Western Area Power Administration, DOE.
Notice of order concerning power rates.
The Deputy Secretary of Energy confirmed and approved Rate Order No. WAPA-125 and Rate Schedule L-F6, placing firm electric service rates from the Loveland Area Projects (LAP) of the Western Area Power Administration (Western) into effect on an interim basis. The provisional rates will be in effect until the Federal Energy Regulatory Commission (Commission) confirms, approves, and places them into effect on a final basis or until they are replaced by other rates. The provisional rates will provide sufficient revenue to pay all annual costs, including interest expenses, and repay power investment and irrigation aid, within the allowable periods.
Rate Schedule L-F6 will be placed into effect on an interim basis on the first day of the first full billing period beginning on or after January 1, 2006, and will be in effect until the Commission confirms, approves, and places the provisional rates into effect on a final basis ending December 31, 2010, or until the rate schedule is superseded.Start Further Info
FOR FURTHER INFORMATION CONTACT:
Mr. Joel K. Bladow, Regional Manager, Rocky Mountain Customer Service Region, Western Area Power Administration, 5555 East Crossroads Boulevard, Loveland, Colorado, 80538-8986, (970) 461-7201, or Mr. Daniel T. Payton, Rates Manager, Rocky Mountain Customer Service Region, Western Area Power Administration, 5555 East Crossroads Boulevard, Loveland, Colorado, 80538-8986, telephone (970) 461-7442, e-mail firstname.lastname@example.org.End Further Info End Preamble Start Supplemental Information
The Deputy Secretary of Energy approved existing Rate Schedule L-F5 for LAP firm electric service on an interim basis on December 24, 2003 (Rate Order No. WAPA-105, 69 FR 644, January 6, 2004). The Commission confirmed and approved the rate schedule on a final basis on December 21, 2004, in FERC Docket No. EF04-5181-000 (109 FERC 62,228). The existing rate schedule is effective from February 1, 2004, through December 31, 2008.
Existing firm electric service Rate Schedule L-F5 is being superseded by Rate Schedule L-F6. Under Rate Schedule L-F5, the energy charge is 11.95 mills per kilowatthour (mills/kWh) and the capacity charge is $3.14 per kilowattmonth (kWmonth). The composite rate is 23.90 mills/kWh. The provisional rates for LAP firm electric service under Rate Schedule L-F6 are being implemented in two steps. The first step of the provisional rates for LAP firm electric service consists of an energy charge of 13.06 mills/kWh and a capacity charge of $3.43 per kWmonth, producing an overall composite rate of 26.12 mills/kWh on January 1, 2006. This represents a 9.3 percent increase when compared with the existing LAP firm electric service rate under Rate Schedule L-F5. The second step of the provisional rates for LAP firm electric service consists of an energy charge of 13.68 mills/kWh and a capacity charge of $3.59 per kWmonth, producing an overall composite rate of 27.36 mills/kWh on January 1, 2007. This represents an additional 5.2 percent increase.
By Delegation Order No. 00-037.00, effective December 6, 2001, the Secretary of Energy delegated: (1) The authority to develop power and transmission rates to Western's Administrator, (2) the authority to confirm, approve, and place such rates into effect on an interim basis to the Deputy Secretary of Energy, and (3) the authority to confirm, approve, and place into effect on a final basis, to remand or to disapprove such rates to the Start Printed Page 71274Commission. Existing DOE procedures for public participation in power rate adjustments (10 CFR part 903) were published on September 18, 1985.
Under Delegation Order Nos. 00-037.00 and 00-001.00A, 10 CFR part 903, and 18 CFR part 300, I hereby confirm, approve, and place Rate Order No. WAPA-125 and the proposed LAP firm electric service rates into effect on an interim basis. The new Rate Schedule L-F6 will be promptly submitted to the Commission for confirmation and approval on a final basis.Start Signature
Dated: November 9, 2005.
Order Confirming, Approving, and Placing the Loveland Area Projects Firm Electric Service Rates Into Effect on an Interim Basis
These rates were established in accordance with section 302 of the Department of Energy (DOE) Organization Act (42 U.S.C. 7152). This Act transferred to and vested in the Secretary of Energy the power marketing functions of the Secretary of the Department of the Interior and the Bureau of Reclamation under the Reclamation Act of 1902 (ch. 1093, 32 Stat. 388), as amended and supplemented by subsequent laws, particularly section 9(c) of the Reclamation Project Act of 1939 (43 U.S.C. 485h(c)), and other Acts that specifically apply to the project involved.
By Delegation Order No. 00-037.00, effective December 6, 2001, the Secretary of Energy delegated: (1) The authority to develop power and transmission rates to Western's Administrator, (2) the authority to confirm, approve, and place such rates into effect on an interim basis to the Deputy Secretary of Energy, and (3) the authority to confirm, approve, and place into effect on a final basis, to remand or to disapprove such rates to the Commission. Existing DOE procedures for public participation in power rate adjustments (10 CFR part 903) were published on September 18, 1985.
Acronyms and Definitions
As used in this Rate Order, the following acronyms and definitions apply:
Administrator: The Administrator of Western Area Power Administration.
Capacity: The electric capability of a generator, transformer, transmission circuit, or other equipment. It is expressed in kW.
Capacity Charge: The rate which sets forth the charges for capacity. It is expressed in dollars per kWmonth.
Commission: Federal Energy Regulatory Commission.
Composite Rate: The rate for commercial firm power and is the total annual revenue requirement for capacity and energy divided by the total annual firm energy sales under contract. It is expressed in mills/kWh and used for comparison purposes.
Criteria: The Post-1989 General Power Marketing and Allocation Criteria for the sale of energy with capacity from the Pick-Sloan Missouri Basin Program—Western Division and the Fryingpan-Arkansas Project.
Customer: An entity with a contract for and receiving firm electric service from Western's Rocky Mountain Region.
Deficits: Deferred or unrecovered annual expenses.
DOE Order RA 6120.2: An order outlining power marketing administration financial reporting and rate-making procedures.
Energy: Measured in terms of the work it is capable of doing over a period of time. It is expressed in kWh.
Energy Charge: The rate which sets forth the charges for energy. It is expressed in mills per kWh and applied to each kWh delivered to each customer.
FERC: The Commission (to be used when referencing Commission Orders).
Firm: A type of product and/or service that is available at the time requested by the customer.
FRN: Federal Register notice.
Fry-Ark: Fryingpan-Arkansas Project.
FY: Fiscal year; October 1 to September 30. kW: Kilowatt—the electrical unit of capacity that equals 1,000 watts.
kWmonth: Kilowattmonth—the electrical unit of the monthly amount of capacity.
kWh: Kilowatthour—the electrical unit of energy that equals 1,000 watts in 1 hour.
kilowattyear: Kilowattyear—the electrical unit of the yearly amount of capacity.
LAP: Loveland Area Projects.
L-F5: Loveland Area Projects existing firm electric service rate schedule (expires December 31, 2008, or until superseded).
L-F6: Loveland Area Projects provisional firm electric service rate schedule (effective January 1, 2006).
M&I: Municipal and industrial water development.
mills/kWh: Mills per kilowatthour—the unit of charge for energy (equals one tenth of a cent or one thousandth of a dollar).
MOU: Memorandum of Understanding for the Pick-Sloan Missouri Basin Program and the Fry-Ark Project. Signatories include Western, Reclamation, U.S. Army Corps of Engineers, Mid-West Electric Consumers Association, Loveland Area Customers Association, and Western States Power Corporation.
NEPA: National Environmental Policy Act of 1969 (42 U.S.C. 4321, et seq.).
O&M: Operation and Maintenance.
P-SMBP: The Pick-Sloan Missouri Basin Program.
P-SMBP—WD: Pick-Sloan Missouri Basin Program—Western Division.
Power: Capacity and energy.
Preference: The requirements of Reclamation Law which provide that preference in the sale of Federal power shall be given to municipalities and other public corporations or agencies and also to cooperatives and other nonprofit organizations financed in whole or in part by loans made under the Rural Electrification Act of 1936 (Reclamation Project Act of 1939, section 9(c), 43 U.S.C. 485h(c)).
Provisional Rates: Rates which have been confirmed, approved, and placed into effect on an interim basis by the Deputy Secretary.
PRS: Power Repayment Study.
Rate Brochure: A document prepared for public distribution explaining the rationale and background of the rate proposal contained in this rate order and dated June 2005.
Ratesetting PRS: The PRS used for the rate adjustment proposal.
Reclamation: United States Department of the Interior, Bureau of Reclamation.
Reclamation Law: A series of Federal laws. Viewed as a whole, these laws create the originating framework in which Western markets power.
Revenue Requirement: The revenue required to recover annual expenses (such as O&M, purchase power, transmission service expenses, interest expenses, and deferred expenses) and repay Federal investments, and other assigned costs.
Rocky Mountain Region: The Rocky Mountain Customer Service Region of Western.
Western: United States Department of Energy, Western Area Power Administration.
The new provisional rates will take effect on the first day of the first full billing period beginning on or after January 1, 2006, and will be in effect until December 31, 2010, pending approval by the Commission on a final basis. Start Printed Page 71275
Public Notice and Comment
Western followed the Procedures for Public Participation in Power and Transmission Rate Adjustments and Extensions, 10 CFR part 903, in developing these rates. The steps Western took to involve interested parties in the rate process were:
1. The proposed rate adjustment was initiated on April 22, 2005, when Western's Rocky Mountain Region mailed a notice announcing an informal customer meeting to discuss the proposed firm electric service rate adjustment to all LAP preference customers and interested parties. The informal meeting was held on May 11, 2005, in Denver, Colorado. At this informal meeting, Western explained the rationale for the rate adjustment, presented rate designs and methodologies, and answered questions.
2. An FRN was published on June 16, 2005 (70 FR 35079), officially announcing proposed LAP rates, initiating the public consultation and comment period, and announcing the public information and public comment forums.
3. On July 1, 2005, Western's Rocky Mountain Region mailed letters to all LAP preference customers and interested parties transmitting a copy of the FRN published on June 16, 2005 (70 FR 35079).
4. The public information forums were held on July 19, 2005, beginning at 10 a.m. MDT, in Denver, Colorado, and again on July 20, 2005, beginning at 8 a.m. CDT, in Lincoln, Nebraska. Western provided detailed explanations of the proposed LAP rates, provided a list of issues that could change the proposed rates, and answered questions. A rate brochure detailing the proposed rates was provided at the forums.
5. The public comment forum was held on August 16, 2005, beginning at 9 a.m. MDT, in Denver, Colorado. Western gave the public an opportunity to comment for the record. No oral comments were made and no written comments were received during the comment forum.
6. Western received four comment letters during the consultation and comment period, which ended September 14, 2005. All formally submitted comments have been considered in preparing this Rate Order.
7. Western's Rocky Mountain Region provided a Web site with all of the letters, time frames, dates and locations of forums, documents discussed at the information meetings, FRNs, and all other information about this rate process for customer access. The Web site is located at http://www.wapa.gov/rm/Rates/firm_power_rate_adj_2006.htm.
Written comments were received from the following organizations: East River Electric Power Cooperative, Mid-West Electric Consumers Association, Municipal Energy Agency of Nebraska, Valley Electric Cooperative, Inc.
Loveland Area Projects
The Post-1989 General Power Marketing and Allocation Criteria, published in the Federal Register on January 31, 1986 (51 FR 4012), integrated the resources of the P-SMBP—WD and Fry-Ark. This operational and contractual integration, known as LAP, allowed an increase in marketable resource, simplified contract administration, and established a blended rate for LAP power sales.
However, the P-SMBP—WD and Fry-Ark retain separate financial status. For this reason, separate PRSs are prepared annually for each project. These PRSs are used to determine the sufficiency of the power rate to generate adequate revenue to repay project investment and costs during each project's prescribed repayment period. The revenue requirement of the Fry-Ark PRS is combined with the P-SMBP—WD revenue requirement derived from the P—SMBP PRS, to develop one rate for LAP firm electric sales.
Pick-Sloan Missouri Basin Program—Western Division
The initial stages of the Missouri River Basin Project were authorized by Congress in section 9 of the Flood Control Act of December 22, 1944, commonly referred to as the 1944 Flood Control Act (Pub. L. 78-534, 58 Stat. 877, 891). The Missouri River Basin Project, later renamed the Pick-Sloan Missouri Basin Program to honor its two principal authors, has been under construction since 1944. The P-SMBP encompasses a comprehensive program of flood control, navigation improvement, irrigation, M&I water development, and hydroelectric production for the entire Missouri River Basin. Multipurpose projects have been developed on the Missouri River and its tributaries in Colorado, Montana, Nebraska, North Dakota, South Dakota, and Wyoming.
The Colorado-Big Thompson, Kendrick, Riverton, and Shoshone projects were administratively combined with P-SMBP in 1954, followed by the North Platte Project in 1959. These projects are known as the “Integrated Projects” of the P-SMBP. The Riverton Project was reauthorized as a unit of the P-SMBP in 1970.
The P-SMBP—WD and the Integrated Projects include 19 powerplants. There are six powerplants in the P-SMBP—WD: Glendo, Kortes, and Fremont Canyon powerplants on the North Platte River; Boysen and Pilot Butte on the Wind River; and Yellowtail powerplant on the Big Horn River.
In the Colorado-Big Thompson Project, there are also six powerplants. Green Mountain powerplant on the Blue River is on the West Slope of the Rocky Mountains. Marys Lake, Estes, Pole Hill, Flatiron, and Big Thompson powerplants are on the East Slope.
The Kendrick Project has two power production facilities: Alcova and Seminoe powerplants. Power production facilities in the Shoshone Project are Shoshone, Buffalo Bill, Heart Mountain, and Spirit Mountain powerplants. The only production facility in the North Platte Project is the Guernsey powerplant.
The Fry-Ark is a transmountain diversion development in southeastern Colorado authorized by the Act of Congress on August 16, 1962 (Pub. L. 87-590, 76 Stat. 389, as amended by Title XI of the Act of Congress on October 27, 1974 (Pub. L. 93-493, 88 Stat. 1486, 1497)). The Fry-Ark diverts water from the Fryingpan River and other tributaries of the Roaring Fork River in the Colorado River Basin on the West Slope of the Rocky Mountains to the Arkansas River on the East Slope. The water diverted from the West Slope, together with regulated Arkansas River water, provides supplemental irrigation, M&I water supplies, and produces hydroelectric power. Flood control, fish and wildlife enhancement, and recreation are other important purposes of Fry-Ark. The only generating facility in Fry-Ark is the Mt. Elbert Pumped-Storage Powerplant on the East Slope.
Power Repayment Studies
Western prepares a PRS each FY to determine if revenues will be sufficient to repay, within the required time, all costs assigned to the LAP revenues. Repayment criteria are based on law, policies including DOE Order RA 6120.2, and authorizing legislation. To meet Cost Recovery Criteria outlined in DOE Order RA 6120.2, a revised study and rate adjustment has been developed to demonstrate that sufficient revenues will be collected to meet future obligations.
In the P-SMBP PRS, payments toward irrigation assistance and capital debt are necessary before deficits are completely repaid. Traditionally, prepayment of irrigation assistance or capital is only Start Printed Page 71276done in the absence of deficits. However, if all revenue were applied toward deficits prior to making any prepayments for irrigation and other capital requirements, an extraordinarily large rate increase to meet single-year repayment obligations would be required. Once these single-year repayment obligations were satisfied, another rate adjustment would be necessary to decrease the rates. While repayment of capital debt and irrigation assistance prior to complete repayment of deficits is not typical, the approach approved within this Rate Order is well within the bounds of DOE Order RA 6120.2. Western will repay all deficits and also make previously planned payments for irrigation assistance and other investments that are due in the years 2013 and 2014. Prepaying irrigation and capital investments has been part of P-SMBP repayment plans and approved rate adjustments for the past 20 years. It is an integral part of the long-term plan for the project and has provided rate stability for consumers while meeting Federal repayment obligations. Modest irrigation and investment payments for a brief period of 2 to 3 years will reduce the single-year revenue requirement for irrigation assistance and hold increases to the “lowest possible rates to consumers consistent with sound business principles,” as outlined in section 5 of the Flood Control Act of 1944.
The provisional rates for LAP will be implemented in two steps. First step rates are to become effective on an interim basis on the first day of the first full billing period beginning on or after January 1, 2006. Second step rates are to become effective on the first day of the first full billing period beginning on or after January 1, 2007. Under Rate Schedule L-F6, the first and second step provisional rates for LAP firm electric service will result in a total composite rate increase of approximately 14.5 percent. The current composite rate under Rate Schedule L-F5 is 23.90 mills/kWh. The provisional composite rate is 27.36 mills/kWh.
Existing and Provisional Rates
A comparison of the existing and provisional rates for LAP firm electric service follows:
|Firm electric service||Existing rates||First step provisional rates and percent change, effective Jan. 1, 2006||Second step provisional rates and percent change, effective Jan. 1, 2007|
|Composite Rate (mills/kWh)||23.90||26.12 (9.3%)||27.36 (5.2%)|
|Firm Capacity ($/kWmonth)||$3.14||$3.43 (9.2%)||$3.59 (5.1%)|
|Firm Energy (mills/kWh)||11.95||13.06 (9.3%)||13.68 (5.2%)|
Certification of Rates
Western's Administrator certified that the provisional rates for LAP firm electric service under Rate Schedule L-F6 are the lowest possible rates consistent with sound business principles. The provisional rates were developed following administrative policies and applicable laws.
LAP Firm Electric Service Discussion
According to Reclamation Law, Western must establish power rates sufficient to recover operation, maintenance, and purchase power expenses, and repay power investment and irrigation aid.
The Criteria, published in the Federal Register on January 31, 1986 (51 FR 4012), operationally and contractually integrated the resources of the P-SMBP—WD and Fry-Ark (thereafter referred to as LAP). A blended rate was established for the sale of LAP power. The P-SMBP—WD portion of the revenue requirements for the LAP firm electric service rates was developed from the revenue requirement calculated in the P-SMBP Ratesetting PRS. The P-SMBP—WD revenue requirement increased approximately 17 percent due to increased purchase power costs due to extended drought as well as costs associated with increased O&M expenses. The adjustment to the P-SMBP revenue requirement is a separate formal rate process which is documented in Rate Order No. WAPA-126. Rate Order No. WAPA-126 is also scheduled to go into effect on the first day of the first full billing period beginning on or after January 1, 2006. The revenue requirements for P-SMBP—WD are as follows:
|Present Revenue Requirement (18.06 mills/kWh × 1,988,000,000 kWh)||$35,903|
|Provisional Increases||Provisional First Step Increase (Jan 06) (1.96 mills/kWh × 1,988,000,000 kWh)|
|Provisional Second Step Increase (Jan 07) (1.07 mills/kWh × 1,988,000,000 kWh)||2,127|
|Total Increase (3.03 mills/kWh × 1,988,000,000 kWh)||6,024|
|Provisional Revenue Requirement (18.06 + 3.03 = 21.09 mills/kWh × 1,988,000,000 kWh)||41,927|
The Fry-Ark piece of the revenue requirements for the LAP firm electric service rates was developed from the revenue requirement calculated in the Fry-Ark Ratesetting PRS, which has been updated to reflect the most current Start Printed Page 71277information. The Fry-Ark revenue requirement contains two components. The project has an average annual energy generation of 52 gigawatthours from flow-through water. The remaining revenue requirement is derived from the firm capacity component. This is the procedure used in the study to account for the Fry-Ark portion of the energy marketed by LAP. The Fry-Ark revenue requirement increased approximately 8 percent also due to increased O&M expenses and higher costs associated with increased purchase power costs due to extended drought.
|Present Revenue Requirement||$12,855|
|Provisional First Step Increase (Jan 06)||650|
|Provisional Second Step Increase (Jan 07)||396|
|Provisional Revenue Requirement||13,901|
This table compares the LAP existing revenue requirements to the proposed revenue requirements:
|Existing||First step (January 2006)||Second step (January 2007)|
Statement of Revenue and Related Expenses
The following table provides a summary of projected revenue and expense data for the Fry-Ark firm electric service revenue requirement through the 5-year provisional rate approval period:
|Existing rate||Proposed rate||Difference|
|Purchase Power and Transmission||21,743||23,399||1,656|
|Original Project and Additions||3,133||940||−2,193|
|Total Principal Payments||4,073||6,843||2,770|
|Total Revenue Distribution||71,850||76,724||4,874|
|1 Interest expenses decreased due to a lower interest rate being used for future replacements and additions in the Ratesetting PRS.|
The summary of P-SMBP—WD revenues and expenses for the 5-year provisional rate approval period is included in the P-SMBP Statement of Revenue and Related Expenses that is part of Rate Order No. WAPA-126.
Basis for Rate Development
The P-SMBP PRS calculates the composite rate in mills/kWh for future firm power (capacity and energy) sales. In the Fry-Ark PRS, the study calculates the capacity charge in dollars per kilowattyear. The charge is adjusted until sufficient revenues are generated to meet the cost-recovery requirement.
The proposed LAP firm electric service rate is designed to recover 50 percent of the revenue requirement from the capacity charge and 50 percent from the energy charge. The capacity charge is calculated by dividing 50 percent of Start Printed Page 71278the total annual revenue requirement by the number of billing units (kWmonth) in a year. The energy charge is calculated by dividing 50 percent of the total annual revenue requirement by the annual energy sales under contract.
The existing rates for LAP firm electric service in Rate Schedule L-F5, which expire on December 31, 2008, no longer provide sufficient revenues to pay all annual costs, including interest expense, and repay power investment and irrigation aid within the allowable period. The adjusted rates reflect increases primarily in purchase power costs, O&M costs, and interest expenses. The provisional rates will provide sufficient revenue to pay all annual costs, including interest expense, and repay power investment and irrigation aid within the allowable periods. The provisional rates will take effect on January 1, 2006, and will remain in effect through December 31, 2010.
The comments and responses applicable to the LAP firm electric service rates, paraphrased for brevity when not affecting the meaning of the statement(s), are discussed below. Comments that apply to P-SMBP only are being answered in Rate Order No. WAPA-126.
A. Comment: Customers support implementing the two-step rate adjustment on a calendar year basis.
Response: The two-step rate adjustment proposal meets all repayment requirements according to DOE Order RA 6120.2, and since the majority of the customers support the calendar year implementation, Western will implement the first step of the two-step rate adjustment on January 1, 2006, and the second step of the two-step rate adjustment on January 1, 2007.
B. Comment: One commenter noted that working with Western through the MOU work group has been beneficial during this process. The MOU group has identified an issue regarding personnel costs of the federal agencies that merits further attention. The commenter recognized that this issue could not be resolved during consideration of the rate increase, but the commenter encouraged Western to move forward with its investigation into this issue.
Response: Western, through the MOU process, has agreed to look into this issue.
C. Comment: Customers noted their concern regarding the rate of increase in Reclamation's O&M costs.
Response: Western is actively participating with the customers through the MOU group, in which Reclamation also participates, to better understand what is driving Reclamation's increases.
D. Comment: One commenter noted that ongoing drought should be viewed as a good opportunity to review cutting discretionary costs where possible and look at the rate structure for some of Western's less widely used products to determine if they are appropriate and if they could be modified to more accurately reflect cost of service principles.
Response: As mentioned above, Western is actively participating with the customers through the MOU group to identify and address such issues.
E. Comment: One commenter encouraged Western to continue investigating ways to maximize the value of its assets, including transmission rights across neighboring systems and high-value transmission across constrained paths.
Response: Western continually looks for ways to increase revenues and decrease costs, including maximizing the use of the transmission system. However, Western has determined that this particular comment is not directly related to the proposed action and is outside the scope of the rate process.
Availability of Information
Information about this rate adjustment, including PRSs, comments, letters, memorandums, and other supporting material made or kept by Western that was used to develop the provisional rates is available for public review in the Rocky Mountain Customer Service Regional Office, Western Area Power Administration, 5555 East Crossroads Boulevard, Loveland, Colorado.
Regulatory Procedure Requirements
Regulatory Flexibility Analysis
The Regulatory Flexibility Act of 1980 (5 U.S.C. 601, et seq.) requires Federal agencies to perform a regulatory flexibility analysis if a final rule is likely to have a significant economic impact on a substantial number of small entities and there is a legal requirement to issue a general notice of proposed rulemaking. Western has determined that this action does not require a regulatory flexibility analysis since it is a rulemaking of particular applicability involving rates or services applicable to public property.
In compliance with the National Environmental Policy Act (NEPA) of 1969 (42 U.S.C. 4321, et seq.); Council on Environmental Quality Regulations (40 CFR parts 1500-1508); and DOE NEPA Regulations (10 CFR part 1021), Western has determined that this action is categorically excluded from preparing an environmental assessment or an environmental impact statement.
Determination Under Executive Order 12866
Western has an exemption from centralized regulatory review under Executive Order 12866; accordingly, no clearance of this notice by the Office of Management and Budget is required.
Small Business Regulatory Enforcement Fairness Act
Western has determined that this rule is exempt from congressional notification requirements under 5 U.S.C. 801 because the action is a rulemaking of particular applicability relating to rates or services and involves matters of procedure.
Submission to the Federal Energy Regulatory Commission
The provisional rates herein confirmed, approved, and placed into effect, together with supporting documents, will be submitted to the Commission for confirmation and final approval.
In view of the foregoing and under the authority delegated to me, I confirm and approve on an interim basis, effective January 1, 2006, Rate Schedule L-F6 for the Loveland Area Projects of the Western Area Power Administration. The rate schedule shall remain in effect on an interim basis, pending the Commission's confirmation and approval of them or substitute rates on a final basis through December 31, 2010.Start Signature
Dated: November 9, 2005.
Rate Schedule L-F6 (Supersedes Schedule L-F5)
Loveland Area Projects; Colorado, Kansas, Nebraska, Wyoming
Schedule of Rates for Firm Electric Service
First Step: Beginning on the first day of the first full billing period on or after January 1, 2006, through December 31, 2006.
Second Step: Beginning on the first day of the first full billing period on or after January 1, 2007, through December 31, 2010.
Within the marketing area served by the Loveland Area Projects. Start Printed Page 71279
To the wholesale power customers for firm power service supplied through one meter at one point of delivery, or as otherwise established by contract.
Alternating current, 60 hertz, three phase, delivered and metered at the voltages and points established by contract.
Demand Charge: $3.43 per kilowatt (kW) of billing demand.
Energy Charge: 13.06 mills per kilowatthour (kWh) of use.
Billing Demand: Unless otherwise specified by contract, the billing demand will be the seasonal contract rate of delivery.
Demand Charge: $3.59 per kW of billing demand.
Energy Charge: 13.68 mills per kWh of use.
Billing Demand: Unless otherwise specified by contract, the billing demand will be the seasonal contract rate of delivery.
For Transformer Losses: If delivery is made at transmission voltage but metered on the low-voltage side of the substation, the meter readings will be increased to compensate for transformer losses as provided for in the contract.
For Power Factor: None. The customer will be required to maintain a power factor at all points of measurement between 95-percent lagging and 95-percent leading.End Supplemental Information
[FR Doc. E5-6575 Filed 11-25-05; 8:45 am]
BILLING CODE 6450-01-P