TEAM 2014 Project
Texas Eastern Transmission, LP
FERC Section 7(b) and 7(c) Application and
Public Exhibits, Except F-1
FERC Docket No. CP13-___-000
Volume I
“PUBLIC”
February 2013
5400 Westheimer Court
Houston, TX 77056-5310
Mailing Address:
P.O. Box 1642
Houston, TX 77251-1642
713.627.5400 main
February 27, 2013
Ms. Kimberly D. Bose, Secretary
Federal Energy Regulatory Commission
888 First Street, N.E.
Washington, D.C. 20426
Re:
Texas Eastern Transmission, LP, Docket No. CP13-___-000
Abbreviated Application for a Certificate of Public Convenience and Necessity and for
Related Authorizations and Order Approving Abandonment
Dear Ms. Bose:
Texas Eastern Transmission, LP (“Texas Eastern”) hereby submits for filing with the
Federal Energy Regulatory Commission (“Commission”) an Abbreviated Application for a
Certificate of Public Convenience and Necessity and for Related Authorizations and Order
Approving Abandonment (“Application”) regarding its proposed Texas Eastern Appalachia to
Market Project 2014 (“TEAM 2014 Project” or “Project”). The TEAM 2014 Project is a
production-driven project designed to provide the pipeline capacity necessary to deliver
production from the emerging Marcellus Shale play to diverse markets in the Northeast,
Midwest, Southeast and Gulf Coast. The Project responds to significant interest from Marcellus
Shale producers who require firm pipeline capacity as their production comes on line. The
Project involves modifications of Texas Eastern’s existing facilities in Pennsylvania, West
Virginia, Ohio, Kentucky, Tennessee, Alabama, and Mississippi.
Included herewith are four volumes. Volume I contains public information and is
comprised of the Application and its public exhibits, except Exhibits F-I and Z-4. Volume II
contains the public version of Exhibit F-I and Exhibit Z-4. Volume III contains privileged and
confidential information and is comprised of Appendix F (landowner and stakeholder lists),
Appendix J (cultural resource survey reports), Exhibit I (confidential market data), and electronic
versions of the hydraulic models supporting Exhibit G. Volume IV contains Critical Energy
Infrastructure Information (“CEII”) and is comprised of Appendix B (plot plans), Exhibits G, GI, G-II, and Exhibit Z-3.
Pursuant to the Commission’s guidelines for eFiling,1 Texas Eastern is hereby eFiling the
Application and will provide two complete copies of the Application to OEP Room 62-46 and
one complete copy to OGC-EP Room 101-66. Volume IV is marked “CONTAINS CRITICAL
ENERGY INFRASTRUCTURE INFORMATION—DO NOT RELEASE”2 and should be
treated as confidential pursuant to Order No. 630, et seq. and is for use by the Commission Staff
1
Federal Energy Regulatory Commission Filing Guide/Qualified Documents List (January 2, 2013).
2
18 C.F.R. §§ 388.112(b), 388.113 (2012).
Ms. Kimberly D. Bose, Secretary
February 27, 2013
Page 2
only and not to be released to the public.3 Volume III is marked “CONTAINS PRIVILEGED
INFORMATION—DO NOT RELEASE.”4 Privileged information should be treated as
confidential and is for use by Commission Staff only and not to be released to the public.
Questions pertaining to confidential information may be submitted to:
Marcy F. Collins
Associate General Counsel
Texas Eastern Transmission, LP
P.O. Box 1642
Houston, Texas 77251-1642
Phone: (713) 627-6137
Fax: (713) 989-3191
Email: mfcollins@spectraenergy.com
The hydraulic models contain both CEII and PRIVILEGED AND CONFIDENTIAL
information. Texas Eastern notes that the Commission’s eFiling system does not include the
ability to designate files as both CEII and privileged and confidential. Accordingly, Texas
Eastern is marking these hydraulic model files as privileged and confidential for eFiling
purposes, but Texas Eastern requests both CEII and privileged and confidential treatment for the
files.
In accordance with Rule 2011(c)(5) of the Commission’s Rules of Practice and
Procedure, 18 C.F.R. § 385.2011(c)(5), I hereby state that I have read the hard copy version of
the filing and am familiar with the contents thereof; that the paper copies contain the same
information as the electronic media; and that all of the statements contained therein are true and
correct, to the best of my knowledge, information and belief.
3
Critical Energy Infrastructure Information, Order No. 630, FERC Stats & Regs Regulations Preambles ¶ 31,140
(2003), 68 Fed. Reg. 9857 (Mar. 3, 2003), order on reh’g, Order No. 630-A, 104 FERC ¶ 61,106 (2003), 68 Fed.
Reg. 46456 (Aug. 6, 2003).
4
18 C.F.R. §§ 380.12, 388.112 (2012).
UNITED STATES OF AMERICA
BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
Texas Eastern Transmission, LP
)
Docket No. CP13-____-000
ABBREVIATED APPLICATION OF
TEXAS EASTERN TRANSMISSION, LP
FOR A CERTIFICATE OF PUBLIC CONVENIENCE AND NECESSITY
AND FOR RELATED AUTHORIZATIONS AND
ORDER APPROVING ABANDONMENT
UNITED STATES OF AMERICA
BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
Texas Eastern Transmission, LP
)
Docket No. CP13-____-000
ABBREVIATED APPLICATION OF
TEXAS EASTERN TRANSMISSION, LP
FOR A CERTIFICATE OF PUBLIC CONVENIENCE AND NECESSITY
AND FOR RELATED AUTHORIZATIONS AND
ORDER APPROVING ABANDONMENT
Pursuant to Sections 7(b) and 7(c) of the Natural Gas Act (“NGA”), as amended,1
and Part 157 of the regulations of the Federal Energy Regulatory Commission
(“Commission”),2 Texas Eastern Transmission, LP (“Texas Eastern”) hereby files this
abbreviated application for a certificate of public convenience and necessity and for
related authorizations and order approving abandonment (“Application”) seeking
Commission authorization to make the necessary facility modifications, as described
herein, and enable Texas Eastern to provide service under the Texas Eastern Appalachia
to Market 2014 Project (“TEAM 2014 Project” or “Project”).
Texas Eastern initiated the pre-filing process for the TEAM 2014 Project in
Docket No. PF12-19-000 and received approval from the Commission to use the prefiling process on July 13, 2012.3 The instant Application incorporates the comments and
information received during the pre-filing process from Commission Staff and relevant
stakeholders.
1
15 U.S.C. §§ 717f(b)-(c) (2012).
2
18 C.F.R. § 157.7 (2012).
3
Texas Eastern Transmission, LP, Approval of Pre-Filing Request, Docket No. PF12-19 (July 13, 2012).
The TEAM 2014 Project is a production-driven project that will provide the
capacity necessary for Texas Eastern to transport an additional 600,000 dekatherms per
day (“Dth/d”) of natural gas from receipt points on the Texas Eastern system in the
Marcellus Shale region in western Pennsylvania and West Virginia to delivery points in
Texas Eastern’s traditional market areas in New Jersey and New York, as well as to
expanding markets in Ohio, Mississippi and Louisiana.
The Project is designed to
provide 300,000 Dth/d of incremental transportation service from western Pennsylvania
to the eastern end of the system in Lambertville, New Jersey and Staten Island, New
York, 50,000 Dth/d of incremental transportation service from western Pennsylvania to
the Lebanon, Ohio hub and 250,000 Dth/d of incremental transportation service from
western Pennsylvania to markets in Texas Eastern’s Zones ELA and WLA in the Access
Area.
The facilities that are proposed as part of the Project are described in detail herein
and involve pipeline looping and aboveground modifications located on various segments
of the Texas Eastern system in Pennsylvania, West Virginia, Ohio, Kentucky, Tennessee,
Alabama, and Mississippi, including approximately 33.6 miles of new 36-inch diameter
pipeline loop and related aboveground facilities, compressor station upgrades and
abandonments resulting in a net increase of 77,100 horsepower (“HP”) of compression,
and certain other facility modifications to accommodate bi-directional flow along Texas
Eastern’s system.
Texas Eastern has executed precedent agreements with two shippers for long-term
firm transportation service for the full 600,000 Dth/d of Project capacity. These two
shippers are major producers in the Marcellus Shale play and require the firm capacity to
be created by the Project to ensure that pipeline capacity exists to transport their
2
production to growing markets as the production comes on line.
Texas Eastern is
proposing to charge initial incremental recourse rates for service on the TEAM 2014
Project facilities under Rate Schedule FT-1. These recourse rates and the support for the
derivation of these rates are set forth in Exhibit P to the Application. The TEAM 2014
Project shippers have agreed to pay negotiated rates in accordance with the terms of the
executed precedent agreements and Section 29 of Texas Eastern’s General Terms and
Conditions (“GT&C”).4
Texas Eastern requests that the Commission grant the authorizations requested
herein on or before November 21, 2013, in order for Texas Eastern to have the time
necessary to complete and place into service the facilities proposed herein by November
1, 2014. Texas Eastern has agreed pursuant to the terms of its Precedent Agreements
with the Project shippers to proceed with due diligence to complete and place the Project
facilities into service by November 1, 2014, which, in turn, will ensure that pipeline
capacity exists to transport the Project shippers’ production to growing markets as that
production comes on line.
In support hereof, Texas Eastern shows as follows:
I.
Identity of Applicant
The exact legal name of Texas Eastern is Texas Eastern Transmission, LP. Texas
Eastern is a limited partnership organized and existing under the laws of the State of
Delaware and has its principal place of business at 5400 Westheimer Court, Houston,
Texas 77056-5310. Texas Eastern is an indirect, wholly owned subsidiary of Spectra
Energy Transmission, LLC.
4
Texas Eastern will file the applicable negotiated rate tariff records for approval within 30 to 60 days prior
to the in-service date of the TEAM 2014 Project.
3
Texas Eastern is a natural gas company as defined in the NGA, engaged in
transmission of natural gas in interstate commerce, subject to the jurisdiction of the
Commission. Texas Eastern’s transmission system extends from Texas, Louisiana and
the Gulf of Mexico, through the states of Mississippi, Arkansas, Missouri, Tennessee,
Illinois, Indiana, Kentucky, Ohio, Pennsylvania and New Jersey, to its principal terminus
in the New York City metropolitan area.
The names, titles and mailing addresses of the persons to whom correspondence
and communications concerning this Application should be addressed are:
*Berk Donaldson
Director, Rates and Certificates
Austin C. Isensee
Analyst, Rates and Certificates
Texas Eastern Transmission, LP
P.O. Box 1642
Houston, Texas 77251-1642
Phone: (713) 627-4488
Fax: (713) 627-5947
Email: bdonaldson@spectraenergy.com
*Marcy F. Collins
Associate General Counsel
Texas Eastern Transmission, LP
P.O. Box 1642
Houston, Texas 77251-1642
Phone: (713) 627-6137
Fax: (713) 989-3191
Email: mfcollins@spectraenergy.com
and
*James D. Seegers
James E. Olson
Sabina D. Walia
Suzanne E. Clevenger
Vinson & Elkins L.L.P.
1001 Fannin, Suite 2500
Houston, Texas 77002
Phone: (713) 758-2939
Fax: (713) 615-5206
Email: jseegers@velaw.com
* Texas Eastern requests that these persons be included on the Commission’s official
service list.
4
II.
Description of Project
A.
Overview of Project
The TEAM 2014 Project is an efficient and cost-effective means for providing
additional capacity to satisfy the need of the Project shippers to have pipeline capacity
available to transport the shippers’ production to growing markets as that production
comes on line. The Project facilities are designed to transport this new production to the
traditional Northeastern market area and to expanding markets in the Midwest, Southeast
and Gulf Coast. The Project will deliver supplies of Marcellus Shale gas from certain
Texas Eastern interconnections in Greene County, Pennsylvania, Fayette County,
Pennsylvania and Marshall County, West Virginia to delivery points along Texas
Eastern’s system at Lambertville, New Jersey and Staten Island, New York, and to
delivery points in other market areas along the system in Lebanon, Ohio, Copiah County,
Mississippi and Acadia Parish, Louisiana. The TEAM 2014 Project will improve the
flexibility and reliability of service on the Texas Eastern system and the overall pipeline
grid. The Project will have no adverse impact on Texas Eastern’s existing customers or
on existing pipelines and their captive customers. As demonstrated by the Resource
Reports accompanying this Application, the construction and operation of the TEAM
2014 Project will not involve any significant environmental or landowner impacts that
cannot be adequately mitigated. For these reasons, the benefits of the Project outweigh
any potential adverse effects.
Texas Eastern has executed precedent agreements with two Project shippers,
Chevron U.S.A., Inc. (“Chevron”) and EQT Energy, LLC (“EQT”) for transportation
service on the Project facilities totaling 600,000 Dth/d, the entire capacity to be created
5
by the Project facilities (“Precedent Agreements”). Chevron and EQT own significant
natural gas production acreage in the Marcellus Shale region, and their respective firm
service commitments are designed to provide the revenue support necessary for Texas
Eastern to construct the firm pipeline capacity that will transport this production to
markets along the Texas Eastern system. In addition to providing access to major natural
gas markets for the Project shippers, the TEAM 2014 Project will also promote increased
commodity price competition and reduce price volatility by introducing new supply
sources from the Appalachian production area, particularly the prolific Marcellus Shale,
to these market areas. The Project also provides supply access to developing markets in
the Gulf Coast Region.
Overall, the Project will improve transportation security,
flexibility, and reliability on the Texas Eastern system.
Pursuant to the Precedent Agreements, Texas Eastern has agreed, subject to
certain conditions, to proceed with due diligence to construct the TEAM 2014 Project
with a targeted in-service date of November 1, 2014, and to provide, collectively,
600,000 Dth/d of firm service to Chevron (300,000 Dth/d) and EQT (300,000 Dth/d)
under firm service agreements with primary terms of 10 years. The Commission views
agreements for long-term firm capacity as important evidence of market demand.5 These
Precedent Agreements are included herewith as Exhibit I and have been submitted as
privileged pursuant to Section 388.112 of the Commission’s regulations.
5
Agreements for long-term firm capacity are important evidence of market demand for a new project.
Certification of New Interstate Natural Gas Pipeline Facilities, 88 FERC ¶ 61,227, at p. 61,744 (1999)
(“Certificate Policy Statement”), order clarifying Statement of Policy, 90 FERC ¶ 61,128 (2000), order
further clarifying Statement of Policy, 92 FERC ¶ 61,094 (2000).
6
B.
Description of Facilities
By this Application, Texas Eastern proposes to construct pipeline looping and
aboveground modifications located on various segments of the Texas Eastern system in
Pennsylvania, West Virginia, Ohio, Kentucky, Tennessee, Alabama, and Mississippi,
including approximately 33.6 miles of new 36-inch diameter pipeline loop and related
aboveground facilities, compressor station upgrades and abandonments resulting in a net
increase of 77,100 HP of compression, and certain other facility modifications to
accommodate bi-directional flow along Texas Eastern’s system.
Specifically, the
proposed pipeline facilities include the following:
(i)
6.7 miles of new 36-inch pipeline loop in Fayette County, Pennsylvania,
downstream of Texas Eastern’s existing Holbrook Compressor Station;
(ii)
8.1 miles total of new 36-inch pipeline loop in two segments (a 2.7-mile
segment and a 5.4-mile segment) in Perry County, Pennsylvania,
downstream of Texas Eastern’s existing Perulack Compressor Station;
(iii)
7.1 miles of new 36-inch pipeline loop in Dauphin County, Pennsylvania,
downstream of Texas Eastern’s existing Shermans Dale Compressor
Station;
(iv)
6.1 miles total of new 36-inch pipeline loop in two segments (a 2.3-mile
segment and a 3.8-mile segment) in Lebanon County, Pennsylvania,
downstream of Texas Eastern’s existing Grantville Compressor Station;
and
(v)
5.6 miles of new 36-inch pipeline loop in Berks County, Pennsylvania,
downstream of Texas Eastern’s existing Bernville Compressor Station in
Berks County, Pennsylvania;
The compressor station modifications include the following:
(i)
uprate of one existing 16,000 HP electric unit to 20,000 HP (by removing
the software restriction currently in place in order to allow the unit to
operate at its full service factor) and uprate of two existing 12,250 HP
units to 13,300 HP each (by exchanging existing engines for new engines
capable of greater horsepower) at Texas Eastern’s existing Uniontown
Compressor Station in Fayette County, Pennsylvania;
7
(ii)
installation of one new 26,000 HP gas turbine compressor unit and one
new 26,000 HP electric motor-driven compressor unit at Texas Eastern’s
existing Delmont Compressor Station in Westmoreland County,
Pennsylvania;
(iii)
abandonment in place of one existing 18,500 HP gas turbine compressor
unit and six 1,100 HP reciprocating gas compressor units for a total
abandonment of 25,100 HP at the Delmont Compressor Station in
Westmoreland County, Pennsylvania;
(iv)
installation of one new 18,100 HP gas turbine compressor unit at Texas
Eastern’s existing Armagh Compressor Station in Indiana County,
Pennsylvania;
(v)
installation of one new 26,000 HP gas turbine compressor unit at Texas
Eastern’s existing Entriken Compressor Station in Huntingdon County,
Pennsylvania; and
(vi)
installation of associated facilities, such as aero assemblies and cooling
equipment, on existing gas compressor units at the Delmont, Uniontown,
Armagh, and Entriken Compressor Stations, as more fully described in
Resource Report 1.
The modifications at the compressor stations described above will result in a net
increase in certificated horsepower at the stations of 77,100 HP. With this net increase in
horsepower, the total certificated horsepower will be: 80,900 HP at the Uniontown
Compressor Station; 73,300 HP at the Delmont Compressor Station; 40,100 HP at the
Armagh Compressor Station; and 48,000 HP at the Entriken Compressor Station.
Texas Eastern proposes to abandon in place the seven compressor units at the
Delmont Compressor Station described above by cutting and capping the aboveground
suction and discharge pipeline.
abandonment.
No ground disturbance will be associated with the
Texas Eastern may, from time to time, use various parts from the
abandoned compressor unit facilities as spare replacement parts for other facilities.
Texas Eastern will achieve the uprate of the existing 16,000 HP electric-powered
compressor unit at the Uniontown Compressor Station by modifying controls and other
8
ancillary facilities on the existing equipment, as described above, and no earth
disturbance will take place as a result of this uprate.
In addition to the facilities above, Texas Eastern is also proposing to install
associated facilities, such as launchers, receivers, and valves to support the pipeline
expansion, as well as minor modifications and maintenance work at 41 existing facility
sites along Texas Eastern’s transmission system between Pennsylvania and Mississippi to
allow for bi-directional flow on Texas Eastern’s system. All of the work associated with
these minor modifications will occur entirely within existing compressor station, launcher
and receiver, or meter and regulating facility sites along Texas Eastern’s existing right of
way, with the exception of one location that will require additional workspace outside of
the previously disturbed pipeline easement.
These facilities and their locations are
described in detail in Resource Report 1.
Texas Eastern requests that the Commission grant the authorizations requested
herein on or before November 21, 2013, in order for Texas Eastern to have the time
necessary to complete and place into service the Project facilities by November 1, 2014.
Texas Eastern has an obligation under the Precedent Agreements to proceed with due
diligence to complete construction of the Project facilities and to place such facilities into
service by November 1, 2014, which, in turn, will ensure that the pipeline capacity
necessary to transport the Marcellus Shale production of Chevron and EQT will be
available for growing markets as that production comes on line. Texas Eastern requests
that the Commission grant any other authorizations and waivers necessary to implement
the proposal contained herein.
9
III.
Evaluation of Application Pursuant to Certificate Policy Statement
The Commission established criteria for determining whether there is a need for a
proposed project and whether the proposed project will serve the public interest in the
Certificate Policy Statement.6 The Certificate Policy Statement explains that, in deciding
whether to authorize the construction of major new pipeline facilities, the Commission
balances the public benefits of the project against the project’s potential adverse
consequences.7 The Commission’s stated goal is to give appropriate consideration to the
enhancement of the competitive transportation alternatives, the possibility of overbuilding, subsidization by existing customers, the applicant’s responsibility for
unsubscribed capacity, the avoidance of unnecessary disruptions of the environment, and
the unneeded exercise of eminent domain in evaluating new pipeline construction.8 Once
the applicant demonstrates that the benefits to be achieved by the project will outweigh
the potential adverse effects, the Commission will find that the project is required by the
public convenience and necessity.9
As demonstrated herein, the facilities proposed
herein meet the criteria of the Certificate Policy Statement, and approval of the Project
will serve the public interest and is required by the public convenience and necessity.
A.
The TEAM 2014 Project Meets the Threshold No-Subsidy Test.
The TEAM 2014 Project satisfies the economic threshold requirement for existing
pipelines because it avoids subsidization by Texas Eastern’s existing customers and does
not adversely impact their rates. Specifically, Texas Eastern is proposing herein initial
6
Id.
7
Tennessee Gas Pipeline Co., 92 FERC ¶ 61,142, pp. 61,519-20 (2000).
8
Id.
9
Certificate Policy Statement at p. 61,746.
10
incremental recourse rates for service on the TEAM 2014 Project facilities. Because
Texas Eastern is proposing herein to recover the costs associated with the TEAM 2014
Project facilities, through incremental rates, the TEAM 2014 Project is financially viable
without any adverse rate effect on, or subsidies from, Texas Eastern’s existing customers.
Accordingly, the TEAM 2014 Project meets the threshold requirement established by the
Commission’s Certificate Policy Statement.10
While Texas Eastern is not seeking
approval at this time to roll-in the costs of the Project, Texas Eastern reserves its right to
do so in the future as part of a general rate case proceeding.
B.
The TEAM 2014 Project Will Have No Adverse Effects on Existing
Customers or on Existing Pipelines and Their Captive Customers.
The next step in the Certificate Policy Statement analysis is to identify potentially
adverse effects of the project on the existing customers of the pipeline proposing the
project, existing pipelines in the market and their captive customers, or landowners and
communities affected by the new construction and to determine whether the applicant has
made efforts to eliminate or minimize those adverse effects.11 If residual adverse effects
on these groups are identified after efforts have been made to minimize them, the
Commission will “evaluate the project by balancing the evidence of public benefits to be
achieved against the residual adverse effects.”12
The TEAM 2014 Project will not be detrimental to Texas Eastern’s existing
customers. The TEAM 2014 Project will result in no degradation of service to existing
customers, and, as explained above, Texas Eastern has proposed incremental rates for the
Project. Additionally, Texas Eastern’s proposal has benefits for existing and potential
10
Id. at p. 61,745.
11
Id.
12
Id.
11
shippers, as well as the Northeast, Midwest, Southeast, and Gulf Coast markets overall.
The additional compression and market reach associated with the Project will benefit
existing customers by increasing the reliability and flexibility of service on the Texas
Eastern system. Furthermore, by transforming the segment of the Texas Eastern system
from the Holbrook, Pennsylvania area to the Access Area in Mississippi and Louisiana
into a bi-directional system, Texas Eastern’s existing shippers and markets south of
Holbrook on the Texas Eastern system will have direct access to the emerging Marcellus
Shale production area for the first time. The bi-directional nature of this segment of the
system will also increase the efficiency of the system and enhance reliability of service
on the system by diversifying supply sources that can be accessed by markets along the
system. This additional access to new and abundant supply sources also will provide the
markets along the system with a better ability to manage price volatility. Accordingly,
the TEAM 2014 Project will not have an adverse effect on existing customers and,
instead, will increase the overall strength, reliability, diversity, and flexibility on the
pipeline grid in market areas along the system.
The TEAM 2014 Project will have no adverse effect on existing pipelines in the
region or their customers. The Project will provide incremental capacity to the Northeast,
Midwest, Southeast and Gulf Coast regions to accommodate new supplies from the
Marcellus Shale play. The Project is not designed to bypass an existing pipeline or to
provide service that is already provided by another pipeline. Therefore, the Project
serves incremental demand and offers new transportation capacity for new production as
that production comes on line and will not have adverse effects on existing pipelines or
their customers. The additional compression associated with the TEAM 2014 Project
will increase the overall reliability of the interstate pipeline grid in the Northeast,
12
Midwest, Southeast and Gulf Coast regions, and the benefits associated with increasing
reliability on the pipeline grid will accrue to customers of all pipelines comprising the
grid. For the foregoing reasons, the TEAM 2014 Project will have no adverse effect on
existing customers or existing pipelines and their customers.
C.
Texas Eastern Has and Continues to Minimize the Potential for Adverse
Impacts on Landowners and Communities Affected by the TEAM 2014
Project.
As demonstrated in the accompanying Resource Reports, Texas Eastern has made
substantial efforts to ensure that the construction of the TEAM 2014 Project will have
limited residual adverse impacts to landowners and the environment. To the extent
practicable, Texas Eastern will construct the facilities utilizing existing rights-of-way and
previously disturbed property, thereby limiting any new disturbances to the environment
during construction. All of the compressor station modifications will be within the fence
line of existing facilities, and the other aboveground modifications to associated facilities
to support the expansion and to allow for bi-directional flow will take place within Texas
Eastern’s existing right-of-way, with the exception of one location that will require
additional workspace as noted in Resource Report 1. Aside from this one location that
will require a new permanent access road within Texas Eastern’s property, no additional
land use impacts will result from operation of these modified facilities. A portion of the
Project consists of Texas Eastern’s replacement of older, less efficient compressor units
with more efficient and, from an emissions standpoint, more environmentally-friendly
units.
Consistent with the Commission’s desire for early input by potential stakeholders
and with the Commission’s endorsement of the use of collaborative procedures in
developing new pipeline projects, since February 2012, Texas Eastern has made
13
significant efforts prior to and throughout the pre-filing process in Docket No. PF12-19,
to inform the public, particularly affected landowners, relevant resource agencies, and
other interested stakeholders about the TEAM 2014 Project.
Texas Eastern will provide timely written notice of this Application and other
required information to landowners that are directly affected by the Application, as well
as to local communities and local, state, and federal governments and agencies involved
in the TEAM 2014 Project in accordance with the Commission’s landowner notification
requirements.13
The TEAM 2014 Project will have limited residual impact on landowners and
communities affected by the Project. Texas Eastern will construct the TEAM 2014
Project utilizing proven construction techniques and mitigation procedures, and the
Project will not result in significant impacts on the environment. The Resource Reports
attached in Exhibit F-1 include a detailed explanation of the limited environmental
impacts associated with the TEAM 2014 Project and the measures that Texas Eastern
intends to take to mitigate any impacts.
D.
The Benefits of the TEAM 2014 Project Outweigh Potential Residual
Adverse Effects.
When determining whether a proposed project is needed and will serve the public
interest, the Commission balances the public benefits to be achieved by the project
against the residual impacts of the proposed project on the relevant interests listed above.
Given Texas Eastern’s mitigation efforts, and the limited residual impacts on the relevant
13
See 18 C.F.R. § 157.6(d)(1)(i) (2012). In accordance with the Commission’s regulations, Texas Eastern
will also publish notice of the Application in relevant daily and/or weekly newspapers of general
circulation. See 18 C.F.R. § 157.6(d)(1)(iii) (2012). In addition, Texas Eastern will place a copy of the
Application in the town or city hall and library of each municipality along the proposed route, thereby
exceeding the Commission’s requirements. See 18 C.F.R. § 157.10(c) (2012).
14
interests listed above, the benefits of the TEAM 2014 Project far outweigh any potential
adverse effects.
The primary purpose of the TEAM 2014 Project is to provide new pipeline
capacity for Marcellus Shale production currently under development to ensure that firm
transportation service is available for the Project shippers to serve growing markets as
their production comes on line.
The Project offers a cost-effective and reliable
transportation outlet for this new production. The ability for Texas Eastern to expand its
system along its existing footprint helps to ensure that Texas Eastern can meet the target
in-service date of November 1, 2014, and at the same time minimizes impacts to the
environment. In addition, the TEAM 2014 Project will benefit system shippers and
markets on the Texas Eastern system by providing additional access to reliable, long-term
production from the emerging Marcellus Shale play to markets along and downstream of
the system. The TEAM 2014 Project will increase diversity of supply, enhance the
ability of markets along the system to better manage price volatility, and provide
additional security and reliability to these markets.
E.
The TEAM 2014 Project Is Required by the Public Convenience and
Necessity.
The TEAM 2014 Project is consistent with the criteria of the Certificate Policy
Statement, and the construction and operation of the facilities proposed herein are in the
public interest and required by the public convenience and necessity. The TEAM 2014
Project will provide numerous benefits to the Project shippers, existing shippers and
markets along the system and natural gas consumers, including:
(i)
providing a long-term, secure firm transportation outlet for the TEAM
2014 Project shippers as the shippers’ Marcellus Shale production comes
on line;
15
(ii)
providing the necessary new capacity to enable new supplies of natural
gas from the Marcellus Shale to reach diverse regions and markets on the
Texas Eastern system;
(iii)
providing existing and new markets with diverse supply that promotes
stability and reliability and better management of price volatility;
(iv)
providing additional operational flexibility and reliability through the
addition of new compression and pipe on Texas Eastern’s system; and
(v)
enhancing flexibility and reliability of service on the pipeline grid
generally by increasing delivery options off the Texas Eastern system.
For the foregoing reasons, Texas Eastern respectfully submits that granting the
authorizations requested herein is required by the public convenience and necessity.
Approval of the TEAM 2014 Project in the timing contemplated herein will benefit the
Northeast, Midwest, Southeast and Gulf Coast regions along the Texas Eastern system by
delivering new long-term sources of natural gas at the earliest possible time to these
market areas.
In summary, the TEAM 2014 Project satisfies the Commission’s Certificate
Policy Statement and is consistent with the Commission’s economic and environmental
goals.
Texas Eastern will construct the Project with minimal landowner and
environmental impacts. As described in detail in this Application and the accompanying
exhibits, the TEAM 2014 Project significantly and substantially benefits the natural gas
transmission grid in the Northeast, Midwest, Southeast and Gulf Coast regions and will
provide the pipeline capacity necessary to transport the Project shippers’ developing
Marcellus Shale production as that new production comes on line. The benefits of this
Project far outweigh the potential residual impacts of the Project, which have been or will
be mitigated through Texas Eastern’s efforts as described in this Application.
Accordingly, the TEAM 2014 Project meets the standards of the Certificate Policy
16
Statement, is in the public interest, and is required by the public convenience and
necessity.
IV.
Open Season/Reverse Open Season
While Texas Eastern believes the information provided in this Application will
show that it has met the tests both factually and legally to build the Project as proposed,
Texas Eastern hereby provides the following summary of the Open Season and Reverse
Open Season process for the TEAM 2014 Project.
A.
Open Season for the TEAM 2014 Project.
Texas Eastern entered into a Precedent Agreement with Chevron in December
2011, and with EQT in January 2012, for transportation service on the Project facilities
totaling 600,000 Dth/d, with a target in-service date of November 1, 2014. In compliance
with Commission policy and precedent, Texas Eastern conducted a binding Open Season
to determine whether additional demand existed for firm service as part of the TEAM
2014 Project. Texas Eastern held the Open Season from January 17, 2012 through
February 17, 2012 requesting bids for up to an overall potential capacity of 1,400,000
Dth/d inclusive of the existing commitments from the Project shippers. The Open Season
Notice described the design of the proposed project to accommodate a primary firm path
for all Project shippers to be split, with 50 percent of the firm path to extend to the East
and 50 percent of the firm path to extend to the West and South from the Appalachian
supply region.14
After the conclusion of the Open Season, Texas Eastern determined to move
forward with a project that was sized to accommodate the two Project shippers, as no
14
A copy of the Open Season Notice is included as part of Exhibit Z-1(a).
17
additional precedent agreements resulted from the Open Season. Texas Eastern then
confirmed the design of the TEAM 2014 Project as an expansion of Texas Eastern’s
Penn-Jersey system,15 taking into consideration the Project shippers’ requested timing
and the fact that no receipt and delivery points had been requested on the Capacity
Restoration Project (“CRP”) system,16 all as more fully described below.
B.
Reverse Open Season for the TEAM 2014 Project.
Promptly following the execution of the Precedent Agreements and the Open
Season, Texas Eastern held a Reverse Open Season in March 2012 to solicit turnback
capacity. In the Reverse Open Season Notice,17 Texas Eastern offered its current firm
shippers the opportunity to release, subject to specified criteria, all or a portion of their
current firm transportation entitlements. The Reverse Open Season Notice made clear
that the capacity that shippers wished to turn back must enable Texas Eastern to reduce
the scope of the proposed incremental facilities, as finally scoped and designed, necessary
to satisfy Texas Eastern’s obligations pursuant to the TEAM 2014 Project, while
maintaining or improving the economics of the Project. Texas Eastern further specified
that the shipper’s turnback capacity must result in available capacity on Texas Eastern’s
facilities from receipt points on the Texas Eastern system to the proposed delivery points
on the Texas Eastern system designated for the Team 2014 Project and must not result in
a release of any capacity unnecessary for the Project.18
15
The Penn-Jersey system extends from the Oakford Storage facilities and Texas Eastern’s Delmont
Compressor Station in western Pennsylvania to Texas Eastern’s Lambertville, New Jersey Compressor
Station.
16
The CRP system extends from Texas Eastern’s Uniontown Compressor Station in western Pennsylvania
to Texas Eastern’s Lambertville, New Jersey Compressor Station.
17
A copy of the Reverse Open Season Notice is included as Exhibit Z-1(b).
18
Texas Eastern’s reverse open season followed the Commission’s policy and precedent regarding reverse
open seasons. See, e.g., PG&E Gas Transmission, 84 FERC ¶ 61,204, at 62,001 (1998) (finding that the
18
In response to the Reverse Open Season Notice, Texas Eastern received requests
from a total of three current Texas Eastern shippers to turn back capacity under a total of
six separate contracts. Texas Eastern has provided a diagram as Exhibit Z-1(c) that
reflects the turnback requests that Texas Eastern received. ConocoPhillips Company
(“ConocoPhillips”) was one of these three shippers and sought to turn back capacity
under two agreements (Nos. 910662-R2 and 910882-R1).19 Both agreements are firm
service agreements that ConocoPhillips executed for service on Texas Eastern’s TEMAX
expansion, on a path that overlays the CRP system. As noted above, however, Texas
Eastern designed the TEAM 2014 Project facilities to consist of an expansion of Texas
Eastern’s Penn-Jersey system and not its CRP system, taking into consideration all of the
shippers’ needs, including the timing required by the shippers (as discussed further
below) and, again, the fact that neither of the Project shippers requested receipt or
delivery points located on the CRP system.
Texas Eastern evaluated each turnback request in conjunction with the other
turnback requests to determine which portions of the paths offered for turnback, in
combination with portions of the paths offered by other shippers for turnback, would
result in the greatest decrease in the scope of Project construction and at the same time
allow Texas Eastern to satisfy its contractual obligations with the TEAM 2014 Project
shippers. No turnback request or combination of requests would have resulted in a
reduction in the scope of the Project for deliveries to the south or west of the western
pipeline did not have to accept turnback of capacity from Kingsgate, British Columbia (at the US-Canada
border) to Malin, Oregon when the expansion only involved a shorter path from Kingsgate to Stanfield,
Oregon); Columbia Gas Transmission Corp. and Texas Eastern Transmission Corp., 79 FERC ¶ 61,160
(1997) (noting that “[a] pipeline should not be required to take back its customers’ unrelated, unwanted
capacity simply because it wants to construct new facilities somewhere else on its system”).
19
ConocoPhillips has disclosed in public filings with the Commission information about ConocoPhillips’
turnback proposal. Accordingly, Texas Eastern identifies ConocoPhillips in this Application but does not
specifically identify the other two shippers that participated in the Reverse Open Season.
19
Pennsylvania receipt points. However, as detailed below, Texas Eastern was able to offer
to accept in one case all of the capacity offered for turnback from one turnback shipper
and portions of the capacity offered for turnback from the two other turnback shippers,
including some of the capacity offered for turnback from ConocoPhillips. Texas Eastern
has provided a diagram as Exhibit Z-1(d) that reflects the Project scope that would have
resulted if all turnback shippers accepted Texas Eastern’s offer to take back their
capacity.
In considering the turnback requests, one turnback shipper offered capacity under
three separate service agreements, including a turnback offer for 50,000 Dth/d that could
satisfy the entire TEAM 2014 Project eastern contract path through to delivery points at
Lambertville and Staten Island. This 50,000 Dth/d turnback offer presented the greatest
volumetric reduction in facilities construction among all turnback requests received.
Therefore, Texas Eastern accepted that entire path for the full quantity.
A second turnback shipper offered 100,000 Dth/d for turnback on a path located
entirely within the TEAM 2014 Project construction path.
Accepting that quantity
provided the second largest reduction in facilities construction for the Project. Therefore,
Texas Eastern accepted that quantity in its entirety.
After accepting the 150,000 Dth/d described above, Texas Eastern allocated the
remaining 150,000 Dth/d (of the 300,000 Dth/d eastern expansion path) among the
remaining requests – one request from ConocoPhillips was for turnback of 395,000 Dth/d
while the other, from another shipper, was for 100,000 Dth/d. The remaining requests
each included primary points of delivery only on Texas Eastern’s CRP system, not on or
to the east of Texas Eastern’s Penn-Jersey system. Therefore, only a portion of the paths
offered for turnback under these remaining requests – from Clarington to Uniontown
20
upstream of the split between the Penn-Jersey system and the CRP system – could result
in any reduction in the scope of facilities construction.
Texas Eastern determined that the turnback offers for these remaining agreements
were similarly situated because the entire path available for turnback from these shippers
was the same and resulted in an equivalent reduction of facilities construction.
Therefore, it was necessary to pro-rate on a volumetric basis Texas Eastern’s proposed
acceptance of the turnback quantity on this path between these two shippers. In doing the
analysis, Texas Eastern capped ConocoPhillips’ 395,000 Dth/d request at 300,000 Dth/d
to make it equivalent to the TEAM 2014 Project quantity in this path. The pro-ration of
the remaining 150,000 Dth/d resulted in ConocoPhillips having the opportunity to
turnback 112,500 Dth/d of its capacity. The result of the credit offered to shippers
turning back capacity based upon the reduction of facilities contemplated to occur with
the requested turnback capacity totaled approximately $11.1 million per year, which is
approximately 13 percent of the annual cost of service for the proposed expansion of the
Penn-Jersey system.
The reverse open season provided shippers with more flexibility than is required
or customary. Pursuant to the Reverse Open Season Notice, each of the three turnback
shippers had five business days – until April 25, 2012 – to consider Texas Eastern’s offer
to accept the turnback capacity. If a shipper did not agree to Texas Eastern’s offer by the
deadline, the offer would expire and the shipper’s turnback request would be null and
void. Two of the three shippers responded prior to the deadline that they had decided to
retain their capacity. Upon inquiry from ConocoPhillips, Texas Eastern clarified that
Reverse Open Season responses would not be finally binding on the shipper. Texas
Eastern also was open to responding to shipper inquiries and requests for clarification.
21
Unlike the other two shippers, ConocoPhillips requested an extension of the
deadline for responding to Texas Eastern’s turnback offer. While Texas Eastern was not
obligated to do so, Texas Eastern agreed as an accommodation to ConocoPhillips to
extend the deadline for all shippers until May 1, 2012. During this extension period, in
response to questions from ConocoPhillips, Texas Eastern provided feedback and
answers to ConocoPhillips’ questions regarding the TEAM 2014 Project and Texas
Eastern’s rationale for selection of the Penn-Jersey system path for the Project, rather
than the CRP system path preferred by ConocoPhillips. Texas Eastern explained to
ConocoPhillips that, with the exception of the Clarington to Uniontown segment that
Texas Eastern had agreed to accept in response to ConocoPhillips’ turnback offer, the
capacity that ConocoPhillips was attempting to turn back was not on Texas Eastern’s
intended construction path for the TEAM 2014 Project. In Texas Eastern’s last piece of
correspondence to ConocoPhillips regarding the Reverse Open Season results, Texas
Eastern informed ConocoPhillips that the revised May 1, 2012 response deadline had
passed and that Texas Eastern would be moving forward with the TEAM 2014 Project
based on the understanding that ConocoPhillips had decided not to turn back the 112,500
Dth/d of capacity from Clarington to Uniontown.
C.
Texas Eastern’s Reverse Open Season Complied with Commission Policy.
Several months following the completion of the Reverse Open Season,
ConocoPhillips filed a complaint against Texas Eastern in Docket No. RP13-128-000 on
October 1, 2012 (“Complaint”). ConocoPhillips claimed that Texas Eastern should have
held a reverse open season for a project other than the project that Texas Eastern has
proposed to construct. ConocoPhillips argued that Texas Eastern’s Reverse Open Season
discriminated against ConocoPhillips because Texas Eastern did not agree to take back
22
the entirety of ConocoPhillips’ firm capacity and construct a project different from the
TEAM 2014 Project. ConocoPhillips argued that Texas Eastern should have accepted
ConocoPhillips’ full turnback offer of 300,000 Dth/d and that then Texas Eastern could
construct another project that would be less costly and have less environmental impacts.
The Commission dismissed the complaint in an order dated October 26, 2012.20
ConocoPhillips filed comments in the TEAM 2014 pre-filing proceeding, Docket No.
PF12-19-000, on November 2, 2012, which continue to argue that Texas Eastern should
construct a project different than the proposed Project (“ConocoPhillips Comments”).
Texas Eastern expects that ConocoPhillips will raise the same arguments in a protest to
the Application.
ConocoPhillips’ arguments about the Project, including the Open
Season and Reverse Open Season, are without merit.
ConocoPhillips’ argument rests on the claim that because the TEAM 2014 Project
involves an expansion of Texas Eastern’s Penn-Jersey system rather than an expansion of
Texas Eastern’s separate CRP system, ConocoPhillips was not able to turn back more of
its capacity during the Reverse Open Season for the TEAM 2014 Project and therefore
the Reverse Open Season discriminated against ConocoPhillips. However, Texas Eastern
considered alternative expansions of the CRP system during the initial project
development stages, but given the impacts to project cost and schedule, as described
further below and in Resource Report 10, the alternatives utilizing Texas Eastern’s CRP
system ceased to be a viable option for this Project early in the development process.
The analysis by Texas Eastern of alternatives involving an expansion of the CRP system
included scenarios with and without a river crossing, as set forth below.
20
ConocoPhillips’ request for rehearing of this order was subsequently denied. ConocoPhillips Co., 141
FERC ¶ 61,071 (2012), reh’g denied, 142 FERC ¶ 61,123 (2013).
23
Texas Eastern’s CRP alternative with river crossing: One alternative utilizing the
CRP system instead of the Penn-Jersey system that Texas Eastern considered would
require significant greenfield construction and a new crossing of the Delaware River.
The flow diagram prepared by Texas Eastern in late 2011 to study this alternative (as
depicted only downstream of the Marietta Compressor Station) is provided as the first
diagram in Exhibit Z-3. Once Texas Eastern finalized the Precedent Agreements with the
anchor shippers in December 2011 and January 2012, respectively, which targeted an inservice date of November 1, 2014, Texas Eastern had to rule out this alternative due to
timing.21 While the estimated cost for this CRP alternative that involved the Delaware
River crossing was nearly the same as the cost of constructing the Penn-Jersey system
expansion, the increased permitting issues and schedule risk involved with the greenfield
construction and the Delaware River crossing associated with a CRP expansion would
not have allowed Texas Eastern to meet the November 1, 2014 in-service date for the
Project.
Texas Eastern’s CRP alternative without river crossing: To avoid the Delaware
River crossing, Texas Eastern also studied an alternative downstream of the Marietta
Compressor Station in late 2011 that would have avoided crossing the Delaware River by
constructing a greenfield cross-over pipeline from the CRP system to the Penn-Jersey
system at a point west of the Delaware River. The flow diagram prepared by Texas
Eastern in late 2011 to study this alternative downstream of the Marietta Compressor
21
In the Open Season Notice, Texas Eastern suggested various delivery points in Zone M3, including a
point off of the Marietta Extension, which is located on the CRP system. While Texas Eastern intended to
expand the Penn-Jersey system as part of the Project, Texas Eastern also could have expanded the CRP
system up to the Marietta Extension without crossing the Delaware River and, therefore, deliveries at or
upstream of the Marietta Extension could have been possible by the November 1, 2014 target in-service
date for the Project. Ultimately, however, no receipt or delivery points on the CRP system were requested
as a result of the Open Season.
24
Station is provided as the second diagram in Exhibit Z-3. The cost estimate for this
alternative that avoided the Delaware River crossing was approximately $95 million
greater than the alternative utilizing the CRP system by crossing the Delaware River.
Due to this significant additional cost, along with the potential scheduling risks related to
the greenfield construction required for this alternative, Texas Eastern ruled out this
alternative as well.
D.
The Commission Should Disregard ConocoPhillips’ GSC Study.
1.
The Commission should not engage in an Ashbacker-style comparison
between Texas Eastern’s Project and ConocoPhillips’ hypothetical
project.
ConocoPhillips included in the pre-filing docket a study prepared by Gas Supply
Consulting, Inc. to support its contentions and its proposed alternative to the Project
(“GSC Study”).22
The GSC Study contains a comparison between ConocoPhillips’
proposed CRP expansion, which does not require crossing the Delaware River, and the
Penn-Jersey expansion that Texas Eastern has proposed herein.
The GSC Study’s
conclusions are incorrect because they are based on faulty assumptions, as explained
further below in Section IV.D.2 and in Resource Report 10. However, there is another
important point regarding the comparison contained in the GSC Study. The study almost
entirely involves a comparison of costs for expansion investment and engineering matters
and analyzes the two separate projects similar to the way potential shippers might review
competing projects in the marketplace or in the way the Commission might have
reviewed competing, mutually exclusive pipeline certificate applications decades ago
under an Ashbacker analysis.23 The Commission has long abandoned Ashbacker-style
22
ConocoPhillips also included the GSC Study in its October 1, 2012 Complaint filing.
23
Ashbacker Radio Corp. v. FCC, 326 U.S. 327 (1945).
25
hearings where these kinds of comparisons of competing projects were analyzed at
length,24 and, in any event, here, Texas Eastern has only proposed the Penn-Jersey
expansion as part of the TEAM 2014 Project, not a CRP expansion. As previously
discussed, Texas Eastern determined that an expansion of the Penn-Jersey system was
preferable from a timing and risk standpoint and more closely-aligned with Texas
Eastern’s business objectives and the needs of the Project shippers.
Texas Eastern
decided to proceed with a proposal for a project that includes an expansion of the PennJersey system and, contrary to ConocoPhillips’ desired outcome, Texas Eastern cannot be
required to build any other project.
ConocoPhillips’ arguments also reflect a fundamental misunderstanding of the
Commission’s reverse open season policy and Commission and court precedent regarding
the discretion that a pipeline company has under the NGA to design and propose projects
that satisfy the pipeline’s business objectives. Texas Eastern was not required to design
the TEAM 2014 Project based upon turnback offers or to accept back from
ConocoPhillips capacity on a project that Texas Eastern had no intention of constructing.
Prior Commission and court decisions have made it clear that pipelines would not be
compelled to build a project different from the one the pipeline has determined to build.25
The Commission has stated that it “does not direct the development of the gas industry’s
24
See ANR Pipeline Co., 78 FERC ¶ 61,326 (1997), order denying reh’g, 85 FERC ¶ 61,056 (1998), aff’d,
ANR Pipeline Co., v. FERC, 205 F.2d 403 (2000) (affirming the Commission’s reliance on market forces
and holding that an Ashbacker comparative hearing was not required).
25
See Panhandle Eastern Pipe Line Co. v. FPC, 204 F.2d 675, 680 (3d Cir. 1953) (“Panhandle v. FPC”)
(“Congress meant to leave the question whether to employ additional capital in the enlargement of its
pipeline facilities to the unfettered judgment of the stockholders and directors of each natural gas company
involved.”); see also Tennessee Gas Pipeline Co. v. Columbia Gulf Transmission Co., 113 FERC ¶ 61,200,
at PP 25-30 (2005); El Paso Natural Gas Co., et al., 104 FERC ¶ 61,045, at P 104 n.104 (2003).
26
infrastructure, neither on a broad regional basis nor in the design of specific projects.”26
Instead, the Commission “respond[s] when an application is presented to [the
Commission], and in each application the parameters of the project are predetermined by
the applicant.”27
Similarly, the Commission has pointed out that “[w]ith limited
exceptions, the Commission has no authority to compel companies to construct gas
facilities,”28 and courts have also made it clear that, except in very limited
circumstances,29 the Commission has no authority under the NGA to order a pipeline
company to construct additional capacity.30
Here, Texas Eastern has proposed facilities to create the additional capacity for
the TEAM 2014 Project by expanding the Penn-Jersey system in concert with the
timeline required by the Project shippers, not the CRP system. As the Commission has
explained, Texas Eastern has the right to determine the project that it will propose to
construct to the Commission. The Commission will not direct the design of the project,
26
Texas Eastern Transmission, LP, et al., 141 FERC ¶ 61,043 at P 25 (2012) (“Texas Eastern”); see also
Millennium Pipeline Company, L.L.C., 141 FERC ¶ 61,198 at PP 43-45 (2012).
27
Texas Eastern, 141 FERC ¶ 61,043 at P 25 (emphasis added).
28
Id. at P 28. The Commission noted that the limited exceptions include its ability, under certain
circumstances, to require open-access transporters to construct interconnections, to direct natural gas
companies to extend facilities to serve a municipality or LDC, and to direct existing pipelines to expand
offshore pipeline capacity. None of these limited exceptions apply here.
29
These circumstances involve limited directives under Section 7(a) of the NGA to extend facilities to
serve a municipality or LDC.
30
See Panhandle v. FPC, 204 F.2d at 680 (“Congress meant to leave the question whether to employ
additional capital in the enlargement of its pipeline facilities to the unfettered judgment of the stockholders
and directors of each natural gas company involved.”); see also Tennessee Gas Pipeline Co. v. Columbia
Gulf Transmission Co., 113 FERC ¶ 61,200, at PP 25-30 (2005); El Paso Natural Gas Co., et al., 104
FERC ¶ 61,045, at P 104 n.104 (2003); In re Panhandle Eastern Pipe Line Co., et al., 15 FPC 46 (1956)
(citing Panhandle v. FPC and stating that “[a]s the court’s language establishes, there is a sphere wherein,
under the [NGA], the judgment of the stockholders and directors of the company has free exercise, and the
investment capital for the purpose of enlarging pipeline facilities comes within that sphere. We can deny
the proposed construction of facilities but except to the limited extent [NGA Section 7(a)] permits, we
cannot require a company to risk its capital in a venture which in the exercise of its officers’ judgment, it
considers unwise to undertake.”).
27
and the Commission does not have the authority to compel Texas Eastern to construct an
expansion of the CRP system or any other different project.
2.
The conclusions in the GSC Study are incorrect.
The Commission should disregard the GSC study because it is predicated on an
expansion path that Texas Eastern ruled out more than one year ago as not viable for the
TEAM 2014 Project. Texas Eastern has explained the shortcomings of the GSC Study in
Resource Report 10 in response to data requests from FERC Staff.
Texas Eastern
provides a summary of its Resource Report 10 analysis here.
In response to Texas Eastern’s concerns regarding scheduling risks for crossing
the Delaware River, the alternative project that the GSC Study attempts to support
involves a greenfield connecting pipeline from a point downstream of Texas Eastern’s
Eagle Compressor Station on the CRP system to a point on the Penn-Jersey system just
west of the Delaware River (“Cross-over Pipeline”) in order to avoid crossing the
Delaware River. Resource Report 10 details the critical engineering flaws associated
with the alternative project, including that the study: (i) incorrectly assumes the PennJersey system has sufficient capacity to flow the entire Project contract quantity from an
interconnection with the Cross-over Pipeline between the CRP system and the PennJersey system across the Delaware River to the delivery points at Lambertville and Staten
Island; (ii) fails to include a greenfield compressor station near the interconnection
between the proposed Cross-over Pipeline and the Penn-Jersey system that is necessary
due to the higher maximum allowable operating pressure on the Penn-Jersey system and
the fact that the operating pressure on the Penn-Jersey system often exceeds the operating
pressure of the Cross-over Pipeline; (iii) miscalculates the additional compression that
would be required at the Eagle Compressor Station; and (iv) depending on the
28
compression required for the alternative project, does not consider that the alternative
project may require a new greenfield compressor station near the Eagle Compressor
Station site.
The flow diagram prepared by Texas Eastern to correct the critical
engineering flaws noted above that occur downstream of the Marietta Compressor Station
is provided as the third diagram in Exhibit Z-3.
The modifications necessary to correct these engineering flaws result in
environmental impacts and permitting issues that make such an alternative incapable of
satisfying the purpose and need of the TEAM 2014 Project, as explained more fully in
Resource Report 10.
In addition, the costs of the alternative project would be
significantly greater than the costs provided in the GSC Study and significantly greater
than the costs associated with expanding the CRP system with a crossing of the Delaware
River. Specifically, the cost associated with the facilities downstream of the Marietta
Compressor Station in the GSC Study alternative, as modified to correct engineering
flaws, would be approximately $125 million greater than the costs associated with the
facilities downstream of the Marietta Compressor Station in Texas Eastern’s alternative
to expand the CRP system with a crossing of the Delaware River. However, as discussed
herein and in Resource Report 10, expanding the CRP system did not meet Texas
Eastern’s business objectives. Thus, for this reason, the reasons stated above and for all
the reasons explained in detail in the Environmental Report, ConocoPhillips’ preferred
CRP system expansion should not be considered and is not a viable alternative for the
Project.
29
E.
The Commission Should Disregard Any Challenge by ConocoPhillips to the
Design of the TEAM 2014 Project.
The Open Season and Reverse Open Season undertaken by Texas Eastern for the
Project complied with Commission policy and precedent and did not result in any
discrimination against ConocoPhillips or any other shipper. Accordingly, the Project is
appropriately designed, and the Commission should disregard arguments to the contrary
by ConocoPhillips. Contrary to ConocoPhillips’ desired outcome, prior Commission and
court decisions are clear that pipelines cannot be compelled to build another project
because the Commission does not direct the design of projects nor does the Commission
have the authority to compel applicants to construct a different project than the one
proposed by the applicant. In addition, ConocoPhillips’ own study is incorrect. For all
these reasons, Texas Eastern respectfully requests that the Commission find that its Open
Season and Reverse Open Season were conducted in compliance with the Commission’s
policy and precedent and deny any requests from ConocoPhillips that Texas Eastern
construct a different project involving an expansion of the CRP system.
V.
Environmental Impact
The Resource Reports included herewith more fully describe the potential
environmental impacts of the TEAM 2014 Project. The information provided in the
Resource Reports has been prepared in accordance with Part 380 of the Commission’s
regulations for the Commission Staff to conduct its environmental analysis of the Project
in this proceeding. In addition, Texas Eastern has included, as Exhibit Z-4 attached
hereto, a draft Environmental Assessment and, as Exhibit Z-5 attached hereto, a matrix
that identifies the specific locations in the Resource Reports where the information
requested by Commission Staff in Docket No. PF12-19 has been incorporated.
30
As the Resource Reports show, the environmental impact associated with the
construction of the TEAM 2014 Project is limited. Texas Eastern has incorporated the
Commission’s Upland Erosion Control, Revegetation and Maintenance Plan and the
Commission’s Wetland and Waterbody Construction and Mitigation Procedures (January
17, 2003 versions of both) into the Erosion and Sediment Control Plan to be used in this
proposal. In addition, Texas Eastern has co-located its pipeline segments with its existing
transmission system and will incorporate standard environmental mitigation measures
into its construction specifications.
The Resource Reports demonstrate that (i) the impact of the proposed TEAM
2014 Project will be minimal, (ii) any adverse impacts can be mitigated or avoided, (iii)
the proposed action is the best alternative, and (iv) the short-term use of the environment
will not conflict with the long-term productivity.
Additionally, Texas Eastern will
accommodate general and site-specific protective measures for any sensitive wildlife
habitat and species identified during the course of the Project.
Under these
circumstances, approval of the proposed facilities described herein will not be a major
federal action significantly affecting the quality of the human environment.
The TEAM 2014 Project will be constructed in accordance with applicable
environmental permits, approvals and regulations.
Texas Eastern is committed to
minimizing the environmental impact of the Project and to reclaiming all disturbed areas
to a consistently high standard, regardless of land ownership. Texas Eastern will work
diligently to ensure that any questions related to the environmental aspects of the TEAM
2014 Project are resolved promptly and completely and that the facilities are constructed
in an efficient and appropriate manner.
In addition, and consistent with the
Commission’s desire for early input by potential stakeholders, Texas Eastern has made
31
significant efforts throughout the pre-filing process in Docket No. PF12-19 to inform the
public, particularly landowners, relevant resource agencies, and other interested
stakeholders, about the TEAM 2014 Project.
The construction activities are not anticipated to have adverse effects on
residences or industrial areas. The construction activities will not have a negative impact
on public, recreational, or scenic areas, and the impact on vegetation, wildlife, and
cultural resources will be minimal. As described in the Resource Reports, Texas Eastern,
to the extent practicable and in most cases, will utilize existing right-of-way to install
new pipeline loop and for the aboveground facility modifications. The abandonment in
place of the compressor units will be achieved by cutting and capping the aboveground
suction and discharge pipeline, without earth disturbance at the compressor station.
VI.
Supply
Texas Eastern’s shippers are responsible for obtaining the gas supplies to be
transported on Texas Eastern’s pipeline system. Texas Eastern proposes to provide only
open-access transportation service for the facilities proposed herein.
VII.
Rates and Tariff
Texas Eastern is proposing to charge initial incremental recourse rates under Rate
Schedule FT-1 for firm service on the TEAM 2014 Project facilities. These rates and the
support for the derivation of these rates are set forth in Exhibit P to this Application. As
reflected on the pro forma tariff records attached hereto as part of Exhibit P, the
incremental recourse reservation rate is $13.798 per month per Dth of capacity
subscribed, with respect to firm service on the TEAM 2014 Project facilities. As shown
32
in Exhibit P, Texas Eastern has utilized its mainline depreciation rate for onshore
facilities of 1.22 percent.
With respect to interruptible service that is available on the TEAM 2014 Project
facilities during those times when all of the reserved firm capacity on the Project facilities
is not being utilized, Texas Eastern does not propose to track interruptible service
separately on existing facilities or the expansion facilities. Accordingly, Texas Eastern
proposes to charge its system interruptible transportation rates for all interruptible
throughput on the TEAM 2014 Project facilities consistent with the rate design approved
by the Commission for various other Texas Eastern incremental projects in the Northeast
market area, including Texas Eastern’s TIME, TIME II, TIME III, TEMAX, and TEAM
2012 Projects.31
Texas Eastern proposes to recover incremental fuel use and lost and unaccounted
for fuel (“LAUF”), as well as incremental electric power costs associated with providing
firm service on the TEAM 2014 Project facilities, through incremental Applicable
Shrinkage Adjustment (“ASA”) percentages and incremental Electric Power Cost
(“EPC”) rates. The incremental fuel and electric power derivation is shown on Exhibit Z2. Consistent with the Commission’s policy and precedent,32 Texas Eastern proposes to
track changes in fuel and electric power costs for these incremental services on an
incremental basis through its ASA mechanism set forth in Section 15.6 of its GT&C and
through its EPC Adjustment mechanism set forth in Section 15.1 of its GT&C. Texas
31
See Texas Eastern Transmission, LP, 137 FERC ¶ 61,140 (2011); Texas Eastern Transmission, LP, 129
FERC ¶ 61,151 (2009); Texas Eastern Transmission, LP, 119 FERC ¶ 61,258 (2007); Texas Eastern
Transmission, LP, 99 FERC ¶ 61,383 (2002), order denying reh’g and granting clarification, 101 FERC ¶
61,046 (2002).
32
Id.
33
Eastern will adjust its periodic tracker mechanisms to ensure that existing customers do
not subsidize the costs resulting from these new incremental services.
Texas Eastern will provide services to the TEAM 2014 Project shippers at
negotiated rates in accordance with the negotiated rate authority set forth in Section 29 of
Texas Eastern’s GT&C and pursuant to the terms of the Precedent Agreement. Texas
Eastern will file tariff records reflecting its negotiated rate agreements with the TEAM
2014 Project shippers within 30 to 60 days prior to when the underlying negotiated rates
are proposed to become effective.
In addition, in light of the north-to-south path subscribed by the TEAM 2014
Project shippers on the Texas Eastern system from Zone M2 to Access Area Zones ELA
and WLA and the modifications proposed herein that are designed to make portions of
the system from Zone M2 to the Access Area bi-directional, Texas Eastern will provide
the TEAM 2014 Project shippers with Order No. 637 rights in Access Area Zones ELA
and WLA. To implement these rights, Texas Eastern will deem that, for purposes of the
TEAM 2014 Rate Schedule FT-1 Agreements, Zones ELA and WLA are Market Area
Zones, as that term is defined in Texas Eastern’s Tariff, for purposes of segmentation
rights under the Tariff. Texas Eastern will make a tariff filing with respect to these rights
prior to placing the TEAM 2014 Project facilities into service.
AFUDC Representation
Texas Eastern hereby provides its statement representing that the Allowance for
Funds Used During Construction (“AFUDC”) accruals included in the cost of the TEAM
2014 Project, reflected in Exhibit K hereto, are in compliance with the Commission’s
34
policy on AFUDC accruals as set forth in the Docket No. AD10-3-000 proceeding.33
Texas Eastern began accruing AFUDC for the TEAM 2014 Project on April 10, 2012,
and in accordance with the Commission’s AFUDC policy, Texas Eastern hereby affirms
that it had begun to incur capital expenditures for the Project on that date and that
activities necessary to prepare the Project for its intended use were in progress at that
time.
VIII.
Other Applications
With the exception of the instant Application, Texas Eastern knows of no other
applications pending or required before the Commission under the NGA for the proposed
TEAM 2014 Project.
Texas Eastern will require other federal, state, and local
authorizations for the facilities proposed herein, in addition to the authorizations
requested in this Application. Texas Eastern is working with a number of federal, state,
and local agencies, as necessary, to obtain permits to complete the construction of the
Project. Texas Eastern has included in Exhibit J a list of all federal approvals and, as part
of Resource Report 1, a list of all required permits and consultations to construct the
facilities proposed in this Application and the agencies in which the application for such
permits or certificates was filed or is expected to be filed.
IX.
Notice
A form of Notice suitable for publication in the Federal Register is attached
hereto.
33
Southern Natural Gas Co., et al., 130 FERC ¶ 61,193 (2010); see also Texas Eastern Transmission, LP,
131 FERC ¶ 61,164 (2010).
35
X.
Exhibits
This is an abbreviated application filed pursuant to Section 157.7 of the
Commission’s regulations under the NGA, pursuant to which Texas Eastern has omitted
the exhibits and data that are inapplicable or are unnecessary to disclose fully the nature
and extent of the proposal herein. A list of the exhibits and documents filed with this
Application, which are incorporated by reference as if set forth fully herein, or which
have been omitted for the reasons set forth below, is as follows:
Exhibit A
Articles of Incorporation
Omitted. Exhibit A has been filed in Docket No. CP06-115-000
and is incorporated herein by reference.
Exhibit B
State Authorization
Omitted. Exhibit B has been filed in Docket No. CP06-115-000
and is incorporated herein by reference.
Exhibit C
Company Officials
Attached.
Exhibit D
Subsidiaries and Affiliates
Attached.
Exhibit E
Other Pending Applications and Filings
Omitted. This information is contained in Section VIII of this
Application.
Exhibit F
Location of Facilities
Attached.
Exhibit F-I
Environmental Report
Attached hereto in Volumes II through IV. Resource Report Nos.
1 through 12 as specified in Sections 380.3 and 380.12 of the
Commission’s regulations are included herewith. Appendices
from Resource Report 1 (landowner information) and Resource
Report 4 (cultural resource assessment) have been segregated and
bound separately in Volume III and are labeled “Contains
Privileged Information—Do Not Release.”
Appendices
containing Critical Energy Infrastructure Information have been
segregated and bound separately in Volume IV and are labeled
36
“Contains Critical Energy Infrastructure Information—Do Not
Release.”
Exhibits G
through G-II
Flow Diagrams and Flow Diagram Data
Attached hereto as part of Volume IV and marked “Contains
Critical Energy Infrastructure Information—Do Not Release.”
The confidential hydraulic models supporting Exhibits G through
G-II are available in electronic form only and are found in
Volume III. Two sets of Exhibit G are included as part of
Volume IV. One set shows the forward-flow component of the
Project, and the other set shows the reverse-flow component of
the Project. With respect to the facilities accommodating the
reverse-flow component of the Project, there have been no
changes with respect to the design of those facilities for
traditional forward flow. The facilities designed to accommodate
the forward-flow component are based on a winter peak day
design, while the facilities designed for the reverse-flow
component are based on a reverse-flow design day. The two
design day scenarios are mutually exclusive.
Exhibit H
Total Gas Supply
Omitted. This information is contained in Section VI of this
Application.
Exhibit I
Market Data
Enclosed herewith under seal as part of Volume III and marked
“Contains Privileged Information—Do Not Release.” This
exhibit includes copies of the Precedent Agreements between
Texas Eastern and the TEAM 2014 Project shippers.
Exhibit J
Federal Authorizations
Attached. This exhibit identifies the following: each federal
authorization that the Project will require; the federal or state
agency or officer that will issue each required authorization; the
date each request for authorization was submitted; why any
request was not submitted and the date submission is expected;
and the date by which final action on each federal authorization
has been requested or is expected.
Exhibit K
Cost of Facilities
Attached.
Exhibit L
Financing
Omitted. Texas Eastern will finance the costs of the TEAM 2014
Project through funds on hand and borrowings under short-term
financing arrangements.
37
Exhibit M
Construction, Operation and Maintenance
Omitted. Texas Eastern will construct or cause the proposed
facilities to be constructed, and will manage and operate the
proposed facilities.
Exhibit N
Revenues, Expenses and Income
Omitted. This information is included in Exhibit P.
Exhibit O
Depreciation and Depletion
Omitted. Texas Eastern will use its existing onshore depreciation
rate of 1.22% for the facilities proposed herein.
Exhibit P
Tariff and Rates
Pro forma tariff records setting forth the proposed initial
incremental recourse rates for the TEAM 2014 Project facilities
are included herewith. In addition, Exhibit P includes the support
schedules for the derivation of such initial recourse rates.
Exhibit T
Related Applications
Three of the six 1,100 HP reciprocating gas compressor units
proposed for abandonment at the Delmont Compressor Station
were certificated in Docket No. G-2341. The additional three
1,100 HP reciprocating gas compressor units proposed for
abandonment at the Delmont Compressor Station were
certificated in Docket No. G-9787. The 18,500 HP gas turbine
compressor unit proposed for abandonment at the Delmont
Compressor Station was certificated in Docket No. CP81-4.
Exhibit U
Contracts and Other Agreements
Omitted. No contracts or other agreements pertain to the
abandonment of the facilities proposed herein.
Exhibit V
Flow Diagram After Abandonment
Omitted. This exhibit is provided as part of Exhibits G through
G-II, which are attached hereto in Volume IV and marked
“Contains Critical Energy Infrastructure Information—Do Not
Release.”
Exhibit W
Impact on Customers
Omitted. No service to customers will be terminated by the
abandonment of facilities proposed herein.
Exhibit X
Effect on Existing Tariffs
Omitted. No effect upon any of Texas Eastern’s rate schedules or
tariffs on file with the Commission will occur from granting the
38
proposed abandonment.
Exhibit Y
Accounting Treatment of Abandonment
Attached.
Exhibit Z
Location of Facilities
Omitted. This information is included as Exhibit F.
Exhibit Z-1
Open Season Notice (Exhibit Z-1(a)), Reverse Open Season
Notice (Exhibit Z-1(b)), and related diagrams referenced in
Section IV.B (Exhibit Z-1(c) and (d)).
Exhibit Z-2
Incremental Fuel and Electric Power Derivation
Exhibit Z-3
Flow diagrams representing the alternatives discussed in Section
IV.C and IV.D.2 and in Resource Report 10, including the
associated costs for each alternative design, are attached hereto as
part of Volume IV and marked “Contains Critical Energy
Infrastructure Information—Do Not Release.”
Exhibit Z-4
Draft Environmental Assessment
Exhibit Z-5
Matrix of information in the Resource Reports reflecting
Commission Staff’s comments in Docket No. PF12-19.
XI.
Other
Texas Eastern requests that the Commission grant this Application in accordance
with the shortened procedures set forth in Rules 801 and 802 of the Commission’s Rules
of Practice and Procedure. Also, if the Commission utilizes the shortened procedures,
Texas Eastern requests that the intermediate decision procedure be omitted and waives
oral hearing and opportunity for filing exceptions.
Exhibits G through G-II and Exhibit Z-3, as well as parts of Exhibit F-I, are found
in Volume IV and contain Critical Energy Infrastructure Information regarding system
pressure and flow. Pursuant to Section 388.112 of the Commission’s regulations, Texas
Eastern hereby requests privileged treatment of these exhibits, which are marked as
“Contains Critical Energy Infrastructure Information—Do Not Release.” In addition,
39
Texas Eastern is marking Volume III as privileged because it contains cultural resource
location information and landowner information from Exhibit F-I, confidential
agreements representing market data from Exhibit I, and confidential hydraulic models
supporting Exhibits G through G-II.34 Texas Eastern requests privileged treatment for
this volume and has marked it “Contains Privileged Information—Do Not Release.”
Texas Eastern has also submitted herewith the Form of Notice of this Application.
XII.
Summary of Authorizations Requested
WHEREFORE, Texas Eastern respectfully requests that for the reasons set forth
herein, the Commission review this Application and issue a final certificate of public
convenience and necessity approving the proposal as described herein without condition
or modification, and approving, authorizing and/or granting Texas Eastern:
(i)
a certificate of public convenience and necessity to construct, install, own,
operate and maintain the facilities, as proposed herein, including an order
to abandon in place certain facilities;
(ii)
authority to charge initial incremental recourse rates for firm service on
the TEAM 2014 Project facilities and existing system recourse rates for
interruptible service on such facilities; and
(iii)
any waivers, authority, and further relief as may be necessary to
implement the proposal contained herein.
34
The hydraulic models supporting Exhibits G through G-II are available only in electronic form in WFP
format. These hydraulic model files should be treated as both Critical Energy Infrastructure Information
(“CEII”) and privileged and confidential pursuant to Section 388.112 of the Commission’s regulations
because the files contain proprietary modeling information. 18 C.F.R. § 388.112 (2012). Accordingly,
Texas Eastern is hereby providing the hydraulic models designated as both CEII and privileged and
confidential. Texas Eastern notes that the Commission’s eFiling system does not include the ability to
designate files as both CEII and privileged and confidential. Accordingly, Texas Eastern is marking these
hydraulic model files as privileged and confidential for eFiling purposes, but Texas Eastern requests both
CEII and privileged and confidential treatment for the files.
40
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Verification
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit C
Company Officials
Texas Eastern Transmission, LP
Uses Officers of its General Partner
Spectra Energy Transmission Services, LLC
EXHIBIT C
Spectra Energy Transmission Services, LLC
As General Partner to Texas Eastern Transmission, LP
Board of Managers:
Theopolis Holeman
J. Patrick Reddy
William T. Yardley
Officers:
William T. Yardley, President
Brian R. McKerlie, Vice President, Business Development, Northeast
Transmission
John V. Adams, Vice President, Supply Chain
Gregory P. Bilinski, Vice President, Transmission Services
Guy G. Buckley, Vice President and Treasurer
Frederick S. (Steve) Bush, Vice President and Controller
Allen C. Capps, Vice President
Stephen W. Craft, Vice President
J. Andrew Drake, Vice President, Asset Integrity
Tina V. Faraca, Vice President, Engineering and Construction
Richard J. Kruse, Jr., Vice President, Regulatory and FERC Compliance Officer
John Thomas McCraw, Vice President
Allison McHenry, Assistant Secretary
James M. Pruett, Vice President
Patricia M. Rice, Vice President and Secretary
David A. Shammo, Vice President
W. L. Whaley, Jr., Vice President, Gas Control
Paul K. Haralson, Assistant Treasurer
Thomas V. Wooden, Vice President, Field Operations
Fulkra J. Mason, Vice President, Environmental, Health and Safety
John Bremner, Vice President, US Storage & Southeast Business Development
Gregg E. McBride, Vice President, Rates & Certificates
Richard Paglia, Vice President, Marketing
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit D
Subsidiaries and Affiliates
Texas Eastern Transmission, LP
Exhibit D
Subsidiaries and Affiliates
Texas Eastern Transmission, LP is owned by:
Spectra Energy Transmission Resources, LLC
Spectra Energy Transmission Services, LLC
99.00 %
1.00 %, General Partner
Texas Eastern Transmission, LP owns:
Texas Eastern Communications, Inc.
Texas Eastern Terminal Company
Spectra Energy Southeast Services, LLC
100.00 %
100.00 %
100.00 %
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit F
Location of Facilities
Texas Eastern Transmission, LP
TEAM 2014 Project 7(b) and 7(c) Application ‐ Exhibit F ‐ Location of Facilities
Richmond County, NY
Hunterdon County, NJ
Bi‐directional flow modifications
Delivery point
Multiple Receipts in:
Greene/Fayette Counties, PA &
Greene/Fayette Counties PA &
Marshall County, WV
Receipt point
Existing TETLP system
Existing TETLP system
Existing station HP upgrades / additions
New loop installation
Warren County, OH
Copiah County, MS
Acadia Parish, LA
Existing station
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit F-I
Environmental Report
Enclosed under separate cover
in Volumes II - IV
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibits G through G-II
Flow Diagram Data
Enclosed under separate cover
in Volume IV,
with confidential information removed to Volume III.
This information has been marked
Contains Critical Energy Infrastructure Information—Do Not Release
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit I
Market Data
Enclosed herewith under seal in Volume III and marked
“Contains Privileged Information—Do Not Release”
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit J
Federal Authorizations
FEDERAL AUTHORIZATIONS
AGENCY
PERMIT/APPROVAL
SUBMISSION STATUS
ANTICIPATED DATE OF
RECEIPT
FEDERAL
FEDERAL ENERGY
REGULATORY COMMISSION
SECTION 7(C) CERTIFICATE OF
PUBLIC CONVENIENCE AND
NECESSITY
SUBMITTED FEBRUARY
2013
11/21/13
U.S. ARMY CORPS OF
ENGINEERS - PITTSBURGH
DISTRICT
CLEAN WATER ACT, SECTION 404
PERMIT
ANTICIPATED SUBMITTAL
IN MARCH 2013
12/1/13
U.S. ARMY CORPS OF
ENGINEERS - BALTIMORE
DISTRICT
CLEAN WATER ACT, SECTION 404
PERMIT
ANTICIPATED SUBMITTAL
IN MARCH 2013
12/1/13
U.S. ARMY CORPS OF
ENGINEERS - PHILADELPHIA
DISTRICT
CLEAN WATER ACT, SECTION 404
PERMIT
ANTICIPATED SUBMITTAL
IN MARCH 2013
12/1/13
U.S. ARMY CORPS OF
ENGINEERS - VICKSBURG
DISTRICT
CLEAN WATER ACT, SECTION 404
PERMIT
ANTICIPATED SUBMITTAL
IN MARCH 2013
12/1/13
U.S. FISH AND WILDLIFE
SERVICE (PENNSYLVANIA
FIELD OFFICE)
ENDANGERED SPECIES ACT,
SECTION 7 CONSULTATION
INITIAL CONSULTATION
LETTER SUBMITTED
MARCH 30, 2012;
CONSULTATION
ONGOING
8/31/2013
U.S. FISH AND WILDLIFE
SERVICE (MISSISSIPPI FIELD
OFFICE)
ENDANGERED SPECIES ACT,
SECTION 7 CONSULTATION
INITIAL CONSULTATION
LETTER SUBMITTED
SEPTEMBER 28, 2012;
CONSULTATION
ONGOING
5/1/2013
U.S. DEPARTMENT OF
COMMERCE
NATIONAL OCEANIC AND
ATMOSPHERIC
ADMINISTRATION
NATIONAL MARINE FISHERIES
SERVICE (NMFS)
ENDANGERED SPECIES ACT,
SECTION 7 CONSULTATION
INITIAL CONSULTATION
LETTER SUBMITTED
MARCH 30, 2012
RECEIVED 4/12/12
PENNSYLVANIA STATE
HISTORIC PRESERVATION
OFFICE
NATIONAL HISTORIC
PRESERVATION ACT, SECTION 106
CONSULTATION
INITIAL CONSULTATION
LETTER SUBMITTED
APRIL 10, 2012;
TECHNICAL REPORT TO BE
SUBMITTED IN FEBRUARY
2013
11/1/13
MISSISSIPPI STATE HISTORIC
PRESERVATION OFFICE
NATIONAL HISTORIC
PRESERVATION ACT, SECTION 106
CONSULTATION
INITIAL CONSULTATION
SUBMITTED JANUARY 16,
2013; TECHNICAL REPORT
TO BE SUBMITTED IN
FEBRUARY 2013
5/1/13
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit K
Cost of Facilities
EXHIBIT K
1 OF 42
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
TEXAS EASTERN TRANSMISSION LP
TEAM 2014
2014
COST BASIS OF FACILITY ESTIMATES
The costs contained in this Exhibit K comprise a detailed estimate of the construction expenditures for the facilities proposed
in this filing.
The cost estimates for all facilities are based on current dollars.
Prices of major equipment items are based on direct contact with selected manufacturers, while minor prices are from recent
experience and manufactures' catalogue information.
Each facility estimate includes contingency reflecting the possible extent that actual costs may exceed the direct estimated
values due to unanticipated elements of cost and changes in design.
Escalation is a calculation of all costs except Engineering, Labor, A&G and AFUDC.
EXHIBIT K
2 OF 42
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
TEAM 2014
2014
DESCRIPTION
TOTAL
Compression
$263,804,789
Pipeline
$212,005,565
M&R
$4,904,216
AFUDC
$27,265,937
SUB TOTAL
Escalation
PROJECT TOTAL
$507,980,507
$11,756,131
$519,736,638
EXHIBIT K
3 OF 42
SUMMARY COST OF FACILITIES
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
ITEM
TEXAS EASTERN TRANSMISSION LP
TEAM 2014
2014
DESCRIPTION
COMPRESSION
PIPELINE
M&R
TOTAL
132
RIGHT OF WAY
$136,000
$10,640,729
$0
$10,776,729
133
RIGHT OF WAY DAMAGES
$110,000
$1,880,641
$0
$1,990,641
134
SURVEYS
$1,628,424
$6,679,923
$0
$8,308,347
135
MATERIALS
$116,555,130
$30,009,501
$1,301,251
$147,865,882
136
LABOR
$65,345,589
$103,012,385
$1,937,002
$170,294,976
137
ENGINEERING & INSPECTION
$29,098,651
$15,070,351
$283,460
$44,452,462
144
OVERHEAD
$24,557,351
$18,323,097
$772,768
$43,653,216
145
AFUDC
$14,896,040
$12,087,860
$282,037
$27,265,937
146
CONTINGENCY
$22,783,198
$22,833,588
$609,735
$46,226,521
147
LEGAL FEES
$225,000
$952,094
$0
$1,177,094
148
OTHER SERVICES
$3,365,446
$2,603,256
$0
$5,968,702
$278,700,829
$224,093,425
$5,186,253
$507,980,507
$5,584,166
$5,989,874
$182,091
$11,756,131
$284,284,995
$230,083,299
$5,368,344
$519,736,638
SUB TOTAL
Escalation
TOTAL PROJECT
EXHIBIT K
4 OF 42
SUMMARY COST OF FACILITIES
NAME;
DOCKET NO.:
PROJECT:
PROJECT YEAR:
TEXAS EASTERN TRANSMISSION LP
TEAM 2014
2014
DESCRIPTION
TOTAL
Compression Facilities
Pipeline Facilities
Meter Station Facilities
$284,284,995
$230,083,299
$5,368,344
PROJECT TOTAL
$519,736,638
EXHIBIT K
5 OF 42
SUMMARY COST OF FACILITIES
NAME;
DOCKET NO.:
PROJECT:
PROJECT YEAR:
DESCRIPTION
TEXAS EASTERN TRANSMISSION LP
TEAM 2014
2014
TOTAL
Holbrook Discharge Pipeline
Bernville Discharge Pipeline
Grantville Discharge Pipeline
Perulack Discharge Pipeline
Shermansdale Discharge Pipeline
Launcher/Receiver Modifications - KY
Launcher/Receiver Modifications - MS
Launcher/Receiver Modifications - OH
Launcher/Receiver Modifications - WV
Launcher/Receiver Modifications - PA
Launcher/Receiver Modifications - TN
Launcher/Receiver Modifications - AL
Armagh Compressor Sta. HP Addition
Delmont Compressor Sta. HP Addition
Delmont Compressor Sta. Retirement
Entriken Compressor Sta. HP Addition
Uniontown Compressor Sta. Upgrade
Wheelersburg Compressor Sta. Upgrade
Athens Compressor Sta. Upgrade
Barton Compressor Sta. Upgrade
Berne Compressor Sta. Upgrade
Clinton Compressor Sta. Upgrade
Danville Compressor Sta. Upgrade
Egypt Compressor Sta. Upgrade
Five Points Compressor Sta. Upgrade
Gladeville Compressor Sta. Upgrade
Holbrook Compressor Sta. Upgrade
Kosciusko Compressor Sta. Upgrade
Mt. Pleasant Compressor Sta. Upgrade
Owingsville Compressor Sta. Upgrade
Somerset Compressor Sta. Upgrade
Summerfield Compressor Sta. Upgrade
Tomkinsville Compressor Sta. Upgrade
Chromatograph Installation - KY
Chromatograph Installation - OH
Chromatograph Installation - TN
Chromatograph Installation - MS
$42,650,756
$44,546,418
$44,788,969
$49,072,066
$43,547,619
$1,076,030
$1,740,434
$973,914
$181,632
$436,916
$894,548
$173,997
$56,994,115
$100,942,093
$1,052,897
$62,705,694
$19,064,806
$4,819,434
$924,990
$1,892,661
$6,161,942
$944,156
$3,267,711
$2,579,437
$889,750
$846,681
$1,021,964
$13,192,087
$1,566,931
$846,681
$842,236
$2,882,048
$846,681
$1,493,139
$959,273
$2,169,364
$746,568
PROJECT TOTAL
$519,736,638
EXHIBIT K
6 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Holbrook Discharge Pipeline
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
133
RIGHT OF WAY DAMAGES
134
SURVEYS
$1,253,458
135
MATERIALS
$5,816,022
136
LABOR
137
ENGINEERING & INSPECTION
$3,056,237
144
OVERHEAD
$3,356,470
145
AFUDC
$2,240,737
146
CONTINGENCY
$4,217,770
147
LEGAL FEES
$172,623
148
OTHER SERVICES
$476,856
$1,962,236
$280,077
$18,716,125
SUBTOTAL
Escalation
PROJECT TOTAL
$41,548,611
3.05%
$1,102,145
$42,650,756
EXHIBIT K
7 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Bernville Discharge Pipeline
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
133
RIGHT OF WAY DAMAGES
134
SURVEYS
$1,207,803
135
MATERIALS
$5,799,872
136
LABOR
137
ENGINEERING & INSPECTION
$2,555,011
144
OVERHEAD
$3,458,677
145
AFUDC
$2,340,329
146
CONTINGENCY
$4,405,233
147
LEGAL FEES
$231,268
148
OTHER SERVICES
$475,010
$2,442,443
$727,255
$19,752,386
SUBTOTAL
Escalation
PROJECT TOTAL
$43,395,287
3.05%
$1,151,131
$44,546,418
EXHIBIT K
8 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Grantville Discharge Pipeline
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
133
RIGHT OF WAY DAMAGES
134
SURVEYS
$1,304,306
135
MATERIALS
$5,947,902
136
LABOR
137
ENGINEERING & INSPECTION
$2,269,911
144
OVERHEAD
$3,508,947
145
AFUDC
$2,353,072
146
CONTINGENCY
$4,429,219
147
LEGAL FEES
$187,019
148
OTHER SERVICES
$660,286
$2,027,376
$347,182
$20,596,350
SUBTOTAL
Escalation
PROJECT TOTAL
$43,631,570
3.05%
$1,157,399
$44,788,969
EXHIBIT K
9 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Perulack Discharge Pipeline
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
133
RIGHT OF WAY DAMAGES
134
SURVEYS
$1,459,706
135
MATERIALS
$6,465,914
136
LABOR
137
ENGINEERING & INSPECTION
$3,375,658
144
OVERHEAD
$3,855,132
145
AFUDC
$2,578,092
146
CONTINGENCY
$4,852,778
147
LEGAL FEES
$191,517
148
OTHER SERVICES
$488,222
$2,242,483
$272,218
$22,022,266
SUBTOTAL
Escalation
PROJECT TOTAL
$47,803,986
3.05%
$1,268,080
$49,072,066
EXHIBIT K
10 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Shermansdale Discharge Pipeline
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
133
RIGHT OF WAY DAMAGES
134
SURVEYS
$1,255,890
135
MATERIALS
$5,677,095
136
LABOR
137
ENGINEERING & INSPECTION
$2,860,838
144
OVERHEAD
$3,431,582
145
AFUDC
$2,287,855
146
CONTINGENCY
$4,306,461
147
LEGAL FEES
$169,667
148
OTHER SERVICES
$502,882
$1,966,191
$253,909
$19,709,928
SUBTOTAL
Escalation
PROJECT TOTAL
$42,422,298
3.05%
$1,125,321
$43,547,619
EXHIBIT K
11 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Launcher/Receiver Modifications - KY
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$42,900
135
MATERIALS
$62,596
136
LABOR
$473,936
137
ENGINEERING & INSPECTION
$131,660
144
OVERHEAD
$149,692
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$56,532
$122,215
SUBTOTAL
Escalation
PROJECT TOTAL
$1,039,531
4.04%
$36,499
$1,076,030
EXHIBIT K
12 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Launcher/Receiver Modifications - MS
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$61,480
135
MATERIALS
$82,174
136
LABOR
$589,585
137
ENGINEERING & INSPECTION
$451,839
144
OVERHEAD
$207,205
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$91,438
$197,677
SUBTOTAL
Escalation
PROJECT TOTAL
$1,681,398
4.04%
$59,036
$1,740,434
EXHIBIT K
13 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Launcher/Receiver Modifications - OH
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$34,320
135
MATERIALS
$53,354
136
LABOR
$421,019
137
ENGINEERING & INSPECTION
$144,985
144
OVERHEAD
$125,415
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$51,170
$110,615
SUBTOTAL
Escalation
PROJECT TOTAL
$940,878
4.04%
$33,036
$973,914
EXHIBIT K
14 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Launcher/Receiver Modifications - WV
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$8,580
135
MATERIALS
$9,607
136
LABOR
$76,674
137
ENGINEERING & INSPECTION
$26,280
144
OVERHEAD
$24,158
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$9,542
$20,630
SUBTOTAL
Escalation
PROJECT TOTAL
$175,471
4.04%
$6,161
$181,632
EXHIBIT K
15 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Launcher/Receiver Modifications - PA
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$17,160
135
MATERIALS
$26,679
136
LABOR
137
ENGINEERING & INSPECTION
$52,692
144
OVERHEAD
$60,824
145
AFUDC
$22,954
146
CONTINGENCY
$49,625
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$192,162
SUBTOTAL
Escalation
PROJECT TOTAL
$422,096
4.04%
$14,820
$436,916
EXHIBIT K
16 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Launcher/Receiver Modifications - TN
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$34,320
135
MATERIALS
$51,214
136
LABOR
$384,325
137
ENGINEERING & INSPECTION
$125,144
144
OVERHEAD
$120,601
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$46,998
$101,602
SUBTOTAL
Escalation
PROJECT TOTAL
$864,204
4.04%
$30,344
$894,548
EXHIBIT K
17 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Launcher/Receiver Modifications - AL
ITEM
DESCRIPTION
PIPELINE
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$0
135
MATERIALS
$17,072
136
LABOR
$77,629
137
ENGINEERING & INSPECTION
$20,096
144
OVERHEAD
$24,394
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$9,141
$19,763
SUBTOTAL
Escalation
PROJECT TOTAL
$168,095
4.04%
$5,902
$173,997
EXHIBIT K
18 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Armagh Compressor Sta. HP Addition
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$22,000
133
RIGHT OF WAY DAMAGES
$25,000
134
SURVEYS
135
MATERIALS
$23,740,030
136
LABOR
$14,900,726
137
ENGINEERING & INSPECTION
$4,847,773
144
OVERHEAD
$4,695,501
145
AFUDC
$2,994,292
146
CONTINGENCY
$4,125,111
147
LEGAL FEES
148
OTHER SERVICES
$277,250
$75,000
$282,055
SUBTOTAL
Escalation
PROJECT TOTAL
$55,984,738
2.07%
$1,009,377
$56,994,115
EXHIBIT K
19 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Delmont Compressor Sta. HP Addition
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$22,000
133
RIGHT OF WAY DAMAGES
$25,000
134
SURVEYS
135
MATERIALS
$45,509,999
136
LABOR
$21,144,291
137
ENGINEERING & INSPECTION
$10,172,323
144
OVERHEAD
$8,521,920
145
AFUDC
$5,358,496
146
CONTINGENCY
$6,725,166
147
LEGAL FEES
148
OTHER SERVICES
$229,250
$75,000
$1,334,555
SUBTOTAL
Escalation
PROJECT TOTAL
$99,118,000
2.09%
$1,824,093
$100,942,093
EXHIBIT K
20 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Delmont Compressor Sta. Retirement
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$0
135
MATERIALS
$0
136
LABOR
137
ENGINEERING & INSPECTION
144
OVERHEAD
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
148
OTHER SERVICES
$452,961
$491,710
$0
$85,658
$0
$1,751
SUBTOTAL
Escalation
PROJECT TOTAL
$0
$1,032,080
2.09%
$20,817
$1,052,897
EXHIBIT K
21 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Entriken Compressor Sta. HP Addition
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$22,000
133
RIGHT OF WAY DAMAGES
$25,000
134
SURVEYS
135
MATERIALS
$28,320,797
136
LABOR
$15,104,379
137
ENGINEERING & INSPECTION
$4,495,125
144
OVERHEAD
$5,094,632
145
AFUDC
$3,294,360
146
CONTINGENCY
$4,538,504
147
LEGAL FEES
148
OTHER SERVICES
$292,250
$75,000
$333,117
SUBTOTAL
Escalation
PROJECT TOTAL
$61,595,164
2.07%
$1,110,530
$62,705,694
EXHIBIT K
22 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Uniontown Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$22,000
133
RIGHT OF WAY DAMAGES
$25,000
134
SURVEYS
135
MATERIALS
136
LABOR
$2,940,480
137
ENGINEERING & INSPECTION
$1,189,138
144
OVERHEAD
$1,500,871
145
AFUDC
$1,001,605
146
CONTINGENCY
$1,379,870
147
LEGAL FEES
148
OTHER SERVICES
$199,250
$10,448,951
$0
$20,000
SUBTOTAL
Escalation
PROJECT TOTAL
$18,727,165
2.07%
$337,641
$19,064,806
EXHIBIT K
23 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Wheelersburg Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
135
MATERIALS
136
LABOR
137
ENGINEERING & INSPECTION
$948,513
144
OVERHEAD
$473,471
145
AFUDC
$253,198
146
CONTINGENCY
$693,995
147
LEGAL FEES
148
OTHER SERVICES
$42,000
$762,751
$1,429,505
$0
$52,527
SUBTOTAL
Escalation
PROJECT TOTAL
$4,655,960
4.04%
$163,474
$4,819,434
EXHIBIT K
24 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Athens Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$15,000
135
MATERIALS
$40,020
136
LABOR
$205,957
137
ENGINEERING & INSPECTION
$345,837
144
OVERHEAD
$105,007
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$48,596
$133,198
SUBTOTAL
Escalation
PROJECT TOTAL
$893,615
4.04%
$31,375
$924,990
EXHIBIT K
25 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Barton Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$30,000
135
MATERIALS
$53,606
136
LABOR
$439,612
137
ENGINEERING & INSPECTION
$491,656
144
OVERHEAD
$237,543
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
148
OTHER SERVICES
$99,435
$272,542
$0
$204,069
SUBTOTAL
Escalation
PROJECT TOTAL
$1,828,463
4.04%
$64,198
$1,892,661
EXHIBIT K
26 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Berne Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
135
MATERIALS
$1,222,174
136
LABOR
$1,626,046
137
ENGINEERING & INSPECTION
$1,064,990
144
OVERHEAD
$671,430
145
AFUDC
$323,729
146
CONTINGENCY
$733,087
147
LEGAL FEES
148
OTHER SERVICES
$112,131
$0
$291,084
SUBTOTAL
Escalation
PROJECT TOTAL
$6,044,671
4.04%
$117,271
$6,161,942
EXHIBIT K
27 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Clinton Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$15,000
135
MATERIALS
$40,020
136
LABOR
$249,041
137
ENGINEERING & INSPECTION
$316,137
144
OVERHEAD
$106,372
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$49,603
$135,958
SUBTOTAL
Escalation
PROJECT TOTAL
$912,131
4.04%
$32,025
$944,156
EXHIBIT K
28 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Danville Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
135
MATERIALS
$813,777
136
LABOR
$923,182
137
ENGINEERING & INSPECTION
$473,877
144
OVERHEAD
$285,712
145
AFUDC
$171,675
146
CONTINGENCY
$470,548
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$18,100
SUBTOTAL
Escalation
PROJECT TOTAL
$3,156,871
4.04%
$110,840
$3,267,711
EXHIBIT K
29 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Egypt Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
135
MATERIALS
$429,518
136
LABOR
$830,556
137
ENGINEERING & INSPECTION
$424,174
144
OVERHEAD
$233,040
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
148
OTHER SERVICES
$22,000
$96,113
$263,438
$0
$218,544
SUBTOTAL
Escalation
PROJECT TOTAL
$2,517,383
4.04%
$62,054
$2,579,437
EXHIBIT K
30 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Five Points Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$92,531
135
MATERIALS
$55,070
136
LABOR
$147,664
137
ENGINEERING & INSPECTION
$325,251
144
OVERHEAD
$76,637
145
AFUDC
$46,744
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$130,614
SUBTOTAL
Escalation
PROJECT TOTAL
$874,511
4.04%
$15,239
$889,750
EXHIBIT K
31 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Gladeville Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
135
MATERIALS
136
LABOR
$249,040
137
ENGINEERING & INSPECTION
$258,068
144
OVERHEAD
$99,430
145
AFUDC
$44,483
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$5,000
$40,020
$121,921
SUBTOTAL
Escalation
PROJECT TOTAL
$817,962
4.04%
$28,719
$846,681
EXHIBIT K
32 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Holbrook Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$15,000
135
MATERIALS
$40,020
136
LABOR
$249,040
137
ENGINEERING & INSPECTION
$370,474
144
OVERHEAD
$111,912
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$53,691
$147,162
SUBTOTAL
Escalation
PROJECT TOTAL
$987,299
4.04%
$34,665
$1,021,964
EXHIBIT K
33 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Kosciusko Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$48,000
133
RIGHT OF WAY DAMAGES
$10,000
134
SURVEYS
$64,000
135
MATERIALS
$4,134,069
136
LABOR
$2,991,954
137
ENGINEERING & INSPECTION
$1,359,001
144
OVERHEAD
$1,132,288
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
148
OTHER SERVICES
$693,071
$1,899,654
$0
$412,579
SUBTOTAL
Escalation
PROJECT TOTAL
$12,744,616
4.04%
$447,471
$13,192,087
EXHIBIT K
34 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Mt. Pleasant Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$10,600
135
MATERIALS
$55,659
136
LABOR
$442,263
137
ENGINEERING & INSPECTION
$267,787
144
OVERHEAD
$214,348
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
148
OTHER SERVICES
$82,321
$225,638
$0
$215,165
SUBTOTAL
Escalation
PROJECT TOTAL
$1,513,781
4.04%
$53,150
$1,566,931
EXHIBIT K
35 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Owingsville Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
135
MATERIALS
136
LABOR
$249,040
137
ENGINEERING & INSPECTION
$258,068
144
OVERHEAD
$99,430
145
AFUDC
$44,483
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$5,000
$40,020
$121,921
SUBTOTAL
Escalation
PROJECT TOTAL
$817,962
4.04%
$28,719
$846,681
EXHIBIT K
36 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Somerset Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$97,531
135
MATERIALS
$12,675
136
LABOR
$67,808
137
ENGINEERING & INSPECTION
144
OVERHEAD
$75,777
145
AFUDC
$44,249
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$123,638
SUBTOTAL
Escalation
PROJECT TOTAL
$406,132
$827,810
4.04%
$14,426
$842,236
EXHIBIT K
37 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Summerfield Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
135
MATERIALS
$755,934
136
LABOR
$453,004
137
ENGINEERING & INSPECTION
$826,259
144
OVERHEAD
$230,890
145
AFUDC
$151,413
146
CONTINGENCY
$333,654
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$81,531
SUBTOTAL
Escalation
PROJECT TOTAL
$2,832,685
4.04%
$49,363
$2,882,048
EXHIBIT K
38 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Tomkinsville Compressor Sta. Upgrade
ITEM
DESCRIPTION
COMPRESSION
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
135
MATERIALS
136
LABOR
$249,040
137
ENGINEERING & INSPECTION
$258,068
144
OVERHEAD
$99,430
145
AFUDC
$44,483
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$5,000
$40,020
$121,921
SUBTOTAL
Escalation
PROJECT TOTAL
$817,962
4.04%
$28,719
$846,681
EXHIBIT K
39 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Chromatograph Installation - KY
ITEM
DESCRIPTION
M&R
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$0
135
MATERIALS
$365,447
136
LABOR
$540,342
137
ENGINEERING & INSPECTION
144
OVERHEAD
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$217,844
$78,445
$169,591
SUBTOTAL
Escalation
PROJECT TOTAL
$70,824
$1,442,493
4.04%
$50,646
$1,493,139
EXHIBIT K
40 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Chromatograph Installation - OH
ITEM
DESCRIPTION
M&R
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$0
135
MATERIALS
$260,382
136
LABOR
$325,476
137
ENGINEERING & INSPECTION
144
OVERHEAD
145
AFUDC
146
CONTINGENCY
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$141,756
$50,398
$108,953
SUBTOTAL
Escalation
PROJECT TOTAL
$39,770
$926,735
4.04%
$32,538
$959,273
EXHIBIT K
41 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Chromatograph Installation - TN
ITEM
DESCRIPTION
M&R
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$0
135
MATERIALS
$492,699
136
LABOR
$801,013
137
ENGINEERING & INSPECTION
$137,454
144
OVERHEAD
$304,246
145
AFUDC
$113,972
146
CONTINGENCY
$246,396
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
SUBTOTAL
Escalation
PROJECT TOTAL
$2,095,780
4.04%
$73,584
$2,169,364
EXHIBIT K
42 OF 42
COST OF FACILITIES
TEXAS EASTERN TRANSMISSION LP
NAME:
DOCKET NO.:
PROJECT:
PROJECT YEAR:
FACILITY:
TEAM 2014
2014
Chromatograph Installation - MS
ITEM
DESCRIPTION
M&R
132
RIGHT OF WAY
$0
133
RIGHT OF WAY DAMAGES
$0
134
SURVEYS
$0
135
MATERIALS
$182,723
136
LABOR
$270,171
137
ENGINEERING & INSPECTION
144
OVERHEAD
145
AFUDC
$39,222
146
CONTINGENCY
$84,795
147
LEGAL FEES
$0
148
OTHER SERVICES
$0
$108,922
SUBTOTAL
Escalation
PROJECT TOTAL
$35,412
$721,245
4.04%
$25,323
$746,568
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit P
Tariff and Rates
Texas Eastern Transmission, LP
Docket No. CP13-____
Exhibit P
TEAM 2014 Project
Cost of Service & Rates
Table of Contents
Schedule
Explanatory Notes
1
Cost of Service and Rate Design
2
Operation and Maintenance Expenses
3
Depreciation Expenses and Other Taxes
4
Rate Base and Return
5
Federal and State Income Taxes
6
Rate of Return
7
Tariff
8
Texas Eastern Transmission, LP
Docket No. CP13-____
Exhibit P
Schedule 1
Explanatory Notes
Rate Derivation
As shown on Schedule 2 herein, the rates proposed for firm service under the
TEAM 2014 Project are 100% reservation rates, based on the incremental cost of
service developed on Schedules 2 through 7 of this Exhibit P. Texas Eastern has
utilized the expansion capacity of 600,000 Dth/d as the volume determinant to develop
the incremental TEAM 2014 rates.
No existing system costs have been assigned to these rates and none of the
incremental cost of service of the new facilities is proposed to be included in Texas
Eastern’s system rates.
Cost of Service
The rate of return and other factors used in this Exhibit P were derived from
Texas Eastern’s cost of service settlement, as amended in Docket Nos. RP98-198-000,
et al., and approved by letter order issued on August 28, 1998. 1 Additionally, the
current federal income tax rate of 35% has been used. Texas Eastern proposes to use
its existing onshore transmission depreciation rate of 1.22% for the TEAM 2014
facilities.
The capital cost estimate used herein to calculate the TEAM 2014 Project
incremental cost of service totals $519,736,638, as detailed in Exhibit K.
Texas Eastern proposes to recover fuel use and lost and unaccounted for fuel,
as well as electric power costs associated with providing service on the TEAM 2014
facilities, through incremental Applicable Shrinkage Adjustment (“ASA”) percentages
and incremental Electric Power Cost (“EPC”) rates. The incremental fuel derivation is
shown on Exhibit Z-2. Consistent with the Commission’s incremental fuel methodology,
Texas Eastern will track changes in fuel and electric power costs for this new
incremental service on an incremental basis through its ASA mechanism set forth in
Section 15.6 of its GT&C and through its EPC Adjustment mechanism set forth in
Section 15.1 of its GT&C. Texas Eastern will adjust its periodic tracker mechanisms to
1
Texas Eastern Transmission Corp., 84 FERC ¶ 61,200 (1998).
ensure that existing customers do not subsidize the costs resulting from this new
incremental service.
Tariff Records
This Exhibit P includes a pro forma updated tariff section for Rate Schedule FT-1,
Statement of Rates, to reflect the proposed incremental rates for the TEAM 2014
Project. The redlined tariff section highlights all changes to the currently effective tariff
section. To the extent other changes to this tariff section become effective prior to
placing TEAM 2014 into service, Texas Eastern will include those changes when filing
to place this tariff section into effect.
Docket No. CP13-___
Exhibit P
Schedule 2
Texas Eastern Transmission, LP
TEAM 2014 Project
Cost of Service and Rate Design
Line
No.
(1)
(2)
(3)
(4)
Description
2014
2015
2016
1
Operation and Maintenance Expense
$4,685,236
$4,919,497
$5,165,472
2
Depreciation Expense
$6,340,787
$6,340,787
$6,340,787
3
Taxes Other than Income
$1,767,715
$1,069,619
$1,080,969
4
Federal Income Taxes
$20,822,695
$20,113,462
$19,268,847
5
State Income Taxes
$3,150,223
$3,042,925
$2,915,145
6
Return
$62,577,926
$60,431,923
$57,876,278
7
Total Cost of Service
$99,344,582
$95,918,213
$92,647,498
8
9
10
11
Rate Derivation:
Capacity (Dth/d)
Design Determinant
Reservation Charge
600,000
7,200,000
$13.798
12
Reservation Charge Adjustment
$0.4536
13
Usage-2 and Volumetric Res. Charge
$0.4536
14
Minimum Reservation Charge
$0.030
Docket No. CP13-___
Exhibit P
Schedule 3
Texas Eastern Transmission, LP
TEAM 2014 Project
Operation and Maintenance Expenses
(1)
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
Account Title
Operation:
850 Supervision & Engr. -Labor
850 Supervision & Engr. -M&O
851 Sys.Control & Load Dis. -Labor
851 Sys.Control & Load Dis. -M&O
852 Communication Systems -Labor
852 Communication Systems -M&O
853 Compressor Stations -Labor
853 Compressor Stations -M&O
855 Electric Power
856 Mains -Labor
856 Mains -M&O
857 M & R Station Expense -Labor
857 M & R Station Expense -M&O
858 Transportation by Others
860 Rents -M & O
Total Operation
Maintenance:
861 Supervision & Engr. -Labor
861 Supervision & Engr. -M&O
862 Structures & Improvements -Labor
862 Structures & Improvements -M&O
863 Mains -Labor
863 Mains -M&O
864 Compressor Stations -Labor
864 Compressor Stations -M&O
865 M & R Stations -Labor
865 M & R Stations -M&O
866 Communication Systems -Labor
866 Communication Systems -M&O
867 Other Equipment -Labor
867 Other Equipment -M&O
Total Maintenance
Total Direct O&M
35
36
37
38
Administrative and General:
Property Insurance @
Pensions & Benefits @
Total Administrative and General
39
Total Operation & Maintenance Expenses
0.20%
23.05%
(2)
(3)
(4)
2014
2015
2016
$37,794
$75,588
$2,537
$5,075
$9,192
$18,383
$58,419
$116,839
$3,043,108
$8,838
$17,675
$0
$0
$0
$1,977
$3,395,425
$39,684
$79,367
$2,664
$5,328
$9,651
$19,303
$61,340
$122,681
$3,195,263
$9,280
$18,559
$0
$0
$0
$2,076
$3,565,196
$41,668
$83,336
$2,797
$5,595
$10,134
$20,268
$64,407
$128,815
$3,355,027
$9,744
$19,487
$0
$0
$0
$2,180
$3,743,456
$9,852
$19,705
$3,501
$7,003
$4,193
$8,385
$50,125
$100,250
$0
$0
$774
$1,548
$716
$1,431
$207,483
$3,602,908
$10,345
$20,690
$3,676
$7,353
$4,402
$8,805
$52,631
$105,262
$0
$0
$813
$1,625
$751
$1,503
$217,857
$3,783,053
$10,862
$21,725
$3,860
$7,721
$4,622
$9,245
$55,263
$110,525
$0
$0
$853
$1,707
$789
$1,578
$228,750
$3,972,206
$1,039,473
$42,855
$1,082,328
$1,091,447
$44,998
$1,136,444
$1,146,019
$47,248
$1,193,267
$4,685,236
$4,919,497
$5,165,472
Docket No. CP13-___
Exhibit P
Schedule 4
Texas Eastern Transmission, LP
TEAM 2014 Project
Depreciation Expense and Other Taxes
Line
No.
(1)
(2)
(3)
(4)
Description
2014
2015
2016
1
2
3
4
Depreciation Expense:
Depreciable Plant
Depreciation Rate
Depreciation Exp.
5
Taxes Other than Income:
6
7
8
9
10
11
12
13
Gross Plant:
Pennslyvania
Ohio
Kentucky
Tennessee
Alabama
Mississippi
Total Gross Plant
14
15
16
17
18
19
20
21
Ad Valorem Taxes:
Pennslyvania
Ohio
Kentucky
Tennessee
Alabama
Mississippi
Total Ad Valorem Taxes
22
23
24
25
26
27
28
29
Franchise Taxes:
Pennslyvania
Ohio
Kentucky
Tennessee
Alabama
Mississippi
Total Franchise Taxes
30
31
32
Payroll Taxes:
Labor Cost
Payroll Taxes
33
34
Total Taxes Other than Income
(Lines 21, 29 & 32)
$519,736,638
1.22%
$6,340,787
$519,736,638
1.22%
$6,340,787
$519,736,638
1.22%
$6,340,787
$467,005,945
$18,453,587
$7,530,242
$5,477,524
$2,066,658
$19,202,682
$519,736,638
$467,005,945
$18,453,587
$7,530,242
$5,477,524
$2,066,658
$19,202,682
$519,736,638
$467,005,945
$18,453,587
$7,530,242
$5,477,524
$2,066,658
$19,202,682
$519,736,638
0.0000%
4.8919%
0.8518%
1.4955%
0.8234%
3.0660%
$0
$902,731
$64,145
$81,914
$17,017
$588,762
$1,654,568
$0
$911,758
$64,786
$82,733
$17,187
$594,649
$976,545
$0
$920,876
$65,434
$83,560
$17,359
$600,596
$986,310
0.0163%
0.0000%
0.0000%
0.0986%
0.0000%
0.0844%
$75,975
$0
$0
$5,403
$0
$16,207
$97,585
$76,735
$0
$0
$5,457
$0
$16,369
$76,735
$77,502
$0
$0
$5,512
$0
$16,533
$77,502
$185,941
$15,561
$195,238
$16,339
$205,000
$17,156
$1,767,715
$1,069,619
$1,080,969
8.3690%
Docket No. CP13-___
Exhibit P
Schedule 5
Texas Eastern Transmission, LP
TEAM 2014 Project
Rate Base and Return
Line
No.
(1)
(2)
(3)
(4)
Description
2014
2015
2016
1
2
3
4
Rate Base:
Gas Plant in Service
Accumulated Depreciation
Net Plant
5
Working Capital:
Materials & Supplies @
6
7
8
$519,736,638
($3,170,394)
$516,566,244
0.5640%
Accum. Deferred Income Taxes
Total Rate Base
Return @
12.130%
$2,931,315
$519,736,638
($9,511,181)
$510,225,457
$3,077,880
$519,736,638
($15,851,968)
$503,884,670
$3,231,774
($3,603,689)
$515,893,870
($15,101,172)
$498,202,165
($29,983,073)
$477,133,372
$62,577,926
$60,431,923
$57,876,278
Docket No. CP13-___
Exhibit P
Schedule 6
Texas Eastern Transmission, LP
TEAM 2014 Project
Federal and State Income Taxes
Line
No.
(1)
(2)
(3)
(4)
Description
2014
2015
2016
1
Return
2
3
4
5
Adjustments:
Interest and Debt Expense
Amortization of Equity AFUDC
Total Adjustments
6
Net Taxable Income
7
Federal Income Tax @
8
Pre-FIT (Lines 6 and 7)
9
State Income Tax @
35.00%
5.03%
$62,577,926
$60,431,923
$57,876,278
($24,169,628)
$262,421
($23,907,207)
($23,340,771)
$262,421
($23,078,350)
($22,353,698)
$262,421
($22,091,277)
$38,670,719
$37,353,573
$35,785,001
$20,822,695
$20,113,462
$19,268,847
$59,493,414
$57,467,035
$55,053,848
$3,150,223
$3,042,925
$2,915,145
Docket No. CP13-___
Exhibit P
Schedule 7
Texas Eastern Transmission, LP
TEAM 2014 Project
Rate of Return
(1)
Line
No.
Description
1
Long-Term Debt
2
Preferred
3
Equity
4
Total
(2)
Capitalization
Ratios
(3)
Component
Cost
(4)
Return
Component
41.35%
11.33%
4.685%
0.49%
5.60%
0.027%
58.16%
12.75%
7.415%
100.00%
12.130%
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 1 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
RESERVATION
CHARGES
Pursuant to Sections 3.2, 3.3, and 3.5 of Rate Schedule FT-1:
ACCESS AREA
STX-AAB
WLA-AAB
ELA-AAB
ETX-AAB
STX-STX
STX-WLA
STX-ELA
STX-ETX
WLA-WLA
WLA-ELA
WLA-ETX
ELA-ELA
ETX-ETX
ETX-ELA
MARKET AREA
M1-M1
M1-M2
M1-M3
M2-M2
M2-M3
M3-M3
FT-1 RESERVATION CHARGE*
$/dth
______________________________
MAXIMUM
MINIMUM
6.5800
0.0000
2.6010
0.0000
2.1510
0.0000
1.9650
0.0000
5.5110
0.0000
5.6700
0.0000
6.5880
0.0000
6.5870
0.0000
1.8340
0.0000
2.6070
0.0000
2.6080
0.0000
2.1550
0.0000
1.9690
0.0000
2.1560
0.0000
MAXIMUM
4.1720
7.7510
10.1930
6.0120
8.5930
4.8760
MINIMUM
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
* Reservation Charge reflects a storage surcharge of:
Issued on:
Effective on:
FT-1 RESERVATION
CHARGE ADJUSTMENT
$/dth
______________________________
MAXIMUM
MINIMUM
0.2163
0.0000
0.0855
0.0000
0.0707
0.0000
0.0646
0.0000
0.1812
0.0000
0.1864
0.0000
0.2166
0.0000
0.2166
0.0000
0.0602
0.0000
0.0857
0.0000
0.0857
0.0000
0.0709
0.0000
0.0647
0.0000
0.0709
0.0000
MAXIMUM
0.1372
0.2548
0.3351
0.1977
0.2825
0.1603
0.0970
MINIMUM
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 2 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
USAGE
CHARGES
ZONE RATE
$/dth
Pursuant to Sections 3.2 and 3.3 of Rate Schedule FT-1:
STX
WLA
ELA
ETX
M1
M2
0.0103
0.0112
0.0170
0.0169
0.0341
0.0563
0.0717
0.0112
0.0073
0.0123
0.0124
0.0295
0.0517
0.0671
0.0170
0.0123
0.0111
0.0112
0.0283
0.0505
0.0659
0.0169
0.0124
0.0112
0.0111
0.0283
0.0505
0.0659
0.0341
0.0295
0.0283
0.0283
0.0172
0.0394
0.0548
0.0563
0.0517
0.0505
0.0505
0.0394
0.0286
0.0440
0.0717
0.0671
0.0659
0.0659
0.0548
0.0440
0.0216
USAGE-1 - MINIMUM
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
0.0061
0.0070
0.0127
0.0126
0.0256
0.0478
0.0632
0.0070
0.0031
0.0080
0.0081
0.0210
0.0432
0.0586
0.0127
0.0080
0.0068
0.0069
0.0198
0.0420
0.0574
0.0126
0.0081
0.0069
0.0068
0.0198
0.0420
0.0574
0.0256
0.0210
0.0198
0.0198
0.0130
0.0352
0.0506
0.0478
0.0432
0.0420
0.0420
0.0352
0.0244
0.0398
0.0632
0.0586
0.0574
0.0574
0.0506
0.0398
0.0174
USAGE-1 - BACKHAUL MAXIMUM
from STX
0.0103
from WLA
0.0112
from ELA
0.0170
from ETX
0.0169
from M1
0.0310
from M2
0.0513
from M3
0.0653
0.0073
0.0123
0.0124
0.0264
0.0467
0.0607
0.0111
0.0112
0.0252
0.0455
0.0595
0.0111
0.0252
0.0455
0.0595
0.0141
0.0344
0.0484
0.0245
0.0385
0.0181
USAGE-1 - BACKHAUL MINIMUM
from STX
0.0061
from WLA
0.0070
from ELA
0.0127
from ETX
0.0126
from M1
0.0225
from M2
0.0428
from M3
0.0568
0.0031
0.0080
0.0081
0.0179
0.0382
0.0522
0.0068
0.0069
0.0167
0.0370
0.0510
0.0068
0.0167
0.0370
0.0510
0.0099
0.0302
0.0442
0.0203
0.0343
0.0139
USAGE-2
0.1148
0.1148
0.1148
0.2692
0.4090
0.5047
0.1148
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
M3
USAGE-1 - MAXIMUM
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 3 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
Pursuant to Section 3.14 of the General Terms and Conditions:
FT-1
CAPACITY RELEASE
RESERVATION CHARGE ADJUSTMENT/
CHARGES
RESERVATION CHARGE*
VOLUMETRIC RESERVATION CHARGE*
$/dth
$/dth
______________________________
______________________________
NONNONACCESS AREA
MILEAGE
MILEAGE
TOTAL
MILEAGE
MILEAGE
TOTAL
STX-AAB
4.1500
2.4300
6.5800
0.1364
0.0799
0.2163
WLA-AAB
1.3100
1.2910
2.6010
0.0431
0.0424
0.0855
ELA-AAB
0.9140
1.2370
2.1510
0.0301
0.0406
0.0707
ETX-AAB
0.8310
1.1340
1.9650
0.0273
0.0373
0.0646
STX-STX
3.0790
2.4320
5.5110
0.1012
0.0800
0.1812
STX-WLA
3.2360
2.4340
5.6700
0.1064
0.0800
0.1864
STX-ELA
4.1510
2.4370
6.5880
0.1365
0.0801
0.2166
STX-ETX
4.1500
2.4370
6.5870
0.1364
0.0802
0.2166
WLA-WLA
0.3970
1.4370
1.8340
0.0131
0.0471
0.0602
WLA-ELA
1.3110
1.2960
2.6070
0.0431
0.0426
0.0857
WLA-ETX
1.3120
1.2960
2.6080
0.0431
0.0426
0.0857
ELA-ELA
0.9140
1.2410
2.1550
0.0301
0.0408
0.0709
ETX-ETX
0.8310
1.1380
1.9690
0.0273
0.0374
0.0647
ETX-ELA
0.9150
1.2410
2.1560
0.0301
0.0408
0.0709
MARKET AREA
M1-M1
M1-M2
M1-M3
M2-M2
M2-M3
M3-M3
1.7340
5.3100
7.7500
3.5740
6.1530
2.4400
2.4380
2.4410
2.4430
2.4380
2.4400
2.4360
4.1720
7.7510
10.1930
6.0120
8.5930
4.8760
0.0570
0.1746
0.2548
0.1175
0.2023
0.0802
*Rates are exclusive of surcharges which can also be recovered.
Issued on:
Effective on:
0.0802
0.0802
0.0803
0.0802
0.0802
0.0801
0.1372
0.2548
0.3351
0.1977
0.2825
0.1603
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 4 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
Pursuant to Section 3.14 of the General Terms and Conditions:
FT-1
CAPACITY RELEASE
CHARGES
$/DTH
USAGE-1 RATE*
MILEAGE
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
NON-MILEAGE
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
TOTAL
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
USAGE-1 BACKHAUL RATE*
MILEAGE
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
NON-MILEAGE
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
TOTAL
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
STX
WLA
ELA
0.0061
0.0070
0.0127
0.0126
0.0256
0.0478
0.0632
0.0070
0.0036
0.0080
0.0081
0.0210
0.0432
0.0586
0.0127
0.0080
0.0068
0.0069
0.0198
0.0420
0.0574
0.0042
0.0042
0.0043
0.0043
0.0085
0.0085
0.0085
0.0042
0.0037
0.0043
0.0043
0.0085
0.0085
0.0085
0.0103
0.0112
0.0170
0.0169
0.0341
0.0563
0.0717
ETX
M1
M2
M3
0.0126
0.0081
0.0069
0.0068
0.0198
0.0420
0.0574
0.0256
0.0210
0.0198
0.0198
0.0130
0.0352
0.0506
0.0478
0.0432
0.0420
0.0420
0.0352
0.0244
0.0398
0.0632
0.0586
0.0574
0.0574
0.0506
0.0398
0.0174
0.0043
0.0043
0.0043
0.0043
0.0085
0.0085
0.0085
0.0043
0.0043
0.0043
0.0043
0.0085
0.0085
0.0085
0.0085
0.0085
0.0085
0.0085
0.0042
0.0042
0.0042
0.0085
0.0085
0.0085
0.0085
0.0042
0.0042
0.0042
0.0085
0.0085
0.0085
0.0085
0.0042
0.0042
0.0042
0.0112
0.0073
0.0123
0.0124
0.0295
0.0517
0.0671
0.0170
0.0123
0.0111
0.0112
0.0283
0.0505
0.0659
0.0169
0.0124
0.0112
0.0111
0.0283
0.0505
0.0659
0.0341
0.0295
0.0283
0.0283
0.0172
0.0394
0.0548
0.0563
0.0517
0.0505
0.0505
0.0394
0.0286
0.0440
0.0717
0.0671
0.0659
0.0659
0.0548
0.0440
0.0216
STX
WLA
ELA
ETX
M1
M2
M3
0.0061
0.0070
0.0127
0.0126
0.0225
0.0428
0.0568
0.0031
0.0080
0.0081
0.0179
0.0382
0.0522
0.0068
0.0069
0.0167
0.0370
0.0510
0.0068
0.0167
0.0370
0.0510
0.0099
0.0302
0.0442
0.0203
0.0343
0.0139
0.0042
0.0042
0.0043
0.0043
0.0085
0.0085
0.0085
0.0042
0.0043
0.0043
0.0085
0.0085
0.0085
0.0043
0.0043
0.0085
0.0085
0.0085
0.0043
0.0085
0.0085
0.0085
0.0042
0.0042
0.0042
0.0042
0.0042
0.0042
0.0103
0.0112
0.0170
0.0169
0.0310
0.0513
0.0653
0.0073
0.0123
0.0124
0.0264
0.0467
0.0607
0.0111
0.0112
0.0252
0.0455
0.0595
0.0111
0.0252
0.0455
0.0595
0.0141
0.0344
0.0484
0.0245
0.0385
0.0181
*Rates are exclusive of surcharges which can also be recovered.
Issued on:
Effective on:
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 5 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1 INCREMENTAL FACILITY CHARGE
PURSUANT TO SECTION 3.4 OF RATE SCHEDULE FT-1:
INCREMENTAL
FACILITY CHARGE
$/dth
Maximum
Minimum
To applicable customers converting from Rate Schedule FTS
in Docket No. CP82-446: RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
0.6600
0.0217
0.0000
0.0000
3.0110
0.0990
0.0000
0.0000
Customer
Bay State Gas Company
Boston Gas Company d/b/a National Grid
Colonial Gas Company d/b/a National Grid
Connecticut Natural Gas Corporation
Town of Middleborough, Massachusetts
New Jersey Natural Gas Company
Northern Utilities, Inc.
Southern Connecticut Gas Company
Yankee Gas Services Company
dth
4,235
21,394
1,951
6,340
116
1,060
965
4,922
6,066
To applicable customers converting from Rate Schedule FTS-4
in Docket No. CP87-4: RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
Customer
Brooklyn Union Gas Company d/b/a National Grid
KeySpan Gas East Corporation d/b/a National Grid
New Jersey Natural Gas Company
Pivotal Utility Holdings, Inc.
Public Service Electric & Gas Company
dth
27,500
22,500
40,000
10,000
40,000
To applicable customers converting from Rate Schedule FTS-5
in Docket No. CP87-312:RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
Customer
Colonial Gas Company d/b/a National Grid
UGI Central Penn Gas, Inc.
Yankee Gas Services Company
Issued on:
Effective on:
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
dth
4,231
3,015
To applicable customers converting from Rate Schedule FTS-8
in Docket No. CP85-803:RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
Customer
Yankee Gas Services Company
0.0000
0.0000
dth
2,326
4,000
125
To applicable customers converting from Rate Schedule FTS-7
in Docket No. CP80-170:RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
Customer
Connecticut Natural Gas Corporation
Yankee Gas Services Company
0.0000
0.0000
dth
39
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 6 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Docket No. CP00-404-000(Columbia Liberty Expansion):
__________________________________________________
Customer
______________________________________
Liberty Electric Power, LLC
dth
_______
84,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
4.4610
0.1467
0.1467
0.1180
0.1467
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 7 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Docket No. CP02-32, TIME Project:
__________________________________________________
Customer
______________________________
dth
______
New Jersey Natural Gas Company
100,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
10.5510
0.3469
0.3469
0.0000
0.3469
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
0.2917
-0.5250
-0.2333
ASA SURCHARGE
-1.7781
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
In-Path
Out-of-Path
3.27%
5.21%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 8 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2008:
Docket No. CP06-115, TIME II Project:
__________________________________________________
Customer
______________________________
dth
______
New Jersey Natural Gas Company
PSEG Power, LLC
100,000
50,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
19.9110
0.6545
0.6545
0.1110
0.0036
0.6545
0.0036
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
1.9722
-2.6030
-0.6308
ASA SURCHARGE
-1.3586
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
In-Path
Out-of-Path
2.44%
3.64%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 9 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
6.5600
0.2156
0.2156
0.080
Docket No. CP92-165 (North Carolina Project):
________________________________________________________
Customer
______________________________________
Dominion Transmission, Inc.
dth
______
30,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
0.2156
0.0000
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 10 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Docket No. CP94-654 (Riverside Storage Project):
_____________________________________________
Customer
______________________________________
PECO Energy Company
UGI Utilities, Inc.
dth
______
29,210
4,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
10.4390
0.3432
0.3432
0.000
0.0000
0.3432
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 11 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
1.9410
0.0638
0.0638
0.0000
0.0638
0.0000
Docket No. CP95-76 and CP95-2 (Philadelphia Lateral Expansion):
____________________________________________________
Customer
______________________________________
Grays Ferry Cogeneration Partnership
Sun Company, Inc.
dth
______
15,000
15,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 12 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Docket No. CP97-276 (1997 Line No. 1-A Expansion):
__________________________________________________
Customer
______________________________________
PECO Energy Company
Paulsboro Refining Company LLC
dth
______
93,000
8,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
1.5830
0.0520
0.0520
0.0000
0.0520
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 13 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Docket No. CP99-621 (Ironwood Lateral):
__________________________________________________
Customer
____________________________________
PPL Energy Plus, LLC
dth
_______
120,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
Effective October 1 through April 30
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
0.6040
0.0199
0.0199
0.0000
Effective May 1 through September 30
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
1.2690
0.0417
0.0417
0.0000
Effective October 1 through April 30
VOLUMETRIC RESERVATION CHARGE
0.0199
0.0000
Effective May 1 through September 30
VOLUMETRIC RESERVATION CHARGE
0.0417
0.0000
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
October 1 through September 30
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 14 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
5.5500
0.1824
0.1824
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
0.1824
0.0000
Docket No. CP02-381 (M1 Expansion Project):
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
APPLICABLE SHRINKAGE PERCENTAGE (LAUF)
Effective Year Around:
December 1 through November 30
0.7921
-1.6630
-0.8709
0.40%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 15 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2010:
Docket No. CP09-68-000, TIME III Project:
______________________________________
Customer
______________________________
dth
______
CenterPoint Energy Services, Inc.
PPL Energy Plus, LLC
25,000
30,000
Maximum
_______
Minimum
_______
$21.7860
$-0.0099
$0.7064
$0.7163
$0.0480
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
$0.0016
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.7163
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
1.0597
-1.4960
-0.4363
ASA USAGE SURCHARGE
-0.0099
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
$0.0016
1.59%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 16 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2010:
Docket No. CP09-68-000, TEMAX Project:
___________________________________
Customer
______________________________
dth
______
ConocoPhillips Company
395,000
Maximum
_______
Minimum
_______
$18.9590
$-0.0001
$0.6232
$0.6233
$0.0710
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
$0.0023
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.6233
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
1.6032
-1.0810
0.5222
ASA USAGE SURCHARGE
-0.0001
$0.0023
APPLICABLE SHRINKAGE PERCENTAGES
P RIMARY RECEIPT POINT TO A PRIMARY OR SECONDARY DELIVERY POINT IN M2 OR M3
December 1 through November 30:
1.15%
SECONDARY RECEIPT POINT TO A PRIMARY OR SECONDARY DELIVERY POINT IN M2 OR M3
December 1 through March 31:
April 1 through November 30:
3.91%
3.48%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 17 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
FIRM MARIETTA EXTENSION TRANSPORTATION SERVICE:
_______________________________________________
Marietta Extension Charge applicable to all Customers contracted for
firm transportation on the Marietta Extension with the exception of TEMAX
and Time III, in addition to other applicable charges
Rates Pursuant to Section 3.2(E&F) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
$3.1240
$0.1027
$0.1027
$0.0000
$0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.1027
$0.0000
MARIETTA EXTENSION APPLICABLE SHRINKAGE PERCENTAGE (LAUF)
_________________________________________________________
December 1 through November 30:
0.27%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5
OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 18 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2012:
Docket No. CP11-67-001, TEAM 2012 Project:
______________________________________
Customer
______________________________
Range Resources-Appalachia, LLC
Chesapeake Utilities Corporation
dth
______
150,000
50,000
Maximum
_______
Minimum
_______
$17.4990
$0.0000
$0.5753
$0.5753
$0.0270
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
$0.0010
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.5753
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
1.3677
0.0000
1.3677
ASA USAGE SURCHARGE
0.0000
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
$0.0010
1.93%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 19 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2012:
Docket No. CP11-508-000, Philadelphia Lateral Expansion Project:
______________________________________
Customer
______________________________
Grays Ferry Cogeneration Partnership
Paulsboro Refining Company LLC
dth
______
20,000
7,000
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
$8.3910
$0.0000
$0.2759
$0.2759
$0.0000
$0.2759
$0.0000
$0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
APPLICABLE SHRINKAGE PERCENTAGE (LAUF)
December 1 through November 30:
0.0467
0.0000
0.0467
0.02%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
Texas Eastern Transmission, LP
Part 4 - Statements of Rates
2. Rate Schedule FT-1
Version 20.0.0
Page 20 of 20
FERC Gas Tariff
Eighth Revised Volume No. 1
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2014:
Docket No. CP13-XXX-000, TEAM 2014 Project:
______________________________________
Customer
______________________________
Chevron U.S.A. Inc.
EQT Energy, LLC
dth
______
300,000
300,000
Maximum
_______
Minimum
_______
$13.7980
$0.0000
$0.4536
$0.4536
$0.0300
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
$0.0010
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.4536
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
0.4227
0.0000
0.4227
ASA USAGE SURCHARGE
0.0000
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
$0.0010
1.67%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 1 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
RESERVATION
CHARGES
Pursuant to Sections 3.2, 3.3, and 3.5 of Rate Schedule FT-1:
ACCESS AREA
STX-AAB
WLA-AAB
ELA-AAB
ETX-AAB
STX-STX
STX-WLA
STX-ELA
STX-ETX
WLA-WLA
WLA-ELA
WLA-ETX
ELA-ELA
ETX-ETX
ETX-ELA
MARKET AREA
M1-M1
M1-M2
M1-M3
M2-M2
M2-M3
M3-M3
FT-1 RESERVATION CHARGE*
$/dth
______________________________
MAXIMUM
MINIMUM
6.5800
0.0000
2.6010
0.0000
2.1510
0.0000
1.9650
0.0000
5.5110
0.0000
5.6700
0.0000
6.5880
0.0000
6.5870
0.0000
1.8340
0.0000
2.6070
0.0000
2.6080
0.0000
2.1550
0.0000
1.9690
0.0000
2.1560
0.0000
MAXIMUM
4.1720
7.7510
10.1930
6.0120
8.5930
4.8760
MINIMUM
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
* Reservation Charge reflects a storage surcharge of:
Issued on:
Effective on:
FT-1 RESERVATION
CHARGE ADJUSTMENT
$/dth
______________________________
MAXIMUM
MINIMUM
0.2163
0.0000
0.0855
0.0000
0.0707
0.0000
0.0646
0.0000
0.1812
0.0000
0.1864
0.0000
0.2166
0.0000
0.2166
0.0000
0.0602
0.0000
0.0857
0.0000
0.0857
0.0000
0.0709
0.0000
0.0647
0.0000
0.0709
0.0000
MAXIMUM
0.1372
0.2548
0.3351
0.1977
0.2825
0.1603
0.0970
MINIMUM
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 2 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
USAGE
CHARGES
ZONE RATE
$/dth
Pursuant to Sections 3.2 and 3.3 of Rate Schedule FT-1:
STX
WLA
ELA
ETX
M1
M2
0.0103
0.0112
0.0170
0.0169
0.0341
0.0563
0.0717
0.0112
0.0073
0.0123
0.0124
0.0295
0.0517
0.0671
0.0170
0.0123
0.0111
0.0112
0.0283
0.0505
0.0659
0.0169
0.0124
0.0112
0.0111
0.0283
0.0505
0.0659
0.0341
0.0295
0.0283
0.0283
0.0172
0.0394
0.0548
0.0563
0.0517
0.0505
0.0505
0.0394
0.0286
0.0440
0.0717
0.0671
0.0659
0.0659
0.0548
0.0440
0.0216
USAGE-1 - MINIMUM
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
0.0061
0.0070
0.0127
0.0126
0.0256
0.0478
0.0632
0.0070
0.0031
0.0080
0.0081
0.0210
0.0432
0.0586
0.0127
0.0080
0.0068
0.0069
0.0198
0.0420
0.0574
0.0126
0.0081
0.0069
0.0068
0.0198
0.0420
0.0574
0.0256
0.0210
0.0198
0.0198
0.0130
0.0352
0.0506
0.0478
0.0432
0.0420
0.0420
0.0352
0.0244
0.0398
0.0632
0.0586
0.0574
0.0574
0.0506
0.0398
0.0174
USAGE-1 - BACKHAUL MAXIMUM
from STX
0.0103
from WLA
0.0112
from ELA
0.0170
from ETX
0.0169
from M1
0.0310
from M2
0.0513
from M3
0.0653
0.0073
0.0123
0.0124
0.0264
0.0467
0.0607
0.0111
0.0112
0.0252
0.0455
0.0595
0.0111
0.0252
0.0455
0.0595
0.0141
0.0344
0.0484
0.0245
0.0385
0.0181
USAGE-1 - BACKHAUL MINIMUM
from STX
0.0061
from WLA
0.0070
from ELA
0.0127
from ETX
0.0126
from M1
0.0225
from M2
0.0428
from M3
0.0568
0.0031
0.0080
0.0081
0.0179
0.0382
0.0522
0.0068
0.0069
0.0167
0.0370
0.0510
0.0068
0.0167
0.0370
0.0510
0.0099
0.0302
0.0442
0.0203
0.0343
0.0139
USAGE-2
0.1148
0.1148
0.1148
0.2692
0.4090
0.5047
0.1148
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
M3
USAGE-1 - MAXIMUM
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 3 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
Pursuant to Section 3.14 of the General Terms and Conditions:
FT-1
CAPACITY RELEASE
RESERVATION CHARGE ADJUSTMENT/
CHARGES
RESERVATION CHARGE*
VOLUMETRIC RESERVATION CHARGE*
$/dth
$/dth
______________________________
______________________________
NONNONACCESS AREA
MILEAGE
MILEAGE
TOTAL
MILEAGE
MILEAGE
TOTAL
STX-AAB
4.1500
2.4300
6.5800
0.1364
0.0799
0.2163
WLA-AAB
1.3100
1.2910
2.6010
0.0431
0.0424
0.0855
ELA-AAB
0.9140
1.2370
2.1510
0.0301
0.0406
0.0707
ETX-AAB
0.8310
1.1340
1.9650
0.0273
0.0373
0.0646
STX-STX
3.0790
2.4320
5.5110
0.1012
0.0800
0.1812
STX-WLA
3.2360
2.4340
5.6700
0.1064
0.0800
0.1864
STX-ELA
4.1510
2.4370
6.5880
0.1365
0.0801
0.2166
STX-ETX
4.1500
2.4370
6.5870
0.1364
0.0802
0.2166
WLA-WLA
0.3970
1.4370
1.8340
0.0131
0.0471
0.0602
WLA-ELA
1.3110
1.2960
2.6070
0.0431
0.0426
0.0857
WLA-ETX
1.3120
1.2960
2.6080
0.0431
0.0426
0.0857
ELA-ELA
0.9140
1.2410
2.1550
0.0301
0.0408
0.0709
ETX-ETX
0.8310
1.1380
1.9690
0.0273
0.0374
0.0647
ETX-ELA
0.9150
1.2410
2.1560
0.0301
0.0408
0.0709
MARKET AREA
M1-M1
M1-M2
M1-M3
M2-M2
M2-M3
M3-M3
1.7340
5.3100
7.7500
3.5740
6.1530
2.4400
2.4380
2.4410
2.4430
2.4380
2.4400
2.4360
4.1720
7.7510
10.1930
6.0120
8.5930
4.8760
0.0570
0.1746
0.2548
0.1175
0.2023
0.0802
*Rates are exclusive of surcharges which can also be recovered.
Issued on:
Effective on:
0.0802
0.0802
0.0803
0.0802
0.0802
0.0801
0.1372
0.2548
0.3351
0.1977
0.2825
0.1603
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 4 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
Pursuant to Section 3.14 of the General Terms and Conditions:
FT-1
CAPACITY RELEASE
CHARGES
$/DTH
USAGE-1 RATE*
MILEAGE
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
NON-MILEAGE
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
TOTAL
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
USAGE-1 BACKHAUL RATE*
MILEAGE
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
NON-MILEAGE
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
TOTAL
from STX
from WLA
from ELA
from ETX
from M1
from M2
from M3
STX
WLA
ELA
0.0061
0.0070
0.0127
0.0126
0.0256
0.0478
0.0632
0.0070
0.0036
0.0080
0.0081
0.0210
0.0432
0.0586
0.0127
0.0080
0.0068
0.0069
0.0198
0.0420
0.0574
0.0042
0.0042
0.0043
0.0043
0.0085
0.0085
0.0085
0.0042
0.0037
0.0043
0.0043
0.0085
0.0085
0.0085
0.0103
0.0112
0.0170
0.0169
0.0341
0.0563
0.0717
ETX
M1
M2
M3
0.0126
0.0081
0.0069
0.0068
0.0198
0.0420
0.0574
0.0256
0.0210
0.0198
0.0198
0.0130
0.0352
0.0506
0.0478
0.0432
0.0420
0.0420
0.0352
0.0244
0.0398
0.0632
0.0586
0.0574
0.0574
0.0506
0.0398
0.0174
0.0043
0.0043
0.0043
0.0043
0.0085
0.0085
0.0085
0.0043
0.0043
0.0043
0.0043
0.0085
0.0085
0.0085
0.0085
0.0085
0.0085
0.0085
0.0042
0.0042
0.0042
0.0085
0.0085
0.0085
0.0085
0.0042
0.0042
0.0042
0.0085
0.0085
0.0085
0.0085
0.0042
0.0042
0.0042
0.0112
0.0073
0.0123
0.0124
0.0295
0.0517
0.0671
0.0170
0.0123
0.0111
0.0112
0.0283
0.0505
0.0659
0.0169
0.0124
0.0112
0.0111
0.0283
0.0505
0.0659
0.0341
0.0295
0.0283
0.0283
0.0172
0.0394
0.0548
0.0563
0.0517
0.0505
0.0505
0.0394
0.0286
0.0440
0.0717
0.0671
0.0659
0.0659
0.0548
0.0440
0.0216
STX
WLA
ELA
ETX
M1
M2
M3
0.0061
0.0070
0.0127
0.0126
0.0225
0.0428
0.0568
0.0031
0.0080
0.0081
0.0179
0.0382
0.0522
0.0068
0.0069
0.0167
0.0370
0.0510
0.0068
0.0167
0.0370
0.0510
0.0099
0.0302
0.0442
0.0203
0.0343
0.0139
0.0042
0.0042
0.0043
0.0043
0.0085
0.0085
0.0085
0.0042
0.0043
0.0043
0.0085
0.0085
0.0085
0.0043
0.0043
0.0085
0.0085
0.0085
0.0043
0.0085
0.0085
0.0085
0.0042
0.0042
0.0042
0.0042
0.0042
0.0042
0.0103
0.0112
0.0170
0.0169
0.0310
0.0513
0.0653
0.0073
0.0123
0.0124
0.0264
0.0467
0.0607
0.0111
0.0112
0.0252
0.0455
0.0595
0.0111
0.0252
0.0455
0.0595
0.0141
0.0344
0.0484
0.0245
0.0385
0.0181
*Rates are exclusive of surcharges which can also be recovered.
Issued on:
Effective on:
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 5 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1 INCREMENTAL FACILITY CHARGE
PURSUANT TO SECTION 3.4 OF RATE SCHEDULE FT-1:
INCREMENTAL
FACILITY CHARGE
$/dth
Maximum
Minimum
To applicable customers converting from Rate Schedule FTS
in Docket No. CP82-446: RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
0.6600
0.0217
0.0000
0.0000
3.0110
0.0990
0.0000
0.0000
Customer
Bay State Gas Company
Boston Gas Company d/b/a National Grid
Colonial Gas Company d/b/a National Grid
Connecticut Natural Gas Corporation
Town of Middleborough, Massachusetts
New Jersey Natural Gas Company
Northern Utilities, Inc.
Southern Connecticut Gas Company
Yankee Gas Services Company
dth
4,235
21,394
1,951
6,340
116
1,060
965
4,922
6,066
To applicable customers converting from Rate Schedule FTS-4
in Docket No. CP87-4: RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
Customer
Brooklyn Union Gas Company d/b/a National Grid
KeySpan Gas East Corporation d/b/a National Grid
New Jersey Natural Gas Company
Pivotal Utility Holdings, Inc.
Public Service Electric & Gas Company
dth
27,500
22,500
40,000
10,000
40,000
To applicable customers converting from Rate Schedule FTS-5
in Docket No. CP87-312:RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
Customer
Colonial Gas Company d/b/a National Grid
UGI Central Penn Gas, Inc.
Yankee Gas Services Company
Issued on:
Effective on:
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
dth
4,231
3,015
To applicable customers converting from Rate Schedule FTS-8
in Docket No. CP85-803:RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
Customer
Yankee Gas Services Company
0.0000
0.0000
dth
2,326
4,000
125
To applicable customers converting from Rate Schedule FTS-7
in Docket No. CP80-170:RESERVATION CHARGE
RESERVATION CHARGE ADJUSTMENT
Customer
Connecticut Natural Gas Corporation
Yankee Gas Services Company
0.0000
0.0000
dth
39
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 6 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Docket No. CP00-404-000(Columbia Liberty Expansion):
__________________________________________________
Customer
______________________________________
Liberty Electric Power, LLC
dth
_______
84,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
4.4610
0.1467
0.1467
0.1180
0.1467
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 7 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Docket No. CP02-32, TIME Project:
__________________________________________________
Customer
______________________________
dth
______
New Jersey Natural Gas Company
100,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
10.5510
0.3469
0.3469
0.0000
0.3469
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
0.2917
-0.5250
-0.2333
ASA SURCHARGE
-1.7781
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
In-Path
Out-of-Path
3.27%
5.21%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 8 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2008:
Docket No. CP06-115, TIME II Project:
__________________________________________________
Customer
______________________________
dth
______
New Jersey Natural Gas Company
PSEG Power, LLC
100,000
50,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
19.9110
0.6545
0.6545
0.1110
0.0036
0.6545
0.0036
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
1.9722
-2.6030
-0.6308
ASA SURCHARGE
-1.3586
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
In-Path
Out-of-Path
2.44%
3.64%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 9 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
6.5600
0.2156
0.2156
0.080
Docket No. CP92-165 (North Carolina Project):
________________________________________________________
Customer
______________________________________
Dominion Transmission, Inc.
dth
______
30,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
0.2156
0.0000
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 10 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Docket No. CP94-654 (Riverside Storage Project):
_____________________________________________
Customer
______________________________________
PECO Energy Company
UGI Utilities, Inc.
dth
______
29,210
4,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
10.4390
0.3432
0.3432
0.000
0.0000
0.3432
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 11 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
1.9410
0.0638
0.0638
0.0000
0.0638
0.0000
Docket No. CP95-76 and CP95-2 (Philadelphia Lateral Expansion):
____________________________________________________
Customer
______________________________________
Grays Ferry Cogeneration Partnership
Sun Company, Inc.
dth
______
15,000
15,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 12 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Docket No. CP97-276 (1997 Line No. 1-A Expansion):
__________________________________________________
Customer
______________________________________
PECO Energy Company
Paulsboro Refining Company LLC
dth
______
93,000
8,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
1.5830
0.0520
0.0520
0.0000
0.0520
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
June 1 through May 31
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 13 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Docket No. CP99-621 (Ironwood Lateral):
__________________________________________________
Customer
____________________________________
PPL Energy Plus, LLC
dth
_______
120,000
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
Effective October 1 through April 30
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
0.6040
0.0199
0.0199
0.0000
Effective May 1 through September 30
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
1.2690
0.0417
0.0417
0.0000
Effective October 1 through April 30
VOLUMETRIC RESERVATION CHARGE
0.0199
0.0000
Effective May 1 through September 30
VOLUMETRIC RESERVATION CHARGE
0.0417
0.0000
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
APPLICABLE SHRINKAGE PERCENTAGE
Effective Year Around:
October 1 through September 30
0.00 %
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 14 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON OR AFTER JUNE 1, 1993:
Maximum
Minimum
Rates Pursuant to Section 3.2 of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
5.5500
0.1824
0.1824
0.0000
0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
0.1824
0.0000
Docket No. CP02-381 (M1 Expansion Project):
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
APPLICABLE SHRINKAGE PERCENTAGE (LAUF)
Effective Year Around:
December 1 through November 30
0.7921
-1.6630
-0.8709
0.40%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 15 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2010:
Docket No. CP09-68-000, TIME III Project:
______________________________________
Customer
______________________________
dth
______
CenterPoint Energy Services, Inc.
PPL Energy Plus, LLC
25,000
30,000
Maximum
_______
Minimum
_______
$21.7860
$-0.0099
$0.7064
$0.7163
$0.0480
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
$0.0016
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.7163
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
1.0597
-1.4960
-0.4363
ASA USAGE SURCHARGE
-0.0099
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
$0.0016
1.59%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 16 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2010:
Docket No. CP09-68-000, TEMAX Project:
___________________________________
Customer
______________________________
dth
______
ConocoPhillips Company
395,000
Maximum
_______
Minimum
_______
$18.9590
$-0.0001
$0.6232
$0.6233
$0.0710
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
$0.0023
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.6233
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
1.6032
-1.0810
0.5222
ASA USAGE SURCHARGE
-0.0001
$0.0023
APPLICABLE SHRINKAGE PERCENTAGES
P RIMARY RECEIPT POINT TO A PRIMARY OR SECONDARY DELIVERY POINT IN M2 OR M3
December 1 through November 30:
1.15%
SECONDARY RECEIPT POINT TO A PRIMARY OR SECONDARY DELIVERY POINT IN M2 OR M3
December 1 through March 31:
April 1 through November 30:
3.91%
3.48%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 17 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
FIRM MARIETTA EXTENSION TRANSPORTATION SERVICE:
_______________________________________________
Marietta Extension Charge applicable to all Customers contracted for
firm transportation on the Marietta Extension with the exception of TEMAX
and Time III, in addition to other applicable charges
Rates Pursuant to Section 3.2(E&F) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
$3.1240
$0.1027
$0.1027
$0.0000
$0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.1027
$0.0000
MARIETTA EXTENSION APPLICABLE SHRINKAGE PERCENTAGE (LAUF)
_________________________________________________________
December 1 through November 30:
0.27%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5
OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 18 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2012:
Docket No. CP11-67-001, TEAM 2012 Project:
______________________________________
Customer
______________________________
Range Resources-Appalachia, LLC
Chesapeake Utilities Corporation
dth
______
150,000
50,000
Maximum
_______
Minimum
_______
$17.4990
$0.0000
$0.5753
$0.5753
$0.0270
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
$0.0010
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.5753
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
1.3677
0.0000
1.3677
ASA USAGE SURCHARGE
0.0000
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
$0.0010
1.93%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 19 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2012:
Docket No. CP11-508-000, Philadelphia Lateral Expansion Project:
______________________________________
Customer
______________________________
Grays Ferry Cogeneration Partnership
Paulsboro Refining Company LLC
dth
______
20,000
7,000
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
$8.3910
$0.0000
$0.2759
$0.2759
$0.0000
$0.2759
$0.0000
$0.0000
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
APPLICABLE SHRINKAGE PERCENTAGE (LAUF)
December 1 through November 30:
0.0467
0.0000
0.0467
0.02%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
2. Rate Schedule FT-1
Version 19.0.0 20.0.0
Page 20 of19 20
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE
SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1
FT-1
CHARGES
CHARGES
$/dth
APPLICABLE TO CUSTOMERS UTILIZING CAPACITY PURSUANT TO INCREMENTAL
FACILITY EXPANSIONS IMPLEMENTED ON NOVEMBER 1, 2014:
Docket No. CP13-XXX-000, TEAM 2014 Project:
______________________________________
Customer
______________________________
dth
______
Chevron U.S.A. Inc.
EQT Energy, LLC
300,000
300,000
Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1:
RESERVATION CHARGE
USAGE-1 CHARGE
USAGE-2 CHARGE
RESERVATION CHARGE ADJUSTMENT
Maximum
_______
Minimum
_______
$13.7980
$0.0000
$0.4536
$0.4536
$0.0300
$0.0010
Rates Pursuant to Section 3.14 of the General Terms and Conditions:
VOLUMETRIC RESERVATION CHARGE
$0.4536
BASE UNIT ELECTRIC POWER COST
ELECTRIC POWER COST ADJUSTMENT
ADJUSTED ELECTRIC POWER COST
0.4227
0.0000
0.4227
ASA USAGE SURCHARGE
0.0000
APPLICABLE SHRINKAGE PERCENTAGE
December 1 through November 30:
$0.0010
1.67%
ALL ZONES
$/dth
ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO
SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS.
Issued on:
Effective on:
0.0018
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Y
Accounting Treatment of Abandonment
TEXAS EASTERN TRANSMISSION, LP
EXHIBIT Y
Retire One 18,500 HP Turbine and Six 1,100 HP Recips
At Delmont Compressor Station For TEAM 2014
ENTRY
DEBIT
1
1088
CREDIT
1010
ACCOUNT DESCRIPTION
Retirement Work in Progress
Gas Plant in Service
DEBIT
CREDIT
5,851,720
5,851,720
To record the retirement from Gas Plant in Service.
2
1088
1310
Retirement Work in Progress
Cash
1,052,897
1,052,897
To record Cost of Removal
3
1080
1088
Provision for Accumulated Depreciation
Retirement Work in Progress
To record clearance of Retirement Work in Progress.
6,904,617
6,904,617
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Z-1(a)-(b)
Open Season and Reverse Open Season Notices
Texas Eastern Appalachia to Market
Expansion Project (TEAM 2014)
Moving emerging natural gas supplies from the Appalachian region to diverse market destinations along
the existing Texas Eastern footprint from the Northeast to the Midwest, and Gulf Coast.
Binding Open Season Notice
January 17, 2012 – February 17, 2012
Texas Eastern Appalachia to Market Expansion Project (TEAM 2014)
Texas Eastern’s Appalachia to Market Expansion Project 2014 offers the unique opportunity for moving emerging natural gas
supplies from the Appalachian region to diverse markets across the Texas Eastern system including premium Northeast
markets, as well as markets in the Midwest, and Gulf Coast.
export, Gas-to-Liquids, and other market opportunities in
the Southeast and Gulf Coast.
Spectra Energy’s Texas Eastern Transmission, LP (“Texas
Eastern” or “TETLP”), a leading provider of natural gas
transportation services for over 60 years, recognized the
potential for emerging Appalachian natural gas supplies to
move further east, west, and southwest on its pipeline
system. TEAM 2014 is a project that will provide an efficient
means to transport these supplies to Northeast, Midwest,
and Gulf Coast markets. Texas Eastern has secured
Precedent Agreements with two anchor shippers that
provide the economic base to move forward with the
project. With this Binding Open Season which shall run from
January 17, 2012 to February 17, 2012, Texas Eastern
invites all parties who are interested in obtaining firm TEAM
2014 capacity to submit a Binding Service Request Form.
The service commencement date for this project is targeted
for November 1, 2014.
Connecting new supply to markets has been instrumental
to Texas Eastern’s success for many years. Texas Eastern
has the proven ability and experience to develop and
execute TEAM 2014 as it has developed and executed
numerous production-driven projects in the past. Texas
Eastern intends to expand existing infrastructure and
utilize existing rights of way, where possible, for TEAM
2014 in order to manage construction costs and minimize
the impact on landowners and the environment.
Project Description
TEAM 2014 provides shippers with the opportunity to
design transportation services from multiple existing and
proposed new receipt points on the Texas Eastern system
within the Appalachian production region in West Virginia
and southwestern Pennsylvania that span portions of Texas
Eastern’s Zones M2 and M3 to delivery points across the
Texas Eastern system, including but not limited to Marietta,
Pa. (head of the Marietta Extension to an interconnect with
Transco near its Station 195); Lambertville, N.J.; Staten
Island, N.Y.; Lebanon, Ohio; the interconnect with Transco
near its Station 195; and other pipeline interconnects and
markets in Zones M3, M2, M1, ELA and WLA.
Project Background
The rapidly expanding Appalachian production area,
including the Marcellus Shale play, has created
opportunities to increase supply diversity for growing
domestic natural gas markets. The formation spans the
regions of West Virginia, Eastern Ohio, Western and
Northern Pennsylvania and Southern New York. With the
successful development of the Northeast Pennsylvania
sector of the Marcellus play over the past few years, Texas
Eastern is now witnessing a similar development curve from
emerging Appalachian production in the Southwestern
Pennsylvania and West Virginia area around its pipeline and
anticipates the positive potential benefits these supplies
will bring to its customers on its system
and the Northeast, Midwest, and Gulf
Coast markets in general.
The proposed expansion contemplates an overall potential
project capacity of up to 1,400,000 Dth/d inclusive of the
two anchor shipper commitments. Texas Eastern is
proposing this Binding Open Season in order to invite all
parties who are interested in obtaining capacity created by
Texas Eastern’s existing facilities are
uniquely positioned over the
Appalachian production area while also
providing significant access to major
Northeast, Midwest, and Gulf Coast
markets. Over the past several years,
Texas Eastern has been developing and
constructing well-timed, cost effective
pipeline expansions that have and will
connect significant sources of supply to
markets and liquid trading points along
the Texas Eastern system. The Texas
Eastern system offers attractive market
options for these newly developing
supply sources, including access to
conventional Northeast market growth,
increasing natural gas power generation
and interconnects with downstream
pipelines that provide direct access to
additional markets, and emerging LNG
Page 2 of 5
the TEAM 2014 Expansion Project to submit a request for
service pursuant to the terms of this open season notice.
Texas Eastern will also consider requests for delivery to off
system points.
Project Rates
Rates will be determined at the conclusion of the Binding
Open Season and are dependent upon the scope and final
facilities required to satisfy the firm service requests for
shippers who are awarded capacity and who have
executed binding Precedent Agreements. Shippers will
have the ability to choose to pay Texas Eastern’s
applicable recourse rates for service on the TEAM 2014
facilities or to pay a mutually agreeable negotiated rate
for such service. The indicative negotiated rates for the
project assuming a project capacity of up to 1,400,000
Dth/d pursuant to the limitation and restrictions described
herein are $0.45-0.50 per Dth/d on a 100% load factor
basis, respectively. In addition to the transportation rates,
any shipper who transports gas will be subject to fuel
charges that will ultimately be determined by the scope
and final facilities required to satisfy the firm service
requirements of those shippers who have executed
binding Precedent Agreements. Initial indicative fuel rates
will be determined after the close of this Binding Open
Season.
Texas Eastern has designed the project to accommodate a
primary firm path for all project shippers to be split, with
50% of the firm path to extend to the East, and 50% of the
firm path to extend to the West and South from the
Appalachian supply region. Inclusive of the anchor shipper
commitments, the project currently contemplates up to
450,000 Dth/d of available firm transport to the
interconnect with Algonquin near Lambertville, N.J., with
limited deliverability available downstream, up to 250,000
Dth/d to Marietta and on the Marietta Extension, and up
to 700,000 Dth/d of firm path to the west and southwest
to various markets and interconnects along the Texas
Eastern system in Zones M2, M1 with limited delivery
downstream to ELA and WLA.
If nominations submitted in response to this Binding Open
Season will result in the execution of binding Precedent
Agreements in excess of 1,400,000 Dth/d or in excess of
the project capacity available in any particular firm path or
any particular point, Texas Eastern will implement a
procedure that allocates the available capacity on a not
unduly discriminatory basis, as described more fully
below. If nominations submitted in response to this
Binding Open Season result in less than the proposed
capacity designed for the project, Texas Eastern may offer
the excess capacity to all shippers that executed binding
Precedent Agreements, including the anchor shipper on a
not unduly discriminatory basis. The project does not
require the 1,400,000 Dth/d of volume to proceed, rather
it may proceed solely with the anchor shipper commitment
or additional volumes up to 1,400,000 Dth/d.
Binding Nomination Process
During the Binding Open Season period interested parties
must submit a Binding Service Request Form, which
specifies the Maximum Daily Quantity (MDQ), contract
term (15-year preferred; 10-year minimum), receipt and
delivery points (both existing and proposed), with the
proposed MDQ split 50/50, with 50 percent of the firm
path extending to delivery points on the Texas Eastern
system to the east and 50 percent of the firm path
extending to delivery points on the Texas Eastern system
to the west and to the south from the Appalachian supply
region. The Binding Service Request Form is included in
this package. The completed Binding Service Request
Form must be executed by a duly authorized
representative and mailed or faxed, to Texas Eastern’s
offices at:
5400 Westheimer Ct.
Houston, TX 77056
Attention: Bobby Huffman
Email: RLHuffman@spectraenergy.com
Fax: (713) 627-4727
Anchor Shipper Status
To qualify as an anchor shipper for the TEAM 2014
Expansion Project, a shipper must execute a Precedent
Agreement acceptable to Texas Eastern that:
• Commits to an MDQ of at least 300,000 Dth/d;
• Reflect a primary term that extends at least ten (10)
years following the service commencement date of the
project; and
• Is executed by a duly authorized officer of the shipper
no later than thirty (30) days following the end of the
Binding Open Season, unless Texas Eastern agrees, in its
sole discretion, to extend such deadline.
Texas Eastern reserves the right to reject any Binding
Service Request Form that is not received by 5:00 p.m.
EST, on Friday, February 17, 2012.
Contracting for Service
Upon the close of the Binding Open Season, Texas Eastern
will evaluate all valid requests for service as set forth in
the Binding Service Request Forms to determine if the
proposed TEAM 2014 Expansion Project is economically
justified. Texas Eastern will also evaluate the availability of
necessary materials, equipment and third-party services at
the time to confirm that Texas Eastern can complete the
facilities necessary to satisfy all valid requests submitted in
this Binding Open Season by the timing contemplated for
the TEAM 2014 Expansion Project. If Texas Eastern elects
to proceed with the project, Texas Eastern representatives
will contact all parties who have submitted valid requests
Shippers qualifying for anchor shipper status may be
entitled to certain rate and rate-related incentives and
priority to project capacity that is not subscribed during
this Binding Open Season or that was subscribed but then
became available to Texas Eastern prior to the service
commencement date for the project. An anchor shipper
may also be entitled to a one-time option to extend its
primary term for an additional five years. An anchor
shipper will receive priority to project capacity as
described more fully below in the Capacity Allocation
Process.
Page 3 of 5
in order to finalize the terms on which service will be
provided.
Limitations and Reservations
Texas Eastern reserves the right, in its sole discretion, to
decline to proceed with the TEAM 2014 Expansion Project
or any portion of the project, including all or any portion
of the project for which Texas Eastern has requested
nominations as part of this Binding Open Season. Texas
Eastern also reserves the right to reject any and all bids
that do not satisfy the requirements set forth in this
Binding Open Season Notice. Without limiting the
foregoing, Texas Eastern may, but is not required to, reject
any request for service in which the Binding Service
Request Form is incomplete, is inconsistent with the terms
and conditions outlined in this Binding Open Season
Notice, contains additional or modified terms, or is
otherwise deficient in any respect. Texas Eastern reserves
the right to request a nominating party to modify its
proposed delivery point(s), to the extent that Texas
Eastern determines that the nominated point(s) will
unduly increase the cost of the overall project or
otherwise adversely affect the scope of the project in light
of the other nominations received prior to or as part of
the Binding Open Season. Texas Eastern also reserves the
right to reject requests for service in the event requesting
parties are unable to meet applicable creditworthiness
requirements. No request for service shall be binding on
Texas Eastern unless and until duly authorized
representatives of both a requesting party and Texas
Eastern have executed binding Precedent Agreements.
Any party who is awarded TEAM 2014 capacity must enter
into a binding Precedent Agreement. Texas Eastern
reserves the right to reject any party’s valid request for
service in the event a duly authorized representative of
such party has not executed a binding Precedent
Agreement on or before 30 days following the end of the
Binding Open Season.
Capacity Allocation Process
In the event that Texas Eastern has received executed
binding Precedent Agreements for a quantity of the TEAM
2014 Expansion Project capacity that exceeds the quantity
of pipeline, point or segment capacity that Texas Eastern is
willing to propose for the project, Texas Eastern will
allocate such capacity first to anchor shippers executing
binding Precedent Agreements that qualify as anchor
shippers under this Binding Open Season and next to other
shippers that have executed binding Precedent
Agreements for the project. In the event that anchor
shippers have executed binding Precedent Agreements for
a quantity of capacity that exceeds the quantity of pipeline,
point or segment capacity proposed for the project, Texas
Eastern will pro rate such capacity among the anchor
shippers on a not unduly discriminatory basis taking into
account the quantities subscribed under each such binding
Precedent Agreement and the quantities associated with
the primary points and primary firm paths under each such
agreement, but deeming the economic value of each such
agreement to Pipeline to be equal. Any reduction in MDQ
among anchor shippers will maintain the even split
between the eastward primary firm path and the
westward/southward primary firm path. If, after allocating
capacity to anchor shippers, Texas Eastern is able to
accommodate some but not all of the pipeline, point or
segment capacity nominated by other (non-anchor)
shippers executing binding Precedent Agreements, Texas
Eastern will allocate such pipeline, point or segment
capacity on a net present value basis among such other
shippers based on rate, contract term and MDQ
nominated, with Texas Eastern having the discretion to
grant capacity to any bid or combination of bids that
provides the highest net present value.
Communications
Interested parties may contact their Texas Eastern account
manager or Bob Riga at 617-560-1436 or Bobby Huffman
at 713-627-5259 to discuss any questions or to seek
additional information about this Binding Open Season.
Spectra Energy Corp (NYSE: SE), a FORTUNE 500 company, is one
of North America's premier natural gas infrastructure companies
serving three key links in the natural gas value chain: gathering
and processing, transmission and storage, and distribution. For
more than a century, Spectra Energy and its predecessor
companies have developed critically important pipelines and
related infrastructure connecting natural gas supply sources to
premium markets. Based in Houston, Texas, the company’s
operations in the United States and Canada include approximately
19,100 miles of transmission pipeline, more than 305 billion cubic
feet of storage, as well as natural gas gathering and processing,
natural gas liquids operations and local distribution assets. The
company also has a 50 percent ownership in DCP Midstream, one
of the largest natural gas gatherers and processors in the United
States. Spectra Energy is a member of the Dow Jones Sustainability
World and North America Indexes and the U.S. S&P 500 Carbon
Disclosure Project's Carbon Disclosure Leadership Index. For more
information, visit www.spectraenergy.com.
Page 4 of 5
Texas Eastern Appalachia to Market Expansion Project (TEAM 2014)
Binding Open Season for 2014 Firm Transportation Capacity
Binding Service Request Form
Texas Eastern Transmission, LP
Shipper Information
Company
Contact
Title
Address
Phone
Fax
Email
Maximum Daily Quantity
____________________________
Eastward Firm Path (50% of MDQ)
Receipt Point(s)
Quantity (Dth/d)
Delivery Point(s) [1]
Quantity (Dth/d)
Delivery Point(s) [1]
Quantity (Dth/d)
Westward Firm Path (50% of MDQ)
Receipt Point(s)
Quantity (Dth/d)
Contract Term:
(15-year preferred, 10-year minimum)
Signature of Requester/Customer and Date:
By completing this Binding Service Request Form, subject to Texas Eastern’s acceptance of shipper’s request for service and
shipper’s receipt of notification from Texas Eastern of quantities of capacity allocated to shipper, shipper hereby agrees to
enter into negotiations with the objective to enter into a binding Precedent Agreement with Texas Eastern. If shipper does
not enter into a binding Precedent Agreement, Texas Eastern reserves the right to reject shipper’s request for service as set
forth in this Binding Service Request Form.
If you have any questions, please contact your Texas Eastern account manager or the contact listed below. In addition, please
send your completed Binding Service Request Form to:
Texas Eastern Transmission
Attention: Bobby Huffman
5400 Westheimer Court
Houston, TX 77056
[1]
713-627-4727 fax
RLHuffman@spectraenergy.com
The sum of multiple nominated delivery point quantities may not exceed the Maximum Daily Quantity.
Page 5 of 5
REVERSE OPEN SEASON
Texas Eastern Appalachia to Market Expansion Program 2014 (TEAM 2014)
March 12 – 30, 2012
In connection with the binding open season held by Texas Eastern Transmission, LP
(“Texas Eastern”) for the TEAM 2014 Project from January 17, 2012 to February 17,
2012, Texas Eastern will consider, from March 12, 2012 through March 30, 2012, offers
by its current firm shippers who desire to release, subject to the criteria set forth below,
all or a portion of their current firm transportation entitlements to reduce the scope of
Texas Eastern’s facility requirements for a proposed expansion designated as the
TEAM 2014 Project. The TEAM 2014 Project contemplates the expansion of Texas
Eastern’s facilities to provide additional firm transportation service on the Texas Eastern
system for a minimum term of ten (10) years, with extension rights, commencing on
November 1, 2014, from receipt points on the Texas Eastern system in M2 in Marshall
County, West Virginia and Greene and Fayette Counties in Pennsylvania to proposed
delivery points on the Texas Eastern system in an easterly direction in M3 near
Lambertville, New Jersey and Staten Island, New York and in a westward and southerly
direction to delivery points in M2 and M1 and in ELA and WLA. Shippers interested in
releasing capacity in connection with this project must have capacity which meets all of
the following criteria:
1.
Shippers must have firm rights to the capacity they desire to release, on a nonrecallable basis, as of November 1, 2014.
2.
Shippers’ capacity must enable Texas Eastern to reduce the scope of its
proposed incremental facilities, as finally scoped and designed, necessary to
satisfy Texas Eastern’s obligations pursuant to the open season held in
January/February, 2012, while maintaining or improving the economics of the
TEAM 2014 Project. Shipper’s capacity must result in available capacity on
Texas Eastern’s facilities from receipt points on the Texas Eastern system to the
proposed delivery points on the Texas Eastern system defined above, and not
result in a release of any capacity unnecessary for the project.
3.
Eligible shippers whose capacity release requests are accepted pursuant to this
notice will receive a credit on their monthly invoice for such release in an amount
equal to the reservation charges received from the TEAM 2014 shipper(s)
utilizing the released capacity during the applicable month, provided the credit
will not exceed the amount equal to the eligible shipper’s reservation charges
associated with such capacity for the month. For the term of any such release as
described above, eligible shippers will continue to be obligated to Texas Eastern,
and must pay Texas Eastern, for all reservation charges associated with their
capacity, as effective from time to time, subject to the credit described in the
preceding sentence.
4.
Any and all releases of capacity meeting the criteria set forth herein will be
subject to and conditioned on Texas Eastern’s receipt of any and all necessary
governmental authorizations with terms and conditions acceptable to Texas
Eastern and Texas Eastern proceeding with, and completing construction of, the
TEAM 2014 Project facilities, subject to any modifications in light of this reverse
open season. No release will become effective until the date on which service
commences under the firm agreement(s) for which capacity has been released
under this reverse open season.
Any shippers meeting the criteria set forth above and interested in releasing, on a nonrecallable basis, their capacity in connection with the TEAM 2014 Project, should
indicate such interest by faxing or e-mailing a notice to Bobby Huffman (713) 627-5259
(phone), (713) 627-4727 (fax), or rlhuffman@spectraenergy.com (email) by Friday,
March 30, 2012, at 5 p.m. EST. Any such notice shall be binding on the shipper
submitting the notice until Texas Eastern has completed its analysis of whether the
shipper’s capacity can be utilized for the limited purposes described herein, and such
notice must include the quantity of firm entitlements which the requestor desires to
release and must identify the applicable Texas Eastern contract(s).
Texas Eastern will notify all shippers responding to this TEAM 2014 Project Reverse
Open Season as soon as reasonably practicable as to whether their capacity can be
utilized for the limited purpose described herein. To the extent there is more capacity
meeting the above stated requirements than is required, all such offers to release
capacity will be prorated. For every offer to release capacity accepted by Texas
Eastern, the Maximum Daily Quantity (“MDQ”) set out in that shipper’s firm service
agreement shall be reduced in accordance with the offer to release capacity and the
shipper shall lose all rights, including renewal options, on the MDQ that has been
released, but shall continue to receive service on all other capacity under the shipper’s
firm service agreement. Every offer to release capacity is contractually binding on the
shippers proposing to release capacity in connection with this reverse open season. In
order to effect an offer to release capacity, the shipper must, within thirty (30) days of
the date that Texas Eastern notifies the shipper that its capacity can be utilized for the
TEAM 2014 Project, execute an agreement that will govern the shipper’s release of
capacity consistent with the provisions set forth in this reverse open season. Any
questions concerning this TEAM 2014 Project Reverse Open Season may be
addressed to Bobby Huffman at the numbers written above or directly to your Texas
Eastern Account Manager.
SUPPLEMENTAL REVERSE OPEN SEASON
Texas Eastern Appalachia to Market Expansion Program 2014 (TEAM 2014)
Texas Eastern Transmission, LP (“Texas Eastern”) is currently conducting a reverse
open season for the TEAM 2014 Project. For details regarding the reverse open
season, please see the reverse open season notice which is currently posted on Texas
Eastern’s LINK® system website. Texas Eastern hereby clarifies that, following the
close of the reverse open season, it will provide notice to each shipper submitting a
timely and valid offer to turnback capacity of the portion of the offered capacity that
Texas Eastern will accept for the TEAM 2014 Project and the amount of the credit to
reservation charges that the shipper will receive for such capacity. If the shipper does
not agree to turnback capacity pursuant to the terms of such notice within five (5)
business days of its receipt thereof, the shipper’s offer to turnback capacity will be null
and void, unless the parties mutually agree to extend the deadline.
The reverse open season period will be extended until Friday, March 30, 2012 at 5 p.m.
EST. Any shipper meeting the criteria set forth in the reverse open season notice, as
clarified herein, and interested in releasing, on a non-recallable basis, their firm capacity
in connection with the TEAM 2014 Project, should indicate such interest by faxing or emailing a notice of its offer by that time to Bobby Huffman (713) 627-5259 (phone),
(713) 627-4727 (fax) or rlhuffman@spectraenergy.com.
All other terms of the reverse open season remain in effect as described in the reverse
open notice currently posted on Texas Eastern LINK® system website.
Any questions regarding this supplement to the TEAM 2014 Project Reverse Open
Season may be addressed to Bobby Huffman at the phone number or email address
provided above or directly to your Texas Eastern Account Manager.
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Z-1(c)
Diagram of Turnback Requests
Texas Eastern Transmission, LP
Docket No. CP13-___-000
Exhibit Z-1(c)
Sheet 1 of 1
TEAM 2014 Path vs. Contract Paths Proposed for Turn Back
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Z-1(d)
Diagram of Project Scope Based on Turnback Offers
Texas Eastern Transmission, LP
Docket No. CP13-___-000
Exhibit Z-1(d)
Sheet 1 of 1
TEAM 2014 Path after Including Capacity Turn Back
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Z-2
Incremental Fuel and Electric Power Derivation
Texas Eastern Transmission, LP
Docket No. CP13-___-000
Exhibit Z-2
Sheet 1 of 4
INCREMENTAL FUEL AND ELECTRIC POWER COST DERIVATION
TEAM 2014 PROJECT (600 MDth/D)
Incremental Fuel and EPC associated with Forward Flow (300 MDth/D)
The incremental fuel and electric power for the TEAM 2014 Project (the Project) associated with the Forward Flow Expansion was calculated from the expected
additional compression requirements for the incremental capacity based on the winter peak day design scenario as illustrated in the flow diagrams (Exhibit G/GI
Forward Flow).
To derive to the incremental fuel and electric power for the Project, Texas Eastern has compared compression requirements according to the flow diagram
under winter peak day operation with existing facilities as currently configured (Exhibit G – Base System, Sheets 1 to 14) and the flow diagram with existing
facilities combined with the full project forward haul volume (300 MDth/D) and proposed facilities (Exhibit G – Expansion System, Sheets 1 to 14). The
incremental fuel and electric power cost were then calculated based on the incremental compression requirement from this comparison between the Base and
Expansion systems.
Based on this comparison, Texas Eastern has determined a daily incremental fuel requirement of 5.299 MDth/D and an annual incremental electric power cost
estimate of $2,804,133 for the Forward Flow Expansion portion of the Project.
The incremental Project fuel shrinkage which includes LAUF associated with Forward Flow Expansion is calculated as follows:
Daily Design Fuel = 5.299 MDth
Volume Determinant = 300 MDth/D
Fuel Shrinkage = 5.299/ (300 +5.299) = 1.74%
LAUF (M2 - M3) = 0.66% (see note below)
Project Shrinkage (Forward Flow Expansion) = 1.74% + 0.66% = 2.40%
Incremental Fuel and EPC associated with Reverse Flow (300 MDth/D)
The incremental fuel and electric power for the TEAM 2014 Project (the Project) associated with the Reverse Flow Expansion was calculated from the expected
additional compression requirements for the incremental capacity based on a reverse flow day design scenario as illustrated in the flow diagrams (Exhibit G/GI
Reverse Flow). In order to establish the reverse flow design scenario, Texas Eastern utilized the recent trend of supply shift from traditional Gulf Coast area to
the Marcellus production area to assume no forward haul flow in the system from the Gulf Coast supply area to the point where Marcellus production comes into
the Texas Eastern system (around Holbrook area). The only flow in the reverse flow design scenario are existing firm "back haul" contracts and approximately
100 MDth/D of system requirement from M2 to the supply area. This establishes the reverse flow design day which is used to determine fuel and electric power
requirements for the reverse flow portion of the Project.
To derive to the incremental fuel and electric power for the Project, Texas Eastern has compared compression requirements according to the flow diagram
under this reverse flow design day operation with existing facilities as currently configured (Exhibit G – Base System, Sheets 1 to 20) and the flow diagram with
existing facilities combined with the full project reverse flow volume (300 MDth/D) and proposed facilities (Exhibit G – Expansion System, Sheets 1 to 20). The
incremental fuel and electric power cost were then calculated based on the incremental compression requirement from this comparison between the Base and
Expansion systems.
Based on this comparison, Texas Eastern has determined a daily incremental fuel requirement of 0.555 MDth/D and an annual incremental electric power cost
estimate of $238,975 for the reverse flow portion of the Project.
The incremental Project fuel shrinkage which includes LAUF associated with Reverse Flow Expansion is calculated as follows:
Daily Design Fuel = 0.555 MDth
Volume Determinant = 300 MDth/D
Fuel Shrinkage = 0.555/ (300 +0.555) = 0.18%
LAUF (M2 - M2/WLA/ELA) = 0.75% (see note below)
Project Shrinkage (Reverse Flow Expansion) = 0.18% + 0.75% = 0.93%
Blended Incremental Fuel and EPC for the entire Project Volume (600 MDth/D)
The combined, blended incremental Fuel and EPC for the entire Project volume of 600 MDth/D is calculated as follows:
Project Shrinkage (Both Forward and Reverse Expansion) = (2.40% + 0.93%) / 2 = 1.67%
Total Estimated Electric Power Cost (EPC) for Entire Project Volume = $2,804,133 + $238,975 = $3,043,108
Note :
LAUF (Lost and Unaccounted For) - The TEAM 2014 forward flow LAUF component (0.66%)is established as the currently effective mainline transmission
LAUF component for a Zone M2-M3 haul per the latest Annual ASA filing in Docket No. RP13-237, which became effective on December 1, 2012. The TEAM
2014 reverse flow LAUF component (0.75%) is likewise established as the weighted average of the currently effective mainline transmission LAUF
components for hauls between (i) Zones M2 and WLA, (ii) Zones M2 and ELA, and (iii) intra Zone M2.
Texas Eastern Transmission, LP
Docket No. CP13-___-000
Exhibit Z-2
Sheet 2 of 4
INCREMENTAL FUEL AND ELECTRIC POWER COST DERIVATION
TEAM 2014 PROJECT FORWARD HAUL (300 MDth/D)
Station
Uniontown
Delmont
Unit(s)
Cent - Mars 100 - Unit 1T
Cent - Mars 100 - Unit 2T
Electric - Unit 1E
Electric - Unit 2E
Electric - Unit 3E
Horsepower Utilized
Installed
"Base" "Expansion"
12,250
12,250
13,300
12,250
12,250
13,300
14,300
13,591
13,591
16,000
19,484
17,728
20,000
20,000
20,000
Difference
1,050
1,050
0
-1,756
0
Fuel rate
0.000274
0.000274
Fuel
Difference
0.288
0.288
N/A
-$210,747
Recip - KVG (6 x 1100 HP each)
Recip - KVS (4 x 2000 HP each)
Cent - Mars 100
Cent - Frame 5
Cent - Titan 250 - TEAM 2014
Electric - TEAM 2014
6,600
8,000
13,300
18,500
26,000
26,000
6,600
8,000
13,300
19,975
0
0
0
0
13,300
0
26,000
26,000
-6,600
-8,000
0
-19,975
26,000
26,000
0.000249
0.000249
-1.643
-1.992
0.000274
0.000229
N/A
-5.473
5.954
Armagh
Cent - Frame 5
Cent - Titan 130 - TEAM 2014
22,000
18,100
23,250
0
22,000
18,008
-1,250
18,008
0.000274
0.000229
-0.343
4.124
Lilly
Cent - W52
Cent - W52
Cent - DC990
Cent - Frame 5
5,000
5,000
5,000
19,800
5,300
5,300
5,300
21,000
5,000
5,000
5,000
19,800
-300
-300
-300
-1,200
0.000274
0.000274
0.000274
0.000274
-0.082
-0.082
-0.082
-0.329
Entriken
Cent - Frame 5
Cent - Titan 250 - TEAM 2014
22,000
26,000
23,250
0
22,000
22,489
-1,250
22,489
0.000274
0.000229
-0.343
5.150
Perulack
Cent - DC990
Cent - DC990
Cent - DC990
Cent - Frame 5
5,000
5,000
5,000
19,800
5,400
5,400
5,400
19,800
5,400
5,400
5,400
19,480
0
0
0
-320
0.000274
-0.088
Shermans Dale
Cent - Frame 5
Cent - Frame 5
19,800
22,000
19,800
22,000
18,960
22,000
-840
0
0.000274
-0.230
Grantville
Cent - W52
Cent - W52
Cent - DC990
Cent - Frame 5
5,000
5,000
5,000
18,500
5,000
5,000
5,000
18,500
5,000
5,000
5,000
19,123
0
0
0
623
0.000274
0.171
Bernville
Cent - Frame 5
Cent - Frame 5
19,800
22,000
19,800
22,000
19,800
22,000
0
0
Bechtelsville
Cent - W52
Cent - W52
Cent - DC990
Cent - Frame 5
5,000
5,000
5,000
18,500
5,000
5,000
5,000
18,500
5,000
5,000
5,000
18,500
0
0
0
0
Lambertville
Recip (2 x 2200 HP)
Cent - DC 990
Cent - DC 990
Electric Unit
4,400
5,100
5,100
10,000
3,419
5,175
5,175
10,000
3,633
5,100
5,100
9,124
214
-75
-75
-876
0.000249
0.000274
0.000274
N/A
0.053
-0.021
-0.021
Total Incremental Fuel (MDth/D)
Total Annual Electric Cost
Incremental Fuel (MDth/D)
TEAM Forward Flow Fuel % (5.299/(5.299+300))
TEAM Forward Flow LAUF (M2-M3)
Total TEAM Forward Flow Shrinkage
Annual
Electric Cost
$3,120,000
-$105,120
5.299
$2,804,133
5.299
1.74%
0.66%
2.40%
Texas Eastern Transmission, LP
Docket No. CP13-___-000
Exhibit Z-2
Sheet 3 of 4
INCREMENTAL FUEL AND ELECTRIC POWER COST DERIVATION
TEAM 2014 PROJECT REVERSE FLOW (300 MDth/D)
Difference
0
0
0
0
0
0
Fuel rate
0.000249
0.000249
0.000249
0.000274
0.000274
0.000265
Fuel
Difference
0.000
0.000
0.000
0.000
0.000
0.000
0
0
0
0
0
0
N/A
N/A
0.000274
0.000
0.000
0.000
0
0
0
0
0
0
N/A
N/A
0.000
0.000
7,700
10,600
0
0
0
0
0
0
0.000249
0.000274
0.000
0.000
Electric Motors (3 x 2000 hp each)
Solar Mars Gas Turbine
6,000
10,600
0
0
0
0
0
0
N/A
0.000274
0.000
0.000
Athens
GE Frame 3 Gas Turbines (4 x 8000 hp each)
32,000
0
0
0
0.000274
0.000
Wheelersburg
Electric Motors (6 x 2500 hp each)
Electric Motor (1 x 15,000 hp)
15,000
15,000
0
0
4,142
0
4,142
0
N/A
N/A
0.000
0.000
Owingsville
GE Frame 3 Gas Turbines (4 x 8000 hp each)
GE Frame 5 Gas Turbine
32,000
18,500
0
0
0
0
0
0
0.000274
0.000274
0.000
0.000
Danville
Recip - HBA-8 (7 x 1760 hp each)
Recip - HBA-8 T(3 x 2050 hp each)
GE Frame 3 Gas Turbines (2 x 8000 hp each)
GE Frame 5 Gas Turbine
12,320
6,150
16,000
18,500
0
0
0
0
0
0
0
0
0
0
0
0
0.000249
0.000249
0.000274
0.000274
0.000
0.000
0.000
0.000
Tompkinsville
Electric Motors (2 x 15500 hp each)
30,000
0
0
0
N/A
0.000
Gladeville
Electric Motors (6 x 2500 hp each)
Electric Motor (1 x 15,000 hp)
GE Frame 5 Gas Turbine
15,000
15,000
18,500
0
0
0
0
0
0
0
0
0
N/A
N/A
0.000274
0.000
0.000
0.000
Mt. Pleasant
Electric Motors (2 x 15,000 hp)
Electric Motor (1 x 20,000 hp)
30,000
20,000
0
0
0
0
0
0
N/A
N/A
0.000
0.000
Barton
Electric Motors (6 x 3000 hp each)
Electric Motor (1 x 20,000 hp)
GE Frame 5 Gas Turbine
18,000
20,000
19,800
0
0
0
0
0
0
0
0
0
N/A
N/A
0.000274
0.000
0.000
0.000
Egypt
Electric Motors (2 x 20,000 hp)
Electric Motor (1 x 15,000 hp)
40,000
15,000
0
0
0
0
0
0
N/A
N/A
0.000
0.000
Kosciusko
Recip - GMV-10-S (14 x 2500 hp each)
Electric Motor
35,000
16,875
0
0
0
5,417
0
5,417
0.000249
N/A
0.000
0.000
Clinton
GE Frame 3 Gas Turbines (4 x 7600 hp each)
30,400
0
0
0
0.000274
0.000
Union Church
Recip - HBA-8 T(9 x 2050 hp each)
Recip - TLA (4 x 3400 hp each)
18,450
13,600
0
0
0
2,357
0
2,357
0.000249
0.000249
0.000
0.588
St. Francisville
GE Frame 3 Gas Turbines (4 x 8000 hp each)
32,000
0
0
0
0.000274
0.000
Opelousas
Recip - HBA-8 T(9 x 2050 hp each)
18,450
4,092
3,960
-132
0.000249
-0.033
Gillis
GE Frame 3 Gas Turbine
GE Frame 3 Gas Turbine
7,600
8,000
0
0
0
0
0
0
0.000274
0.000274
0.000
0.000
Horsepower Utilized
Installed
"Base"
"Expansion"
5,400
0
0
5,400
0
0
8,000
0
0
13,333
0
0
13,333
0
0
13,333
0
0
Station
Holbrook
Unit(s)
Recip - GMV-10-S (4 x 1350 hp each)
Recip - GMVA-10 (4 x 1350 hp each)
Recip - KVS412 (4 x 2000 hp each)
Gas Turbine 1T
Gas Turbine 2T
Gas Turbine 3T
Berne
Electric Motors (6 x 2500 hp each)
Electric Motor (1 x 15,000 hp)
DC 990
15,000
15,000
5,100
0
0
0
Summerfield
Electric Motors (4 x 2000 hp each)
Electric Motors (1 x 11000 hp each)
8,000
11,000
Somerset
Recip - GMV-10 (7 x 1100 hp each)
Solar Mars Gas Turbine
Five Points
Total Incremental Fuel (MDth/D)
Total Annual Electric Cost
Incremental Fuel (MDth/D)
TEAM Reverse Flow Fuel % (0.555/(0.555+300))
TEAM Reverse Flow LAUF
Total Reverse Flow Shrinkage
Annual
Electric Cost
103,550
135,425
0.555
$238,975
0.555
0.18%
0.75%
0.93%
Texas Eastern Transmission, LP
Docket No. CP13-___-000
Exhibit Z-2
Sheet 4 of 4
INCREMENTAL FUEL AND ELECTRIC POWER COST DERIVATION
TEAM 2014 PROJECT (600 MDth/D)
SUMMARY
Percentage
Forward Flow (300 MDth/D)
Fuel
EPC
Reverse Flow (300 MDth/D)
Fuel
EPC
LAUF (Lost and Unaccounted For)
Forward Flow (M2 - M3)
Reverse Flow (M2 - M2/WLA/ELA)
Total Daily Fuel including LAUF
TEAM 2014 Fuel Shrinkage (600 MDth/D)
Total Annual Estimated EPC
EPC : Electric Power Cost
Dollars ($)
1.74%
$2,804,133
0.18%
$238,975
0.66%
0.75%
3.33%
1.67%
$3,043,108
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Z-3
Flow Diagrams and Cost Information for Alternatives
Enclosed under separate cover
in Volume IV.
This information has been marked
Contains Critical Energy Infrastructure Information—Do Not Release
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Z-4
Draft Environmental Assessment
Enclosed under separate cover
in Volume II.
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Z-5
Matrix of Information Incorporated into Resource Reports
Based on Commission Staff Comments
TEAM 2014 Project
FERC Resource Report Data Requests
Response Location/Comment
Resource Report 1
1. Indicate whether the access roads in table 1.3-2 are all existing roads. If not, please indicate which
access roads or portions of access roads are to be widened, improved or newly constructed for the
project.
2. Provide the geotechnical investigations for all of the proposed horizontal directional drill (HDD)
crossings for the Project as described in Section 1.5.2. Include a discussion about unanticipated
release potential when drilling in karst areas.
3. Identify the amount (feet and total acres) of overlap between existing right(s)-of-way and the
proposed construction and permanent rights-of-way.
Resource Report 1 Table 1.3-2 and Resource Report 8 Table 8.1-5 have been
updated to include the requested information.
updated Section 1.5.2 - geotech info to be provided supplemental
Table 1.3-1 provides temporary workspace, existing easement and new
easement acreage and has been updated to include the total acreage. Typical
figure 1 reference in text of Section 1.3.1
4. Identify all existing permanent access roads associated with each segment of pipeline that would Access Road Table 1.3-2 in Section 1.3.1 includes identification of permanent
be looped, and confirm that landowner permission would be obtained for all permanent access roads. access roads (existing and new). The Access Roads description within Section
1.31 includes a statement that landowner permission will be obtained for the
two new permenant access roads.
5. Identify and describe the locations of the proposed pipeyards and wareyards.
6. Confirm that all bi-directional facility modifications would take place entirely on Texas Eastern
owned or leased property.
7. Provide a table identifying the location, timeframe, and general scope of existing, approved,
under construction, and planned major projects (e.g., roads, bridges, mining, other pipeline project,
large commercial/industrial/residential developments) in the Project area. Do not limit the
identification of other projects to a narrow corridor around the project but, rather, consider the
location, scope, and timing of each project in determining whether it could have a cumulative impact
on the resources affected by the project. Provide a detailed discussion of cumulative impacts that any
identified projects and the project would have on each applicable environmental resource, and the
measures that Texas Eastern would implement to minimize cumulative impacts. (Repeated as
Question 1. from Staff's January 18, 2013 Comments )
Pipeyared and wareyard locations and descriptions can be found in Table 1.33, which has been added to Section 1.3.1
Section 1.3.3 - text has been updated to include information about work that
will occur outside of the Texas Eastern ROW.
Section 1.4 has been revised and now also includes Table 1.4-1 Cumulative
Projects.
Page 1 of 13
TEAM 2014 Project
FERC Resource Report Data Requests
8. Confirm that all applicable measures of the Erosion and Sediment Control Plan (E&SCP) would be
applied to stream pre-blasting activities and provide Appendix E: E&SCP.
9. Describe the process Texas Eastern would implement to resolve landowner complaints.
10. Identify how many environmental inspectors Texas Eastern would employ to ensure
environmental compliance during construction of the facilities.
11. Section 9.1.2.2 states that the project would include truck loading activities associated with the
Delmont Compressor Station. Provide a description of this activity including what material would be
loaded onto trucks and an estimate of how many trucks per year would be loaded with material.
Resource Report 2 - Water Use and Quality
1. Provide the following tables:
a. Waterbody Crossing Summary Table – number and types of waterbodies crossed by loop
(including project totals);
b. Wetlands Crossing Summary Table – number and types of wetlands crossed by loop (including
project totals);
c. Revised table 2.2-1 – remove “county/state”, “latitude/longitude”, “USGS quad name”, “class of
aquatic resources”, “impact type”, and “stream impact (sq ft)”; and
d. Revised table 2.3-1 – remove “county/state”, “hgm code”, “water type”, “latitude/longitude”,
“USGS quad name”, “watershed”, and “class of aquatic resources”.
Resource Report 3 - Fisheries, Vegetation, and Wildlife
1. Identify in table format the fish species commonly associated with each fisheries and waterbody
type.
2. Identify in table format the wildlife species commonly associated with each habitat type.
Response Location/Comment
Section 1.5.2, Pre-Blasting In Streams has been updated to confirm that any
blasting activities will be completed in accordance with the E&SCP.
Section 1.8 has been updated to include a summary of Texas Eastern's
process for resolving landowner concerns.
Section 1.5.5 has been updated to state that There will be a minimum of one
environmental inspector per construction spread.
Section 9.1.2.2 has been revised to state while truck loading activities were a
part of the Plan Approval they are no longer proposed as needed by
construction.
Table Added 2.2-3
Table Added 2.3-3
Edited Table 2.2-1 and 2.2-2
Edited Table 2.3-1 and 2.3-2
Edited Table 3.1-1
Edited Table 3.3-1
3. Revise table 3.3-1 so that it is consistent with the identified vegetation and habitat types.
Edited Table 3.3-1
4. Identify and describe the migratory bird species of special concern and their habitats known to
occur in the project area. Provide the following information:
Section 3.3.2 Migatory Birds was added
Page 2 of 13
TEAM 2014 Project
FERC Resource Report Data Requests
a. an evaluation of the short-term, long-term, and permanent impacts on these species of special
concern by construction and operation of the proposed facilities. The evaluation should include the
direct, indirect, and cumulative effects of the project;
b. project-specific conservation measures and best management practices, developed in
consultation with the U.S. Fish and Wildlife Service (FWS), to protect migratory birds and their habitats
and to avoid or minimize take; and
c. documentation of consultation with the FWS regarding project-related impacts on migratory bird
species of special concern.
5. Confirm that birds of conservation concern were accounted for in table 3.3-2.
6. Describe the feasibility of clearing natural or semi-natural habitats and performing maintenance
activities between September 1 and March 31.
Question 2. from Staff's January 18, 2013 Comments: Specifically address the concerns raised by the
United States Fish and Wildlife in the letter dated November 2, 2012.
Resource Report 6 – Geological Resources
1. In section 6.1.1, provide maximum and minimum slope angles for each proposed loop. Provide
length of slopes where slope angles exceed 37 degrees (75% grade) for each loop.
Response Location/Comment
additional text added to Section 3.3.3
additional text added to Section 3.3.3
additional text added to Section 3.3.3
Table 3.3-3 was added
Section 3.3.3 provides Texas Eastern's standard schedule that maintenance
activites will not occur April 15-August 1.
Section 3.3.2 Migatory Birds was added
Information has been added to Section 6.1.1 for each loop description
2. In Section 6.1, provide detailed geologic mapping for all of the loops and compressor stations
specifically identifying active or potentially active landslides which includes the following:
A landslide potential map was added as Figure 6.4-3; individual detail maps
were added as Figures 6.4-4 to 6.4-6
a. structural geology (such as bedding attitudes);
b. discussion of how landslides in adjacent slope could affect the pipeline or facility;
c. identify by milepost which landslides may pose a threat to the pipeline and how that specific
hazard will be mitigated. Also provide follow-up discussion in Section 6.4.4 and 6.4.5;
Section 6.4.5 has been updated.
Information added to intro of Section 6.4.5
Table 6.4.3 Areas with Potential for Increased Landslides Hazard was added
to Section 6.4.5 and Sections 6.4.4 and 6.4.5 have been updated.
d. provide more detail discussion regarding landslide potential along the Holbrook Loop; and
Discussion added to Holbrook Loop section of 6.4.5
e. evaluation of the potential for landslides to affect proposed access roads.
3. In Section 6.1.2 describe or clarify the following:
a. each compressor station site’s vertical relief and slope configuration;
Discussion added to intro of 6.4.5
Information has been added to Section 6.1.2
Page 3 of 13
TEAM 2014 Project
FERC Resource Report Data Requests
b. describe slope stability of immediately adjacent ascending and descending slopes from the
facility;
c. state if grading will be required to build the compressor modifications and how much cut and/or
fill is planned for each; and
d. describe if modifications to the slopes are anticipated.
4. Section 6.2 states that blasting will be required. Provide a blasting plan for the Project.
Response Location/Comment
Information has been added to Section 6.1.2
Information has been added to Section 6.1.2
Information has been added to Section 6.1.2
Information has been added to Section 6.2.1.
5. Section 6.4.4 stated that research identified karst sinkholes which are located within 0.25 miles Karst location map added as figure 6.4-2 and discussion was added to the
of the Bernville Loop. Perform detailed field mapping to investigate the presence of possible karst
individual segments in 6.4.4 including past experience.
features (sinkholes, swallets, etc.) in the area of the Bernville Loop as well as all other loops and all
compressor station locations. Also evaluate if any significant dewatering has been performed in these
areas (from quarries or other operations). Include past existing pipeline performance data for the
parallel pipelines adjacent to proposed loops.
6. As part of Section 6.4.4, provide a detailed map which shows the location of the proposed
pipeline loops and compressor stations on the Pennsylvanian state karst density map.
map included as figure 6.4-2
7. In Section 6.4.5, describe any grading or slope modification proposed in the Fayette County Ware Added to Section 6.4.5 under "Pipeyards and Wareyards"
Yard.
8. In Section 6.4.6, identify Project sites or proposed loops that are located within a 100 year flood Added to Section 6.4.6 and the alignments
zone and depict boundaries of the flood zone on alignment sheets.
Resource Report 7 – Soils
1. Under Section 7.0, identify any contaminated soil locations within the Project.
Added information under section 7.2.6 and referenced Resource Reports 2
and 12.
2. Identify what percentage of the Project area is prime farmland and farmland of state-wide
Information included under Section 7.3
importance.
3. Given the history of oil and gas exploration and production in the region, discuss the potential for This comment is addressed in section 7.2.6.
surficial soil and/or shallow groundwater contamination along the pipeline route and provide an
unanticipated discovery plan if soil and/or shallow groundwater contamination is encountered during
construction and construction dewatering activities.
Page 4 of 13
TEAM 2014 Project
FERC Resource Report Data Requests
4. Provide a discussion of the consultation with local conservation authorities and government land
agencies with respect to their recommendations/requirements for seed mixes, seeding dates,
fertilizer, erosion control, and noxious weed control.
Resource Report 8 – Land Use
1. Provide site-specific residential construction plans for residences with 50 feet of the construction
work area. These will be attached to the environmental assessment as an appendix and should be
filed with the application.
2. For those access roads or portions of access roads identified in table 1.3-2 that would be newly
constructed for the project, please provide the current land use and type of vegetation for these
areas.
3. In table 8.2-1 the distances from some of the structures are several hundred feet to the
centerline, but within 50 feet of workspace. Add a column to the table that defines the type of
workspace if it not directly along the pipeline construction right-of-way (i.e. contractor yards and
access roads).
Resource Report 9 – Air and Noise Quality
1. Include a table identifying all existing emission sources at each compressor station.
Response Location/Comment
NRCS consultation discussed in Section 7.4
Site-specific residential plans have been added to RR8.
Section 8.1.5 has been updated to provide the requested information.
Table 8.2-1 has been updated to include a column for workspace location.
Tables have been added that list each existing emission source for each
compressor station in RR9 Section 9.0 under station headings
2. Provide a table identifying each existing compressor unit at each compressor station. Include the Tables have been added that identify each existing compressor unit at each
type (reciprocating, turbine), horsepower, and fuel type for each unit.
station with request information in RR9 Section 9.0 under appropriate
compressor station headings.
3. Update table 9.1-2 of Resource Report 9 to include the attainment status of all Project
Information to be provided in a Supplemental submission.
component locations, including pipeline loops, meter stations, launcher and receivers, main line
valves, etc. Provide the appropriate level of clarity as some counties can be included in different Air
Quality Control Regions for various non-attainment pollutants.
4. Provide the emission estimates associated with the fuel gas heaters proposed at the Uniontown
Compressor Station. Include detailed emission calculations to support the emission estimates.
Discussion was added addressing the exemption criteria that the fuel gas
heaters fall under. Emission estimates were included to reflect what was in
the Plan Approval application
Page 5 of 13
TEAM 2014 Project
FERC Resource Report Data Requests
Response Location/Comment
5. Include a discussion on the applicability of New Source Performance Standard Subpart Kb for the Discussion of NSPS and NESHAP applicability to storage tanks and truck
Delmont Compressor Station related to the pressure vessels and storage tanks proposed to be
loading at Delmont is addressed in Section 9.1.3.2.
installed. Also provide a discussion on the applicability of National Emission Standard for Hazardous
Air Pollutants Subpart EEEE related to truck loading activities.
6. Include a discussion for each compressor station of the potentially applicable NESHAPs (including Discussion of NESHAP applicability is addressed in Sections 9.1.3.1 thru
subparts YYYY and ZZZZ).
9.1.3.4.
7. Revise table 9.1-3 to include a per pollutant breakdown, for each compressor station, of the
Information to be provided in a Supplemental submission.
existing emissions associated with each emission source, the new emissions associated with the
Project for each emission source, the new total emissions from the facility, and the net change in
emissions. The emissions should include all emission sources, even those exempt from permitting.
8. Revise tables 9.1-4A and 9.1-4B to provide construction emissions for all facilities associated with Information to be provided in a Supplemental submission.
the project, including those listed in Tables 1.2-3 and 1.2-4. Provide the supporting detailed emission
calculations.
9. Provide an air modeling screening analysis (AERSCREEN) for operating emissions for existing and Information to be provided in a Supplemental submission.
proposed emissions from each compressor station for both Class II and Class I areas for criteria
pollutants. Provide the distance from the compressor stations and pipelines to the nearest Class I
areas and demonstrate that emissions from pipeline construction and operations would not
significantly impact air quality on Class I areas within 100 kilometers. Include all correspondence with
the appropriate Federal Land Manager(s) regarding air quality as necessary.
Page 6 of 13
TEAM 2014 Project
FERC Resource Report Data Requests
Response Location/Comment
10. General Conformity applies to all portions of the project located within designated nonInformation to be provided in a Supplemental submission.
attainment or maintenance areas. Although a non-attainment or maintenance area may also be
within the Ozone Transport Region (OTR) and are subject to more stringent thresholds, project
facilities located within an attainment area and the OTR do not fall within General Conformity
regulations. In addition, only portions of a facility subject to a New Source Review, Non-attainment
New Source Review, or minor New Source Review permit are exempt from General Conformity. If a
source at a compressor station is exempt from permitting or is not subject to one of these types of
permits, it is subject to General Conformity. Update Section 9.1.5.1 to rectify these facility
applicability errors in the text to reflect the appropriate project facilities that are subject to General
Conformity review and the General Conformity Applicability Analysis provided. Also, Update Table 9.15 and 9.1-6 to include all project facilities including the compressor stations and those facilities listed
in Tables 1.2-3 and 1.2-4.
11. Update Section 9.1.5.2 (Cumulative Impacts) to address other projects or facilities besides the
Information to be provided in a Supplemental submission.
Project facilities. Identify any other existing or proposed PSD facilities in proximity to each compressor
station and the cumulative impact their operation. Identify any other construction activities near the
compressor stations or pipeline (other energy infrastructure, road projects, housing development
construction, etc.) and the cumulative impact of their construction.
12. For each compressor station, Resource Report 9 identifies potential noise control mitigation which A statement has been added to each noise control mitigation section in
match those identified in the Hoover and Keith, Inc reports. Clarify whether Texas Eastern commits to report confirming mitigation measures will be implemented.
implementing these noise control mitigation measures. Also identify whether the projected noise
levels for the compressor station assumes these measures are implemented.
13. Provide copies of all supporting background sound surveys for each compressor station as
identified in each Hoover & Keith, Inc. Acoustical Analysis (Report Nos. 2551, 1750, 2454, 1779, and
1751).
Information is included in Appendix L
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14. Clarify whether the current sound levels provided for the Uniontown Compressor Station include
units 1R – 4R. Although these units do not run frequently, if they are included as part of the FERC
certificated capacity of the compressor station, and can be run during peak flow, they should be
included in the noise analysis.
15. Update table 1 of the Hoover and Keith report for the Delmont Compressor Station to include the
in-service date for each compressor unit. Also, provide one horsepower rating type for all compressor
units (i.e. NEMA, ISO, bhp).
16. Update the Hoover and Keith report for the Delmont Compressor Station to include a description
of the methodology used to calculate the existing compressor station contribution minus the
retirement of Units 2T and Units #1-6. The summary table and Table 1 of the report do not appear to
take into account whether actual ambient conditions (i.e. birds, traffic, insects etc.) are the
contributing factor to the ambient conditions or the existing compressor station with all units running.
For example, at Noise Sensitive Area (NSA) 2, which is the furthest set of NSAs, an almost overall 8
decibel reduction is projected. However, no indication is provided whether the existing units are
currently audible at this location. The background noise level is also currently the highest at this
location while being the furthest from the compressor station, which also indicates that other factors
may be contributing to the ambient noise over the compressor station.
Response Location/Comment
Statement added to Uniontown CS section in RR9 Noise Section 9.2.4.1. Units
1R – 4R were retired. As a result, potential noise of Units 1R – 4R should not
be included in the noise analysis.
Information is included in Appendix L. Section 3.0 of H&K Report No. 2711
(dated Jan. 11, 2013), discusses in-service dates (or lack of this information).
Also, NEMA HP ratings for units included.
Information is included in Appendix L. Section 4.0 of H&K Report No. 2711
(dated Jan. 11, 2013), discusses the methodology to calculate station noise
minus retirement of Unit 2T and Units #1-#6. Regarding influence of actual
ambient noise (i.e., birds, traffic), the station noise was considered the
primary noise contributor at all identified NSAs, and primary factor that
affects station noise contribution at NSAs is existing terrain. For example,
NSA #2 is in direct line-of- sight with Unit 2T and noise of Unit 2T, during
operation, is the major noise contributor to noise level at NSA #2. As a result,
after Unit 2T is retired, there will be a substantial decrease in the overall
station noise at NSA #2 but the effect of station noise reduction after Unit 2T
retirement is less at other NSAs.
17. Update the Hoover and Keith reports for the Armagh and Entriken Compressor Stations to include Information is included in Appendix L. Section 3.0 of H&K Report No. 2710 for
a table of each existing compressor unit, the manufacturer, unit type and model, fuel source,
Entriken (dated Jan. 7, 2013) & Section 3.0 of H&K Report No. 2713 for
horsepower (using the same rating methodology for all units), and in-service dates.
Armagh (dated Jan. 7, 2013) discusses in-service dates and NEMA HP ratings
for the station compressor units.
18. The Hoover and Keith reports for the Delmont, Armagh, and Entriken Compressor Stations states Information is included in Appendix L. Respective H&K reports for Delmont,
that there would also be an added “maintenance” type of gas blowdown vent associated with the
Armagh and Entriken includes noise analysis of the maintenance gas
compressor units. Provide a noise analysis associated with this maintenance blowdown identifying the blowdown event and whether blowdown venting will include a silencer.
projected noise level at the nearest NSAs for each compressor station and identify whether the
blowdowns would be piped to a silencer.
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Response Location/Comment
19. Provide a noise analysis, including all supporting detailed calculations, for all NSAs within one-half Appendix L and new section 9.2.4.6 added to RR9. Currently, there will be
mile of each HDD entry and exit site. This analysis should include:
one (1) HDD associated with the Project (i.e., HDD at Schuylkill River) and
H&K Report No. 2798 (dated Jan. 7, 2013) provides an acoustical assessment
of this HDD.
a. the distance and direction to the NSAs and the proposed length of time HDD activities would
Distance/direction of identified closest NSAs included in Section 2.0 of the
occur;
respective H&K report. Updated Section 9.2.4.6 to include HDD duration.
b. a plot plan showing the distance and direction of the nearest NSAs;
Information is included in Appendix L (Page 6 of the respective H&K report)
and summary in section 9.2.4.6
Information is included in Appendix L (Section 5.0 the respective H&K report)
c. background noise levels and estimated drilling noise contributions at the NSAs;
d. any noise mitigation measures Texas Eastern would commit to implement at each HDD entry or
exit location where estimated drilling noise contributions would exceed a day/night sound level (Ldn)
of 55 decibels (dBA), and the projected resulting noise levels with the mitigation measures employed;
and
Question 3 from Staff's January 18, 2013 Comments: Provide a description of the potential cumulative
effects on air and noise resulting from the construction and operation of the TEAM 2014 Project in
Pennsylvania.
Resource Report 10 – Alternatives
4. Provide detailed flow diagrams and hydraulic flow models to support Texas Eastern’s TEAM 2014
Project as currently contemplated.
Statement added to each noise control mitigation section in report
confirming mitigation measures will be implemented.
Information to be provided in a Supplemental submission.
Attachment B of Texas Eastern's February 6, 2013 Response
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5. Discuss the system operational reasons for Texas Eastern rejecting the following alternatives:
Response Location/Comment
Attachments C and D of Texas Eastern's February 6, 2013 Response
a. expanding the Capacity Restoration Project (CRP) system. Also, compare and contrast the future
expandability of the Penn-Jersey system versus the CRP system; and
b. using the Penn-Jersey and CRP systems nearly equally, differing by consideration for volumes to be
delivered at a point along the CRP system at Marietta, Pennsylvania.
Support the response with detailed flow diagrams and hydraulic flow models.
6. Gas Supply Consulting, Inc. (GSC) identified four system alternatives in ConocoPhillips November 2,
2012 comments in response to the “Notice of Intent to Prepare an Environmental Assessment for
Texas Eastern and Appalachia Market Expansion Project 2014 and Request for Comments on
Environmental Issues.”
Attachments C and D of Texas Eastern's February 6, 2013 Response
Assess and describe the feasibility of the alternatives proffered by GSC. Specifically discuss the
operational feasibility of each study in meeting the desired operational flexibility of Texas Eastern’s
TEAM 2014 Project. Texas Eastern’s evaluation of each alternative should be supported by detailed
flow diagrams and hydraulic models.
7. Identify and describe system alternatives that incorporate GSC’s inclusion of various levels of
turnback capacity from ConocoPhillips. These alternatives should address:
Attachments C and D of Texas Eastern's February 6, 2013 Response
a. expanding the CRP system; and
b. using the Penn-Jersey and CRP systems nearly equally, differing by a consideration for volumes to be
delivered at a point along the CRP system at Marietta, Pennsylvania.
Support the response with detailed flow diagrams and hydraulic flow models.
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Response Location/Comment
8. Provide the information below for each system alternative identified in Question 5:
Attachments C and D of Texas Eastern's February 6, 2013 Response
a. pipeline location(s), diameter(s) and length(s);
b. compressor station locations, and descriptions of these facilities (including horsepower and turbine
type);
c. acres of land temporarily and permanently required to construct and operate the alternative;
d. number of wetland and waterbodies crossed;
e. types and acres of vegetation potentially affected;
f. number of residences located within 50 feet of proposed construction workspaces;
g. the right-of-way (in miles) that facilities would parallel or be adjacent to existing rights-of-way;
h. sensitive areas; and
i. cultural resources.
The information should be provided in table format, comparing each system alternative to the
proposal. Texas Eastern may supplement its response with additional information/text that may be
relevant to the analysis of the system alternatives.
9. Specifically describe the potential scheduling, permitting and costs impacts associated with the
Attachments C and D of Texas Eastern's February 6, 2013 Response
development of the CRP system alternative in more detail, as identified in Section 10.2 of RR 10. Also,
describe these impacts as they apply to Question 8 of this request.
10. Clarify terminology used in alternatives and explain how this information was utilized in the
assessment. Specific terminology that is unclear:
a. In Section 10.2.1 Holbrook Discharge Pipeline – “high compression ratios”;
10. Clarify terminology used in alternatives and explain how this information was utilized in the
assessment. Specific terminology that is unclear:
b. in Section 10.2.9 Delmont Compressor Station – “the pressure gradient profile”; and
Section 10.2.1 of Resource Report 10
Section 10.2.9 of Resource Report 10
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10. Clarify terminology used in alternatives and explain how this information was utilized in the
assessment. Specific terminology that is unclear:
c. in Section 10.2.10 Armagh Compressor Station and Section 10.2.11 Entriken Compressor Station–
“improved compressor balance.”
11. Provide tables that compare the following:
Response Location/Comment
Section 10.2.10 of Resource Report 10
Table 10.2-1 of Resource Report 10
a. the proposed 2.7-mile Perulack West Discharge Pipeline and the 4.5-mile alternative identified in
Section 10.2.2 of RR 10; and
The table should address items a – i identified in Question 8 of this request.
11. Provide tables that compare the following:
b. the proposed 2.4-mile Grantville West Discharge Pipeline and the 5.0-mile alternative identified in
Section 10.2.5 of RR 10.
12. Identify and describe pipeline looping and/or compression alternatives that would satisfy the
purpose of the Project, but may not include construction of one or more of the following:
Table 10.2-2 of Resource Report 10
Section 10.2.3 of Resource Report 10
a. the Perulack East Discharge Pipeline;
12. Identify and describe pipeline looping and/or compression alternatives that would satisfy the
purpose of the Project, but may not include construction of one or more of the following:
Section 10.2.4 of Resource Report 10
b. the Shermans Dale Discharge Pipeline;
12. Identify and describe pipeline looping and/or compression alternatives that would satisfy the
purpose of the Project, but may not include construction of one or more of the following:
Section 10.2.4 of Resource Report 10
c. the Grantville East Discharge Pipeline; and
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12. Identify and describe pipeline looping and/or compression alternatives that would satisfy the
purpose of the Project, but may not include construction of one or more of the following:
Response Location/Comment
Section 10.2.7 of Resource Report 10
d. the Bernville Discharge Pipeline.
13. Identify and describe a pipeline route alternative that would avoid impacts to the Beaumariage
property and compare to the proposed route. Address items a – i identified in Question 8 of this
request in your response.
14. Identify the locations of known (ongoing or planned) long wall mining activities underlying the
Holbrook Loop alternative identified in Section 10.3.1 of RR 10. Also, identify the percentage of the
5.8-mile alternative that would be underlain by long wall mining activities.
Resource Report 11 – Reliability and Safety
1. Identify the US Department of Transportation Class locations and High Consequence Areas by
milepost along the pipeline loops.
Section 10.3.2 of Resource Report 10
Section 10.2.1 of Resource Report 10
shown on alignments / referenced in RR11
Page 13 of 13
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Notice
UNITED STATES OF AMERICA
FEDERAL ENERGY REGULATORY COMMISSION
Texas Eastern Transmission, LP
)
Docket No. CP13-___-000
ABBREVIATED APPLICATION OF
TEXAS EASTERN TRANSMISSION, LP
FOR A CERTIFICATE OF PUBLIC CONVENIENCE AND NECESSITY
AND FOR RELATED AUTHORIZATIONS AND
ORDER APPROVING ABANDONMENT
(
)
Take notice that on February 27, 2013, Texas Eastern Transmission, LP (“Texas
Eastern”), 5400 Westheimer Court, Houston, Texas 77056, filed with the Federal Energy
Regulatory Commission an application under Sections 7(b) and 7(c) of the Natural Gas
Act (“NGA”) for its proposed TEAM 2014 Project. Specifically, Texas Eastern requests:
(i) authorization under NGA Sections 7(b) and 7(c) to construct, own, operate, and
maintain certain pipeline and compression facilities and related appurtenances and to
abandon in place certain compression facilities necessary to increase capacity on the
Texas Eastern system by 600,000 dekatherms per day from supply points in the
Marcellus Shale region to delivery points in New York, New Jersey, Ohio, Mississippi
and Louisiana; (ii) authority to charge initial incremental recourse rates for firm service
on the TEAM 2014 Project facilities and existing system rates for interruptible service on
such facilities; and (iii) any waivers, authority, and further relief as may be necessary to
implement the proposal contained in its application.
Texas Eastern requests that the Commission grant the requested authorizations
and related approvals on or before November 21, 2013. Texas Eastern states that issuing
an order by this date will help to ensure that the TEAM 2014 Project is in service by
November 1, 2014, in time to meet the transportation needs of the TEAM 2014 Project
shippers and to ensure that the additional capacity is available as the TEAM 2014 Project
shippers’ production comes on line.
The name, address, and telephone number of the person to whom correspondence
and communications concerning this Application should be addressed is:
Berk Donaldson
Director, Rates and Certificates
Texas Eastern Transmission, LP
P.O. Box 1642
Houston, Texas 77251-1642
Phone: (713) 627-4488
Fax: (713) 627-5947
Any person desiring to intervene or to protest this filing must file in accordance
with Rules 211 and 214 of the Commission’s Rules of Practice and Procedure (18 C.F.R.
§§ 385.211 and 385.214). 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 notice of intervention or
motion to intervene, as appropriate. Such notices, motions, or protests must be filed on
or before the comment date. Anyone filing a motion to intervene or protest must serve a
copy of that document on the Applicant. On or before the comment date, it is not
necessary to serve motions to intervene or protests on persons other than the Applicant.
The Commission encourages electronic submission of protests and interventions
in lieu of paper using the “eFiling” link at http://www.ferc.gov. Persons unable to file
electronically should submit an original and 14 copies of the protest or intervention to the
Federal Energy Regulatory Commission, 888 First Street, N.E., Washington, D.C. 20426.
This filing is accessible on-line at http://www.ferc.gov, using the “eLibrary” link
and is available for review in the Commission’s Public Reference Room in Washington,
D.C. There is an “eSubscription” link on the web site that enables subscribers to receive
email notification when a document is added to a subscribed docket(s). For assistance
with any FERC Online service, please email FERCOnlineSupport@ferc.gov, or call
(866) 208-3676 (toll free). For TTY, call (202) 502-8659.
Comment Date: 5:00 pm Eastern Time on [INSERT DATE].
Kimberly D. Bose
Secretary
US 1735967v.23
2