[Federal Register Volume 61, Number 233 (Tuesday, December 3, 1996)]
[Notices]
[Pages 64077-64080]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 96-30667]
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DEPARTMENT OF ENERGY
[Docket No. CP97-92-000, et al.]
Transcontinental Gas Pipe Line Corporation, et al.; Natural Gas
Certificate Filings
November 22, 1996.
Take notice that the following filings have been made with the
Commission:
1. Transcontinental Gas Pipe Line Corporation
[Docket No. CP97-92-000]
Take notice that on November 12, 1996, Transcontinental Gas Pipe
Line Corporation (Transco), P. O. Box 1396, Houston, Texas 77251, filed
in Docket No. CP97-92-000 an application pursuant to Section 7(c) of
the Natural Gas Act for a certificate of public convenience and
necessity authorizing an extension and expansion of Transco's Mobile
Bay Lateral including (i) authorization to construct and operate
approximately 76.8 miles of 30-inch diameter pipeline extending from a
proposed new platform in Main Pass Area, Block 260 to its existing
Compressor Station No. 82 in Mobile County, Alabama; approximately 17.5
miles of 36-inch diameter onshore pipeline loop located immediately
downstream of Station No. 82 in southern Mobile County, Alabama; a new
30,000 horsepower compressor Station No. 83 located in northern Mobile
County, Alabama; and a 26,000 horsepower compression addition at
Transco's existing Station No. 82; all of which facilities will provide
a total of the dekatherm equivalent of 600 MMcf per day of additional
service offshore \1\
[[Page 64078]]
and 500 MMcf per day of additional service onshore \2\, to become
available in late 1998; (ii) approval of Transco's initial rates for
such service to be Transco's then-current Rate schedule FT rate for
Zone 4A, and (iii) approval of rolled-in rate treatment for costs
associated with the Mobile Bay Lateral Extension and Expansion Project,
to be made effective in Transco's first NGA Section 4 rate proceeding
following the in-service date of the project, all as more fully set
forth in the application which is on file with the Commission and open
to public inspection.
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\1\ In referring to the ``offshore extension'' of its Mobile Bay
Lateral, Transco states that approximately 73.0 miles of the
extension will be located offshore and approximately 4.0 miles will
be located onshore upstream of and connecting with Station No. 82,
which is the existing terminus of the Mobile Bay Lateral.
\2\ Transco states that it is sizing its onshore expansion
facilities smaller than its offshore facilities based on informal
indications that it will receive 100 MMcf of capacity turnback on
the Mobile Bay Lateral.
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In order to create the firm transportation capacity under the
project, Transco states that it will construct and operate the
following facilities:
Offshore Facilities
Approximately 76.8 miles of 30-inch diameter pipeline
commencing at a proposed offshore platform in Main Pass Area, Block 260
to be constructed by a producer, to Transco's Station No. 82 in Mobile
County, Alabama.
Onshore Facilities
Approximately 17.5 miles of 36-inch diameter pipeline loop
located immediately downstream of Station No. 82 in Mobile County,
Alabama, from Mobile Bay Lateral MP 105.19 to MP 122.68;
A new 30,000 horsepower compressor Station No. 83 located
in Mobile County, Alabama at Mobile Bay Lateral MP 71.57; and
A 26,000 horsepower compression addition at Transco's
existing Station No. 82 in Mobile County, Alabama.
Third Party/Non-Jurisdictional Facilities
A third party will construct, own and operate a 600 MMcf
per day separation plant, including a slug catcher, immediately
upstream of Compressor Station No. 82. The plant will be designed to
remove liquids from the pipeline and deliver pipeline quality natural
gas to the suction side of Compressor Station No. 82. The plant is
estimated to require thirty acres of land and is planned to be located
immediately to the west and adjacent to Compressor Station No. 82.
Transco states that the proposed in-service date for the project is
December 1, 1998. Transco estimates that the proposed facilities will
cost, in the aggregate, $171.5 million.
According to Transco, the project will create firm transportation
capacity of the dekatherm equivalent of 600 MMcf per day from Main Pass
Block 260 to Transco's Station No. 82 and 500 MMcf per day from Station
No. 82 to Station No. 85, where Transco's Mobile Bay Lateral
interconnects with its mainline in Choctaw County, Alabama. Transco
states that it will make the capacity under the project available to
all shippers by means of an ``open season'' planned to be held
commencing November 15, 1996. It is stated that the open season will
extend until December 16, 1996. Concurrent with the open season,
Transco states that it intends to solicit interest in the
relinquishment of firm capacity currently held by shippers on the
Mobile Bay Lateral, in order to assure that the project facilities are
properly sized. Transco states that it will notify the Commission of
the commitments received from customers as soon as practicable after
the end of the open season period, and Transco will seek to enter into
firm transportation precedent agreements which reflect a minimum 15
year term. Transco states that it expects to file these executed
precedent agreements within thirty days of the end of the open season
period. Transco states that the firm transportation service to be
rendered through this new capacity will be performed under its Rate
Schedule FT and Part 284(G) of the Commission's regulations. Transco
states that it will charge the project shippers the then-current Zone
4A rate under Rate Schedule FT in effect when the facilities are placed
in service, plus any applicable surcharges.
Transco avers that the project shippers will have primary firm
transportation rights to all delivery points located in Transco's Rate
Zone 4A, enabling them to access various market points on the
interstate pipeline grid, including markets at the pooling points
located at Transco's Station No. 85 and the existing upstream and
downstream interconnections with other pipelines on Transco's system.
Transco requests that the Commission grant rolled-in rate treatment
for the costs associated with the project in Transco's first Section 4
rate proceeding to become effective after the in-service date of this
project. Transco states that the presumption to roll-in the project
costs applies because the rate impact on its existing customers under
each firm rate schedule is less than five percent, which is the level
set forth in the Commission's Statement of Policy for a presumption of
rolled-in rate treatment on the pricing of new pipeline construction.
Transco also states that the facilities constructed as part of the
project will produce significant system-wide operational and financial
benefits and will be operated on an integrated basis with its existing
facilities.
To meet the proposed in-service date for the project, Transco
requests that the Commission issue a preliminary determination
approving all aspects of the proposal other than environmental matters
by July 1, 1997, with a final determination and all appropriate
certificate authorizations by February 1, 1998.
The Commission staff cannot schedule a completion date for the
environmental analysis of this project, because Transco has not begun
certain critical processes. Transco has not yet filed applications with
the Minerals Management Service (MMS) or the U.S. Army Corps of
Engineers (COE), nor has it requested a determination of consistency
with the Coastal Zone Management Plan (Alabama Department of
Environmental Management (ADEM)). The staff wants to coordinate its
environmental analysis with the MMS, ADEM, and the COE.
Other missing material that will delay the completion of the
environmental analysis include surveys for threatened or endangered
species and consultation with the U.S. Fish and Wildlife Service and
completion of surveys for cultural resources and consultation with the
State Historic Preservation Office. These resources are of particular
interest because they were of concern with respect to the construction
of the original Mobile Bay Lateral.
Concerns over erosion and sedimentation plans must also be resolved
as part of our environmental analysis.
Comment date: December 13, 1996, in accordance with Standard
Paragraph F at the end of this notice.
2. Colorado Interstate Gas Company
[Docket No. CP97-94-000]
Take notice that on November 12, 1996, Colorado Interstate Gas
Company (CIG), P.O. Box 1087, Colorado Springs, Colorado 80944, filed
in Docket No. CP97-94-000 a request pursuant to Sections 157.205 and
157.216 of the Commission's Regulations under the Natural Gas Act (18
CFR 157.205, 157.216) for authorization to lease to Vessels
Hydrocarbons, Inc. (Vessels) almost 2.22 miles of 8-inch diameter pipe
located in Adams County, Colorado, under CIG's blanket certificate
issued in Docket No. CP83-21-000 pursuant to Section 7 of the Natural
Gas
[[Page 64079]]
Act, all as more fully set forth in the request that is on file with
the Commission and open to public inspection.
CIG states it has been advised by Vessels that Vessels plans to
consolidate its processing activities by closing its Third Creek plant
and constructing a line to move raw gas from the tailgate of the Third
Creek plant to its Wattenberg plant which is almost 18.5 miles away.
CIG also states the abandonment by lease to Vessels of CIG's Third
Creek Lateral will prevent the construction of almost 2.22 miles of
pipe and avoid the associated environmental disruption. Vessels has
advised CIG that Shippers using the Wattenberg plant will have access
to CIG's transmission after processing.
CIG further states that the subject facilities were certificated
and operated pursuant to the certificate of public convenience and
necessity issued in Docket No. CP79-284.
Comment date: January 6, 1997, in accordance with Standard
Paragraph G at the end of this notice.
3. Columbia Gas Transmission Corporation
[Docket No. CP97-95-000]
Take notice that on November 13, 1996, Columbia Gas Transmission
Corporation (Columbia), 1700 MacCorkle Avenue, SE., Charleston, West
Virginia 25314-1599, filed in Docket No. CP97-95-000, pursuant to
Section 7(b) of the Natural Gas Act (NGA), as amended, and Section
157.7 and 157.18 of the Commission's Regulations thereunder, an
abbreviated application requesting permission and approval to abandon
certain natural gas compression facilities, all as more fully set forth
in the application on file with the Commission.
Columbia requests NGA Section 7(b) authorization for the
abandonment of seven 500 horsepower horizontal type engine compressor
units, located within the York Compressor Station, located in Medina
County, Ohio.
Columbia states that in addition to the abandonment of the
compressor units for which Columbia is seeking authorization, Columbia
would also remove any associated equipment, appurtenances and buildings
associated with these units.
Columbia further states that the York Compressor Station has been
in service since 1914 to compress local field production gas and relay
transmission volumes into Columbia's Line L. Columbia states that
although authorization to abandon the horizontal units, originally
installed between 1914 and 1928, was received in Docket No. CP80-14-000
(Columbia Gas Transmission Corporation, 11 FERC Paragraph 61,047
(1980); order amending certificate, 11 FERC Paragraph 61,214 (1980)),
an increase in actual over estimated local production in the area
prompted Columbia to retract its abandonment authorization.
Columbia states that in a letter dated January 21, 1982 to the
Commission, Columbia advised that the horizontal units would be
retained in service. It is stated that since that time, the decline in
location production along with other facility upgrades in the York
Production field rendered the horizontal units inactive by 1989.
Columbia now requests approval to proceed with the abandonment granted
by the Commission in 1980. Columbia states that the horizontal units
are no longer needed and have become obsolete and their abandonment
will not result in any termination of service. Therefore, Columbia
submits that the proposed abandonment is required by the present and
future public convenience and necessity.
Columbia states that the cost of retiring the seven horizontal
compressor units is approximately $264,000, with an estimated net debit
to accumulated provision for depreciation of $835,305.
Comment date: December 13, 1996, in accordance with Standard
Paragraph F at the end of this notice.
4. National Fuel Gas Supply Corporation
[Docket No. CP97-101-000]
Take notice that on November 18, 1996, National Fuel Gas Supply
Corporation (National), 10 Lafayette Square, Buffalo, New York 14203,
filed in Docket No. CP97-101-000 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 a
residential sales tap under National's blanket certificate issued in
Docket No. CP83-4-000 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.
Specifically, National proposes to construct and operate a sales
tap for delivery of approximately 150 Mcf annually of gas to National
Fuel Gas Distribution Corporation (Distribution) at an estimated cost
of $1,500, for which National would be reimbursed by Distribution.
Comment date: January 6, 1997, in accordance with Standard
Paragraph G at the end of this notice.
5. ANR Pipeline Company
[Docket No. CP97-103-000]
Take notice that on November 18, 1996, ANR Pipeline Company (ANR),
500 Renaissance Center, Detroit, Michigan 48243-1902, filed in Docket
No. CP97-103-000 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 operate an existing interconnection
constructed under the authorization of Section 311 of the Natural Gas
Policy Act of 1978 and to construct and operate additional facilities
for the delivery of natural gas to Alcan Ingot, a division of Alcan
Aluminum Corporation (Alcan) in Webster County, Kentucky, under ANR's
blanket certificate issued in Docket No. CP82-480-000, 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.
ANR proposes to operate the existing facilities, which consist of a
4-inch tap and associated piping, valves and fittings, and to construct
and operate electronic measurement equipment in order to provide a
transportation service for Alcan pursuant to a firm transportation rate
schedule. It is stated that the existing facilities were installed in
1984 to deliver gas to Alcan on behalf of Orbit Gas Company (Orbit). It
is explained that Orbit deactivated its interconnection with Alcan and
that Alcan purchased the facilities downstream of ANR from Orbit.
It is stated that the facilities would be designed to deliver up to
417 Mcf of natural gas per hour. ANR estimates the cost of the
facilities at $23,100, for which ANR would be fully reimbursed. It is
explained that Alcan has informed ANR that it proposes to use capacity
release transportation on ANR's system. It is stated that the proposal
would have no adverse impact on ANR's peak day deliveries or on annual
entitlements of ANR's existing customers. It is further stated that ANR
has sufficient gas supply to make the deliveries and that the
deliveries can be made without detriment or disadvantage to ANR's
existing customers.
Comment date: January 6, 1997, in accordance with Standard
Paragraph G at the end of this notice.
6. Texas Gas Transmission Corporation
[Docket No. CP97-106-000]
Take notice that on November 19, 1996, Texas Gas Transmission
Corporation (Texas Gas), 3800 Frederica Street, Owensboro, Kentucky
42301, filed in Docket No. CP97-106-000 a
[[Page 64080]]
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 a delivery point for Clarksdale
Public Utilities (Clarksdale), in Coahoma County, Mississippi, under
Texas Gas's blanket certificate issued in Docket No. CP82-407-000
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.
Texas Gas proposes to install, operate, maintain and own a dual,
four-inch meter station with electronic flow measurement equipment and
remote flow control equipment and related facilities on a site to be
provided by Clarksdale. Texas Gas states that the proposed delivery
point will be known as the Clarksdale P.U.C. Meter Station.
Texas Gas states that Clarksdale is requesting up to 16,800 MMBtu
per day of interruptible natural gas transportation service for use at
its Clarksdale facility for electric generation.
Texas Gas states that Clarksdale's natural gas requirements are
presently supplied by Mississippi Valley Gas Company, a local
distribution customer of Texas Gas, and that Clarksdale has requested
that Texas Gas construct a new delivery point in Coahoma County,
Mississippi to enable Clarksdale to receive natural gas transportation
service directly from Texas Gas.
Texas Gas states that Clarksdale will reimburse Texas Gas in full
for the cost of the facilities to be installed by Texas Gas, which cost
is estimated to be $139,670.
Comment date: January 6, 1997, in accordance with Standard
Paragraph G at the end of this notice.
Standard Paragraphs
F. Any person desiring to be heard or make any protest with
reference to said filing should on or before the comment date file with
the Federal Energy Regulatory Commission, 888 First Street, N.E.,
Washington, D.C. 20426, a motion to intervene or a protest in
accordance with the requirements of the Commission's Rules of Practice
and Procedure (18 CFR 385.211 and 385.214) and the Regulations under
the Natural Gas Act (18 CFR 157.10). All protests filed with the
Commission will be considered by it in determining the appropriate
action to be taken but will not serve to make the protestants parties
to the proceeding. Any person wishing to become a party to a proceeding
or to participate as a party in any hearing therein must file a motion
to intervene in accordance with the Commission's Rules.
Take further notice that, pursuant to the authority contained in
and subject to jurisdiction conferred upon the Federal Energy
Regulatory Commission by Sections 7 and 15 of the Natural Gas Act and
the Commission's Rules of Practice and Procedure, a hearing will be
held without further notice before the Commission or its designee on
this filing if no motion to intervene is filed within the time required
herein, if the Commission on its own review of the matter finds that a
grant of the certificate is required by the public convenience and
necessity. If a motion for leave to intervene is timely filed, or if
the Commission on its own motion believes that a formal hearing is
required, further notice of such hearing will be duly given.
Under the procedure herein provided for, unless otherwise advised,
it will be unnecessary for the applicant to appear or be represented at
the hearing.
G. Any person or the Commission's staff may, within 45 days after
the 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
therefore, 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 authorization pursuant to Section 7 of the Natural
Gas Act.
Lois D. Cashell,
Secretary.
[FR Doc. 96-30667 Filed 12-2-96; 8:45 am]
BILLING CODE 6717-01-P
