Federal Register / Vol. 63, No. 118 / Friday, June 19, 1998 / Notices 33649

Comment date: June 25, 1998, in

accordance with Standard Paragraph E

at the end of this notice.

Standard Paragraph

E. Any person desiring to be heard or

to protest said filing should file a

motion to intervene or protest with the

Federal Energy Regulatory Commission,

888 First Street, N.E., Washington, D.C.

20426, in accordance with Rules 211

and 214 of the Commission’s Rules of

Practice and Procedure (18 CFR 385.211

and 18 CFR 385.214). All such motions

or protests should be filed on or before

the comment date. Protests will be

considered by the Commission in

determining the appropriate action to be

taken, but will not serve to make

protestants parties to the proceeding.

Any person wishing to become a party

must file a motion to intervene. Copies

of these filings are on file with the

Commission and are available for public

inspection.

David P. Boergers,

Acting Secretary.

[FR Doc. 98–16283 Filed 6–18–98; 8:45 am]

BILLING CODE 6717–01–P

DEPARTMENT OF ENERGY

Western Area Power Administration

Proposed Rate Formulas for Desert

Southwest Customer Service Region

Transmission and Ancillary Services

AGENCY: Western Area Power

Administration, DOE.

ACTION: Notice of proposed rate

adjustments.

SUMMARY: The Western Area Power

Administration’s (Western) Desert

Southwest Region (DSW) is initiating a

rate adjustment process for network

integration transmission service for both

the Parker-Davis Project (P–DP) and the

Pacific Northwest-Pacific Southwest

Intertie Project (Intertie) and for

ancillary services from the P–DP,

Boulder Canyon Project (BCP), and part

of the Colorado River Storage Project

(CRSP) located in DSW’s Control Area.

This action is necessary to bring DSW

into compliance with the intent of

Federal Energy Regulatory Commission

(FERC) Order Nos. 888 and 888–A. To

date, DSW has not developed charges

for the long term sales of the six

ancillary services defined by FERC, or

for network integration transmission

service.

The proposed rate and its impact are

explained in greater detail in a rate

brochure which will be made available

to all interested parties.

The proposed rate is scheduled to go

into effect on November 1, 1998. This

Federal Register notice initiates the

formal process for the proposed rate.

DATES: Submit comments on or before

September 17, 1998.

The forum dates are:

1. Public Information Forum, June 30,

1998, 10 a.m. MST, Phoenix, Arizona.

2. Public Comment Forum, July 30,

1998, 10 a.m. MST, Phoenix, Arizona.

ADDRESSES: Written comments should

be sent to Mr. J. Tyler Carlson, Regional

Manager, Desert Southwest Customer

Service Region, Western Area Power

Administration, P.O. Box 6457,

Phoenix, AZ 85005–6457. Western

should receive written comments by the

end of the consultation and comment

period to be assured consideration. The

public forums will be held at the Desert

Southwest Regional Office, 615 South

43rd Avenue, Phoenix, Arizona.

FOR FURTHER INFORMATION CONTACT: Mr.

Maher A. 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.

SUPPLEMENTARY INFORMATION:

Proposed Rate for Network Integration

Transmission Service

The DSW will offer, subject to

provisions in its Open Access

Transmission Service Tariff (OAT),

Network Integration Transmission

Service (NTS) to eligible transmission

customers. The customer must obtain

ancillary services for NTS pursuant to

Western’s OAT. The NTS charge for

Intertie and P–DP will be calculated

independently. The monthly charge for

NTS is the product of the network

transmission customer’s load-ratio share

times one-twelfth of the annual revenue

requirement allocated to transmission.

The customer’s load-ratio share is

calculated on a rolling 12-month basis

(12 CP). It is equal to the network

transmission customer’s hourly load

coincident with DSW’s monthly

transmission system peak divided by

the resultant value of DSW’s monthly

transmission system peak minus the

coincident peak (CP) for all firm pointto-point transmission service plus firm

point-to-point reservations. Service for

point-to-point transmission service can

be obtained through rate schedules PDFT6 and INT–FT2.

The projected annual revenue

requirement allocated to transmission

for Fiscal Year (FY) 1999 for P–DP is

$23,001,589, and for Intertie the

projected annual revenue requirement is

$21,943,150. The annual power

repayment study derives the revenue

requirement to be recovered from

network and firm point-to-point

transmission service. The annual

transmission costs included in the

revenue requirement are operation and

maintenance expenses, administrative

and general expenses, interest expense,

and principal expenses associated with

transmission.

Proposed Rates For Ancillary Services

Western will provide ancillary

services subject to provisions in the

OAT. The proposed rates are designed

to recover only the costs incurred for the

service(s). The annual generation costs

included in the revenue requirement for

Reactive Supply and Voltage Control,

Regulation and Frequency Response,

and Spinning and Supplemental

Reserves are operation and maintenance

expenses, administrative and general

expenses, interest expense, and

principal expense associated with

providing ancillary services.

On April 1, 1998, the Western Area

Upper Colorado Control Area, which

includes the Salt Lake City Area

Integrated Projects (SLCA/IP) generation

and most of the CRSP transmission

system, was merged with two other

Control Areas: The Western Area

Colorado Missouri, operated by

Western’s Rocky Mountain Region, and

the Western Area Lower Colorado

(WALC) Control Area, operated by

DSW. As a result, regulation and

frequency response and reactive supply

and voltage control ancillary services

will include certain SLCA/IP generation

costs as well as DSW generation costs.

Proposed Rate for Scheduling, System

Control, and Dispatch Service

Scheduling, System Control and

Dispatch ancillary service is required to

schedule the movement of power

through, out of, within, or into a Control

Area. This ancillary service can be

provided only by the Control Area

operator or transmission provider.

Scheduling, System Control and

Dispatch ancillary service costs are

calculated as an annual cost of all

personnel, capital costs (such as the

dispatch center building), and other

related costs involved in providing the

service. The cost is divided by the

number of schedules per year to derive

a rate per schedule per day. Up to five

schedule changes per transaction, per

day will be allowed at no additional

charge.

The rates charged for the Scheduling,

System Control and Dispatch ancillary

service are contingent on the type of

service required. The range of the

service on a cost per schedule per day
33650 Federal Register / Vol. 63, No. 118 / Friday, June 19, 1998 / Notices

is up to $34.10 for an existing schedule,

which requires no Supervisory Control

and Data Acquisition (SCADA)

programming or intra-bus transfer, and

up to $56.20 for a new schedule which

requires both SCADA programming and

intra-bus transfer. Intermediate rates are

available for schedules requiring

combinations of the two. This ancillary

service is included in the transmission

customer’s rate.

Proposed Rate for Reactive Supply and

Voltage Control from Generation

Sources

In order to maintain transmission

voltages on the transmission provider’s

transmission facilities within acceptable

limits, generation facilities under the

control of the Control Area operator are

operated to produce or absorb reactive

power. Thus, Reactive Supply and

Voltage Control from generation sources

service must be provided for each

transaction on the transmission

provider’s transmission facilities. This

ancillary service is required to be

offered to the transmission customer by

the transmission provider in order to

maintain transmission voltages on the

transmission provider’s transmission

facilities within acceptable limits.

The rate for Reactive Supply and

Voltage Control ancillary service is

calculated by combining the revenue

requirements of P–DP, BCP, and SLCA/

IP. This total revenue requirement is

then divided by the sum of the longterm firm transmission reservations,

yielding a rate of $0.08/kilowattmonth

(kWmo). The transmission customer is

required to maintain a power factor

between 95 percent leading and 95

percent lagging. The rate of $0.08/kWmo

will be applied to all transmission

customers taking service under

Western’s OAT.

Proposed Rate for Regulation and

Frequency Response Service

Regulation and Frequency Response

service is necessary to provide for the

continuous balancing of resources,

generation and interchange, with load

and for maintaining scheduled

interconnection frequency at 60 cycles

per second (60 Hz). The transmission

provider must offer this service when

the transmission service is used to serve

load within its Control Area. The

transmission customer must either

purchase this service from the

transmission provider or make

alternative comparable arrangements to

satisfy its regulation and frequency

response service obligation.

DSW will offer regulation from its

own resources, if available. The charge

for this service from DSW resources is

calculated based on P–DP, BCP, and

SLCA/IP data. The total annual revenue

requirement of P–DP, BCP, and SLCA/

IP is divided by the nameplate plant

capacities to derive an average revenue

requirement per kilowatt (kW) result.

The resultant average revenue

requirement per kW is multiplied by the

capacity used to provide regulation

service and then divided by the CP of

the Control Area load. This result is

divided by 12 to derive a monthly rate

of $0.20/kWmo. If DSW cannot supply

this service from its resources, it will

purchase the service on the market

adding a 10 percent administrative

charge.

Proposed Rate for Energy Imbalance

Service

Energy Imbalance service is provided

when a difference occurs between the

scheduled and the actual delivery of

energy to a load located within a

Control Area over a single hour. The

transmission provider must offer this

service when the transmission service is

used to serve load within its Control

Area. The transmission customer must

either purchase this service from the

transmission provider or make

alternative comparable arrangements to

satisfy its Energy Imbalance service

obligation.

The Energy Imbalance Service rate

will be a penalty-type rate which DSW

reserves the right to apply against

deviations outside a 3 percent

bandwidth (± 1.5 percent deviations),

with a 2 MW deviation minimum.

Negative excursions (under deliveries)

greater than 1.5 percent and occurring

more than five times per month will be

assessed a penalty charge of 100 mills/

kilowatthour (kWh); e.g., the sixth time

an under delivery occurs within a

month, the 100 mills/kWh charge will

be applied to the difference between the

total excursion and 1.5 percent.

Any positive excursion (over delivery)

will be credited to the customer within

thirty days for 50 percent of the market

value of the over delivery, provided the

over deliveries do not impinge upon

WALC Control Area operations. For

example, during times of high water or

operating constraints, DSW reserves the

right to eliminate credits for over

deliveries. The market value

determinant will be the average monthly

non-firm price from Western merchants

operating within the WALC Control

Area.

Proposed Rate for Operating Reserves:

Spinning Reserve Service

Spinning Reserve service is needed to

serve load immediately in the event of

a system contingency. Spinning Reserve

service may be provided by generating

units that are on-line and loaded at less

than maximum output. The

transmission provider must offer this

service when the transmission service is

used to serve load within its Control

Area. The transmission customer must

purchase this ancillary service either

from DSW or make alternative

comparable arrangements to satisfy its

Spinning Reserve service obligation.

The transmission customer will be

responsible for the transmission service

to get these reserves to their destination.

These reserves will not be available

from DSW resources on a long-term

basis. If Spinning Reserves are

unavailable from WALC resources,

Western may obtain the reserves on the

open market for the customer and pass

through the cost, with an added 10

percent administrative charge.

Proposed Rate for Operating Reserves:

Supplemental Reserve Service

Supplemental Reserve service is

needed to serve load in the event of a

system contingency; however, it is not

available immediately to serve load, but

rather within a short period of time.

Supplemental Reserve service may be

provided by generating units that are

on-line and unloaded, by quick-start

generation or by interruptible load. The

transmission provider must offer this

service when the transmission service is

used to serve load within its Control

Area. The transmission customer must

purchase this ancillary service either

from DSW or make alternative

comparable arrangements to satisfy its

Supplemental Reserve service

obligation. The transmission customer

will be responsible for the transmission

service to get these reserves to their

destination.

These reserves will not be available

from DSW resources on a long-term

basis. If Supplemental Reserves are

unavailable from WALC resources,

Western may obtain the reserves on the

open market for the customer and pass

through the cost, with an added 10

percent administrative charge.

Authorities

Since the proposed rates constitute a

major rate adjustment as defined in 10

CFR 903.2, both a public information

forum and a public comment forum will

be held. After review of public

comments, Western will recommend the

proposed rates or revised proposed rates

for approval on an interim basis by the

Deputy Secretary of Department of

Energy (DOE).

The proposed Project transmission

and ancillary service rates are being

established pursuant to the Department
Federal Register / Vol. 63, No. 118 / Friday, June 19, 1998 / Notices 33651

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

7101, et seq.) and the Reclamation Act

of 1902 (43 U.S.C. 371, et seq.), 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

section 8 of the Act of August 31, 1964,

(16 U.S.C. 837g).

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 Western; (2) the authority to confirm,

approve, and place such rates in effect

on an interim basis to the Deputy

Secretary; and (3) the authority to

confirm, approve, and place into effect

on a final basis, to remand, or to

disapprove such rates to the FERC.

Existing DOE procedures for public

participation in power rate adjustments

(10 CFR Part 903) became effective on

September 18, 1985 (50 FR 37835).

Regulatory Procedure Requirements

Regulatory Flexibility Analysis

The Regulatory Flexibility Act of

1980, 5 U.S.C. 601–612, requires Federal

agencies to perform a regulatory

flexibility analysis if a proposed rule is

likely to have a significant economic

impact on a substantial number of small

entities. Western has determined that

this action relates to rates or services

offered by Western, and therefore is not

a rule within the purview of the act.

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 conducts environmental

evaluations of the proposed rates and

develops the appropriate level of

documentation.

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.

Availability of Information

All brochures, studies, comments,

letters, memorandums, and other

documents made or kept by Western for

the purpose of developing the proposed

rates will be made available for

inspection and copying at Western’s

Desert Southwest Regional Office at 615

South 43rd Avenue in Phoenix,

Arizona.

Dated: June 8, 1998.

Michael S. Hacskaylo,

Administrator.

[FR Doc. 98–16341 Filed 6–18–98; 8:45 am]

BILLING CODE 6450–01–P

ENVIRONMENTAL PROTECTION

AGENCY

[ER–FRL–5492–8]

Environmental Impact Statements;

Notice of Availability

Responsible Agency: Office of Federal

Activities, General Information, (202)

564–7167 or (202) 564–7153.

Weekly Receipt of Environmental

Impact Statements

Filed June 8, 1998 Through June 12,

1998

Pursuant to 40 CFR 1506.9.

EIS No. 980225, Draft EIS, EPA, FL,

Tampa Water Resource Recovery

Project, (TWRRP), Design and

Construction, Funding and COE

Section 404 Permit, City of Tampa,

FL, Due: August 3, 1998, Contact:

Robert B. Howard (404) 562–9370.

EIS No. 980226, Final EIS, COE, FL, C–

51 West End Flood Control Project,

Implementation To Improve the Level

of Flood Control, Central and

Southern Florida Project, Palm Beach

County, FL, Due: July 20, 1998,

Contact: Rudy Nyc (404) 331–4619.

EIS No. 980227, Final EIS, BLM, AK,

Northern Intertie Project,

Construction of 230 kV Transmission

Line from Healy to Fairbanks, AK,

Application for Right-of-Way Grant,

Gold Valley Electric Association, AK,

Due: July 20, 1998, Contact: Gary

Foreman (907) 474–2339.

EIS No. 980228, Final Supplement,

COE, OR, WA, Columbia and Lower

Willamette River Federal Navigation

Channel, Integrated Dredge Material

Management Study, OR and WA, Due:

July 20, 1998, Contact: Steven J.

Stevens (503) 808–4768.

EIS No. 980229, Draft Supplement, AFS,

ID, Thompson Creek Mine (TCM),

Updated Information, Prevent and/or

Control Potential Acid-Rock Drainage,

Plan of Operations, Custer County, ID,

Due: August 3, 1998, Contact: Leon

Jadlowski (208) 838–3300.

EIS No. 980230, Draft, EIS, AFS, MT,

Hemlock Point Access Project,

Construction of 860 feet of Low

Standard Road, Plum Creek, Swan

Valley, Flathead National Forest,

Missoula County, MT Due: August 3,

1998, Contact: Earl Sutton (405) 758–

5326.

EIS No. 980231, Final EIS, NPS, MI,

Keweenaw National Historical Park

General Management Plan,

Implementation, Houghton County,

MI, Due: July 20, 1998, Contact:

Michael Madell (402) 221–3493.

EIS No. 980232, Final EIS, BLM, OR,

Beaty Butte Allotment Management

Plan, Implementation, Lakeview

District, Hart Mountain National

Antelope Refuge, Lake and Harney

Counties, OR, Due: July 20, 1998,

Contact: Paul Whitman (541) 947–

2177.

EIS No. 980233, Draft EIS, COE, FL,

Jacksonville Harbor Navigation

Channel Deepening Improvements,

Construction, St. Johns River, Duval

County, FL, Due: August 3, 1998,

Contact: Kenneth Dugger (907) 232–

1686.

EIS No. 980234, Final EIS, AFS, MI,

Porter Creek Recreational Lake and

Complex, Implementation,

Homochitto National Forest,

Homochitto Ranger District, Franklin

County, MI, Due: July 20, 1998,

Contact: Gary W. Bennett (601) 384–

5876.

EIS No. 980235, Draft Supplement,

BLM, CO, Glenwood Springs

Resource Area, Updated Information,

Oil & Gas Leasing and Development,

Leasing Lands in the Naval Oil Shale

Reserves, Resource Management Plan

Amendment, Garfield County, CO,

Due: September 17, 1998, Contact:

Steve Moore (970) 947–2824.

Amended Notices

EIS No. 980191, Final EIS, NPS, OR,

Crater Lake National Park, Visitor

Services Plan, Implementation, OR,

Due: June 29, 1998, Contact: Al

Hendricks (541) 594–2211.

Published FR–05–29–98–Correction

to Title, Due Date and Contact Person.

Dated: June 16, 1998.

B. Katherine Biggs,

Associate Director, NEPA Compliance

Division, Office of Federal Activities.

[FR Doc. 98–16396 Filed 6–18–98; 8:45 am]

BILLING CODE 6560–50–M

ENVIRONMENTAL PROTECTION

AGENCY

[ER–FRL–5492–9]

Environmental Impact Statements and

Regulations: Availability of EPA

Comments

Availability of EPA comments

prepared June 1, 1998 Through June 5,

1998 pursuant to the Environmental

Review Process (ERP), Under Section

309 of the Clean Air Act and Section