14130 Federal Register / Vol. 62, No. 57 / Tuesday, March 25, 1997 / Notices

Tentative Agenda:

Thursday, April 17, 1997

9:00 a.m.—Review of Subpanel Reports

5:00 p.m.—Public Comments

6:00 p.m.—Adjourn

Friday, April 18, 1997

9:00 a.m.—Executive Summary

11:00 a.m.—Preparation of FESAC

Report

1:00 p.m.—Presentation of Results to Dr.

Martha Krebs

4:00 p.m.—Adjourn

Public Participation: The meeting is

open to the public. Written statements

may be filed with the Committee either

before or after the meeting. Members of

the public who wish to make oral

statements pertaining to agenda items

should contact Albert L. Opdenaker at

301–903–8584 (fax) or

albert.opdenaker@mailgw.er.doe.gov (email). Requests to make oral statements

must be received 5 days prior to the

meeting; reasonable provision will be

made to include the statement in the

agenda. The Chairperson of the

Committee is empowered to conduct the

meeting in a fashion that will facilitate

the orderly conduct of business.

Minutes: The minutes of this meeting

will be available for public review and

copying within 30 days at the Freedom

of Information Public Reading Room,

1E–190, Forrestal Building, 1000

Independence Avenue, SW,

Washington, DC, between 9 a.m. and 4

p.m., Monday through Friday, except

Federal holidays.

Issued at Washington, DC on March 20,

1997

Rachel M. Samuel,

Acting Deputy Advisory Committee

Management Officer

[FR Doc. 97–7476 Filed 3–24–97; 8:45 am]

BILLING CODE 6450–01–P

Federal Energy Regulatory

Commission

[Docket No. RP97–290–000]

Colorado Interstate Gas Company;

Notice of Proposed Changes in FERC

Gas Tariff

March 19, 1997.

Take notice that on March 14, 1997,

Colorado Interstate Gas Company (CIG),

tendered for filing to become part of its

FERC Gas Tariff, First Revised Volume

No. 1, the tariff sheets listed on

Appendix A to the filing, to be effective

April 14, 1997.

CIG states on November 1, 1996 it

filed in Docket No. RP97–63–000 pro

forma tariff sheets to comply with Order

No. 587. As part of CIG’s filing it

proposed a new Headstation Pooling

Rate Schedule (HPS–1). CIG further

states in the Commission’s order on

CIG’s compliance filing issued January

16, 1997, the Commission stated that the

GISB standards ‘‘intended the pipeline

to implement a new pooling service but

in order to implement a new service the

pipeline must make a section 4 filing’’

(that is a filing pursuant to Section 4 of

the Natural Gas Act). CIG states this is

the purpose of this filing.

CIG states that copies of this filing

have been served on CIG’s jurisdictional

customers and public bodies.

Any person desiring to be heard or to

protest this filing should file a motion

to intervene or protest with the Federal

Energy Regulatory Commission, 888

First Street, N.E., Washington, DC

20426, in accordance with Section

385.214 and Section 385.211 of the

Commission’s Regulations. All such

motions or protests must be filed as

provided in Section 154.210 of the

Commission’s Regulations. Protests will

be consider 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 this filing are on file with the

Commission and are available for public

inspection in the Public Reference

Room.

Linwood A. Watson, Jr.

Acting Secretary.

[FR Doc. 97–7425 Filed 3–24–97; 8:45 am]

BILLING CODE 6717–01–M

[Docket No. CP97–284–000]

Columbia Gas Transmission

Corporation; Notice of Request Under

Blanket Authorization

March 19, 1997.

Take notice that on March 11, 1997,

Columbia Gas Transmission Corporation

(Columbia), 1700 MacCorkle Avenue,

S.E., Charleston, West Virginia 25314,

filed in Docket No. CP97–284–000 a

request pursuant to Sections 157.205

and 157.211 of the Commission’s

Regulations under the Natural Gas Act

(18 CFR 157.205, 157.211) for

authorization to construct and operate

additional points of delivery for firm

transportation service to existing

customers, under Columbia’s blanket

certificate issued in Docket No. CP83–

76–000 pursuant to Section 7 of the

Natural Gas Act, all as more fully set

forth in the request that is on file with

the Commission and open to public

inspection.

Columbia proposes to construct and

operate the facilities needed to establish

thirteen additional delivery points. The

customers and counties involved are:

Columbia Gas of Kentucky, Inc. (CKY)

(Martin and Clark Counties, Kentucky);

Columbia Gas of Ohio, Inc. (COH)

(Ottawa, Medina and Carroll Counties,

Ohio); Mountaineer Gas Company

(MGC) (Boone, Marshall, Barbour,

Gilmer, Wayne, Wyoming and Tucker

Counties, West Virginia), and The

Waterville Gas Company (WGC) (Wood

County, Ohio).

Each new delivery point’s

interconnecting facility will vary

according to area conditions; but, in

most cases, the following will be

installed: a 4-inch by 1-inch tap saddle

(depending on pipeline size), a 1-inch

valve, nipple, and less than 20 feet of

pipe on Columbia’s existing right-ofway. CKY, COH, MGC and WGC will set

the meter and regulator for each

location. The estimated natural gas

quantities are: 10,851 Dth/day and

4,398,250 Dth/annual for CKY; 4.5 Dth/

day and 450 Dth/annual for COH; 13.5

Dth/day and 1,650 Dth/annual for MGC,

and 1.8 Dth/day and 200 Dth/annual for

WGC.

Columbia states that the new delivery

points are not prohibited by its existing

tariff and that it has sufficient capacity

to accomplish deliveries without

detriment or disadvantage to other

customers. The proposed delivery

points will not have an effect on

Columbia’s peak day and annual

deliveries and the total volumes

delivered will not exceed total volumes

authorized prior to this request.

Columbia estimates the new tap

installation costs to be approximately

$150 each and will be treated as an

O&M expense, except for the Martin

County, Kentucky project which is an

existing tap and will require no

additional cost.

Any person or the Commission’s staff

may, within 45 days after issuance of

the instant notice by the Commission,

file pursuant to Rule 214 of the

Commission’s Procedural Rules (18 CFR

385.214) a motion to intervene or notice

of intervention and pursuant to Section

157.205 of the Regulations under the

Natural Gas Act (18 CFR 157.205) a

protest to the request. If no protest is

filed within the time allowed therefor,

the proposed activity shall be deemed to

be authorized effective the day after the

time allowed for filing a protest. If a

protest is filed and not withdrawn

within 30 days after the time allowed

for filing a protest, the instant request

shall be treated as an application for
Federal Register / Vol. 62, No. 57 / Tuesday, March 25, 1997 / Notices 14131

authorization pursuant to Section 7 of

the Natural Gas Act.

Linwood A. Watson, Jr.

Acting Secretary.

[FR Doc. 97–7418 Filed 3–24–97; 8:45 am]

BILLING CODE 6717–01–M

[Docket Nos. CP96–655–001, CP96–656–

001, and CP96–657–001]

Destin Pipeline Company, L.L.C.;

Notice of Amendment

March 19, 1997.

Take notice that on March 14, 1997,

Destin Pipeline Company, L.L.C.

(Destin) successor in interest to Destin

Pipeline Company Inc. (DPC), P.O. Box

2563, Birmingham, Alabama 35202–

2563, filed in Docket No. CP96–655–

001, et al., an amendment to the

pending application for a certificate of

public convenience and necessity filed

on July 24, 1996, in Docket No. CP96–

655–000, et al., pursuant to Section 7(c)

of the Natural Gas Act and Parts 284 and

157 of the Commission’s Regulations, to

modify proposed facilities to include

executed Precedent Agreements

providing market support for the Destin

Pipeline, to revise Destin’s proposed

FERC Gas Tariff and initial rates to

provide a new flexible firm

transportation service to meet the needs

of deepwater producers and to renew

requests for blanket certificates of

construction and transportation, all as

more fully set forth in the amendment

which is on file with the Commission

and open to public inspection.

Destin states that in its initial filing,

as supplemented, DPC requested

authorization to construct, install and

operate a new large diameter interstate

pipeline (Destin Pipeline) to transport

gas from the Gulf of Mexico to

interconnections with five interstate

pipelines in the State of Mississippi,

Destin states that due to favorable

reaction from the shipper community,

on December 21, 1996, Amoco Pipeline

Company (Amoco Pipeline), Shell Gas

Pipeline Company (Shell Pipeline),

Amoco Production Company (Amoco),

Shell Deepwater Development Inc.

(SDDI) and shell Deepwater Production

Inc. (SDPI) agreed with DPC to have

affiliates of Amoco Pipeline and Shell

Pipeline become equity owners in the

Destin Pipeline project. Additionally,

Destin states that Amoco, SDDI and

SDPI have executed Precedent

Agreements dated as of February 28,

1997, for the proposed flexible firm

transportation service on Destine

Pipeline with average Transportation

Demand (TD) levels over the first five

years at 562 MMcf per day and peak

TDs of 844 MMcf per day.

Destin states that its initial filing

requested authorization to construct,

install, and operate one gathering

platform in Main Pass Block 260, Gulf

of Mexico; one offshore junction

platform in Viosca Knoll Block 119,

Gulf of Mexico; 76 miles of 36-inch

offshore pipeline facilities; 134 miles of

36-inch and 30-inch onshore pipeline

facilities; two miles of 16-inch pipeline

facilities; one 14,100 horsepower

compressor station in Jackson County,

Mississippi; one 11,600 horsepower

compressor station in Greene county,

Mississippi; and related pipeline

interconnection, measurement and

appurtenant facilities to accommodate

the transportation of 1 Bcf of gas per day

for delivery to downstream

interconnections in southern and

central Mississippi. Destin states that

the pipeline route was to extend in a

northerly direction from Main Pass

Block 260, Gulf of Mexico, to an

onshore terminus at its interconnection

with Southern Natural Gas Company

(Southern) near Enterprise, Mississippi.

Destin further states that the original

filing contemplated interconnections

with four other pipelines, as well as

Southern; Florida Gas Transmission

Corporation, Transcontinental Gas Pipe

Line Corporation, Tennessee Gas

Pipeline Company and Texas Eastern

Transmission Corporation.

Destin states that, specifically, the

amended filing seeks the following

modifications to the original proposal:

(a) Several modifications to the

jurisdictional facilities, (b) an

interconnection with an additional

interstate pipeline, (c) the deletion of

the levelized rates for the FT–1 firm

transportation service, (d) the addition

of a flexible firm transportation service

similar to that approved in Shell Gas

Pipeline Company, 76 FERC ¶ 61,126

(1996), (e) a decrease in the proposed

initial rates, (f) inclusion of capacity

lease payments to Southern in Destin’s

proposed cost of service in accordance

to the pending joint application of

Southern and Destin filed on March 14,

1997, in Docket No. CP97–291–000, (g)

revisions to Destin’s proposed FERC Gas

Tariff, primarily attributable to the

addition of the flexible firm

transportation service and the

incorporation of the Gas Industry

Standards Board standards.

It is stated that the modifications to

the facilities originally proposed are as

follows: (a) The deletion of the junction

platform in Viosca Knoll Block 119,

Gulf of Mexico, (b) an interconnection

with Koch Gateway Pipeline Company

in Jackson County, Mississippi, (c) the

deletion of the onshore receipt point, (d)

increase compression capabilities at the

Pascagoula compression site from

14,100 horsepower to 17,040

horsepower, (e) decrease compression at

the Sand Hill compression site from

11,600 horsepower to 9,400 horsepower,

and (f) in addition to the measurement

facilities to connect to the inlet and

outlet of a non-jurisdictional processing

plant to be operated by Amoco in

Pascagoula, Mississippi, Destin

proposed to add as an auxiliary facility

a liquids slug catcher facility in Jackson

County, Mississippi, which will be

located upstream of the site of the nonjurisdictional processing plant. Destin

estimates the revised cost of the

proposed facilities to be $308.1 million.

In regard to its transportation services,

Destin states that it is deleting the 10-

year levelized firm transportation

services and adding a flexible firm

transportation service. Interruptible

transportation service under Rate

Schedule IT will be applicable to any

shipper that contracts for interruptible

transportation on Destin Pipeline. In its

amended proposal, Destin proposes to

offer two firm transportation services:

(1) A traditional firm transportation

service (Rate Schedule FT–1) and (2) a

flexible firm transportation service (Rate

Schedule FT–2). Destin states that Rate

Schedule FT–1 is a traditional firm

transportation service with a fixed TD

and a reservation charge to be billed

regardless of throughput levels. The

maximum initial monthly reservation

rate to be charged for service under Rate

Schedule FT–1 is $7.35 per Dth, a

decrease of 58 cents per Dth per month

from the comparable rate proposed for

the traditional firm rate schedule in the

initial filing. Destin states that Rate

Schedule FT–2 is a flexible firm

transportation service which will

provide for variable levels of TD and

volumetric rate treatment depending on

throughput levels relative to TD. Destin

states that to be eligible for service

under Rate Schedule FT–2, a shipper

must execute a Reserve Commitment

Agreement wherein the shipper

identifies OCS lease(s) with estimated

proven recoverable reserves of 100 Bcf

or more attributable to the shipper’s

interests and its affiliates or aggregated

with other shipper(s) committed

interest(s) in such leases (Committed

Leases) and make a life of reserves

commitment of its share of production

therefrom. In addition, Destin states that

each shipper will be required to submit

documentation and technical data to

support its reserve commitment when

placing a request for transportation

service under Rate Schedule FT–2. It is