Federal Register / Vol. 65, No. 217 / Wednesday, November 8, 2000 / Notices 66995

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 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 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.

Dated: October 16, 2000.

Michael S. Hacskaylo,

Administrator.

[FR Doc. 00–28626 Filed 11–07–00; 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 proposed rates.

SUMMARY: The Western Area Power

Administration’s (Western) Colorado

River Storage Project (CRSP)

Management Center (MC) is proposing a

rate formula adder to the existing rate

for firm long-term sales of Salt Lake City

Area Integrated Projects (SLCA/IP)

power. The SLCA/IP consists of the

CRSP, Collbran, and Rio Grande Projects

which were integrated for marketing

and ratemaking purposes on October 1,

1987. The CRSP described here includes

two CRSP participating projects which

have power facilities, Dolores and

Seedskadee Projects.

In the long term, the existing SLCA/

IP composite rate of 17.57 mills/

kilowatthour (kWh) is sufficient to pay

for all costs including operation,

maintenance, replacement, and interest

expenses and to repay investment and

irrigation assistance obligations within

the required period. CRSP MC staff will

continue to monitor the long-term firm

power rate for the SLCA/IP to determine

if a long-term rate adjustment will need

to be placed into effect.

The proposed rate formula adder is

needed to provide additional revenue in

the CRSP Basin Fund, a revolving fund

in the United States Treasury, to pay for

near-term purchase power costs and to

increase the working capital in the

CRSP Basin Fund. The proposed rate

formula adder scheduled to go into

effect on February 1, 2001, will remain

in effect until September 30, 2003, or

until superseded by another rate

adjustment, whichever occurs first. This

Federal Register notice initiates the

formal process for the proposed rate

formula adder.

DATES: The consultation and comment

period will begin when this Federal

Register notice is published and will

end December 8, 2000. Public

information forum and public comment

forum meeting dates are scheduled for

these locations:

1. Public information forum—

November 20, 2000, 10:30 a.m., Salt

Lake City, Utah; Public comment

forum—November 20, 2000, 2 p.m., Salt

Lake City, Utah.

2. Public information forum—

November 21, 2001, 10:30 a.m.,

Phoenix, Arizona; Public comment

forum—November 21, 2001, 2 p.m.,

Phoenix, Arizona.

ADDRESSES: The address for the Salt

Lake meetings is at the Sheraton Hotel

(formerly the Hilton), 150 West 500

South, Salt Lake City, Utah. The address

for the meetings in Phoenix is Western

Area Power Administration, Desert

Southwest Region, 615 South 43rd

Avenue, Phoenix, Arizona. 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 should receive

written comments by the end of the

consultation and comment period to be

assured they are considered. Oral

comments will be received at the public

comment meetings.

FOR FURTHER INFORMATION CONTACT: Ms.

Carol Loftin, Rates Manager, CRSP

Management Center, Western Area

Power Administration, P.O. Box 11606,

Salt Lake City, UT 84147–0606,

telephone (801) 524–6380, e-mail

loftinc@wapa.gov, or visit CRSP MC’s

home page at: www.wapa.gov/crsp/

crsp.htm.

SUPPLEMENTARY INFORMATION: The

existing long-term rate for SLCA/IP firm

power is designed to recover an annual

revenue requirement based on repaying

power investment; paying interest,

purchased power, operation,

maintenance, and replacement

expenses; and repaying irrigation

assistance costs, as required by law.

The Deputy Secretary of the

Department of Energy (DOE) approved

the existing Rate Schedule SLIP–F6 for

SLCA/IP firm power on March 23, 1998

(Rate Order No. WAPA–78). The Federal

Energy Regulatory Commission (FERC)

confirmed and approved the rate

schedule on July 17, 1998, in FERC

Docket No. EF98–5171–000. The

existing Firm Power Rate Schedule

expires on March 31, 2003. Under Rate

Schedule SLIP–F6, the energy rate is

8.10 mills/kWh, and the capacity rate is

$3.44 per kilowattmonth (kWmonth).

The composite rate (revenue

requirements per kWh usage) is 17.57

mills/kWh.

The proposed rate formula adder is

needed to provide additional revenue to

fund near-term purchased power costs

and to increase the working capital

balance in the CRSP Basin Fund.

Higher-than-normal purchased power

expenses have resulted from lower-thanexpected hydrology conditions, higherthan-normal purchase power prices, and

the summer test release for endangered

fish from Glen Canyon Dam (GCD).

The rate formula adder will be

applied during the next 3 fiscal years

(FY) from February 1, 2001, through

September 30, 2003. The following

proposed formulas will be used to

determine the rate formula adder:

(1) BB + ER—PP—O&M = EB

BB = CRSP Basin Fund balance at the

beginning of the FY

ER = expected revenues for the

current FY

PP = estimated purchase power costs

which could include nonreimbursable purchase power costs

O&M = operation and maintenance

expenses which includes nonreimbursable expenses,

replacements, and transmission

expenses

EB = CRSP Basin Fund balance at the

end of the FY

(2) RB—EB = RN

RB = minimum required balance in

the CRSP Basin Fund at the end of

the FY (FY 2001 = $35 million, FY

2002 = $50 million, FY 2003 = $60

million)

RN = additional revenue needed

The RN is divided by the projected

energy sales as shown in the existing

ratesetting study to determine the

additional composite rate needed.

66996 Federal Register / Vol. 65, No. 217 / Wednesday, November 8, 2000 / Notices

RATE FORMULA ADDER ESTIMATED BY FISCAL YEAR

[$1,000,000]

FY 2001

February 1, 2001-

September 30, 2001

FY 2002

October 1, 2001-

September 30, 2002

FY 2003

October 1, 2002-

September 30, 2003

Beginning Balance ............................................................................. 45.2 35.0 50.0

Expected Revenue 1 .......................................................................... 140.0 140.0 140.0

Expected Costs:

Purchased Power 2 ..................................................................... 108.8 108.8 108.8

OM&R 3 ....................................................................................... 79.1 79.1 79.1

Unbudgeted Costs 4 .................................................................... 2.0 2.0 2.0

Total Costs .......................................................................... 189.9 189.9 189.9

Ending Balance .................................................................................. (4.7) (14.9) 0.1

Minimum Required Balance .............................................................. 35.0 50.0 60.0

Revenue Needed ............................................................................... 39.7 64.9 59.9

Rate Adder Needed: 5

Composite (mills/kWh) ................................................................ 11.02 10.52 9.70

1 Current revenue based on FY 1999 Sales and Revenue Report.

2Based on latest 10/20/00 estimate.

3As currently budgeted (2002). Includes budgeted Recovery Implementation Program costs.

4 Cost required by recent HR 2348, legislation, Upper Colorado Fish Recovery Program.

5Based on power sales as projected in existing rate PRS (FY 1997).

Based upon the most recent data

available at the time of this publication,

the proposed rate formula adder for FY

2001 (which is proposed to be effective

February 1, 2001) is expected to be an

additional 5.1 mills/kWh for energy and

$2.17 per kWmonth for capacity. The

proposed composite rate adder is 11.02

mills/kWh.

At the end of FY 2001, an update of

the data in the rate formula adder will

indicate the adder for the following FY.

At the end of the Winter Season each

year, FY data and current projections

will be reviewed to determine if the FY

rate formula adder needs to be revised.

If needed, a mid-FY revision to the

adder would be made at this time. The

Winter Season is the period from

October 1 to March 31. The Summer

Season is the period from April 1 to

September 30. The rate formula adder

calculations that are updated each FY

will provide for an increase in the CRSP

Basin Fund working capital balance

until it reaches $60 million by the end

of FY 2003. Customers will be notified

in September of each year as to the next

FY rate formula adder. In March of each

year, the customers will be notified if a

mid-FY revision is required. The rate

formula adder will be charged by adding

an additional capacity and energy rate

to the SLIP–F6 rate. The table below

displays the existing rate and the

estimated rate formula adders for the

next 3 FYs.

TOTAL SLCA/IP FIRM POWER RATE ESTIMATED BY FISCAL YEAR

FY 2001

February 1, 2001-

September 30, 2001

FY 2002

October 1, 2001-

September 30, 2002

FY 2003

October 1, 2002-

September 30, 2003

Existing

rate Adder Total Adder Total Adder Total

Energy rate (mills/kWh) ......................................... 8.1 5.1 13.2 4.8 12.9 4.5 12.6

Capacity rate ($/kWmonth) .................................... 3.44 2.17 5.61 2.07 5.51 1.91 5.35

Composite rate (mills/kWh) .................................... 17.57 11.02 28.59 10.52 28.09 9.70 27.27

At the public information forums on

November 20 and 21, 2000, in Salt Lake

City and Phoenix, CRSP MC staff will

explain in detail the rate formula adder

and its application for the period of

February 1, 2001, through September

30, 2001, and also provide estimates for

the following 2 FYs.

The proposed rate formula adder is

highly dependent upon hydrology

conditions of the Upper Colorado River

Basin, volatility of purchased power

prices, potential of continuing test flows

this summer at GCD, and the CRSP

Basin Fund cash balance. A discussion

of these issues follows.

Hydrology Conditions

Water year (WY) 2000 ended on

September 30, 2000. The unregulated

inflow to Lake Powell during the run-off

season was 4.35 million acre-feet (maf)

or 56 percent of average.

Hydrological assumptions are used in

preparing estimates for generation from

the SLCA/IP facilities. This, combined

with contractual commitments, gives

Western its purchased power

requirements. Releases assumed by

Western for the Winter Season 2001 are

from the 24-month study prepared by

the Bureau of Reclamation in October

2000. For the Summer Season 2001,

Western assumed an amount of water

release which, when added to the

Winter season releases, totaled 8.23 maf

from GCD. Summer releases were

patterned by month using a dry-year

pattern. For all other SLCA/IP power

facilities, the Reclamation 24-month

study was used.

Purchased Power Prices

Western may need to purchase

electrical power from other utilities to

support its minimum contractual

commitment referred to as Sustainable

Hydro Power (SHP). Given the water

conditions previously described,

Western developed estimates of the

purchased power amounts required to

Federal Register / Vol. 65, No. 217 / Wednesday, November 8, 2000 / Notices 66997

provide the SHP amounts for each

season. For the Winter Season 2001,

Western included purchased power

prices for which Western has already

contracted. For the Summer Season

2001, Western’s estimates of purchased

power prices were derived from the

New York Merchantile Exchange’s

(NYMEX) Palo Verde Electricity futures

prices at the time the analysis was

prepared.

Test Flows

Test flows at GCD are possible again

next summer, as a result of an obligation

the Bureau of Reclamation has under

the conditions of a biological opinion (a

requirement under the Endangered

Species Act). Test flows occur in

minimum-flow years. The probability of

such an occurrence in FY 2001 is 34

percent.

CRSP Basin Fund Cash Balance

The CRSP Basin Fund ended FY 2000

with a balance of about $42.5 million in

cash. The lower-than-normal balance

was mainly due to the high cost of

purchased power prices during July,

August, and September 2000. The need

to purchase additional power was

compounded by the low environmental

test flows from GCD.

Purchase arrangements for energy

needed to meet contractual obligations

have been made for the Winter Season

2001. These purchases were at much

higher costs than normal and adversely

affected the CRSP Basin Fund’s cash

flow. Monthly revenues into the CRSP

Basin Fund normally run from $10

million to $14 million per month;

expenditures for purchased power are

now at these levels. Any spending on

transmission, replacements, and

operation and maintenance costs will

result in a negative cash flow during

months when purchased energy costs

are equivalent to or greater than revenue

inflows.

In the event of another year where

hydrology conditions are significantly

below average and where low test flows

from GCD are required, the CRSP Basin

Fund working capital would be

insufficient at the present rate.

Procedural Requirements

Since the proposed rate formula adder

constitutes a major rate adjustment as

defined at 10 CFR 903.2, both public

information forums and public

comment forums will be held. However,

the consultation and comment period

has been shortened because of the

financial hardship faced by the CRSP

Basin Fund. After reviewing public

comments, Western will recommend

that the proposed rate formula adder or

a revised proposed rate formula adder

be approved on an interim basis by the

DOE Deputy Secretary.

The proposed rate formula adder to

the SLCA/IP firm power rates is being

established pursuant to the Department

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

7101–7352; 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 projects

involved.

By Amendment No. 3 to Delegation

Order No. 0204–108, published

November 10, 1993 (58 FR 59716), the

Secretary of DOE delegated (1) the

authority to develop long-term power

and transmission rates on a

nonexclusive basis to the Administrator

of Western; and (2) the authority to

confirm, approve, and place into effect

on a final basis, to remand, or to

disapprove such rates to 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 DOE

procedures for public participation in

power rate adjustments are found at 10

CFR part 903.

Availability of Information

All studies, comments, letters,

memorandums, or other documents

made or kept by Western for developing

the proposed rates are and will be made

available for inspection and copying at

the CRSP Management Center, located

at 150 East Social Hall Avenue, Suite

300, Salt Lake City, UT 84111–1534.

Regulatory Procedural 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.

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 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.

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.

Dated: October 27, 2000.

Michael S. Hacskaylo,

Administrator.

[FR Doc. 00–28627 Filed 11–7–00; 8:45 am]

BILLING CODE 6450–01–P

ENVIRONMENTAL PROTECTION

AGENCY

[OPP–34225A; FRL–6753–2]

Diazinon; Revised Pesticide Risk

Assessment; Notice of Public Meeting

AGENCY: Environmental Protection

Agency (EPA).

ACTION: Notice.

SUMMARY: EPA will hold a public

meeting to present the revised risk

assessment for the organophosphate

pesticide diazinon to interested

stakeholders. This public meeting,

called a ‘‘Technical Briefing,’’ will

provide an opportunity for stakeholders

to learn about the data, information, and

methodologies that the Agency used in

revising its risk assessment for diazinon.

In addition, representatives of the

Department of Agriculture (USDA) will

also provide ideas on possible risk

management for diazinon.

DATES: The technical briefing will be

held on, December 5, 2000, from 1:00

p.m. to 5:00 p.m.

ADDRESSES: The technical briefing will

be held at the Radisson Hotel, Old Town

Alexandria, 901 N. Fairfax St.,

Alexandria, VA 22314, (703) 683–6000.

FOR FURTHER INFORMATION CONTACT: By

mail: Ben Chambliss, Special Review

and Registration Division (7508C),