77368 Federal Register / Vol. 65, No. 238 / Monday, December 11, 2000 / Notices

EL00–98, 003, INVESTIGATION OF

PRACTICES OF THE CALIFORNIA

INDEPENDENT SYSTEM OPERATOR

AND THE CALIFORNIA POWER

EXCHANGE

EL00–107, 000 PUBLIC MEETING IN SAN

DIEGO, CALIFORNIA EL00–97, 000

RELIANT ENERGY POWER

GENERATION, INC., DYNEGY POWER

MARKETING, INC. AND SOUTHERN

ENERGY CALIFORNIA, L.L.C. V.

CALIFORNIA INDEPENDENT SYSTEM

OPERATOR CORPORATION

EL00–104, 000, CALIFORNIA

ELECTRICTY OVERSIGHT BOARD V.

ALL SELLERS OF ENERGY AND

ANCILLARY SERVICES INTO THE

ENERGY AND ANCILLARY SERVICES

MARKETS OPERATED BY THE

CALIFORNIA INDEPENDENT SYSTEM

OPERATOR AND THE CALIFORNIA

POWER EXCHANGE

EL01–1, 000, CALIFORNIA MUNICIPAL

UTILITIES ASSOCIATION V. ALL

JURISDICTIONAL SELLERS OF

ENERGY AND ANCILLARY SERVICES

INTO MARKETS OPERATED BY THE

CALIFORNIA INDEPENDENT SYSTEM

OPERATOR AND THE CALIFORNIA

POWER EXCHANGE

EL01–2, 000, CALIFORNIANS FOR

RENEWABLE ENERGY, INC. V.

INDEPENDENT ENERGY PRODUCERS,

INC., AND ALL SELLERS OF ENERGY

AND ANCILLARY SERVICES INTO

MARKETS OPERATED BY THE

CALIFORNIA INDEPENDENT SYSTEM

OPERATOR AND THE CALIFORNIA

POWER EXCHANGE; ALL

SCHEDULING COORDINATORS

ACTING ON BEHALF OF THE ABOVE

SELLERS; CALIFORNIA INDEPENDENT

SYSTEM OPERATOR CORPORATION;

AND CALIFORNIA POWER EXCHANGE

CORPORATION

EL01–10, 000, PUGET SOUND ENERGY,

INC. V. ALL JURISDICTIONAL SELLERS

OF ENERGY AND/OR CAPACITY AT

WHOLESALE INTO ELECTRIC ENERGY

AND/OR CAPACITY MARKETS IN THE

PACIFIC NORTHWEST, INCLUDING

PARTIES TO THE WESTERN SYSTEMS

POWER POOL AGREEMENT

Order on wholesale electric markets. this

order may be considered at the December 13,

2000 meeting or, subject to further notice, at

another date later this month.

Markets, Tariffs and Rates—Gas Agenda

G–1.

RESERVED

David P. Boergers

Secretary.

[FR Doc. 00–31533 Filed 12–7–00; 10:47 am]

BILLING CODE 6717–01–U

DEPARTMENT OF ENERGY

Western Area Power Administration

Formula Rates for the Central Arizona

Project 115-kV/230-kV Transmission

System—Rate Order No. WAPA–88

AGENCY: Western Area Power

Administration, DOE.

ACTION: Notice of rate order.

SUMMARY: Notice is given of the

confirmation and approval by the

Deputy Secretary of the Department of

Energy (DOE) of Rate Order No. WAPA–

88 and Rate Schedules CAP–FT1, CAP–

NFT1, and CAP–NITS1 placing Formula

Rates for firm point-to-point

transmission service, nonfirm point-topoint transmission service, and Network

Integration Transmission Service (NITS)

on the Central Arizona Project (CAP)

115-kV/230-kV transmission system of

the Western Area Power Administration

(Western) into effect on an interim basis.

The Formula Rates will remain in effect

on an interim basis until the Federal

Energy Regulatory Commission (FERC)

confirms, approves, and places them

into effect on a final basis or until they

are replaced by other rates. The Formula

Rates will provide sufficient revenue to

pay all annual costs, including interest

expense, and repayment of required

investment within the allowable period.

DATES: The Formula Rates will be

placed into effect on an interim basis on

January 1, 2001, and will be in effect

until FERC confirms, approves, and

places the Formula Rates in effect on a

final basis for a 5-year period ending

December 31, 2005, or until superseded.

FOR FURTHER INFORMATION CONTACT: Mr.

Maher Nasir, Rates Team Lead, Desert

Southwest Customer Service Region,

Western Area Power Administration,

P.O. Box 6457, Phoenix, AZ 85005–

6457, telephone (602) 352–2768, or by email: nasir@wapa.gov.

SUPPLEMENTARY INFORMATION: The CAP

115-kV/230–kV transmission system has

been used primarily to provide power to

the CAP water pumps. The planned

construction of a number of

independent powerplants in Arizona

and Nevada creates a potential demand

for use of surplus transmission capacity

on the CAP 115-kV/230-kV transmission

system.

The proposed Formula Rates for

point-to-point transmission service and

NITS on the CAP 115-kV/230-kV

transmission system are based on a

revenue requirement that recovers costs

for facilities associated with providing

transmission service and the nonfacilities costs allocated to transmission

service. The rates for point-to-point

transmission service on the CAP 115-

kV/230-kV transmission system are

determined by combining the average

annual amortization costs with the

average annual operations and

maintenance costs, and dividing them

by the average annual contract rate of

delivery for the cost evaluation period

FY 2001–FY 2005. Implementing the

proposed Formula Rates results in a

firm point-to-point CAP 115-kV/230-kV

transmission system rate of $9.83 per

kilowattyear and a nonfirm point-topoint CAP 115-kV/230-kV transmission

system rate of 1.12 mills/kWh.

NITS allows a transmission customer

to integrate, plan, economically

dispatch, and regulate its network

resources to serve its native load in a

way comparable to that used by the

transmission provider to service its

native load customers. The monthly

charge methodology for NITS on the

CAP 115-kV/230-kV transmission

system is the product of the

transmission customer’s load-ratio share

times one-twelfth of the annual

transmission revenue requirement. The

customer’s load-ratio share is calculated

on a rolling 12-month basis (12CP). The

customer’s load-ratio share is equal to

that customers’ hourly load coincident

with the CAP 115-kV/230-kV

transmission system monthly

transmission system peak divided by

the resultant value of the CAP 115-kV/

230-kV transmission system’s monthly

transmission system peak minus the

CAP 115-kV/230-kV transmission

system’s coincident peak for all firm

point-to-point transmission service plus

the CAP 115-kV/230-kV transmission

system’s firm point-to-point

transmission service reservations.

The Formula Rates for transmission

service on the CAP 115-kV/230-kV

transmission system are being

developed pursuant to the Department

of Energy Organization Act (42 U.S.C.

7101–7352), through which the power

marketing functions of the Secretary 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 enactments, particularly

section 9(c) of the Reclamation Project

Act of 1939 (43 U.S.C. 485h(c)), and

other acts specifically applicable to the

project involved, were transferred to

and vested in the Secretary of Energy.

By Amendment No. 3 to Delegation

Order No. 0204–108, published

November 10, 1993 (58 FR 59716), the

Secretary of Energy delegated (1) the

authority to develop long-term power

and transmission rates on a

nonexclusive basis to Western’s

Administrator; and (2) the authority to

Federal Register / Vol. 65, No. 238 / Monday, December 11, 2000 / Notices 77369

confirm, approve, and place into effect

on a final basis, to remand, or to

disapprove such rates to the FERC. In

Delegation Order No. 0204–172,

effective November 24, 1999, the

Secretary of Energy delegated the

authority to confirm, approve, and place

such rates into effect on an interim basis

to the Deputy Secretary.

Existing Department of Energy

procedures for public participation in

power and transmission rate

adjustments are located at 10 CFR part

903, effective on September 18, 1985 (50

FR 37835), and have been followed by

Western in the development of these

provisional rates.

Rate Order No. WAPA–88,

confirming, approving, and placing the

proposed CAP 115-kV/230-kV

transmission system Formula Rates into

effect on an interim basis, is issued; and

the new Rate Schedules CAP–FT1,

CAP–NFT1, and CAP–NITS1 will be

submitted promptly to FERC for

confirmation and approval on a final

basis.

Dated: November 30, 2000.

T.J. Glauthier,

Deputy Secretary.

Order Confirming, Approving, and

Placing the Central Arizona Project

Transmission System Formula Rates

into Effect on an Interim Basis

These Formula Rates are developed

pursuant to the Department of Energy

Organization Act (42 U.S.C. 7101–7352),

through which the power marketing

functions of the Secretary 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

enactments, particularly section 9(c) of

the Reclamation Project Act of 1939 (43

U.S.C. 485h(c)), and other acts

specifically applicable to the project

involved, were transferred to and vested

in the Secretary of Energy.

By Amendment No. 3 to Delegation

Order No. 0204–108, published

November 10, 1993 (58 FR 59716), the

Secretary of Energy delegated (1) the

authority to develop long-term power

and transmission rates on a

nonexclusive basis to the Administrator

of the Western Area Power

Administration (Western); and (2) the

authority to confirm, approve, and place

into effect on a final basis, to remand,

or to disapprove such rates to the

Federal Energy Regulatory Commission

(FERC). In Delegation Order No. 0204–

172, effective November 24, 1999, the

Secretary of Energy delegated the

authority to confirm, approve, and place

such rates into effect on an interim basis

to the Deputy Secretary. Existing

Department of Energy (DOE) procedures

for public participation in power rate

adjustments are found in 10 CFR part

903. Procedures for approving Power

Marketing Administration rates by FERC

are found in 18 CFR part 300.

Acronyms and Definitions

As used in this rate order, the

following acronyms and definitions

apply:

Administrator: The Administrator of the

Western Area Power Administration

(Western).

Capacity: The rated continuous electric

load-carrying capability of a

generator, transformer, transmission

circuit, or other equipment. It is

expressed in kW.

Central Arizona Project (CAP): One of

three related water development

projects that make up the Colorado

River Basin Project.

Customer: An entity with a contract and

receiving service from Western’s

Desert Southwest Region or from

CAP.

DOE: United States Department of

Energy.

DOE Order RA 6120.2: An order dealing

with 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.

FERC: Federal Energy Regulatory

Commission.

Firm: A type of product and/or service

that is available at the time requested

by the customer.

Formula Rates: A rate which is based

upon a formula calculated yearly.

FY: Fiscal year; October 1 to September

30.

kV: Kilovolt—the electrical unit of

measure of electric potential that

equals 1,000 volts.

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.

Mill: A monetary denomination of the

United States that equals one tenth of

a cent or one thousandth of a dollar.

NEPA: National Environmental Policy

Act of 1969 (42 U.S.C. 4321, et seq.).

Nonfirm: A type of product and/or

service that is not always available at

the time requested by the customer.

O&M: Operation and maintenance.

Power: Capacity and energy.

Reclamation: United States Department

of the Interior, Bureau of Reclamation.

Revenue Requirement: The revenue

required to recover O&M expenses,

transmission service expenses,

interest, deferred expenses, and

repayment of Federal investments, or

other assigned costs.

Effective Date

The new rates will become effective

on an interim basis on the first day of

the first full billing period beginning on

or after January 1, 2001, and will be in

effect pending FERC’s approval of them

or substitute rates on a final basis for a

5-year period ending December 31,

2005, or until superseded.

Public Notice and Comment

Existing Department of Energy

procedures for public participation in

power and transmission rate

adjustments, 10 CFR part 903, have been

followed by Western in the

development of these rates. The

following summarizes the steps Western

took to ensure involvement of interested

parties in the rate process:

1. The proposed rate adjustment was

initiated on May 23, 2000, when a letter

announcing the first informal customer

information forum was mailed to all

Central Arizona Project (CAP) customers

and interested parties. The first informal

customer information forum was held

on June 7, 2000, at the Desert Southwest

Customer Service Regional office (DSW)

in Phoenix, Arizona. At the informal

customer information forum, Western

and Reclamation staff explained the

rationale for the rate adjustment,

presented rate designs and

methodologies, and answered questions.

2. A Federal Register notice was

published on May 24, 2000 (65 FR

33541), officially announcing the

proposed rates for the CAP 115-kV/230-

kV transmission system, initiating the

public consultation and comment

period, and announcing the public

information and public comment

forums.

3. On June 7, 2000, a brochure

prepared by Western’s DSW office was

provided to all CAP firm transmission

customers and interested parties,

included in the Federal Register notice

of May 24, 2000, and announced the

times and locations for the two public

forums.

4. On June 16, 2000, beginning at 10

a.m. MST, the public information forum

was held at Western’s DSW office in

Phoenix, Arizona. At the public

information forum, Western provided

detailed explanations of the proposed

Formula Rates for the CAP 115-kV/230-

kV transmission system and provided a

list of issues that could change the

proposed rates, and answered questions.

77370 Federal Register / Vol. 65, No. 238 / Monday, December 11, 2000 / Notices

Notice was given that additional

information would be provided at the

public comment forum. An information

handout was provided at the forum.

5. On July 17, 2000, beginning at 10

a.m., the public comment forum was

held at Western’s DSW office in

Phoenix, Arizona. At the start of the

forum, Western gave the public an

opportunity to comment for the record.

Three customer representatives were

present and declined to make oral

comments.

6. Two comment letters were received

during the consultation and comment

period. The consultation and comment

period ended August 22, 2000. All

formally submitted comments have been

considered in the preparation of this

rate order.

Project Description

The CAP is one of three related water

development projects that make up the

Colorado River Basin Project. The others

are the Dixie and the Upper Basin

projects. The CAP was developed for

Arizona and western New Mexico; the

Dixie Project for southeastern Utah; and

the Upper Basin Project for Colorado

and New Mexico.

Congress authorized the project in

1968 to improve water resources in the

Colorado River Basin. Segments of the

1968 authorization allowed Federal

participation in the Navajo Generating

Station, which has three coal-fired

steam electric generating units for a

combined capacity of 2,250 MW.

Construction of the plant, located near

Lake Powell at Page, Ariz., began in

1970. Navajo began generating in 1976.

The Federal share of 24.3 percent, or

546,750 kW, is used to power the

pumps that move Colorado River water

through CAP canals. Surplus generation

is currently marketed under the Navajo

Power Marketing Plan adopted on Dec.

1, 1987.

Revenue Requirement

The Revenue Requirement will be

calculated each fiscal year to determine

if transmission revenues will be

sufficient to pay, within the prescribed

time periods, all costs assigned to the

CAP 115-kV/230-kV transmission

system function. Repayment criteria is

based on law, policies, and authorizing

legislation, including DOE Order RA

6120.2.

Certification of Rate

Western’s Administrator has certified

that the Formula Rates for transmission

service on the CAP 115-kV/230-kV

transmission system, placed into effect

on an interim basis herein, are the

lowest possible rates consistent with

sound business principles, and have

been developed in accordance with

administrative policies and applicable

laws.

Discussion

The CAP 115-kV/230-kV transmission

system has been used primarily to

provide power to the CAP water pumps.

The planned construction of a number

of independent powerplants in Arizona

and Nevada creates a potential demand

for use of surplus transmission capacity

on the CAP 115-kV/230-kV transmission

system.

The proposed Formula Rates for

point-to-point transmission service and

NITS on the CAP 115-kV/230-kV

transmission system are based on a

Revenue Requirement that recovers

costs for facilities associated with

providing transmission service and for

non-facilities allocated to transmission

service.

Point-to-Point Transmission Service

The rate for firm point-to-point

transmission service on the CAP 115-

kV/230-kV transmission system is

determined by combining the annual

amortization costs with the annual

operations and maintenance costs, and

dividing them by the annual average

contract rate of delivery. The nonfirm

rate is determined by converting the

firm annual rate into an hourly rate.

Implementing the proposed rate

formulas results in a firm point-to-point

CAP 115-kV/230-kV transmission

system rate of $9.83 per kilowattyear

and a nonfirm point-to-point CAP 115-

kV/230-kV transmission system rate of

1.12 mills/kWh.

Network Integration Transmission

Service

NITS allows a transmission customer

to integrate, plan, economically

dispatch, and regulate its network

resources to serve its native load in a

way comparable to how a transmission

provider uses its own transmission

system to service its native load

customers. The monthly charge

methodology for NITS on the CAP 115-

kV/230-kV transmission system is the

product of the transmission customer’s

load-ratio share times one-twelfth of the

annual transmission revenue

requirement. The customer’s load-ratio

share is calculated on a rolling 12-

month basis (12CP). The customer’s

load-ratio share is equal to that

customers’ hourly load coincident with

the CAP 115-kV/230-kV transmission

system’s monthly transmission system

peak divided by the resultant value of

the CAP 115-kV/230-kV transmission

system’s monthly transmission system

peak minus the CAP 115-kV/230-kV

transmission system coincident peak for

all firm point-to-point transmission

service plus the CAP 115-kV/230-kV

transmission system’s firm point-topoint transmission service reservations.

In order to ensure the collection of the

transmission system’s annual revenue

requirement, the difference between the

first two components of the resultant

value outlined above constitutes the

network transmission systems’ monthly

peak and is anticipated to be metered.

Thus, a NITS customer, based on its 12-

CP load, will pay its proportionate share

of the revenue requirement for the

month. Since point-to-point

transmission service customers are

charged on a reservation basis and not

a usage basis, for the purpose of

determining the NITS charge, the

transmission system’s monthly peak

will coincide with the network

transmission system’s monthly peak.

Ancillary Service

The proposed revenue requirement

includes the costs for scheduling,

system control, and dispatch service.

The reactive supply and voltage control

ancillary service must be purchased

from the Western Area Lower Colorado

(WALC) control area. The transmission

customer may self-supply the four

remaining ancillary services or request

them from WALC. These four ancillary

services are regulation and frequency

response service, energy imbalance

service, spinning reserve service, and

supplemental reserve service.

Statement of Revenue and Related

Expenses

The following table provides a

summary of revenues and expenses for

the 5-year provisional rate period.

REVENUES AND EXPENSES

[In thousands of dollars]

Formula

rates 1

Total Revenues ................ 34,429

Revenue Distribution:

O&M ........................................ 6,763

Purchase Power ...................... 0

Transmission ........................... 0

Interest .................................... 19,343

Other ....................................... 0

Investment Repayment ........... 8,323

Capitalized Expenses ............. 0

Prior-Year Adjustment ............. 0

1The revenues and expenses for the Formula Rates are for 5 years.

Basis for Rate Development

This proposed rate adjustment is

needed to put into place, for the first

Federal Register / Vol. 65, No. 238 / Monday, December 11, 2000 / Notices 77371

time, rate formulas to calculate the rate

to be charged for the sale of surplus

transmission capacity on the CAP 115-

kV/230-kV transmission system. The

assessed calculated rates will provide

sufficient revenue to pay all annual

costs, including interest expense, and

repayment of required investment

within the allowable period. The

Formula Rates are scheduled to go in

effect on January 1, 2001, and will

remain in effect through December 31,

2005.

Comments

During the public consultation and

comment period, Western received two

written comment letters on the rate

adjustment. All comments received by

the end of the public consultation and

comment period, August 22, 2000, were

reviewed and considered in the

preparation of this rate order.

Written comments were received from

the following sources: Central Arizona

Project, August 21, 2000, Robert S.

Lynch, Attorney at Law, August 22,

2000.

The comments received dealt with the

disposition of revenues derived from the

assessment of the CAP 115-kV/230-kV

transmission system rates and its

applicability to the Lower Colorado

River Basin Development Fund

(LCRBDF). All comments supported

Western’s efforts to establish the new

CAP 115-kV/230-kV transmission

system rates. The following is a

summary of the comments received by

the end of the consultation and

comment period and Western’s response

to those comments.

Comment: Both commentors stated

that there are significant unresolved

issues regarding the disposition of any

revenues received from Western’s

marketing of CAP transmission service,

and that any revenues received should

be applied in the following manner. The

annual amortization cost component of

the CAP rate should be deposited in the

LCRBF and applied to the CAP capital

investment, however, revenues derived

from the operation and maintenance

cost component of the CAP transmission

rate should be used to offset amounts

otherwise due from the Central Arizona

Water Conservation District (CAWCD).

Response: Western agrees in concept

with the commentors and upon

approval of the provisional rates

Western will evaluate its authority and

ability to disburse revenues in the

manner similar to that suggested by the

commentor. Western will not double

collect its operation and maintenance

cost component through rates and

through CAWCD trust funds.

Environmental Compliance

In compliance with the National

Environmental Policy Act of 1969

(NEPA) (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 the preparation of 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.

Regulatory Flexibility Analysis

The Regulatory Flexibility Act of 1980

(5 U.S.C. 601–612, 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.

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.

Availability of Information

Information regarding this rate

adjustment, including the repayment

studies, comments, letters,

memorandums, and other supporting

material made or kept by Western for

the purpose of developing the Formula

Rates, is available for public review in

the Office of the Power Marketing

Manager, Desert Southwest Customer

Service Regional Office, Western Area

Power Administration, 615 South 43rd

Avenue, Phoenix, Arizona.

Submission to the Federal Energy

Regulatory Commission

The Formula Rates herein confirmed,

approved, and placed into effect on an

interim basis, together with supporting

documents, will be submitted to FERC

for confirmation and approval on a final

basis.

Order

In view of the foregoing and pursuant

to the authority delegated to me by the

Secretary of Energy, I confirm and

approve on an interim basis, effective

January 1, 2001, Formula Rates under

Rate Schedules CAP–NFT1, CAP–NFT1,

and CAP–NITS1 for the Central Arizona

Project 115-kV/230-kV transmission

system of the Western Area Power

Administration. The Formula Rates

under the rate schedules shall remain in

effect on an interim basis, pending

FERC confirmation and approval of

them or substitute rates on a final basis

through December 31, 2005.

Dated: November 30, 2000.

T.J. Glauthier,

Deputy Secretary.

Central Arizona Project

Schedule of Rate(s) for Firm Point-toPoint Cap 115-kV/230-kV Transmission

Service

[Rate Schedule CAP–FT1]

Effective: The first day of the first full

billing period beginning on or after

January 1, 2001, through December 31,

2005.

Available: In the marketing area

served by the Central Arizona Project

(CAP) 115-kV/230-kV transmission

system.

Applicable: The transmission service

customers shall compensate the CAP

where firm capacity and energy are

supplied to the CAP 115-kV/230-kV

transmission system at points of

interconnection with other systems and

transmitted and delivered, less losses, to

points of delivery on the CAP 115-kV/

230-kV system specified in the service

contract. The formula for the annual

revenue requirement used to calculate

the charges for this firm service under

this schedule was promulgated and may

be modified pursuant to applicable

Federal laws, regulations, and policies.

The Desert Southwest Customer Service

Region (DSW) may modify the charges

for firm point-to-point transmission

service upon written notice to the

transmission customer. Any change to

the charges to the transmission

customer for firm point-to-point

transmission, shall be as set forth in a

revision to this rate schedule

promulgated pursuant to applicable

Federal laws, regulations, and policies

and made part of the applicable service

contract. DSW shall charge the

transmission customer in accordance

with the revenue requirements then in

effect.

Character and Conditions of Service:

Alternating current at 60 Hertz, threephase, delivered and metered at the

77372 Federal Register / Vol. 65, No. 238 / Monday, December 11, 2000 / Notices

voltages and points of delivery

established by contract over the CAP

115-kV/230-kV transmission system.

Formula Rate For Firm Point-to-Point

Transmission Service:

Annual Rate = Five Year Average

Annual Revenue Requirement

divided by the Five Year Average

Contract Rate of Delivery, rounded

to the penny.

Monthly Rate = Annual Rate divided by

12, rounded to the penny.

Calculated Rates: For FY 2001, the

annual firm rate calculates to $9.83 per

kWyear, and the monthly firm rate

calculates to $0.82 per kWmonth. Based

on updated financial and load data,

recalculated rates will go into effect on

January 1 of each year during the

effective rate schedule period.

Adjustments

For Reactive Power: There shall be no

entitlement to transfer of reactive

kilovoltamperes at delivery points,

except when such transfers may be

mutually agreed upon by contractor and

contracting officer or their authorized

representatives.

For Losses: Capacity and energy losses

incurred in connection with the

transmission and delivery of capacity

and energy under this rate schedule

shall be supplied by the customer in

accordance with the service contract.

Billing for Unauthorized Overruns:

For each billing period in which there

is a contract violation involving an

unauthorized overrun of the contractual

firm transmission obligations, such

overrun shall be billed at 10 times the

above rates.

Central Arizona Project

Schedule of Rate(s) for Nonfirm Pointto-Point Cap 115-kV/230-kV

Transmission Service

[Rate Schedule CAP–FT1]

Effective: The first day of the first full

billing period beginning on or after

January 1, 2001, through December 31,

2005.

Available: In the marketing area

served by the Central Arizona Project

115-kV/230-kV transmission system.

Applicable: The transmission service

customer shall compensate the Central

Arizona Project (CAP) for nonfirm

point-to-point transmission service

where capacity and energy are supplied

to the CAP 115-kV/230-kV transmission

system at points of interconnection with

other systems, transmitted subject to the

availability of the transmission capacity,

and delivered less losses, to points of

delivery on the CAP 115-kV/230-kV

system specified in the service contract.

Character and Conditions of Service:

Alternating current at 60 Hertz, threephase, delivered and metered at the

voltages and points of delivery

established by contract over the CAP

115-kV/230-kV transmission system.

Formula Rate for Nonfirm Point-toPoint Transmission Service: Nonfirm

Point-To-Point Transmission Service

Rate: Each Contractor shall be billed

monthly a mills per kilowatthour rate of

scheduled or delivered kilowatthours at

point of delivery, established by

contract, payable monthly. This rate is

equal to the CAP 115-kV/230-kV Firm

Transmission dollar per kilowatt-year

rate then in effect divided by 8,760,

multiplied by 1,000, rounded to two

decimal places.

Calculated Rate: For FY 2001, the

nonfirm rate calculates to 1.12 mills/

kWh. Based on updated financial and

load data, a recalcualted rate will go

into effect on January 1 of each year

during the effective rate schedule

period.

Adjustments

For Reactive Power: There shall be no

entitlement to transfer of reactive

kilovoltamperes at delivery points,

except when such transfers may be

mutually agreed upon by contractor and

contracting officer or their authorized

representatives.

For Losses: Capacity and energy losses

incurred in connection with the

transmission and delivery of capacity

and energy under this rate schedule

shall be supplied by the customer in

accordance with the service contract.

Central Arizona Project

Schedule of Rate(s) for Network

Integration Transmission Service

[Rate Schedule CAP–NITS1

Effective: The first day of the first full

billing period beginning on or after

January 1, 2001, through December 31,

2005.

Applicable: The transmission

customer shall compensate the Central

Arizona Project (CAP) each month for

Network Integration Transmission

Service (NITS) pursuant to the

applicable Network Integration

Transmission Service Agreement and

annual revenue requirement referred to

below. The formula for the annual

revenue requirement used to calculate

the charges for this service under this

schedule was promulgated and may be

modified pursuant to applicable Federal

laws, regulations, and policies.

The Desert Southwest Customer

Service Region (DSW) may modify the

charges for NITS upon written notice to

the transmission customer. Any change

to the charges to the transmission

customer for NITS shall be as set forth

in a revision to this rate schedule

promulgated pursuant to applicable

Federal laws, regulations, and policies

and made part of the applicable service

agreement. DSW shall charge the

transmission customer in accordance

with the revenue requirement then in

effect.

Formula Rate:

Monthly Charge = Transmission

Customer’s Load-Ratio Share ×

(Revenue Requirement/12)

Calculated Rate: The projected annual

revenue requirement for FY 2001 for the

CAP 115-kV/230-kV transmission

system is $6,556,547. Based on updated

financial and load data, a recalculated

revenue requirement will go into effect

on January 1 of each year during the

effective rate schedule period.

[FR Doc. 00–31442 Filed 12–8–00; 8:45 am]

BILLING CODE 6450–01–P

DEPARTMENT OF ENERGY

Western Area Power Administration

Proposed Salt Lake City Area

Integrated Projects Firm Power Rate

Formula Adder

AGENCY: Western Area Power

Administration, DOE.

ACTION: Notice of extension of comment

and consultation period.

SUMMARY: The Western Area Power

Administration’s (Western) Colorado

River Storage Project (CRSP)

Management Center (MC) published a

Notice of Proposed Salt Lake City Area

Integrated Projects (SLCA/IP) Firm

Power Rate Formula Adder in the

Federal Register (65 FR 66995) on

November 8, 2000. This notice extends

the comment and consultation period by

3 weeks. The MC plans to have the rate

formula adder become effective March

1, 2001, instead of February 1, 2001, as

was previously stated in the Federal

Register, dated November 8, 2000.

DATES: The consultation and comment

period will end on December 29, 2000.

ADDRESSES: Written comments may be

sent to: Mr. Dave Sabo, CRSP Manager,

CRSP Management Center, Western

Area Power Administration, P.O. Box

11606, Salt Lake City, UT 84147–0606,

e-mail sabo@wapa.gov. Western must

receive written comments by the end of

the consultation and comment period to

assure consideration.

FOR FURTHER INFORMATION CONTACT: Ms.

Carol Loftin, Rates Manager, CRSP