September 30, 2007. This power rate case will establish the General Transfer Agreement Delivery Charge for the period of October 1, 2007, through September 30, 2009. 1. Subscription On December 21, 1998, BPA issued the Power Subscription Strategy and Record of Decision (Subscription Strategy). The Subscription Strategy reflected BPA’s position on the equitable distribution of Federal power for the Fiscal Year (FY) 2002–2011 period. The Subscription Strategy was the culmination of a multi-year public process that established BPA’s plan for the availability of Federal power post2001, the products from which customers could choose, along with an outline of the contracts and pricing framework for those products. The Subscription Strategy provided a marketing framework for the WP–02 power rate case. The WP–02 power rate case developed the rates and rate schedules necessary for the products and contracts that were developed through Subscription. However, the rates established in the WP–02 power rate proceeding applied only to the first five years of the 10-year Subscription contracts. As noted above, the WP–02 power rates applicable to the Subscription contracts are set to expire on September 30, 2006, and must be replaced. The Subscription contracts continue to be the basis for the contractual relationship between BPA and nearly all of its firm power customers. 2. Firm Power Products and Services Rate Schedule In addition to revising the rates for the Subscription contracts, BPA is proposing the successor to the Firm Power Products and Services (FPS) rate schedule. The FPS rate schedule is available for the purchase of surplus firm power and other products and services for use inside and outside the Pacific Northwest. The FPS rate schedule and associated GRSPs were established for a 10-year period running from October 1, 1996, to September 30, PO 00000 Frm 00030 Fmt 4703 Sfmt 4703 67687 2006. The rate schedule and GRSPs were slightly modified in 2000 through a 7(i) process (FPS–96R). The FPS rate schedule is used primarily for the sale at negotiated and/or posted rates of surplus firm power and related products. Unless replaced, BPA would lack a rate schedule to sell surplus power in the West Coast wholesale energy markets. 3. Regional Dialogue and the Policy for Power Supply Role for Fiscal Years 2007–2011 (Near-Term Policy) The Regional Dialogue process began in April 2002 when a group of BPA’s Pacific Northwest electric utility customers submitted a ‘‘joint customer proposal’’ to BPA that addressed both near-term and long-term contract and rate issues. Since then, BPA, the Northwest Power and Conservation Council (Council), customers, and other interested parties have worked on these near- and long-term issues. Considering the depth and complexity of many of these issues, BPA concluded it was not practical to resolve all issues before the start of the 2007 rate period. Therefore, BPA determined that it would address the issues in two phases. The first phase of the Regional Dialogue addresses issues that had to be resolved in order to replace power rates that will expire in September 2006. The second phase is expected to be implemented through new power sales contracts and in a future rate case before new power sales contracts go into effect. BPA issued the Near-Term Policy and Record of Decision on February 4, 2005. The Near-Term Policy has resolved some outstanding issues prior to the start of the 2007 rate period. Those issues include, but are not limited to, the following: a. FY 2007–2011 Rights to Lowest-Cost Priority Firm (PF) Rate BPA will apply the lowest-cost PF rates to its public agency customers whose contracts contain the lowest-cost PF rate guarantee throughout the remaining term of the Subscription power sales contracts. b. Term of the Next Rate Period BPA will limit the duration of the next rate period to three years, from FY 2007 through FY 2009. c. Five-Year Contract Holders Public customers whose contracts do not contain a guarantee of the lowest cost-based PF rates for FY 2007–2011 will receive the same rate treatment in the FY 2007–2011 period as customers whose contracts contain this guarantee, so long as such customers signed a new E:\FR\FM\08NON1.SGM 08NON1 67688 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices benefits. See Section 4, below, for a description of that later decision. contract or amendment by June 30, 2005, extending the term of the agreement through 2011. d. Product Availability Any new or existing public customer whose contract expires in 2006 may select from any of the standard products except Complex Partial (Factoring), Block with Factoring, or Slice. In addition, BPA resolved not to offer contract amendments that would allow changes in the power products and services purchased under a customer’s 10-year Subscription contract. e. Service to Residential and SmallFarm Consumers of Investor-Owned Utilities (IOUs) BPA’s Subscription contracts with the region’s six IOUs require the agency to provide 2,200 aMW of power or financial benefits to the residential and small-farm consumers of these customers during FY 2007–2011. BPA signed agreements in late May 2004, with all six regional IOUs that provide certainty in the amount and manner that benefits will be provided to their residential and small-farm consumers under their Subscription contracts for 2007–2011. These agreements provide certainty by defining benefits based on a methodology that uses independent market-prices in calculating the financial benefits, and establishing a floor of $100 million and a cap of $300 million per year for the financial benefits. f. Service to Direct Service Industries (DSIs) BPA determined that it will provide eligible Pacific Northwest DSIs some level of Federal power service benefits, at a known quantity and capped cost, in the FY 2007–2011 period. In the NearTerm Policy, BPA decided that for the FY 2007–2011 period it would continue the ramp-down in DSI service by providing eligible DSI customers some level of service benefits, at a known quantity and capped cost, at rates no lower than rates paid by BPA’s public customers, and under contractual terms no better than those offered to other customers. In order to provide an opportunity for additional dialogue with (and among) customers in the hope of achieving consensus for a balanced and durable solution for service to the DSIs, BPA noted in the Near-Term Policy that it reserved for later decision: (1) The actual level of service benefits it would provide; (2) the eligibility criteria it would apply in determining which DSIs would qualify for such service benefits; and (3) the mechanism or mechanisms it would use to deliver those service VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 4. Service to DSIs The Near-Term Policy established parameters for service to the DSIs which were addressed in Bonneville Power Administration’s Service to DSI Customers for Fiscal Years 2007–2011 Administrator’s Record of Decision (DSI ROD) (June 30, 2005). In the DSI ROD, BPA determined to offer the aluminum company DSIs power sales contracts for an aggregate 560 aMW of benefits at a capped $59 million cost. In addition, BPA offered a 17 aMW surplus firm power sales contract for Port Townsend Paper Company through the local public utility under the FPS rate (or the IP rate if viable) at a price approximately equivalent to, but in no case less than, its lowest-cost PF rate. BPA decided to allocate a share of the 560 aMW service benefits to each DSI aluminum company for purposes of making an initial offer of service, but the creditworthiness of each DSI, on a prospective basis, will determine whether BPA executes a contract with that company. In addition, each DSI aluminum company must demonstrate that it is operational. Because of the financial risks inherent in providing actual power and in order to meet the known and capped cost prerequisite, BPA determined that the default delivery mechanism would be to monetize the value of the below-market power sales to provide service benefits through cash payments. However, BPA retains an option to provide actual power in-lieu of monetizing the transaction. 5. Power Function Review In January 2005, BPA initiated an extensive and in depth process to examine the PBL’s program levels. This Power Function Review (PFR) provided customers and constituent’s significant opportunity to provide input into the policy choices that drive program cost projections to be used in BPA’s initial power rate proposal. The PFR focused on nine major cost areas: a. Army Corps of Engineer and Bureau of Reclamation operation and maintenance costs and capital investments; b. Columbia Generating Station operation and maintenance costs and capital investments; c. Conservation program costs; d. Fish and wildlife program expenses and capital investments; e. Internal operations costs charged to power rates; f. Renewable program costs; PO 00000 Frm 00031 Fmt 4703 Sfmt 4703 g. Transmission acquisition costs; h. Risk mitigation packages and tools; and i. Federal and Non-Federal debt service and debt management. Two main areas, (1) debt service and debt management and (2) risk mitigation, were discussed but not decided in the PFR. The PFR involved technical staff meetings, management level discussions, and regional public meetings. In total, BPA held seven technical meetings, five formal discussion sessions with utility managers and five regional public meetings that involved general managers representing public customers, and customer representatives representing customers and constituent groups. During this five-month review, interested persons submitted a total of 94 written comments to BPA about the issues under discussion. At the close of the comment period, BPA issued a draft close-out letter with proposed program cost levels, delineated the consequences and opportunities of further reductions, and sought comment on those proposed levels. BPA received a number of additional written comments on the draft close-out letter. A final close-out letter was issued June 24, 2005. The PFR resulted in $96 million in reductions per year in forecasted program level cost estimates. In the close-out letter, BPA responded to the comments provided on the draft and laid out the program level cost estimates that would be used in BPA’s WP–07 Initial Proposal. In addition, BPA committed to revisit many of the program areas when more information is known. BPA will hold discussions separately from the rate case proceedings to share the updated forecasts, define associated policy choices, and solicit feedback from customers and constituents before they are incorporated into the final rates. 6. Post-2006 Conservation Program Structure Proposal In the fall of 2004, BPA established a post-2006 conservation workgroup. The conservation workgroup was composed of over 65 utility representatives and conservation stakeholders. The purpose of the workgroup was to discuss and develop BPA’s conservation program for the post-2006 time frame. In January 2005, the workgroup provided BPA with recommendations and comments on how BPA should design its conservation program. On March 28, 2005, BPA issued its Post-2006 Conservation Program Structure Proposal for review and a 30day comment period. BPA received 56 comments on the proposal. On June 28, E:\FR\FM\08NON1.SGM 08NON1 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices reflected the terms of the Settlement Agreement. On June 20, 2005, BPA issued the Final Transmission ProposalAdministrator’s Record of Decision that adopted the transmission and ancillary services rates as reflected in the Settlement Agreement. Final approval of these TBL rates was issued by FERC on September 29, 2005. The TBL rate case settlement established formula rates for ancillary services and some 7. Transmission Rate Case transmission rates that incorporate ancillary services. For FY 2007, these BPA is committed to marketing its formula rates will be affected by the power and transmission services pricing of generation inputs to ancillary separately in a manner that is modeled services that will be determined in this after the regulatory initiatives adopted PBL rate case. The pricing of generation in 1996 by FERC to promote inputs to ancillary services determined competition in wholesale power in this rate case also will be a factor in markets. The Commission’s initiatives in Orders 888 1 and 889 2 directed public TBL’s rates in FY 2008–2009. utilities regulated under the Federal B. Scope of the 2007 Rate Case Power Act to separate their power Many of the decisions that guide merchant functions from their BPA’s power marketing policies have transmission reliability functions; been made or will be made in other unbundle transmission and ancillary services from wholesale power services; public review processes. This section provides guidance to the Hearing Officer and set separate rates for wholesale as to those matters that are within the generation, transmission, and ancillary scope of the rate case, and those that are services. Although BPA is not required outside the scope. by law to follow the Commission’s 2005, BPA issued its response to the comments along with its final decision on the design and scope of the Post2006 proposal. The proposal described the approach of the conservation programs that BPA will offer during the FY 2007 through 2009 timeframe. The decisions in the Post-2006 proposal have been used as inputs in the development of BPA’s WP–07 Initial Proposal. regulatory directives that promote competition and open access transmission service, BPA elected to separate its power and transmission operations and unbundle its rates in a manner consistent with the directives concerning open access transmission service. BPA develops its transmission rates in separate proceedings from its power rates. On February 2, 2005, BPA’s Transmission Business Line (TBL) initiated a rate case to establish transmission rates for the FY 2006–2007 transmission rate period. Prior to the initiation of that rate case, TBL held several public meetings with customers over the period July through September 2004 to discuss transmission costs, revenues, and rate design issues for the FY 2006–2007 rate period. The customers expressed interest in meeting with TBL to develop a settlement for the FY 2006–2007 rate period. TBL continued meetings with customers between October and early December 2004, resulting in a Settlement Agreement. TBL’s initial rate proposal 1 Promoting Wholesale Competition Through Open Access Non-Discriminatory Transmission Services by Pubic Utilities; Recovery of Stranded Costs by Public Utilities and Transmitting Utilities Reg-Preamble, FERC Stats & Regs 1991–96, para. 31,036 (1996). 2 Open Access Same-Time Information System (formerly Real-Time Information Networks) and Standards of Conduct, Reg-Preamble, FERC Stats & Regs 1991–96, para. 31,035 (1996). VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 1. Program Level Expenses Decided in the PFR As described above, the program level expense estimates, except those decided elsewhere, have already received extensive public review and comment in the PFR process. Pursuant to § 1010.3(f) of BPA Hearing Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record any material attempted to be submitted or arguments attempted to be made in the hearing which seek to in any way revisit the appropriateness or reasonableness of BPA’s decisions on spending levels, as included in BPA’s revenue requirements for FYs 2007 through 2009. However, as noted above, BPA did commit to revisit many of the program areas where final results were not known at the time the final report was issued and will hold discussion separately from the rate case proceeding to share the updated forecasts, define associated policy choices, and solicit feedback from customers and constituents before they are incorporated into the final rates. Excepted from this direction due to their variable nature, dependency on BPA’s rate case models, and/or timing, are: (1) Forecasts of short-term purchase power costs; (2) capital recovery matters such as interest rate forecasts, scheduled amortization, depreciation, replacements, and interest expense; and (3) risk mitigation packages and tools. PO 00000 Frm 00032 Fmt 4703 Sfmt 4703 67689 2. Near-Term Policy Decisions As detailed above, BPA issued the Near-Term Policy on February 4, 2005. The Policy resolved a number of policy decisions that impact the design and features of BPA’s WP–07 Initial Proposal. Those issues include but are not limited to, decisions on the availability of the lowest cost PF rate to public customers, term of the rate period, IOU and DSI service options, and the availability of products for new or existing customers. Pursuant to § 1010.3(f) of BPA Hearing Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record any material attempted to be submitted or arguments attempted to be made in the hearing which seek to in any way revisit the appropriateness or reasonableness of BPA’s decisions made in the Near-Term Policy ROD. 3. DSI Service The DSI Service decisions finalized and established the manner and method by which BPA would provide service and benefits to its DSI customers. The decisions in that ROD resolved the method and level of service to be provided DSIs in the FY 2007–2011 period. Pursuant to § 1010.3(f) of BPA Hearing Procedures, the Administrator directs the Hearing Officer to exclude from the record any material attempted to be submitted or arguments attempted to be made in the hearing which seek to in any way revisit the appropriateness or reasonableness of BPA’s decisions made in the DSI ROD. 4. Transmission Acquisition Expense In addition to the program cost decisions, the PFR close-out letter also included transmission acquisition program cost level decisions. This program represents the cost associated with services necessary to deliver energy from generating resources to markets and loads. These costs include: transmission expenses; ancillary services; real power losses; generation integration costs associated with the U.S. Army Corps of Engineers and Bureau of Reclamation transmission facilities; and metering and communication requirements. In addition to these decisions, BPA determined the mechanism for modeling the variability in transmission expenses for the upcoming rate period. Pursuant to § 1010.3(f) of BPA Hearing Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record any material attempted to be submitted or arguments attempted to be made in the hearing which seek to in any way revisit the E:\FR\FM\08NON1.SGM 08NON1 67690 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices appropriateness or reasonableness of BPA’s transmission acquisition program level estimates or the modeling used to calculate the variability of the transmission expense. The only issue associated with the transmission acquisition program within the scope of this rate case is the risk analysis associated with modeling the transmission expense. In the PFR close-out letter, BPA agreed to model the transmission expense based on the full distribution of secondary sales rather than the average transmission expense. This issue will be addressed in the risk analysis portion of the rate case. 5. Other Transmission Issues a. Generation Inputs BPA’s Power Business Line (PBL) provides a portion of the FCRPS’s available generation to the TBL to enable TBL to meet its various transmission requirements. TBL uses the generation inputs to provide ancillary and control area services. To recover the costs associated with providing these generation inputs, PBL assigns a portion of the FCRPS costs to the transmission function. The cost allocations PBL is proposing to use to determine the generation input costs and associated unit costs to the TBL is a matter that is included within the scope of this rate proceeding. Pursuant to § 1010.3(f) of BPA Hearing Procedures, the Administrator directs the Hearing Officer to exclude from the record any material attempted to be submitted or arguments attempted to be made in the hearing that seek in any way to revisit the appropriateness or reasonableness of any other issues related to the generation inputs. This includes, but is not limited to, issues regarding the level or quality of the generation inputs that TBL requests from PBL. These determinations are generally made by TBL in accordance with industry, reliability, and other compliance standards and criteria, and are not matters appropriate for the rate case. b. Transmission Rate Case On June 20, 2005, BPA issued the Final Transmission Proposal ROD in TBL’s rate case, which received final approval on September 29, 2005. Pursuant to § 1010.3(f) of BPA Hearing Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record any material attempted to be submitted or arguments attempted to be made in the hearing which seek in any way to revisit the appropriateness or reasonableness of issues determined in the TBL rate case. That proceeding VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 addressed, among other things, transmission and ancillary service rate levels, the $1.5 million payment from TBL to PBL for Attachment K redispatch for FY 2006–2007, and the GTA Delivery Charge for FY 2007. 6. Post-2006 Conservation Program Structure Proposal Through the post-2006 workgroup collaboration, customers and constituents provided input on the development of BPA’s post-2006 conservation approach. Pursuant to § 1010.3(f) of BPA Hearing Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record any material attempted to be submitted or arguments attempted to be made in the hearing that seek to in any way revisit the appropriateness or reasonableness of BPA’s conservation programs and establishment of expense levels through the Post-2006 Conservation Program Structure Proposal dated June 28, 2005. The Hearing Officer is directed to exclude from the scope of this proceeding evidence regarding BPA’s portfolio of conservation programs and the expenses BPA intends to pursue during the upcoming rate period. 7. Federal and Non-Federal Debt Service and Debt Management During the PFR, and in other forums, BPA provided background information on its internal Federal and non-Federal debt management policies and practices. The discussions of these topics in the PFR and other forums were not intended to seek input from customers and constituents regarding BPA’s debt management policies and practices. Rather, these discussions were intended to merely inform interested parties about these matters so that they would better understand BPA’s debt structure. Although the PFR close-out letter did not make any decisions regarding BPA’s debt management policies and practices, these remain outside the scope of the rate case. Therefore, pursuant to § 1010.3(f) of BPA Hearing Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record any material attempted to be submitted or arguments attempted to be made in the hearing which seek to in any way visit the appropriateness or reasonableness of BPA’s debt management policies and practices. 8. Potential Environmental Impacts The Administrator directs the Hearing Officer to exclude from the record all evidence and argument that seek in any way to address the potential environmental impacts of the rates PO 00000 Frm 00033 Fmt 4703 Sfmt 4703 being developed in the 2007 Wholesale Power Rate Case. See Section C, below. C. The National Environmental Policy Act BPA is in the process of assessing the potential environmental effects of its WP–07 Initial Proposal, consistent with the National Environmental Policy Act (NEPA). BPA’s Business Plan Environmental Impact Statement (Business Plan EIS), completed in June 1995, evaluated the environmental impacts of a range of business plan alternatives that could be varied by applying policy modules, including one for rates. Any combination of alternative policy modules should allow BPA to balance its costs and revenues. The Business Plan EIS also addressed response strategies, including adjusting rates that BPA could pursue if BPA’s costs exceeded its revenues. In August 1995, the BPA Administrator issued a Record of Decision (Business Plan ROD) that adopted the Market-Driven Alternative from the Business Plan EIS. This alternative was selected because, among other reasons, it allows BPA to: (1) Recover costs through rates; (2) competitively market BPA’s products and services; (3) develop rates that meet customer needs for clarity and simplicity; (4) continue to meet BPA’s legal mandates; and (5) avoid adverse environmental impacts. BPA also committed to apply as many response strategies as necessary when BPA’s costs and revenues do not balance. Because the WP–07 Initial Proposal likely would assist BPA in accomplishing these goals, the proposal appears consistent with these aspects of the Market-Driven Alternative. In addition, this rate proposal is similar to the type of rate designs evaluated in the Business Plan EIS; thus implementation of this rate proposal would not be expected to result in significantly different environmental impacts from those examined in the Business Plan EIS. Therefore, BPA expects that this WP–07 Initial Proposal will fall within the scope of the Market-Driven Alternative that was evaluated in the Business Plan EIS and adopted in the Business Plan ROD. As part of the Administrator’s ROD that will be prepared regarding this 2007 Wholesale Power Rate Case, BPA may tier its decision under NEPA to the Business Plan ROD. However, depending upon the ongoing environmental review, BPA may, instead, issue another appropriate NEPA document. E:\FR\FM\08NON1.SGM 08NON1 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices Part III—Public Participation A. Distinguishing Between ‘‘Participants’’ and ‘‘Parties’’ BPA distinguishes between ‘‘participants in’’ and ‘‘parties to’’ the 7(i) hearing process. Apart from the formal hearing process, BPA will accept comments, views, opinions, and information from ‘‘participants’’ who are defined in the BPA Hearing Procedures as persons who may submit comments without being subject to the duties of, or having the privileges of, parties. Participants’ written and oral comments will be made a part of the official record and considered by the Administrator when making his decision. Participants are not entitled to participate in the prehearing conference; may not cross-examine parties’ witnesses, seek discovery, or serve or be served with documents; and are not subject to the same procedural requirements as parties. The views of the participants are important to BPA. Written comments by participants will be included in the record if they are received by 5 p.m. on February 13, 2006. This date follows the anticipated submission of BPA’s and all other parties’ direct cases. Written views, supporting information, questions, and arguments should be submitted to BPA Communications at the address listed in Section 2 of this Notice. In addition, BPA will hold six field hearings in the Pacific Northwest region. Participants may appear at the field hearings and present oral statements. The transcripts of these hearings will be part of the record upon which the Administrator makes his final rate decisions. Persons wishing to become a party to BPA’s rate proceeding must notify BPA in writing and file a Petition to Intervene with the Hearing Officer. Petitioners may designate no more than two representatives upon whom service of documents will be made. Petitions to Intervene shall state the name and address of the person requesting party status and the person’s interest in the hearing. Petitions to Intervene as parties in the rate proceeding are due to the Hearing Office by 5 p.m. on November 17, 2005. The petitions should be directed as stated below or may be e-mailed to the following e-mail address: jsanders@bpa.gov: Jennifer Sanders, Hearing Clerk—LP–7, Bonneville Power Administration, 905 NE 11th Avenue, P.O. Box 3621, Portland, OR 97208– 3621. Petitioners must explain their interests in sufficient detail to permit the Hearing Officer to determine VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 whether they have a relevant interest in the proceeding. Pursuant to § 1010.1(d) of BPA Hearing Procedures, BPA waives the requirement in § 1010.4(d) that an opposition to an intervention petition must be filed and served 24 hours before the November 21, 2005, prehearing conference. Any opposition to an intervention petition may instead be made at the prehearing conference. Any party, including BPA, may oppose a petition for intervention. Persons who have been denied party status in any past BPA rate proceeding shall continue to be denied party status unless they establish a significant change of circumstances. All timely applications will be ruled on by the Hearing Officer. Late interventions are strongly disfavored. B. Developing the Record The record will comprise, among other things, verbal and written comments made by participants, including the transcripts of all hearings, any written material submitted by the parties, documents developed by BPA staff, BPA’s environmental analysis and comments accepted on it, and other material accepted into the record by the Hearing Officer. Written comments by participants will be included in the record if they are received by 5 p.m., Pacific Standard Time, on February 13, 2006. The Hearing Officer will then review the record, supplement it if necessary, and will certify the record to the Administrator for decision. The Administrator will develop final proposed rates based on the entire record, which includes the record certified by the Hearing Officer, as described above. The basis for the final proposed rates first will be expressed in the Administrator’s draft ROD. Parties will have an opportunity to respond to the draft ROD as provided in BPA Hearing Procedures. The Administrator will serve copies of the final ROD on all parties. At the conclusion of the rate proceeding, BPA will file its rates with FERC for confirmation and approval at least 60 days prior to October 1, 2006. BPA must continue to meet with customers in the ordinary course of business during the rate case. To comport with the rate case procedural rule prohibiting ex parte communications, BPA will provide the prescribed notice of meetings involving rate case issues in order to permit the opportunity for participation by all rate case parties. These meetings may be held on very short notice. Consequently, the parties should be prepared to devote the necessary resources to participate fully in every aspect of the rate PO 00000 Frm 00034 Fmt 4703 Sfmt 4703 67691 proceeding and attend meetings any day during the course of the rate case. Part IV—Major Studies and Summary of Proposal A. Summary of Proposed 2007 Wholesale Power Rate Structure 1. List of Proposed 2007 Wholesale Power Rates BPA is proposing five different rate schedules for its 2007 Wholesale Power Rates. The actual rate schedules and the GRSPs are available for viewing and downloading on PBL’s Web site at www.bpa.gov/power/ratecase as discussed in Part V of this Notice. a. PF–07 Priority Firm Power Rate The PF rate schedule is comprised of two rates: the PF Preference rate and the PF Exchange rate. The PF Preference rate applies to BPA’s firm power sales to be used within the Pacific Northwest by public bodies, cooperatives, and Federal agencies. This power is guaranteed to be continuously available. The rate applies to the following products: Full Service Product Actual Partial Service Product—Simple Actual Partial Service Product— Complex Block Product Block Product with Factoring Block Product with Shaping Capacity Slice Product The PF Exchange rate applies to sales of power to regional utilities that participate in the Residential Exchange Program established under Section 5(c) of the Northwest Power Act, 16 U.S.C. 839c(c). b. NR–07 New Resource Firm Power Rate The New Resource Firm Power (NR) rate applies to net requirements power sales to IOUs for resale to ultimate consumers for direct consumption, construction, test, and start-up, and for station service. NR–07 firm power is also available to public utility customers for serving New Large Single Loads. This rate applies to the following products: New Large Single Loads Full Service Product Actual Partial Service Product—Simple Actual Partial Service Product— Complex Block Product Block Product with Factoring Block Product with Shaping Capacity c. IP–07 Industrial Firm Power Rate The IP rate is available for discretionary firm power sales to DSI E:\FR\FM\08NON1.SGM 08NON1 67692 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices customers authorized by Section (5)(d)(1)(A) of the Northwest Power Act, 16 U.S.C. 839c(d)(1)(A). d. FPS–07 Firm Power Products and Services Rate Schedule FPS The FPS rate schedule is available for the purchase of Firm Power, Capacity Without Energy, Supplemental Control Area Services, Shaping Services, and Reservation and Rights to Change Services for use inside and outside the Pacific Northwest. The rates for these products are posted and/or negotiated. BPA is not obligated to enter into agreements to sell products and services under this rate schedule. e. GTA–07 General Transfer Agreement Delivery Charge The GTA Delivery Charge applies to customers who purchase Federal power that is delivered over non-Federal low voltage transmission facilities. The rate was set in the 2006 TBL Rate Case Settlement and approved by FERC on September 29, 2005, to mirror the Utility Delivery rate from October 1, 2005, through September 30, 2007. The 2006 TBL Rate Case Settlement set the GTA Delivery Charge at $1.119 per kilowatt-month through September 30, 2007. For the period of October 1, 2007 through September 30, 2009, PBL is proposing to continue to set the GTA Delivery Charge to the same rate as TBL’s posted Utility Delivery rate. As adjustments are made to the Utility Delivery rate in future TBL rate cases, PBL proposes to reflect these changes in the GTA Delivery Charge. 2. Significant Rate Development Issues a. Risk Mitigation Several factors present new challenges for BPA to keep its power rates low while fulfilling its mission and meeting its obligations to the U.S. Treasury consistent with sound business principles. Increased market price volatility and six consecutive years of below-average runoff have significantly changed the landscape of risk and uncertainty facing BPA and its stakeholders. The uncertainty and volatility of market prices are greater today than they have been in the past. As a consequence, the cost of covering the risk BPA faces in crediting a large portion of secondary revenues to power rates before receiving those uncertain funds is now greater. BPA also faces uncertainty around the operational costs for fish programs in FY 2006 and in the FY 2007–2009 rate period. A new Biological Opinion or possible courtordered change to river operations would directly affect BPA’s net VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 revenues. In addition, enhanced risk management practices resulted in analysis that accounts for operational risks not previously modeled as well as a more comprehensive analysis of nonoperating risks. Finally, the $325 million Fish Cost Contingency Fund (FCCF) was fully depleted in FY 2003 resulting in the loss of a risk tool that was available to mitigate dry year impacts on fish operations. These changes create greater risk for BPA, reduce BPA’s ability to absorb those risks, increase the costs of managing risks, and/or more fully reflect the costs of managing them. If rates were designed using a traditional approach of adding Planned Net Revenues for Risk (PNRR), these changes would require that power rates be set to recover a much larger ‘‘risk premium’’ than ever before in order to meet the Treasury Payment Probability (TPP) standard which, if this was the sole approach to managing risk, would result in a relatively high rate. Additional cash reserves and/or a more comprehensive risk mitigation package, such as the cost recovery adjustment clauses implemented in the FY 2002– 2006 rates, are necessary to address these risks and ensure that BPA can maintain its minimum TPP standard of 92.6% 3 for the rate period. As noted above, BPA faces a level of uncertainty regarding its assumption concerning river operations as well as direct program costs for fish and wildlife due to the ongoing issues surrounding BPA fish and wildlife obligations. To mitigate against this risk, BPA has proposed a specific rate adjustment (NFB adjustment). In order to balance the need to cover risk with overall rate levels, BPA is proposing to meet its TPP standard through a combination of PNRR, cost recovery adjustment charges, the NFB adjustment and a dividend distribution clause. See Sections 3 and 4, below. BPA has been meeting with customers and the parties over the last year to explore alternative means of managing risk that would allow the TPP standard to be met with lower rates. BPA has committed to continue these discussions over the next several months in properly noticed meetings to continue to pursue the viability of these options in order to include them in the final studies. 3 92.6% TPP for a three-year rate period is equivalent to BPA’s TPP standard of 95% applied to a two-year rate period. Two years were assumed to be the length of rate periods when the TPP standard was set. PO 00000 Frm 00035 Fmt 4703 Sfmt 4703 b. Residential Exchange Program Settlement Benefits Under Residential Exchange Program (REP) settlement agreements executed by BPA and the IOUs in 2000, BPA originally provided the IOUs 1,000 aMW of power benefits and 900 aMW of monetary benefits for the FY 2002–2006 period. Power sales were originally made at the Residential Load (RL) Firm Power Rate and the PF Exchange Subscription rate. Monetary benefits were originally calculated based on the difference between BPA’s RL rate and BPA’s then-current rate case 5-year flat block price forecast. The benefits increase to 2,200 aMW for the FY 2007– 2011 period either in the form of power or monetary benefits, at BPA’s discretion. Based on amendments of the REP settlement agreements in 2004, and the Near-Term Policy, however, BPA will not sell power to the IOUs during FY 2007–2011. BPA therefore is not proposing to establish an RL rate or a PF Exchange Subscription rate for IOU power sales in the WP–07 rate case. Instead, all IOU Settlement benefits for the FY 2007–2011 period are monetary benefits calculated based on the difference between an independent determination of a forecast of a forward flat block market price and BPA’s flat PF rate, consistent with the IOU contracts. c. Inter-Business Line Calculations BPA is addressing certain interbusiness line issues in this 2007 Power Rate Case. These include the generation inputs for: generation supplied reactive and voltage support; operating reserves; regulating reserves; generation and energy imbalance; generation dropping for remedial action schemes; and station service. Segmentation of the Corps of Engineers (COE) and the Bureau of Reclamation (Reclamation) facilities will also be addressed. BPA is proposing methodologies to calculate the costs of these services, and forecast revenues, in order to determine BPA’s power revenue requirement to be recovered through power rates. These generation costs, or associated unit costs, will be allocated to TBL to support TBL’s ancillary services and other operations. Relevant transmission and ancillary service rates for FY 2006– 2007 include formulas that allow for the costs and charges developed in this power rate case to be factored into the transmission and ancillary service rates. BPA is also proposing to set a GTA Delivery Charge as determined by the 2006 Transmission rate settlement. This power rate proceeding will establish the GTA Delivery Charge for FY 2008 and 2009. E:\FR\FM\08NON1.SGM 08NON1 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices d. DSI Service 2007–2011 Consistent with the DSI ROD, BPA is not forecasting direct service under the IP rate to the DSI customers. Instead, BPA plans to offer the DSI aluminum smelters 560 aMW of surplus firm power service benefits for the FY 2007– 2011 period at a capped cost of $59 million per year. BPA will offer Port Townsend Paper Company 17 aMW of surplus firm power service benefits, whereupon its local utility will provide power at a utility rate expected to be approximately equivalent to, but in no case lower than, BPA’s PF rate. With the DSI aluminum companies, creditworthiness standards must be met or acceptable credit assurances must be provided by those companies qualifying for benefits. In addition, benefits can be monetized under the proposed contracts with these companies, but BPA will retain the right to provide physically delivered surplus power, subject to long-term interruption rights, in lieu of a financial transaction. 3. Changes in Rate Design BPA is continuing, in general, its existing rate design for its FY 2007– 2009 rates, with some changes and modifications as described below. Complete details on these changes are available for viewing and downloading on PBL’s Web site at www.bpa.gov/ power/ratecase as discussed in Part V of this Notice. a. Conservation Rate Credit (CRC) BPA is proposing to replace the Conservation and Renewables (C&R) Discount with a Conservation Rate Credit (CRC) program. The CRC will retain many of the features of the C&R Discount including: (1) The credit will remain at 0.5 mills per kWh; (2) monthly bill credits; (3) no decrement to customers’ net requirements for CRC participation (including Slice customers); (4) customer flexibility in choosing between several eligible conservation and renewable energy measures; and (5) funding under the CRC for customer renewable resource activities is limited to $6 million annually. b. Dividend Distribution Clause (DDC) BPA is proposing to continue the DDC with a modification to the Threshold. BPA proposes that there will be a DDC if Accumulated Modified Net Revenues (AMNR) reach the equivalent of $800 million in reserves attributable to PBL. c. Excess Factoring Charge This is a charge that applies to purchasers of the Complex Actual Partial Service Product under the PF VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 67693 rate schedule. BPA is proposing minor changes to eliminate references to the California Power Exchange. market prices. The charge is set at 0.53 mills per kWh and is charged against the customer’s Total Retail Load. d. Green Energy Premium BPA is proposing to continue the Green Energy Premium (GEP), available to customers purchasing firm power. The GEP is an adjustment to the PF rate when a customer chooses to designate any portion (up to 100 percent) of its Subscription purchase as Environmentally Preferred Power. The GEP will range from zero to 40 mills per kWh depending on the specific products and associated costs selected by each customer. BPA forecasts an average of $1.4 million of annual revenue from the GEP over the rate period. Revenues from the GEP will support BPA renewable resource facilitation and research and development. g. Low Density Discount (LDD) e. Load-Based Cost Recovery Adjustment Charge (LB CRAC) True-Up BPA is not proposing to continue the existing LB CRAC in the FY 2007–2009 rate period. However, the LB CRAC contemplates an after-the-fact true-up as soon as the necessary actual data is available after each sixth-month LB CRAC period. The final LB CRAC TrueUp is anticipated to occur in December 2006, after the expiration of BPA’s current rates on September 30, 2006. Therefore, BPA is proposing to carry over the LB CRAC True-Up provisions in the GRSPs for the FY 2007–2009 rate period to allow for the final True-Up. Implementation will be limited to the true-up for the final 6 months (LBCRAC10 period) of the 2002–2006 rate period. True-Up billing adjustments will be made over twelve months starting in early 2007. f. Load Variance Charge BPA is proposing to continue the Load Variance Charge. This charge covers BPA’s cost of meeting customers’ load growth for reasons other than annexation or retail access load gain or loss. In addition, it provides Full and Partial Service purchasers the right to deviate from their monthly forecast BPA purchases due to weather, economic business cycles, plant energy consumptions and other reasons. The method for setting the Load Variance charge in this rate proposal differs from the WP–02 rate-setting process. It is no longer based on the cost of put or call options. Instead, load growth is forecast, and the cost is estimated based on a forecast of future market prices. The cost of forecast error is estimated based on an assumption of a two percent forecast error and a forecast of future PO 00000 Frm 00036 Fmt 4703 Sfmt 4703 BPA is proposing four changes to the LDD: (1) BPA proposes to change the eligibility criteria to account for BPA’s separation of power and transmission rates which first occurred in 1996, and also to ensure that customers with very low retail rates will not qualify for the LDD; (2) one of the measures used in calculating the LDD is proposed to use ‘‘consumers per mile’’ instead of ‘‘meters per mile’’ to ensure consistency and equity; (3) the term ‘‘average retail rate’’ has been clarified for simplification of the LDD administration; and (4) BPA proposes to amend LDD to ensure it only applies to the qualifying Slice purchaser’s net requirements. h. Monthly Demand and Energy Charges BPA is not proposing changes to the methodology for calculating energy charges. There will be two diurnal periods, Heavy Load Hour (HLH) and Light Load Hours (LLH), for each month. BPA is proposing slight changes to the definitions of HLH and LLH to be consistent with NERC definitions. BPA is proposing to revise the definition of HLH and LLH included in the 2006 Transmission General Rate Schedule Provisions for FY 2007 to be consistent with NERC and BPA’s proposed definitions in the GRSPs for the power rates. The actual energy charges will be updated consistent with the method used in WP–2002. BPA is proposing a minor modification to the methodology for calculating the demand charge. There will continue to be 12 monthly demand charges, but the average rate will decrease from $2.00 per kW-month to $1.05 per kW-month. This change is to better reflect the market price for demand with energy. i. PF Targeted Adjustment Charge (PF TAC) BPA is continuing the Targeted Adjustment Charge, with some proposed modifications. BPA proposes to exempt PF TAC loads from the PF TAC in any year of the three years of the rate period that the load subject to the TAC is less than 1 aMW. The TAC will apply to the entire load if it exceeds the minimum. Also, the calculation of the PF TAC rate will be based on monthly availability of the Federal Base System (FBS), rather than an annual calculation. E:\FR\FM\08NON1.SGM 08NON1 67694 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices j. Unauthorized Increase Charges (UAI) for Power Sales These are penalty charges for Unauthorized Increases in Energy and Unauthorized Increases in Demand for deliveries that exceed contractual entitlements for energy and demand, respectively. BPA is proposing minor changes to the UAI to eliminate references to the California Power Exchange. 4. New Adjustments in Rates BPA is proposing a number of new adjustments and continuing some existing adjustments. Complete details of these adjustments are available for viewing and downloading on PBL’s Web site at www.bpa.gov/power/ratecase as discussed in Part V of this Notice. a. Operating Reserves BPA is proposing changes in how it handles its forecasted revenues from providing operating reserves to the TBL. BPA’s Open Access Transmission Tariff requires transmission customers serving load with generation located in the Transmission Provider’s Control Area to acquire Operating Reserves from the Transmission Provider, from a third party, or by self-supply. The 2002 power rate case estimated total revenue recovered by PBL selling Operating Reserves generation inputs to TBL, assuming all customers purchased Operating Reserves from TBL. The expected revenue from the sale of Operating Reserves was deducted from the overall revenue requirement when determining the cost of the Federal system which is the basis for calculating power rates. During this current rate period, some customers began selfsupplying Operating Reserves, and TBL has purchased less generation inputs from PBL. Therefore, PBL did not fully recover expected revenues. To avoid this under-recovery in the FY 2007– 2009 rate period and to ensure that revenues are allocated equitably, PBL is proposing to estimate total revenues from the sale of generation inputs to TBL and give a 0.89 mills per kWh credit on the power bills of customers that elect to purchase Operating Reserves from TBL. This will prevent both under-recovery and over-recovery. While BPA proposes not to allocate these revenues or credits to those customers that self-supply Operating Reserves or acquire Operating Reserves from a third party, BPA will consider alternatives to this proposal that address BPA’s concerns regarding the proper allocation of costs and revenues. b. Cost Recovery Adjustment Clause (CRAC) Prior to the beginning of each fiscal year of the rate period (i.e., FY 2007– 2009), a forecast of the previous year’s end-of-year AMNR will be completed. If the AMNR at the end of the forecast year falls below the defined CRAC Threshold for that fiscal year, the CRAC will trigger, and a rate increase will go into effect beginning in October of the upcoming fiscal year. Any such increase in a fiscal year’s rates would remain in effect through September of the following year. This adjustment could occur as early as August 2006 for the rates in effect for FY 2007. The amount of the rate increase is limited to the lower of the annual Maximum Planned Recovery Amount of $300 million or the amount by which AMNRs under run the threshold. CRAC ANNUAL THRESHOLDS AND CAPS (Dollars in millions) CRAC applied to fiscal year AMNR calculated at end of fiscal year 2006 ................................................................................................................. 2007 ................................................................................................................. 2008 ................................................................................................................. c. The NFB Adjustment (National Marine Fisheries Service (NMFS) Federal Columbia River Power System (FCRPS) Biological Opinion (BiOp) Adjustment) The NFB adjustment results in an upward adjustment to the CRAC Maximum Planned Recovery Amount (Cap) for any year in the rate period if unforeseen fish and wildlife costs arise from a predetermined set of circumstances. The NFB Adjustment calculation will result in an increase in the annual CRAC maximum recovery amount defined in Table A for the next fiscal year following the year the NFB Adjustment was triggered. The NFB Adjustment is applicable to FY 2007— 2009. The NFB Adjustment will address increases in financial impacts to the anadromous fish portion of the Fish and Wildlife program only when those impacts result from changes in FCRPS Endangered Species Act (ESA) compliance as required by a court order VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 2007 2008 2009 (including court-approved agreements), an agreement related to litigation, a new NMFS FCRPS BiOp, or Recovery Plans under the ESA. Financial impacts include foregone revenue, power purchases, direct program expense, fish credits, COE and BOR O&M, and capital repayment. Financial impacts will be calculated net of forecast 4(h)(10)(C) credits. This adjustment would be calculated at the same time that the calculation of the CRAC would be made. 5. Rates With No Proposed Changes The following is a list of rates or adjustments that BPA proposes to continue with no changes from current rates. Complete details on the rates or adjustments are available for viewing and downloading on PBL’s Web site at www.bpa.gov/power/ratecase as discussed in Part V of this Notice. PO 00000 CRAC threshold Approx. threshold as measured in PBL reserves ¥$193 ¥36 ¥45 Maximum CRAC recovery amount (cap)* $470 500 500 a. Demand Adjuster This is an adjustment that is made to the demand billing factor for certain requirements products. b. Flexible PF and NR These are rate options available, at BPA’s discretion, to purchasers under the PF and NR rate schedules. c. Slice True-Up Adjustment BPA is not proposing any changes to the methodology used to conduct the Slice True-up. However, BPA does clarify in its proposal how certain costs are treated with the Slice Rate and Trueup. These include debt optimization, bad debt expenses, augmentation expenses, Conservation Augmentation, IOU and DSI benefits, and Slice implementation expenses. d. Value of Reserves Section 7(c)(3) of the Northwest Power Act, 16 U.S.C. 839e(c)(3), Frm 00037 Fmt 4703 Sfmt 4703 $300 300 300 E:\FR\FM\08NON1.SGM 08NON1 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices provides that the Administrator shall adjust rates to the DSI customers ‘‘to take into account the value of power system reserves made available to the Administrator through his rights to interrupt or curtail service to such direct service industrial customers.’’ The DSIs may provide two types of reserves: Supplemental Contingency Reserves and Stability Reserves. The WP–07 Initial Proposal reflects Stability Reserves being purchased by the TBL and addressed in TBL’s transmission rate case. The PBL is proposing in this rate case to continue the approach to procure Supplemental Reserves developed in the WP–02 Rate Case. The PBL will purchase the most cost-effective Supplemental Reserves or provide those reserves itself. No Supplemental Reserves are explicitly forecast to be provided by the DSIs in this rate case. Any payment to the DSIs for Supplemental Contingency Reserves will be negotiated within a specified range on an individual customer basis rather than a credit applied to some or all of BPA’s DSI load. The maximum amount PBL may pay is $6.96 per kW– month. 6. Rates and Adjustments Proposed To Be Discontinued The following are rates and adjustments that BPA is proposing to discontinue. a. Cost-Based-Indexed IP Rate BPA does not forecast any sales under this product. b. Cost-Based-Indexed PF Rate BPA does not forecast any sales under this product. c. Financial-Based Cost Recovery Adjustment Clause (FB CRAC) BPA is not proposing a FB CRAC for this rate period. See Section 4.b., above, for BPA’s risk mitigation. d. Flexible IP BPA is not proposing a flexible IP rate in the IP rate schedule as BPA does not forecast any sales under the IP rate schedule. e. Industrial Power Targeted Adjustment Charge BPA is not proposing to continue the industrial power targeted adjustment charge as BPA does not forecast any sales under the IP rate schedule. f. Nonfirm Energy Rate Schedule BPA is proposing to discontinue the NF rate in this rate proposal as it is no longer used. VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 g. Residential Load Firm Power Rate (RL) BPA is proposing to discontinue the RL rate in this rate proposal as it is no longer necessary. See Section 2.b. above. h. Safety Net Cost Recovery Adjustment Clause (SN CRAC) BPA is not proposing a SN CRAC for this rate period. See Section 4.b., above, for BPA’s risk mitigation. i. Stepped Rates BPA is not proposing stepped rates in this rate proposal because this is only a 3-year, not a 5-year, rate period. j. Stepped Up Multi-Year (SUMY) Block Charge BPA is not proposing a SUMY block charge in this rate proposal. 7. Development of IP Rate/7(c)(2) Adjustment The IP–07 rate applies to discretionary firm power sales to BPA’s DSI customers who purchase under Section 5(d) of the Northwest Power Act, 16 U.S.C. 839c(d). In this rate proposal, BPA is not forecasting any sales to DSIs under the IP rate but, for various reasons, the IP rate is nonetheless being set according to the rate directives contained in Section 7(c) of the Northwest Power Act, 16 U.S.C. 839e(c). Section 7(c)(1)(B) provides that after July 1, 1985, DSI rates will be set ‘‘at a level which the Administrator determines to be equitable in relation to the retail rates charged by the pubic body and cooperative customers to their industrial consumers in the region.’’ 16 U.S.C. 839e(c)(1)(B). Pursuant to Section 7(c)(2), the IP rate is to be based on BPA’s ‘‘applicable wholesale rates’’ to its preference customers and the ‘‘typical margins’’ included by those customers in their retail industrial rates. 16 U.S.C. 839e(c)(2). Section 7(c)(3) provides that the IP rate is also to be adjusted to account for the value of power system reserves provided through contractual rights that allow BPA to restrict portions of the DSI load. 16 U.S.C. 839e(c)(3). This adjustment is typically made through a value of reserves credit. Continuing past practice and given current circumstances, BPA will not propose a uniform value of reserves credit to be applied against the IP rate. Thus, the IP rate will be set equal to the applicable wholesale rate, plus a typical margin, subject to the floor rate test. As a final step in rate design, BPA develops monthly and diurnally differentiated energy charges and monthly differentiated demand charges based on allocated costs and PO 00000 Frm 00038 Fmt 4703 Sfmt 4703 67695 scaled, based on the results of BPA’s rate design. The typical Industrial Margin is 0.573 mills per kWh. As stated above, a zero value of reserves credit is being forecast in this rate case. Thus, the net margin of 0.573 mills per kWh is added to the seasonal and diurnal PF energy charges to produce the initial IP rate charges. BPA conducts a Section 7(b)(2) rate test as part of its ratemaking process and if the test ‘‘triggers,’’ the initial IP rate charges are increased. In the current rate case, the 7(b)(2) rate test does trigger and additional costs are allocated to the IP rate pool, substantially increasing the IP rate charges above their initial PFplus margin level. In addition, Section 7(c)(2) of the Northwest Power Act requires that IP rates in the post-1985 period ‘‘shall in no event be less than the rates in effect for the contract year ending on June 30, 1985.’’ 16 U.S.C. § 839e(c)(2). Accordingly, a floor rate test is performed to determine if the IP rate has been set at a level below the floor rate. If so, an adjustment is made that raises the IP rate to recover revenues that would be generated by application of the floor rate. Other customer classes are then credited with the increased revenue generated by application of the floor rate test and any resulting adjustment of the IP rate. If the IP rate has been set at a level above the floor rate, no floor rate adjustment is necessary. The first step in calculating the floor rate is to apply the IP–83 Standard rate charges to test period (FY 2007–2009) DSI billing determinants. The resulting revenue figure is then divided by total IP test period loads to arrive at an average rate in mills per kWh. This rate is reduced by an Exchange Cost Adjustment and a deferral that were included in the IP–83 rate. Both adjustments are made on a mills per kWh basis. BPA continues to conduct separate rate cases for power and transmission. Therefore, BPA has removed all transmission costs from the IP–83 rate to make a power-only floor rate comparison. These calculations result in a DSI floor rate of 20.97 mills per kWh. Because the proposed IP rate revenues are greater than the floor rate revenues, no adjustment was necessary. 8. Rate Design and Methodology a. Risk Mitigation Package PBL is proposing to rely on a number of elements for its risk mitigation package in its WP–07 Initial Proposal. These include a Cost Recovery Adjustment Clause (CRAC), with the E:\FR\FM\08NON1.SGM 08NON1 67696 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices NFB Adjustment and a DDC, as described above, as well as the following: (1) Starting Reserves. The financial reserves attributable to PBL at the start of the rate period provide some financial protection against the financial uncertainties it faces. Starting financial reserves include the portions attributed to the generation function of cash in the BPA Fund and the deferred borrowing balance. The expected value for starting reserves is currently $381 million at the beginning of FY 2007. (2) Other Agency Reserves Temporarily Available for Rate-Setting Purposes. BPA will assume that other agency reserves above the level required to meet the transmission function TPP for FY 2006–2007 can be considered for PBL rate-setting purposes to be temporarily available to PBL in FY 2007 only. BPA will ensure that this will not harm the interests of TBL or its customers. (3) PNRR. The anticipated generation function reserves, with the tools noted above, are not sufficient for the agency to meet its financial objective of a 92.6 percent TPP. As a result, BPA’s risk mitigation package includes some PNRR. PNRR is a dollar amount in the generation revenue requirement that generates additional revenue in order to increase the generation function reserves. b. Rates Analysis Model (RAM) The RAM2007 model is a large Excel spreadsheet model that is automated with Visual Basic macros. RAM2007 has three main steps: a Rate Design Step; a Subscription Step; and a Slice Separation Step. The RAM2007 Rate Design Step follows BPA’s rate directives by determining the costs associated with the three resource pools (FBS resources, Residential Exchange resources, and new resources) used to serve sales load, and then allocates those costs to the rate pools (PF, IP, and NR). After the initial allocation of costs, the Northwest Power Act requires that some rate adjustments be made, such as those described in Section 7(b) and Section 7(c) of the Act. The RAM2007 performs these rate adjustments including the 7(b)(2) rate test in its Rate Design Step. The Rate Design Step of the RAM2007 concludes with the calculation of the ‘‘Rate Design Step’’ rates. At this point in the modeling, all posted rates are still preliminary except for the PF Exchange rate which is set and is then used to calculate the net cost of any public utility exchange. The Subscription Step calculates rates that will include the costs of the IOU Residential Exchange Program (REP) VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 settlement. The Subscription Step section takes the rates resulting for the Rate Design Step and adjusts them by first subtracting any net cost of the traditional REP for the IOUs that have been included in the Rate Design Step rates, and then adding the costs of the IOU REP settlement. In the Rate Design and Subscription steps, costs were allocated to the various rate pools, including the PF Preference rate pool that contained all firm PF Preference loads. The Slice Separation Step separates out the PF Slice product revenues and firm loads from the overall PF Preference rate pool, leaving the costs that must be covered by the remaining non-Slice product PF Preference load. B. Studies in Support of WP–07 Initial Proposal The studies that have been prepared to support BPA’s 2007 Initial Wholesale Power Rate proposal are described in detail in this section: Load Resource Study and Documentation (Study about 35 pages, documentation about 120 pages); Revenue Requirement Study and Documentation (Study about 200 pages, documentation about 450 pages); Market Price Forecast Study and Documentation (Study about 25 pages, documentation about 400 pages); Risk Analysis Study and Documentation (Study about 75 pages, documentation about 175 pages); Wholesale Power Rate Development Study and Documentation (Study about 120 pages, documentation about 600 pages); and Section 7(b)(2) Rate Test Study and Documentation (Study about 20 pages, documentation about 120 pages). 1. Load Resource Study The Load Resource Study represents the compilation of the load and resource data necessary for developing BPA’s wholesale rates. The Study has three major interrelated components: (a) BPA’s Federal system load forecast; (b) BPA’s Federal system resource forecast; and (c) the Federal system load and resource balances. The Federal system forecast is composed of customer and group sales forecasts for public utilities and Federal agencies, IOUs, and other BPA contractual obligations. The Federal system resource forecast includes power generated by both Federal and non-Federal hydro projects, return energy associated with BPA’s existing capacity-for-energy exchanges, contracted resources, and other BPA hydro related contracts. The Federal system hydro resource estimates are PO 00000 Frm 00039 Fmt 4703 Sfmt 4703 derived from a hydro regulation study that estimates generation under 50 water years conditions using the operating provisions of the Pacific Northwest Coordination Agreement. The seasonal shape and magnitude of the Federal system hydro generation depends on availability of all regional resources and coordination of those resources to meet regional loads. The projections of Federal system resources are compared with projected Federal system firm loads for each month of Fiscal Years 2007–2009 (October 2007–September 2009) under 1937 water conditions. The resulting load and resource balances yield the firm energy surplus or deficit of the Federal system resources. Similarly, firm capacity surpluses and deficits are determined for the same period. 2. Revenue Requirement Study The purpose of the Revenue Requirement Study is to establish the level of revenues from wholesale power rates necessary to recover, in accordance with sound business principles, the FCRPS costs associated with the production, acquisition, marketing, and conservation of electric power. Generation revenue requirements include: Recovery of the Federal investments in hydrogeneration, fish and wildlife recovery, and energy conservation; Federal agencies’ operations and maintenance expenses allocated to power; capitalized contract expenses associated with such nonFederal power suppliers as Energy Northwest; other purchase power expenses, such as short-term power purchases; power marketing expenses; cost of transmission services necessary for the sale and delivery of FCRPS power; and all other power-related costs incurred by the Administrator pursuant to law. Cost estimates reflect the results of the Power Function Review and certain components of the Subscription Strategy. The repayment studies reflect updated actual and projected repayment obligations and accommodate the ongoing implementation of BPA’s Debt Optimization Program. All new capital investments are assumed to be financed from debt or appropriations. The adequacy of projected revenues to recover rate test period revenue requirements and to recover the Federal investment over the prescribed repayment period is tested and demonstrated for the generation function. 3. Market Price Forecast Study The Market Price Forecast Study estimates the variable hourly cost of the E:\FR\FM\08NON1.SGM 08NON1 Federal Register / Vol. 70, No. 215 / Tuesday, November 8, 2005 / Notices marginal resource for transactions in the wholesale energy market. The specific market used in this analysis is the MidColumbia trading hub in the State of Washington. The Market Price Forecast is used for two purposes in BPA’s rate case. First, it is the basis for approximating the prices BPA may experience when selling to or buying from the wholesale power market. The Market Price Forecast estimates are therefore used to inform, but not directly set, the price used in BPA’s surplus or net secondary revenue forecast. Second, the Market Price Forecast represents BPA’s marginal cost in acquiring new energy, or the opportunity cost BPA may see in selling wholesale energy. The Market Price Forecast is therefore used in rate design and to send market-based price signals. The Market Price Forecast uses a production cost model, AURORA, to estimate a market clearing price for wholesale energy. The fundamental assumption underlying AURORA modeling is the existence of a competitive wholesale energy pricing structure in the Western Electricity Coordinating Council Region. The model dispatches resources in a least cost order to meet a specified demand. Short-term prices are set at the variable cost of the marginal generator. Longterm capital investment decisions are based on economic profitability in an unregulated environment. The study will also forecast independent marketprice forecasts used for IOU and DSI benefits. 4. Risk Analysis Study The Risk Analysis Study focuses upon two types of risks and their impacts on BPA’s revenues and expenses. The first class of risks is comprised of operating risks such as variations in economic conditions, load, and generation resource capability. These operating risks include the impacts of water supply conditions, alternative hydro operations, and market prices on net revenues. These operating risks are modeled in the Risk Analysis Model (RiskMod). The second class of risks comprises non-operating risks—all the risks included in the rate case risk modeling other than operating risks. This class of non-operating risks also includes uncertainty in achieving cost reductions identified in the Power Function Review. These risks are modeled in the Non-Operating Risk Model (NORM). The outputs from RiskMod and NORM are combined to develop the distribution of net revenues and cash flows that are required as input by the ToolKit Model. VerDate Aug<31>2005 16:11 Nov 07, 2005 Jkt 208001 BPA subsequently evaluates the impact that different risk mitigation measures have on reducing net revenue risk by calculating the TPP. The ToolKit Model assesses the impact that the net revenue deviations have on cash reserve levels, calculates the probability that BPA will make each Treasury payment on time and in full. If the TPP is below BPA’s three-year 92.6 percent TPP standard, analysts change the combination of risk mitigation tools (e.g., Cost Recovery Adjustment Clauses, Planned Net Revenues for Risk, Dividend Distribution Clause, etc.) to meet the TPP standard. The amount of PNRR calculated in the ToolKit Model is included in revenue requirements and, thus, affects the level of the rates calculated in the rates analysis model below. 5. Wholesale Power Rate Development Study The Wholesale Power Rate Development Study (WPRDS) is the primary source for details concerning BPA’s power rates. It reflects the results of all of the other studies, documents the Rates Analysis Model, and documents the development of rates for BPA’s wholesale power products and services. The WPRDS documents the allocation and recovery of Federal power costs, development of the Slice cost table; the development and forecast of inter-business line revenues and expenses (including Generation Input of Ancillary Services, segmentation of COE/Reclamation Transmission Facilities and GTA Delivery Charge), the development of charges for demand, load variance, unauthorized increase usage, excess load factoring, numerous rate provisions (e.g. the low-density discount, conservation and renewable discount, and rate mitigation), and the development of diurnal energy charges. Notably, one chapter of the WPRDS discusses BPA’s risk mitigation package (i.e., the CRAC, NFB Adjustment, and DDC). The results of the WPRDS are the wholesale power rate schedules. 6. Section 7(b)(2) Rate Test Study Section 7(b)(2) of the Northwest Power Act directs BPA to assure that the wholesale power rates effective after July 1, 1985, to be charged its public body, cooperative, and Federal agency customers (the 7(b)(2) Customers) for their general requirements for the rate period, plus the ensuing four years (in total, this is known as the test period), are no higher than the costs of power would be to those customers for the same time period if specified assumptions are made. The effect of the rate test is to protect the 7(b)(2) PO 00000 Frm 00040 Fmt 4703 Sfmt 4703 67697 Customers’ wholesale firm power rates from certain costs resulting from provisions of the Northwest Power Act. The rate test can result in a reallocation of costs from the 7(b)(2) Customers to other rate classes. The Section 7(b)(2) Rate Test Study describes the application and results of the Section 7(b)(2) Implementation Methodology. The Section 7(b)(2) rate test triggers in this proposal, causing costs to be reallocated in the test period. The PF Preference rate applied to the general requirements of the 7(b)(2) Customers has been partially reduced by the 7(b)(2) amount. Other rates, including the PF Exchange Program rate applied to customers purchasing under the REP and the IP rate to be charged to any DSI taking direct service from BPA during the rate period, have been increased by an allocation of the 7(b)(2) amount. Because, after allocation of the 7(b)(2) amount, there are no REP loads, no power sales to IOUs, and no direct power sales to DSIs, remaining 7(b)(2) amount costs were allocated to the PF Preference rate. This is required by Section 7(a)(1) of the Northwest Power Act, which provides that BPA’s power rates must recover BPA’s power costs. V. 2007 Wholesale Power Rate Schedules and General Rate Schedule Provisions (GRSPs) BPA’s proposed 2007 Wholesale Power Rate Schedules and GRSPs are available for viewing and downloading on PBL’s Web site at www.bpa.gov/ power/ratecase. A copy of the proposed rate schedules and GRSPs are also available for viewing in BPA’s Public Reference Room at the BPA Headquarters, 1st Floor, 905 NE 11th Avenue, Portland, OR. Issued this 26th day of October, 2005. Stephen J. Wright, Administrator and Chief Executive Officer. [FR Doc. 05–22233 Filed 11–7–05; 8:45 am] BILLING CODE 6450–01–P ENVIRONMENTAL PROTECTION AGENCY [OPPT–2005–0050; FRL–7740–5] Notification of Chemical Exports TSCA Section 12(b); Request for Comment on Renewal of Information Collection Activities Environmental Protection Agency (EPA). ACTION: Notice. AGENCY: SUMMARY: In compliance with the Paperwork Reduction Act (PRA) (44 U.S.C. 3501 et seq.) EPA is seeking E:\FR\FM\08NON1.SGM 08NON1

Agencies

[Federal Register Volume 70, Number 215 (Tuesday, November 8, 2005)]
[Notices]
[Pages 67685-67697]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 05-22233]


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DEPARTMENT OF ENERGY

Bonneville Power Administration

[BPA File No.: WP-07]


2007 Wholesale Power Rate Adjustment Proceeding; Public Hearings, 
and Opportunities for Public Review and Comment

AGENCY: Bonneville Power Administration (BPA), Department of Energy 
(DOE).

ACTION: Notice of proposed wholesale power rates.

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SUMMARY: The Pacific Northwest Electric Power Planning and Conservation 
Act (Northwest Power Act), 16 U.S.C. 839, provides that BPA must 
establish and periodically review and revise its rates so that they are 
adequate to recover, in accordance with sound business principles, the 
costs associated with the acquisition, conservation and transmission of 
electric power, and to recover the Federal investment in the Federal 
Columbia River Power System (FCRPS) and other costs incurred by BPA.

ADDRESSES: 1. Persons wishing to become formal parties to the 
proceeding must file a petition to intervene notifying BPA in writing 
of their intention to do so in conformance with the requirements stated 
in this notice. Petitions to intervene should be directed to Jennifer 
Sanders, Hearing Clerk, LP-7, Bonneville Power Administration, 905 NE 
11th Avenue, Portland, OR 97232 or may be e-mailed to the following e-
mail address: jsanders@bpa.gov, and must be received no later than 5 
p.m., Pacific Standard Time, on November 17, 2005. In addition, a copy 
of the petition must be served concurrently on BPA's General Counsel 
and directed to Peter J. Burger, LP-7, Office of General Counsel, 
Bonneville Power Administration, 905 NE 11th Avenue, Portland, OR 97232 
or be e-mailed to the following e-mail address: http://
www.pjburger@bpa.gov">www.pjburger@bpa.gov. (See Part III (A) for more information.)
    2. Non-party participants may submit written comments between 
November 21, 2005, and February 13, 2006. Comments must be received no 
later than 5 p.m., Pacific Standard Time, on February 13, 2006, in 
order to be considered in the draft Record of Decision (ROD). Written 
comments may be made as follows: in person at the field hearings (see 
schedule and locations in Part I of this Notice), online at BPA's Web 
site: www.bpa.gov/comment, or by mail to: BPA Communications, DKP-7, 
P.O. Box 14428, Portland, OR 97293-4428. Please

[[Page 67686]]

identify written or electronic comments as ``FY 07-09 Power Rate 
Case.'' BPA will consider and address the comments received in the 
draft ROD.
    3. The rate adjustment proceeding will begin with a prehearing 
conference at 9 a.m., Pacific Standard Time on November 21, 2005, held 
in the BPA Rates Hearing Room, 2nd Floor, 911 NE 11th Avenue, Portland, 
OR. BPA will release its 2007 Wholesale Power Rate Case Initial 
Proposal (WP-07 Initial Proposal) and supporting documents at this 
prehearing conference. Compact discs (CDs) containing the WP-07 Initial 
Proposal documents, in PDF format, will be provided to the parties at 
the prehearing conference. The WP-07 Initial Proposal documents will 
also be available on BPA's Web site www.bpa.gov/power/rates. Due to 
increased security, attendees should allow additional time to enter the 
building and sign in at the security desk where photo identification 
will be required for entry.

FOR FURTHER INFORMATION CONTACT: Ms. Jamae Hilliard Creecy, Public 
Affairs Specialist, Public Affairs Office, DKP-7, P.O. Box 14428, 
Portland, OR 97293-4428. Interested persons may also call (503) 230-
4328 or 1-800-622-4519 (toll-free). Information also may be obtained 
from:

Ms. Kimberly Leathley, Manager, Financial Management, Rates, and 
Planning--PF-6, P.O. Box 3621, Portland, OR 97208.
Ms. Elizabeth Evans, Acting Rates Manager--PFR-6, P.O. Box 3621, 
Portland, OR 97208.
Mr. Garry Thompson, Hub Manager, Mr. Ken Hustad, Senior Customer 
Account Executive, or Ms. Carol Hustad, Customer Account Executive, 
Eastern Power Business Area-PSE, 707 W. Main, Suite 500, Spokane, WA 
99201.
Mr. John Lebens, Hub Manager, Western Power Business Area--PSW-6, P.O. 
Box 3621, Portland, OR 97208.
Mr. Larry King, Customer Account Executive, 2700 Overland, Burley, ID 
83318.
Mr. C. T. Beede, Customer Account Executive, P.O. Box 40, Big Arm, MT 
59910.
Mr. Dan Bloyer, Customer Account Executive, 1011 SW Emkay Drive, Suite 
211, Bend, OR 97702.
Mr. Edward Brost, Senior Customer Account Executive, Kootenai Building, 
Room 215, N. Power Plant Loop, Richland, WA 99352-0968.
Mr. Stuart Clarke, Senior Customer Account Executive, Mr. George Reich, 
Senior Customer Account Executive, or Ms. R. Kirsten Watts, Customer 
Account Executive, 909 First Avenue, Suite 380, Seattle, WA 98104-3636.

    Responsible Official: Ms. Elizabeth Evans, Acting Rates Manager, is 
the official responsible for the development of BPA's wholesale power 
rates.

SUPPLEMENTARY INFORMATION:

Table of Contents

I. Introduction and Procedural Background
II. Purpose and Scope of Hearing
III. Public Participation
IV. Major Studies and Summary of Proposal
V. 2007 Wholesale Power Rate Case Schedules and General Rate 
Schedule Provisions

Part I--Introduction and Procedural Background

    Section 7(i) of the Northwest Power Act, 16 U.S.C. 839e(i), 
requires that BPA's rates be established according to certain 
procedures. These procedures include, among other things, publication 
of this notice of the proposed rates in the Federal Register (Notice); 
one or more hearings conducted as expeditiously as practicable by a 
Hearing Officer; public opportunity to provide both oral and written 
views; data requests and responses and argument related to the proposed 
rates; and a decision by the Administrator based on the record. This 
proceeding is governed by Sec.  1010, et seq., of BPA's Rules of 
Procedure Governing Rate Hearings, 51 FR 7611 (1986) (BPA Hearing 
Procedures). These procedures implement the statutory Section 7(i) 
requirements.
    Section 1010.7 of the BPA Hearing Procedures prohibits ex parte 
communications. The ex parte rule applies to all BPA and all DOE 
employees. Except as provided below, any outside communications with 
BPA and/or DOE personnel regarding BPA's rate case by other Executive 
Branch agencies, Congress, existing or potential BPA customers 
(including tribes), and nonprofit or public interest groups are all 
considered outside communications and are subject to the ex parte rule. 
The general rule does not apply to communications relating to (1) 
Matters of procedure only (the status of the rate case, for example); 
(2) exchanges of data in the course of business or under the Freedom of 
Information Act; (3) requests for factual information; (4) matters for 
which BPA is responsible under statutes other than the ratemaking 
provisions; or (5) matters which all parties agree may be made on an ex 
parte basis. The ex parte rule remains in effect until the 
Administrator's final ROD is issued, which is scheduled to occur on 
July 7, 2006.
    The Bonneville Project Act, 16 U.S.C. 832, the Flood Control Act of 
1944, 16 U.S.C. 825s, the Federal Columbia River Transmission System 
Act, 16 U.S.C. 838, and the Northwest Power Act, 16 U.S.C. 839, provide 
guidance regarding BPA ratemaking. The Northwest Power Act requires BPA 
to set rates that are sufficient to recover, in accordance with sound 
business principles, the cost of acquiring, conserving and transmitting 
electric power, including amortization of the Federal investment in the 
FCRPS over a reasonable period of years, and certain other costs and 
expenses incurred by the Administrator.
    BPA's initial proposed 2007 Wholesale Power Rate Schedules and 
General Rate Schedule Provisions (GRSPs) are available for viewing and 
downloading on PBL's Web site at http://www.bpa.gov/power/ratecase as 
discussed in Part V of this Notice. The studies addressing the factors 
used to develop these rates are listed in Part IV and will be available 
for examination on November 21, 2005, at BPA's Public Information 
Center, BPA Headquarters Building, 1st Floor, 905 NE 11th Avenue, 
Portland, Oregon, and will be provided to parties at the prehearing 
conference to be held on November 21, 2005, beginning at 9:00 am, 
Pacific Standard Time, Room 223, 911 NE 11th Avenue, Portland, Oregon.
    You may download copies of the studies and documentation from BPA's 
Web site at http://www.bpa.gov/power/ratecase or request them (on a CD 
or hard copy) by calling BPA's document request line toll-free at: 1-
800-622-4519.
    BPA will release its WP-07 Initial Proposal and supporting 
documents on November 21, 2005, and expects to publish a final ROD on 
July 7, 2006. BPA will be conducting a formal evidentiary rate hearing 
attended by rate case parties. Interested parties must file petitions 
to intervene in order to take part in the formal hearing. A proposed 
schedule for the formal hearing is stated below. A final schedule will 
be established by the Hearing Officer at the prehearing conference.

November 21, 2005; BPA files Direct Case/Prehearing Conference
December 5-9, 2005; Clarification
December 9, 2005; Data Request Deadline
December 9, 2005; Motions to Strike
December 15, 2005; Data Response Deadline
December 15, 2005; Answers to Motions to Strike
January 6, 2006; Parties file Direct Cases
January 17-20, 2006; Clarification
January 24, 2006; Data Request Deadline
January 24, 2006; Motions to Strike
January 30, 2006; Data Response Deadline

[[Page 67687]]

January 30, 2006; Answers to Motions to Strike
February 13, 2006; Close of Participant Comments
February 13, 2006; Litigants File Rebuttal Testimony
February 16-17, 2006; Clarification
February 17, 2006; Data Request Deadline
February 17, 2006; Motions to Strike
February 23, 2006; Data Response Deadline
February 23, 2006; Answers to Motions to Strike
March 6-17, 2006; Cross-Examination
April 14, 2006; Initial Briefs Filed
April 26-27, 2006; Oral Argument before Administrator
May 26, 2006; Draft ROD issued
June 9, 2006; Briefs on Exceptions
July 7, 2006; Final ROD--Final Studies

    BPA will also be conducting six public field hearings in cities 
throughout the Pacific Northwest. Public field hearings are an 
opportunity for persons who are not parties in the formal rate hearing 
to have their views included in the official record. Written 
transcripts will be made at all of the field hearings. The field 
hearings have been scheduled to take place at the locations, dates, and 
times specified below. The hearing dates also will be posted on the 
rate case Web site (www.bpa.gov/power/rates) and through announcements 
in local newspapers. Any changes to the scheduled public hearings will 
be available on the rate case Web site. The BPA Public Affairs Office 
also may be contacted for this information at the telephone number 
previously listed.

Public Field Hearings Schedule

November 29, 2005; Springfield, Oregon
November 30, 2005; Kalispell, Montana
December 1, 2005; Spokane, Washington
December 5, 2005; Idaho Falls, Idaho
December 6, 2005; Tacoma, Washington
December 7, 2005; Portland, Oregon

Part II--Purpose and Scope of Hearing

A. The Overview and Background to this Rate Filing

    The WP-07 rate proceeding is designed to establish rates to replace 
existing rate schedules and GRSPs. One existing rate schedule, the Firm 
Power Products and Services rate schedule, was established for 10 years 
in the 1996 Wholesale Power Rate and Transmission Rate Adjustment 
Proceeding (WP-96/TR-96) and amended in the 1996 Firm Power Products 
and Services Rate Schedule Correction Proceeding (FPS-96R). The 
remaining power rate schedules and GRSPs were established in BPA's 2002 
Wholesale Power Rate Adjustment Proceeding (WP-02). All of BPA's power 
rate schedules expire on September 30, 2006. Accordingly, BPA must 
conduct a rate case, pursuant to the 7(i) process, in order to comply 
with its statutory obligations to establish rates to market the power 
of the FCRPS.
    The General Transfer Agreement (GTA) Delivery Charge, was 
established in the 2006 Transmission Rate Case (TR-06) for the period 
of October 1, 2005, through September 30, 2007. This power rate case 
will establish the General Transfer Agreement Delivery Charge for the 
period of October 1, 2007, through September 30, 2009.
1. Subscription
    On December 21, 1998, BPA issued the Power Subscription Strategy 
and Record of Decision (Subscription Strategy). The Subscription 
Strategy reflected BPA's position on the equitable distribution of 
Federal power for the Fiscal Year (FY) 2002-2011 period. The 
Subscription Strategy was the culmination of a multi-year public 
process that established BPA's plan for the availability of Federal 
power post-2001, the products from which customers could choose, along 
with an outline of the contracts and pricing framework for those 
products.
    The Subscription Strategy provided a marketing framework for the 
WP-02 power rate case. The WP-02 power rate case developed the rates 
and rate schedules necessary for the products and contracts that were 
developed through Subscription. However, the rates established in the 
WP-02 power rate proceeding applied only to the first five years of the 
10-year Subscription contracts. As noted above, the WP-02 power rates 
applicable to the Subscription contracts are set to expire on September 
30, 2006, and must be replaced. The Subscription contracts continue to 
be the basis for the contractual relationship between BPA and nearly 
all of its firm power customers.
2. Firm Power Products and Services Rate Schedule
    In addition to revising the rates for the Subscription contracts, 
BPA is proposing the successor to the Firm Power Products and Services 
(FPS) rate schedule. The FPS rate schedule is available for the 
purchase of surplus firm power and other products and services for use 
inside and outside the Pacific Northwest. The FPS rate schedule and 
associated GRSPs were established for a 10-year period running from 
October 1, 1996, to September 30, 2006. The rate schedule and GRSPs 
were slightly modified in 2000 through a 7(i) process (FPS-96R). The 
FPS rate schedule is used primarily for the sale at negotiated and/or 
posted rates of surplus firm power and related products. Unless 
replaced, BPA would lack a rate schedule to sell surplus power in the 
West Coast wholesale energy markets.
3. Regional Dialogue and the Policy for Power Supply Role for Fiscal 
Years 2007-2011 (Near-Term Policy)
    The Regional Dialogue process began in April 2002 when a group of 
BPA's Pacific Northwest electric utility customers submitted a ``joint 
customer proposal'' to BPA that addressed both near-term and long-term 
contract and rate issues. Since then, BPA, the Northwest Power and 
Conservation Council (Council), customers, and other interested parties 
have worked on these near- and long-term issues. Considering the depth 
and complexity of many of these issues, BPA concluded it was not 
practical to resolve all issues before the start of the 2007 rate 
period. Therefore, BPA determined that it would address the issues in 
two phases. The first phase of the Regional Dialogue addresses issues 
that had to be resolved in order to replace power rates that will 
expire in September 2006. The second phase is expected to be 
implemented through new power sales contracts and in a future rate case 
before new power sales contracts go into effect.
    BPA issued the Near-Term Policy and Record of Decision on February 
4, 2005. The Near-Term Policy has resolved some outstanding issues 
prior to the start of the 2007 rate period. Those issues include, but 
are not limited to, the following:
a. FY 2007-2011 Rights to Lowest-Cost Priority Firm (PF) Rate
    BPA will apply the lowest-cost PF rates to its public agency 
customers whose contracts contain the lowest-cost PF rate guarantee 
throughout the remaining term of the Subscription power sales 
contracts.
b. Term of the Next Rate Period
    BPA will limit the duration of the next rate period to three years, 
from FY 2007 through FY 2009.
c. Five-Year Contract Holders
    Public customers whose contracts do not contain a guarantee of the 
lowest cost-based PF rates for FY 2007-2011 will receive the same rate 
treatment in the FY 2007-2011 period as customers whose contracts 
contain this guarantee, so long as such customers signed a new

[[Page 67688]]

contract or amendment by June 30, 2005, extending the term of the 
agreement through 2011.
d. Product Availability
    Any new or existing public customer whose contract expires in 2006 
may select from any of the standard products except Complex Partial 
(Factoring), Block with Factoring, or Slice. In addition, BPA resolved 
not to offer contract amendments that would allow changes in the power 
products and services purchased under a customer's 10-year Subscription 
contract.
e. Service to Residential and Small-Farm Consumers of Investor-Owned 
Utilities (IOUs)
    BPA's Subscription contracts with the region's six IOUs require the 
agency to provide 2,200 aMW of power or financial benefits to the 
residential and small-farm consumers of these customers during FY 2007-
2011. BPA signed agreements in late May 2004, with all six regional 
IOUs that provide certainty in the amount and manner that benefits will 
be provided to their residential and small-farm consumers under their 
Subscription contracts for 2007-2011. These agreements provide 
certainty by defining benefits based on a methodology that uses 
independent market-prices in calculating the financial benefits, and 
establishing a floor of $100 million and a cap of $300 million per year 
for the financial benefits.
f. Service to Direct Service Industries (DSIs)
    BPA determined that it will provide eligible Pacific Northwest DSIs 
some level of Federal power service benefits, at a known quantity and 
capped cost, in the FY 2007-2011 period. In the Near-Term Policy, BPA 
decided that for the FY 2007-2011 period it would continue the ramp-
down in DSI service by providing eligible DSI customers some level of 
service benefits, at a known quantity and capped cost, at rates no 
lower than rates paid by BPA's public customers, and under contractual 
terms no better than those offered to other customers. In order to 
provide an opportunity for additional dialogue with (and among) 
customers in the hope of achieving consensus for a balanced and durable 
solution for service to the DSIs, BPA noted in the Near-Term Policy 
that it reserved for later decision: (1) The actual level of service 
benefits it would provide; (2) the eligibility criteria it would apply 
in determining which DSIs would qualify for such service benefits; and 
(3) the mechanism or mechanisms it would use to deliver those service 
benefits. See Section 4, below, for a description of that later 
decision.
4. Service to DSIs
    The Near-Term Policy established parameters for service to the DSIs 
which were addressed in Bonneville Power Administration's Service to 
DSI Customers for Fiscal Years 2007-2011 Administrator's Record of 
Decision (DSI ROD) (June 30, 2005).
    In the DSI ROD, BPA determined to offer the aluminum company DSIs 
power sales contracts for an aggregate 560 aMW of benefits at a capped 
$59 million cost. In addition, BPA offered a 17 aMW surplus firm power 
sales contract for Port Townsend Paper Company through the local public 
utility under the FPS rate (or the IP rate if viable) at a price 
approximately equivalent to, but in no case less than, its lowest-cost 
PF rate.
    BPA decided to allocate a share of the 560 aMW service benefits to 
each DSI aluminum company for purposes of making an initial offer of 
service, but the creditworthiness of each DSI, on a prospective basis, 
will determine whether BPA executes a contract with that company. In 
addition, each DSI aluminum company must demonstrate that it is 
operational. Because of the financial risks inherent in providing 
actual power and in order to meet the known and capped cost 
prerequisite, BPA determined that the default delivery mechanism would 
be to monetize the value of the below-market power sales to provide 
service benefits through cash payments. However, BPA retains an option 
to provide actual power in-lieu of monetizing the transaction.
5. Power Function Review
    In January 2005, BPA initiated an extensive and in depth process to 
examine the PBL's program levels. This Power Function Review (PFR) 
provided customers and constituent's significant opportunity to provide 
input into the policy choices that drive program cost projections to be 
used in BPA's initial power rate proposal. The PFR focused on nine 
major cost areas:
    a. Army Corps of Engineer and Bureau of Reclamation operation and 
maintenance costs and capital investments;
    b. Columbia Generating Station operation and maintenance costs and 
capital investments;
    c. Conservation program costs;
    d. Fish and wildlife program expenses and capital investments;
    e. Internal operations costs charged to power rates;
    f. Renewable program costs;
    g. Transmission acquisition costs;
    h. Risk mitigation packages and tools; and
    i. Federal and Non-Federal debt service and debt management.
    Two main areas, (1) debt service and debt management and (2) risk 
mitigation, were discussed but not decided in the PFR. The PFR involved 
technical staff meetings, management level discussions, and regional 
public meetings. In total, BPA held seven technical meetings, five 
formal discussion sessions with utility managers and five regional 
public meetings that involved general managers representing public 
customers, and customer representatives representing customers and 
constituent groups. During this five-month review, interested persons 
submitted a total of 94 written comments to BPA about the issues under 
discussion. At the close of the comment period, BPA issued a draft 
close-out letter with proposed program cost levels, delineated the 
consequences and opportunities of further reductions, and sought 
comment on those proposed levels. BPA received a number of additional 
written comments on the draft close-out letter. A final close-out 
letter was issued June 24, 2005. The PFR resulted in $96 million in 
reductions per year in forecasted program level cost estimates.
    In the close-out letter, BPA responded to the comments provided on 
the draft and laid out the program level cost estimates that would be 
used in BPA's WP-07 Initial Proposal. In addition, BPA committed to 
revisit many of the program areas when more information is known. BPA 
will hold discussions separately from the rate case proceedings to 
share the updated forecasts, define associated policy choices, and 
solicit feedback from customers and constituents before they are 
incorporated into the final rates.
6. Post-2006 Conservation Program Structure Proposal
    In the fall of 2004, BPA established a post-2006 conservation 
workgroup. The conservation workgroup was composed of over 65 utility 
representatives and conservation stakeholders. The purpose of the 
workgroup was to discuss and develop BPA's conservation program for the 
post-2006 time frame. In January 2005, the workgroup provided BPA with 
recommendations and comments on how BPA should design its conservation 
program.
    On March 28, 2005, BPA issued its Post-2006 Conservation Program 
Structure Proposal for review and a 30-day comment period. BPA received 
56 comments on the proposal. On June 28,

[[Page 67689]]

2005, BPA issued its response to the comments along with its final 
decision on the design and scope of the Post-2006 proposal.
    The proposal described the approach of the conservation programs 
that BPA will offer during the FY 2007 through 2009 timeframe. The 
decisions in the Post-2006 proposal have been used as inputs in the 
development of BPA's WP-07 Initial Proposal.
7. Transmission Rate Case
    BPA is committed to marketing its power and transmission services 
separately in a manner that is modeled after the regulatory initiatives 
adopted in 1996 by FERC to promote competition in wholesale power 
markets. The Commission's initiatives in Orders 888 \1\ and 889 \2\ 
directed public utilities regulated under the Federal Power Act to 
separate their power merchant functions from their transmission 
reliability functions; unbundle transmission and ancillary services 
from wholesale power services; and set separate rates for wholesale 
generation, transmission, and ancillary services. Although BPA is not 
required by law to follow the Commission's regulatory directives that 
promote competition and open access transmission service, BPA elected 
to separate its power and transmission operations and unbundle its 
rates in a manner consistent with the directives concerning open access 
transmission service. BPA develops its transmission rates in separate 
proceedings from its power rates.
---------------------------------------------------------------------------

    \1\ Promoting Wholesale Competition Through Open Access Non-
Discriminatory Transmission Services by Pubic Utilities; Recovery of 
Stranded Costs by Public Utilities and Transmitting Utilities Reg-
Preamble, FERC Stats & Regs 1991-96, para. 31,036 (1996).
    \2\ Open Access Same-Time Information System (formerly Real-Time 
Information Networks) and Standards of Conduct, Reg-Preamble, FERC 
Stats & Regs 1991-96, para. 31,035 (1996).
---------------------------------------------------------------------------

    On February 2, 2005, BPA's Transmission Business Line (TBL) 
initiated a rate case to establish transmission rates for the FY 2006-
2007 transmission rate period. Prior to the initiation of that rate 
case, TBL held several public meetings with customers over the period 
July through September 2004 to discuss transmission costs, revenues, 
and rate design issues for the FY 2006-2007 rate period. The customers 
expressed interest in meeting with TBL to develop a settlement for the 
FY 2006-2007 rate period. TBL continued meetings with customers between 
October and early December 2004, resulting in a Settlement Agreement. 
TBL's initial rate proposal reflected the terms of the Settlement 
Agreement.
    On June 20, 2005, BPA issued the Final Transmission Proposal-
Administrator's Record of Decision that adopted the transmission and 
ancillary services rates as reflected in the Settlement Agreement. 
Final approval of these TBL rates was issued by FERC on September 29, 
2005. The TBL rate case settlement established formula rates for 
ancillary services and some transmission rates that incorporate 
ancillary services. For FY 2007, these formula rates will be affected 
by the pricing of generation inputs to ancillary services that will be 
determined in this PBL rate case. The pricing of generation inputs to 
ancillary services determined in this rate case also will be a factor 
in TBL's rates in FY 2008-2009.

B. Scope of the 2007 Rate Case

    Many of the decisions that guide BPA's power marketing policies 
have been made or will be made in other public review processes. This 
section provides guidance to the Hearing Officer as to those matters 
that are within the scope of the rate case, and those that are outside 
the scope.
1. Program Level Expenses Decided in the PFR
    As described above, the program level expense estimates, except 
those decided elsewhere, have already received extensive public review 
and comment in the PFR process. Pursuant to Sec.  1010.3(f) of BPA 
Hearing Procedures, the Administrator hereby directs the Hearing 
Officer to exclude from the record any material attempted to be 
submitted or arguments attempted to be made in the hearing which seek 
to in any way revisit the appropriateness or reasonableness of BPA's 
decisions on spending levels, as included in BPA's revenue requirements 
for FYs 2007 through 2009. However, as noted above, BPA did commit to 
revisit many of the program areas where final results were not known at 
the time the final report was issued and will hold discussion 
separately from the rate case proceeding to share the updated 
forecasts, define associated policy choices, and solicit feedback from 
customers and constituents before they are incorporated into the final 
rates. Excepted from this direction due to their variable nature, 
dependency on BPA's rate case models, and/or timing, are: (1) Forecasts 
of short-term purchase power costs; (2) capital recovery matters such 
as interest rate forecasts, scheduled amortization, depreciation, 
replacements, and interest expense; and (3) risk mitigation packages 
and tools.
2. Near-Term Policy Decisions
    As detailed above, BPA issued the Near-Term Policy on February 4, 
2005. The Policy resolved a number of policy decisions that impact the 
design and features of BPA's WP-07 Initial Proposal. Those issues 
include but are not limited to, decisions on the availability of the 
lowest cost PF rate to public customers, term of the rate period, IOU 
and DSI service options, and the availability of products for new or 
existing customers. Pursuant to Sec.  1010.3(f) of BPA Hearing 
Procedures, the Administrator hereby directs the Hearing Officer to 
exclude from the record any material attempted to be submitted or 
arguments attempted to be made in the hearing which seek to in any way 
revisit the appropriateness or reasonableness of BPA's decisions made 
in the Near-Term Policy ROD.
3. DSI Service
    The DSI Service decisions finalized and established the manner and 
method by which BPA would provide service and benefits to its DSI 
customers. The decisions in that ROD resolved the method and level of 
service to be provided DSIs in the FY 2007-2011 period. Pursuant to 
Sec.  1010.3(f) of BPA Hearing Procedures, the Administrator directs 
the Hearing Officer to exclude from the record any material attempted 
to be submitted or arguments attempted to be made in the hearing which 
seek to in any way revisit the appropriateness or reasonableness of 
BPA's decisions made in the DSI ROD.
4. Transmission Acquisition Expense
    In addition to the program cost decisions, the PFR close-out letter 
also included transmission acquisition program cost level decisions. 
This program represents the cost associated with services necessary to 
deliver energy from generating resources to markets and loads. These 
costs include: transmission expenses; ancillary services; real power 
losses; generation integration costs associated with the U.S. Army 
Corps of Engineers and Bureau of Reclamation transmission facilities; 
and metering and communication requirements. In addition to these 
decisions, BPA determined the mechanism for modeling the variability in 
transmission expenses for the upcoming rate period.
    Pursuant to Sec.  1010.3(f) of BPA Hearing Procedures, the 
Administrator hereby directs the Hearing Officer to exclude from the 
record any material attempted to be submitted or arguments attempted to 
be made in the hearing which seek to in any way revisit the

[[Page 67690]]

appropriateness or reasonableness of BPA's transmission acquisition 
program level estimates or the modeling used to calculate the 
variability of the transmission expense.
    The only issue associated with the transmission acquisition program 
within the scope of this rate case is the risk analysis associated with 
modeling the transmission expense. In the PFR close-out letter, BPA 
agreed to model the transmission expense based on the full distribution 
of secondary sales rather than the average transmission expense. This 
issue will be addressed in the risk analysis portion of the rate case.
5. Other Transmission Issues
a. Generation Inputs
    BPA's Power Business Line (PBL) provides a portion of the FCRPS's 
available generation to the TBL to enable TBL to meet its various 
transmission requirements. TBL uses the generation inputs to provide 
ancillary and control area services. To recover the costs associated 
with providing these generation inputs, PBL assigns a portion of the 
FCRPS costs to the transmission function. The cost allocations PBL is 
proposing to use to determine the generation input costs and associated 
unit costs to the TBL is a matter that is included within the scope of 
this rate proceeding.
    Pursuant to Sec.  1010.3(f) of BPA Hearing Procedures, the 
Administrator directs the Hearing Officer to exclude from the record 
any material attempted to be submitted or arguments attempted to be 
made in the hearing that seek in any way to revisit the appropriateness 
or reasonableness of any other issues related to the generation inputs. 
This includes, but is not limited to, issues regarding the level or 
quality of the generation inputs that TBL requests from PBL. These 
determinations are generally made by TBL in accordance with industry, 
reliability, and other compliance standards and criteria, and are not 
matters appropriate for the rate case.
b. Transmission Rate Case
    On June 20, 2005, BPA issued the Final Transmission Proposal ROD in 
TBL's rate case, which received final approval on September 29, 2005. 
Pursuant to Sec.  1010.3(f) of BPA Hearing Procedures, the 
Administrator hereby directs the Hearing Officer to exclude from the 
record any material attempted to be submitted or arguments attempted to 
be made in the hearing which seek in any way to revisit the 
appropriateness or reasonableness of issues determined in the TBL rate 
case. That proceeding addressed, among other things, transmission and 
ancillary service rate levels, the $1.5 million payment from TBL to PBL 
for Attachment K redispatch for FY 2006-2007, and the GTA Delivery 
Charge for FY 2007.
6. Post-2006 Conservation Program Structure Proposal
    Through the post-2006 workgroup collaboration, customers and 
constituents provided input on the development of BPA's post-2006 
conservation approach. Pursuant to Sec.  1010.3(f) of BPA Hearing 
Procedures, the Administrator hereby directs the Hearing Officer to 
exclude from the record any material attempted to be submitted or 
arguments attempted to be made in the hearing that seek to in any way 
revisit the appropriateness or reasonableness of BPA's conservation 
programs and establishment of expense levels through the Post-2006 
Conservation Program Structure Proposal dated June 28, 2005. The 
Hearing Officer is directed to exclude from the scope of this 
proceeding evidence regarding BPA's portfolio of conservation programs 
and the expenses BPA intends to pursue during the upcoming rate period.
7. Federal and Non-Federal Debt Service and Debt Management
    During the PFR, and in other forums, BPA provided background 
information on its internal Federal and non-Federal debt management 
policies and practices. The discussions of these topics in the PFR and 
other forums were not intended to seek input from customers and 
constituents regarding BPA's debt management policies and practices. 
Rather, these discussions were intended to merely inform interested 
parties about these matters so that they would better understand BPA's 
debt structure. Although the PFR close-out letter did not make any 
decisions regarding BPA's debt management policies and practices, these 
remain outside the scope of the rate case. Therefore, pursuant to Sec.  
1010.3(f) of BPA Hearing Procedures, the Administrator hereby directs 
the Hearing Officer to exclude from the record any material attempted 
to be submitted or arguments attempted to be made in the hearing which 
seek to in any way visit the appropriateness or reasonableness of BPA's 
debt management policies and practices.
8. Potential Environmental Impacts
    The Administrator directs the Hearing Officer to exclude from the 
record all evidence and argument that seek in any way to address the 
potential environmental impacts of the rates being developed in the 
2007 Wholesale Power Rate Case. See Section C, below.

C. The National Environmental Policy Act

    BPA is in the process of assessing the potential environmental 
effects of its WP-07 Initial Proposal, consistent with the National 
Environmental Policy Act (NEPA). BPA's Business Plan Environmental 
Impact Statement (Business Plan EIS), completed in June 1995, evaluated 
the environmental impacts of a range of business plan alternatives that 
could be varied by applying policy modules, including one for rates. 
Any combination of alternative policy modules should allow BPA to 
balance its costs and revenues. The Business Plan EIS also addressed 
response strategies, including adjusting rates that BPA could pursue if 
BPA's costs exceeded its revenues. In August 1995, the BPA 
Administrator issued a Record of Decision (Business Plan ROD) that 
adopted the Market-Driven Alternative from the Business Plan EIS. This 
alternative was selected because, among other reasons, it allows BPA 
to: (1) Recover costs through rates; (2) competitively market BPA's 
products and services; (3) develop rates that meet customer needs for 
clarity and simplicity; (4) continue to meet BPA's legal mandates; and 
(5) avoid adverse environmental impacts. BPA also committed to apply as 
many response strategies as necessary when BPA's costs and revenues do 
not balance. Because the WP-07 Initial Proposal likely would assist BPA 
in accomplishing these goals, the proposal appears consistent with 
these aspects of the Market-Driven Alternative. In addition, this rate 
proposal is similar to the type of rate designs evaluated in the 
Business Plan EIS; thus implementation of this rate proposal would not 
be expected to result in significantly different environmental impacts 
from those examined in the Business Plan EIS. Therefore, BPA expects 
that this WP-07 Initial Proposal will fall within the scope of the 
Market-Driven Alternative that was evaluated in the Business Plan EIS 
and adopted in the Business Plan ROD.
    As part of the Administrator's ROD that will be prepared regarding 
this 2007 Wholesale Power Rate Case, BPA may tier its decision under 
NEPA to the Business Plan ROD. However, depending upon the ongoing 
environmental review, BPA may, instead, issue another appropriate NEPA 
document.

[[Page 67691]]

Part III--Public Participation

A. Distinguishing Between ``Participants'' and ``Parties''

    BPA distinguishes between ``participants in'' and ``parties to'' 
the 7(i) hearing process. Apart from the formal hearing process, BPA 
will accept comments, views, opinions, and information from 
``participants'' who are defined in the BPA Hearing Procedures as 
persons who may submit comments without being subject to the duties of, 
or having the privileges of, parties. Participants' written and oral 
comments will be made a part of the official record and considered by 
the Administrator when making his decision. Participants are not 
entitled to participate in the prehearing conference; may not cross-
examine parties' witnesses, seek discovery, or serve or be served with 
documents; and are not subject to the same procedural requirements as 
parties.
    The views of the participants are important to BPA. Written 
comments by participants will be included in the record if they are 
received by 5 p.m. on February 13, 2006. This date follows the 
anticipated submission of BPA's and all other parties' direct cases. 
Written views, supporting information, questions, and arguments should 
be submitted to BPA Communications at the address listed in Section 2 
of this Notice. In addition, BPA will hold six field hearings in the 
Pacific Northwest region. Participants may appear at the field hearings 
and present oral statements. The transcripts of these hearings will be 
part of the record upon which the Administrator makes his final rate 
decisions.
    Persons wishing to become a party to BPA's rate proceeding must 
notify BPA in writing and file a Petition to Intervene with the Hearing 
Officer. Petitioners may designate no more than two representatives 
upon whom service of documents will be made. Petitions to Intervene 
shall state the name and address of the person requesting party status 
and the person's interest in the hearing.
    Petitions to Intervene as parties in the rate proceeding are due to 
the Hearing Office by 5 p.m. on November 17, 2005. The petitions should 
be directed as stated below or may be e-mailed to the following e-mail 
address: jsanders@bpa.gov: Jennifer Sanders, Hearing Clerk--LP-7, 
Bonneville Power Administration, 905 NE 11th Avenue, P.O. Box 3621, 
Portland, OR 97208-3621.
    Petitioners must explain their interests in sufficient detail to 
permit the Hearing Officer to determine whether they have a relevant 
interest in the proceeding. Pursuant to Sec.  1010.1(d) of BPA Hearing 
Procedures, BPA waives the requirement in Sec.  1010.4(d) that an 
opposition to an intervention petition must be filed and served 24 
hours before the November 21, 2005, prehearing conference. Any 
opposition to an intervention petition may instead be made at the 
prehearing conference. Any party, including BPA, may oppose a petition 
for intervention. Persons who have been denied party status in any past 
BPA rate proceeding shall continue to be denied party status unless 
they establish a significant change of circumstances. All timely 
applications will be ruled on by the Hearing Officer. Late 
interventions are strongly disfavored.

B. Developing the Record

    The record will comprise, among other things, verbal and written 
comments made by participants, including the transcripts of all 
hearings, any written material submitted by the parties, documents 
developed by BPA staff, BPA's environmental analysis and comments 
accepted on it, and other material accepted into the record by the 
Hearing Officer. Written comments by participants will be included in 
the record if they are received by 5 p.m., Pacific Standard Time, on 
February 13, 2006. The Hearing Officer will then review the record, 
supplement it if necessary, and will certify the record to the 
Administrator for decision.
    The Administrator will develop final proposed rates based on the 
entire record, which includes the record certified by the Hearing 
Officer, as described above. The basis for the final proposed rates 
first will be expressed in the Administrator's draft ROD. Parties will 
have an opportunity to respond to the draft ROD as provided in BPA 
Hearing Procedures. The Administrator will serve copies of the final 
ROD on all parties. At the conclusion of the rate proceeding, BPA will 
file its rates with FERC for confirmation and approval at least 60 days 
prior to October 1, 2006.
    BPA must continue to meet with customers in the ordinary course of 
business during the rate case. To comport with the rate case procedural 
rule prohibiting ex parte communications, BPA will provide the 
prescribed notice of meetings involving rate case issues in order to 
permit the opportunity for participation by all rate case parties. 
These meetings may be held on very short notice. Consequently, the 
parties should be prepared to devote the necessary resources to 
participate fully in every aspect of the rate proceeding and attend 
meetings any day during the course of the rate case.

Part IV--Major Studies and Summary of Proposal

A. Summary of Proposed 2007 Wholesale Power Rate Structure

1. List of Proposed 2007 Wholesale Power Rates
    BPA is proposing five different rate schedules for its 2007 
Wholesale Power Rates. The actual rate schedules and the GRSPs are 
available for viewing and downloading on PBL's Web site at www.bpa.gov/
power/ratecase as discussed in Part V of this Notice.
a. PF-07 Priority Firm Power Rate
    The PF rate schedule is comprised of two rates: the PF Preference 
rate and the PF Exchange rate.
    The PF Preference rate applies to BPA's firm power sales to be used 
within the Pacific Northwest by public bodies, cooperatives, and 
Federal agencies. This power is guaranteed to be continuously 
available. The rate applies to the following products:

Full Service Product
Actual Partial Service Product--Simple
Actual Partial Service Product--Complex
Block Product
Block Product with Factoring
Block Product with Shaping Capacity
Slice Product

    The PF Exchange rate applies to sales of power to regional 
utilities that participate in the Residential Exchange Program 
established under Section 5(c) of the Northwest Power Act, 16 U.S.C. 
839c(c).
b. NR-07 New Resource Firm Power Rate
    The New Resource Firm Power (NR) rate applies to net requirements 
power sales to IOUs for resale to ultimate consumers for direct 
consumption, construction, test, and start-up, and for station service. 
NR-07 firm power is also available to public utility customers for 
serving New Large Single Loads. This rate applies to the following 
products:

New Large Single Loads
Full Service Product
Actual Partial Service Product--Simple
Actual Partial Service Product--Complex
Block Product
Block Product with Factoring
Block Product with Shaping Capacity

c. IP-07 Industrial Firm Power Rate
    The IP rate is available for discretionary firm power sales to DSI

[[Page 67692]]

customers authorized by Section (5)(d)(1)(A) of the Northwest Power 
Act, 16 U.S.C. 839c(d)(1)(A).
d. FPS-07 Firm Power Products and Services Rate Schedule FPS
    The FPS rate schedule is available for the purchase of Firm Power, 
Capacity Without Energy, Supplemental Control Area Services, Shaping 
Services, and Reservation and Rights to Change Services for use inside 
and outside the Pacific Northwest. The rates for these products are 
posted and/or negotiated. BPA is not obligated to enter into agreements 
to sell products and services under this rate schedule.
e. GTA-07 General Transfer Agreement Delivery Charge
    The GTA Delivery Charge applies to customers who purchase Federal 
power that is delivered over non-Federal low voltage transmission 
facilities. The rate was set in the 2006 TBL Rate Case Settlement and 
approved by FERC on September 29, 2005, to mirror the Utility Delivery 
rate from October 1, 2005, through September 30, 2007. The 2006 TBL 
Rate Case Settlement set the GTA Delivery Charge at $1.119 per 
kilowatt-month through September 30, 2007. For the period of October 1, 
2007 through September 30, 2009, PBL is proposing to continue to set 
the GTA Delivery Charge to the same rate as TBL's posted Utility 
Delivery rate. As adjustments are made to the Utility Delivery rate in 
future TBL rate cases, PBL proposes to reflect these changes in the GTA 
Delivery Charge.
2. Significant Rate Development Issues
a. Risk Mitigation
    Several factors present new challenges for BPA to keep its power 
rates low while fulfilling its mission and meeting its obligations to 
the U.S. Treasury consistent with sound business principles. Increased 
market price volatility and six consecutive years of below-average 
runoff have significantly changed the landscape of risk and uncertainty 
facing BPA and its stakeholders.
    The uncertainty and volatility of market prices are greater today 
than they have been in the past. As a consequence, the cost of covering 
the risk BPA faces in crediting a large portion of secondary revenues 
to power rates before receiving those uncertain funds is now greater. 
BPA also faces uncertainty around the operational costs for fish 
programs in FY 2006 and in the FY 2007-2009 rate period. A new 
Biological Opinion or possible court-ordered change to river operations 
would directly affect BPA's net revenues. In addition, enhanced risk 
management practices resulted in analysis that accounts for operational 
risks not previously modeled as well as a more comprehensive analysis 
of non-operating risks. Finally, the $325 million Fish Cost Contingency 
Fund (FCCF) was fully depleted in FY 2003 resulting in the loss of a 
risk tool that was available to mitigate dry year impacts on fish 
operations.
    These changes create greater risk for BPA, reduce BPA's ability to 
absorb those risks, increase the costs of managing risks, and/or more 
fully reflect the costs of managing them. If rates were designed using 
a traditional approach of adding Planned Net Revenues for Risk (PNRR), 
these changes would require that power rates be set to recover a much 
larger ``risk premium'' than ever before in order to meet the Treasury 
Payment Probability (TPP) standard which, if this was the sole approach 
to managing risk, would result in a relatively high rate. Additional 
cash reserves and/or a more comprehensive risk mitigation package, such 
as the cost recovery adjustment clauses implemented in the FY 2002-2006 
rates, are necessary to address these risks and ensure that BPA can 
maintain its minimum TPP standard of 92.6% \3\ for the rate period.
---------------------------------------------------------------------------

    \3\ 92.6% TPP for a three-year rate period is equivalent to 
BPA's TPP standard of 95% applied to a two-year rate period. Two 
years were assumed to be the length of rate periods when the TPP 
standard was set.
---------------------------------------------------------------------------

    As noted above, BPA faces a level of uncertainty regarding its 
assumption concerning river operations as well as direct program costs 
for fish and wildlife due to the ongoing issues surrounding BPA fish 
and wildlife obligations. To mitigate against this risk, BPA has 
proposed a specific rate adjustment (NFB adjustment). In order to 
balance the need to cover risk with overall rate levels, BPA is 
proposing to meet its TPP standard through a combination of PNRR, cost 
recovery adjustment charges, the NFB adjustment and a dividend 
distribution clause. See Sections 3 and 4, below.
    BPA has been meeting with customers and the parties over the last 
year to explore alternative means of managing risk that would allow the 
TPP standard to be met with lower rates. BPA has committed to continue 
these discussions over the next several months in properly noticed 
meetings to continue to pursue the viability of these options in order 
to include them in the final studies.
b. Residential Exchange Program Settlement Benefits
    Under Residential Exchange Program (REP) settlement agreements 
executed by BPA and the IOUs in 2000, BPA originally provided the IOUs 
1,000 aMW of power benefits and 900 aMW of monetary benefits for the FY 
2002-2006 period. Power sales were originally made at the Residential 
Load (RL) Firm Power Rate and the PF Exchange Subscription rate. 
Monetary benefits were originally calculated based on the difference 
between BPA's RL rate and BPA's then-current rate case 5-year flat 
block price forecast. The benefits increase to 2,200 aMW for the FY 
2007-2011 period either in the form of power or monetary benefits, at 
BPA's discretion. Based on amendments of the REP settlement agreements 
in 2004, and the Near-Term Policy, however, BPA will not sell power to 
the IOUs during FY 2007-2011. BPA therefore is not proposing to 
establish an RL rate or a PF Exchange Subscription rate for IOU power 
sales in the WP-07 rate case. Instead, all IOU Settlement benefits for 
the FY 2007-2011 period are monetary benefits calculated based on the 
difference between an independent determination of a forecast of a 
forward flat block market price and BPA's flat PF rate, consistent with 
the IOU contracts.
c. Inter-Business Line Calculations
    BPA is addressing certain inter-business line issues in this 2007 
Power Rate Case. These include the generation inputs for: generation 
supplied reactive and voltage support; operating reserves; regulating 
reserves; generation and energy imbalance; generation dropping for 
remedial action schemes; and station service. Segmentation of the Corps 
of Engineers (COE) and the Bureau of Reclamation (Reclamation) 
facilities will also be addressed. BPA is proposing methodologies to 
calculate the costs of these services, and forecast revenues, in order 
to determine BPA's power revenue requirement to be recovered through 
power rates. These generation costs, or associated unit costs, will be 
allocated to TBL to support TBL's ancillary services and other 
operations. Relevant transmission and ancillary service rates for FY 
2006-2007 include formulas that allow for the costs and charges 
developed in this power rate case to be factored into the transmission 
and ancillary service rates. BPA is also proposing to set a GTA 
Delivery Charge as determined by the 2006 Transmission rate settlement. 
This power rate proceeding will establish the GTA Delivery Charge for 
FY 2008 and 2009.

[[Page 67693]]

d. DSI Service 2007-2011
    Consistent with the DSI ROD, BPA is not forecasting direct service 
under the IP rate to the DSI customers. Instead, BPA plans to offer the 
DSI aluminum smelters 560 aMW of surplus firm power service benefits 
for the FY 2007-2011 period at a capped cost of $59 million per year. 
BPA will offer Port Townsend Paper Company 17 aMW of surplus firm power 
service benefits, whereupon its local utility will provide power at a 
utility rate expected to be approximately equivalent to, but in no case 
lower than, BPA's PF rate. With the DSI aluminum companies, 
creditworthiness standards must be met or acceptable credit assurances 
must be provided by those companies qualifying for benefits. In 
addition, benefits can be monetized under the proposed contracts with 
these companies, but BPA will retain the right to provide physically 
delivered surplus power, subject to long-term interruption rights, in 
lieu of a financial transaction.
3. Changes in Rate Design
    BPA is continuing, in general, its existing rate design for its FY 
2007-2009 rates, with some changes and modifications as described 
below. Complete details on these changes are available for viewing and 
downloading on PBL's Web site at www.bpa.gov/power/ratecase as 
discussed in Part V of this Notice.
a. Conservation Rate Credit (CRC)
    BPA is proposing to replace the Conservation and Renewables (C&R) 
Discount with a Conservation Rate Credit (CRC) program. The CRC will 
retain many of the features of the C&R Discount including: (1) The 
credit will remain at 0.5 mills per kWh; (2) monthly bill credits; (3) 
no decrement to customers' net requirements for CRC participation 
(including Slice customers); (4) customer flexibility in choosing 
between several eligible conservation and renewable energy measures; 
and (5) funding under the CRC for customer renewable resource 
activities is limited to $6 million annually.
b. Dividend Distribution Clause (DDC)
    BPA is proposing to continue the DDC with a modification to the 
Threshold. BPA proposes that there will be a DDC if Accumulated 
Modified Net Revenues (AMNR) reach the equivalent of $800 million in 
reserves attributable to PBL.
c. Excess Factoring Charge
    This is a charge that applies to purchasers of the Complex Actual 
Partial Service Product under the PF rate schedule. BPA is proposing 
minor changes to eliminate references to the California Power Exchange.
d. Green Energy Premium
    BPA is proposing to continue the Green Energy Premium (GEP), 
available to customers purchasing firm power. The GEP is an adjustment 
to the PF rate when a customer chooses to designate any portion (up to 
100 percent) of its Subscription purchase as Environmentally Preferred 
Power.
    The GEP will range from zero to 40 mills per kWh depending on the 
specific products and associated costs selected by each customer. BPA 
forecasts an average of $1.4 million of annual revenue from the GEP 
over the rate period. Revenues from the GEP will support BPA renewable 
resource facilitation and research and development.
e. Load-Based Cost Recovery Adjustment Charge (LB CRAC) True-Up
    BPA is not proposing to continue the existing LB CRAC in the FY 
2007-2009 rate period. However, the LB CRAC contemplates an after-the-
fact true-up as soon as the necessary actual data is available after 
each sixth-month LB CRAC period. The final LB CRAC True-Up is 
anticipated to occur in December 2006, after the expiration of BPA's 
current rates on September 30, 2006. Therefore, BPA is proposing to 
carry over the LB CRAC True-Up provisions in the GRSPs for the FY 2007-
2009 rate period to allow for the final True-Up. Implementation will be 
limited to the true-up for the final 6 months (LBCRAC10 period) of the 
2002-2006 rate period. True-Up billing adjustments will be made over 
twelve months starting in early 2007.
f. Load Variance Charge
    BPA is proposing to continue the Load Variance Charge. This charge 
covers BPA's cost of meeting customers' load growth for reasons other 
than annexation or retail access load gain or loss. In addition, it 
provides Full and Partial Service purchasers the right to deviate from 
their monthly forecast BPA purchases due to weather, economic business 
cycles, plant energy consumptions and other reasons. The method for 
setting the Load Variance charge in this rate proposal differs from the 
WP-02 rate-setting process. It is no longer based on the cost of put or 
call options. Instead, load growth is forecast, and the cost is 
estimated based on a forecast of future market prices. The cost of 
forecast error is estimated based on an assumption of a two percent 
forecast error and a forecast of future market prices. The charge is 
set at 0.53 mills per kWh and is charged against the customer's Total 
Retail Load.
g. Low Density Discount (LDD)
    BPA is proposing four changes to the LDD: (1) BPA proposes to 
change the eligibility criteria to account for BPA's separation of 
power and transmission rates which first occurred in 1996, and also to 
ensure that customers with very low retail rates will not qualify for 
the LDD; (2) one of the measures used in calculating the LDD is 
proposed to use ``consumers per mile'' instead of ``meters per mile'' 
to ensure consistency and equity; (3) the term ``average retail rate'' 
has been clarified for simplification of the LDD administration; and 
(4) BPA proposes to amend LDD to ensure it only applies to the 
qualifying Slice purchaser's net requirements.
h. Monthly Demand and Energy Charges
    BPA is not proposing changes to the methodology for calculating 
energy charges. There will be two diurnal periods, Heavy Load Hour 
(HLH) and Light Load Hours (LLH), for each month. BPA is proposing 
slight changes to the definitions of HLH and LLH to be consistent with 
NERC definitions. BPA is proposing to revise the definition of HLH and 
LLH included in the 2006 Transmission General Rate Schedule Provisions 
for FY 2007 to be consistent with NERC and BPA's proposed definitions 
in the GRSPs for the power rates. The actual energy charges will be 
updated consistent with the method used in WP-2002.
    BPA is proposing a minor modification to the methodology for 
calculating the demand charge. There will continue to be 12 monthly 
demand charges, but the average rate will decrease from $2.00 per kW-
month to $1.05 per kW-month. This change is to better reflect the 
market price for demand with energy.
i. PF Targeted Adjustment Charge (PF TAC)
    BPA is continuing the Targeted Adjustment Charge, with some 
proposed modifications. BPA proposes to exempt PF TAC loads from the PF 
TAC in any year of the three years of the rate period that the load 
subject to the TAC is less than 1 aMW. The TAC will apply to the entire 
load if it exceeds the minimum. Also, the calculation of the PF TAC 
rate will be based on monthly availability of the Federal Base System 
(FBS), rather than an annual calculation.

[[Page 67694]]

j. Unauthorized Increase Charges (UAI) for Power Sales
    These are penalty charges for Unauthorized Increases in Energy and 
Unauthorized Increases in Demand for deliveries that exceed contractual 
entitlements for energy and demand, respectively. BPA is proposing 
minor changes to the UAI to eliminate references to the California 
Power Exchange.
4. New Adjustments in Rates
    BPA is proposing a number of new adjustments and continuing some 
existing adjustments. Complete details of these adjustments are 
available for viewing and downloading on PBL's Web site at www.bpa.gov/
power/ratecase as discussed in Part V of this Notice.
a. Operating Reserves
    BPA is proposing changes in how it handles its forecasted revenues 
from providing operating reserves to the TBL. BPA's Open Access 
Transmission Tariff requires transmission customers serving load with 
generation located in the Transmission Provider's Control Area to 
acquire Operating Reserves from the Transmission Provider, from a third 
party, or by self-supply. The 2002 power rate case estimated total 
revenue recovered by PBL selling Operating Reserves generation inputs 
to TBL, assuming all customers purchased Operating Reserves from TBL. 
The expected revenue from the sale of Operating Reserves was deducted 
from the overall revenue requirement when determining the cost of the 
Federal system which is the basis for calculating power rates. During 
this current rate period, some customers began self-supplying Operating 
Reserves, and TBL has purchased less generation inputs from PBL. 
Therefore, PBL did not fully recover expected revenues. To avoid this 
under-recovery in the FY 2007-2009 rate period and to ensure that 
revenues are allocated equitably, PBL is proposing to estimate total 
revenues from the sale of generation inputs to TBL and give a 0.89 
mills per kWh credit on the power bills of customers that elect to 
purchase Operating Reserves from TBL. This will prevent both under-
recovery and over-recovery. While BPA proposes not to allocate these 
revenues or credits to those customers that self-supply Operating 
Reserves or acquire Operating Reserves from a third party, BPA will 
consider alternatives to this proposal that address BPA's concerns 
regarding the proper allocation of costs and revenues.
b. Cost Recovery Adjustment Clause (CRAC)
    Prior to the beginning of each fiscal year of the rate period 
(i.e., FY 2007-2009), a forecast of the previous year's end-of-year 
AMNR will be completed. If the AMNR at the end of the forecast year 
falls below the defined CRAC Threshold for that fiscal year, the CRAC 
will trigger, and a rate increase will go into effect beginning in 
October of the upcoming fiscal year. Any such increase in a fiscal 
year's rates would remain in effect through September of the following 
year. This adjustment could occur as early as August 2006 for the rates 
in effect for FY 2007. The amount of the rate increase is limited to 
the lower of the annual Maximum Planned Recovery Amount of $300 million 
or the amount by which AMNRs under run the threshold.

                                         CRAC Annual Thresholds and Caps
                                              (Dollars in millions)
----------------------------------------------------------------------------------------------------------------
                                                                                      Approx.
                                                   CRAC applied                    threshold as    Maximum CRAC
      AMNR calculated at end of fiscal year       to fiscal year  CRAC threshold    measured in      recovery
                                                                                   PBL reserves    amount (cap)*
----------------------------------------------------------------------------------------------------------------
2006............................................            2007           -$193            $470            $300
2007............................................            2008             -36             500             300
2008............................................            2009             -45             500             300
----------------------------------------------------------------------------------------------------------------

c. The NFB Adjustment (National Marine Fisheries Service (NMFS) Federal 
Columbia River Power System (FCRPS) Biological Opinion (BiOp) 
Adjustment)
    The NFB adjustment results in an upward adjustment to the CRAC 
Maximum Planned Recovery Amount (Cap) for any ye