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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 CourtHouston, TX 77056-5310
713.627.5400 main
Mailing Address:P.O. Box 1642
Houston, TX 77251-1642
February 27, 2013
Ms. Kimberly D. Bose, SecretaryFederal Energy Regulatory Commission888 First Street, N.E.Washington, D.C. 20426
Re: Texas Eastern Transmission, LP, Docket No. CP13-___-000Abbreviated Application for a Certificate of Public Convenience and Necessity and forRelated Authorizations and Order Approving Abandonment
Dear Ms. Bose:
Texas Eastern Transmission, LP (“Texas Eastern”) hereby submits for filing with theFederal Energy Regulatory Commission (“Commission”) an Abbreviated Application for aCertificate of Public Convenience and Necessity and for Related Authorizations and OrderApproving Abandonment (“Application”) regarding its proposed Texas Eastern Appalachia toMarket Project 2014 (“TEAM 2014 Project” or “Project”). The TEAM 2014 Project is aproduction-driven project designed to provide the pipeline capacity necessary to deliverproduction from the emerging Marcellus Shale play to diverse markets in the Northeast,Midwest, Southeast and Gulf Coast. The Project responds to significant interest from MarcellusShale producers who require firm pipeline capacity as their production comes on line. TheProject involves modifications of Texas Eastern’s existing facilities in Pennsylvania, WestVirginia, Ohio, Kentucky, Tennessee, Alabama, and Mississippi.
Included herewith are four volumes. Volume I contains public information and iscomprised of the Application and its public exhibits, except Exhibits F-I and Z-4. Volume IIcontains the public version of Exhibit F-I and Exhibit Z-4. Volume III contains privileged andconfidential information and is comprised of Appendix F (landowner and stakeholder lists),Appendix J (cultural resource survey reports), Exhibit I (confidential market data), and electronicversions of the hydraulic models supporting Exhibit G. Volume IV contains Critical EnergyInfrastructure Information (“CEII”) and is comprised of Appendix B (plot plans), Exhibits G, G-I, G-II, and Exhibit Z-3.
Pursuant to the Commission’s guidelines for eFiling,1 Texas Eastern is hereby eFiling theApplication and will provide two complete copies of the Application to OEP Room 62-46 andone complete copy to OGC-EP Room 101-66. Volume IV is marked “CONTAINS CRITICALENERGY INFRASTRUCTURE INFORMATION—DO NOT RELEASE”2 and should betreated 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, SecretaryFebruary 27, 2013Page 2
only and not to be released to the public.3 Volume III is marked “CONTAINS PRIVILEGEDINFORMATION—DO NOT RELEASE.”4 Privileged information should be treated asconfidential 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. CollinsAssociate General CounselTexas Eastern Transmission, LPP.O. Box 1642Houston, Texas 77251-1642Phone: (713) 627-6137Fax: (713) 989-3191Email: mfcollins@spectraenergy.com
The hydraulic models contain both CEII and PRIVILEGED AND CONFIDENTIALinformation. Texas Eastern notes that the Commission’s eFiling system does not include theability to designate files as both CEII and privileged and confidential. Accordingly, TexasEastern is marking these hydraulic model files as privileged and confidential for eFilingpurposes, but Texas Eastern requests both CEII and privileged and confidential treatment for thefiles.
In accordance with Rule 2011(c)(5) of the Commission’s Rules of Practice andProcedure, 18 C.F.R. § 385.2011(c)(5), I hereby state that I have read the hard copy version ofthe filing and am familiar with the contents thereof; that the paper copies contain the sameinformation as the electronic media; and that all of the statements contained therein are true andcorrect, 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 AMERICABEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
Texas Eastern Transmission, LP ) Docket No. CP13-____-000
ABBREVIATED APPLICATION OFTEXAS EASTERN TRANSMISSION, LP
FOR A CERTIFICATE OF PUBLIC CONVENIENCE AND NECESSITYAND FOR RELATED AUTHORIZATIONS AND
ORDER APPROVING ABANDONMENT
UNITED STATES OF AMERICABEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
Texas Eastern Transmission, LP ) Docket No. CP13-____-000
ABBREVIATED APPLICATION OFTEXAS EASTERN TRANSMISSION, LP
FOR A CERTIFICATE OF PUBLIC CONVENIENCE AND NECESSITYAND 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 pre-
filing 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).
2
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
3
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 priorto the in-service date of the TEAM 2014 Project.
4
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 DonaldsonDirector, Rates and CertificatesAustin C. IsenseeAnalyst, Rates and CertificatesTexas Eastern Transmission, LPP.O. Box 1642Houston, Texas 77251-1642Phone: (713) 627-4488Fax: (713) 627-5947Email: bdonaldson@spectraenergy.com
*Marcy F. CollinsAssociate General CounselTexas Eastern Transmission, LPP.O. Box 1642Houston, Texas 77251-1642Phone: (713) 627-6137Fax: (713) 989-3191Email: mfcollins@spectraenergy.com
and
*James D. SeegersJames E. OlsonSabina D. WaliaSuzanne E. ClevengerVinson & Elkins L.L.P.1001 Fannin, Suite 2500Houston, Texas 77002Phone: (713) 758-2939Fax: (713) 615-5206Email: jseegers@velaw.com
* Texas Eastern requests that these persons be included on the Commission’s officialservice list.
5
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
6
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), orderfurther clarifying Statement of Policy, 92 FERC ¶ 61,094 (2000).
7
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-milesegment 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 CompressorStation;
(iv) 6.1 miles total of new 36-inch pipeline loop in two segments (a 2.3-milesegment 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 inBerks County, Pennsylvania;
The compressor station modifications include the following:
(i) uprate of one existing 16,000 HP electric unit to 20,000 HP (by removingthe software restriction currently in place in order to allow the unit tooperate at its full service factor) and uprate of two existing 12,250 HPunits to 13,300 HP each (by exchanging existing engines for new enginescapable of greater horsepower) at Texas Eastern’s existing UniontownCompressor Station in Fayette County, Pennsylvania;
8
(ii) installation of one new 26,000 HP gas turbine compressor unit and onenew 26,000 HP electric motor-driven compressor unit at Texas Eastern’sexisting Delmont Compressor Station in Westmoreland County,Pennsylvania;
(iii) abandonment in place of one existing 18,500 HP gas turbine compressorunit and six 1,100 HP reciprocating gas compressor units for a totalabandonment of 25,100 HP at the Delmont Compressor Station inWestmoreland County, Pennsylvania;
(iv) installation of one new 18,100 HP gas turbine compressor unit at TexasEastern’s existing Armagh Compressor Station in Indiana County,Pennsylvania;
(v) installation of one new 26,000 HP gas turbine compressor unit at TexasEastern’s existing Entriken Compressor Station in Huntingdon County,Pennsylvania; and
(vi) installation of associated facilities, such as aero assemblies and coolingequipment, on existing gas compressor units at the Delmont, Uniontown,Armagh, and Entriken Compressor Stations, as more fully described inResource 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. No ground disturbance will be associated with the
abandonment. 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
9
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.
10
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 over-
building, 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.
11
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 ExistingCustomers 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.
12
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,
13
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 AdverseImpacts on Landowners and Communities Affected by the TEAM 2014Project.
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
14
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 ResidualAdverse 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 Easternwill also publish notice of the Application in relevant daily and/or weekly newspapers of generalcirculation. See 18 C.F.R. § 157.6(d)(1)(iii) (2012). In addition, Texas Eastern will place a copy of theApplication in the town or city hall and library of each municipality along the proposed route, therebyexceeding the Commission’s requirements. See 18 C.F.R. § 157.10(c) (2012).
15
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 andNecessity.
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 TEAM2014 Project shippers as the shippers’ Marcellus Shale production comeson line;
16
(ii) providing the necessary new capacity to enable new supplies of naturalgas from the Marcellus Shale to reach diverse regions and markets on theTexas Eastern system;
(iii) providing existing and new markets with diverse supply that promotesstability and reliability and better management of price volatility;
(iv) providing additional operational flexibility and reliability through theaddition of new compression and pipe on Texas Eastern’s system; and
(v) enhancing flexibility and reliability of service on the pipeline gridgenerally 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
17
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).
18
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 DelmontCompressor Station in western Pennsylvania to Texas Eastern’s Lambertville, New Jersey CompressorStation.
16 The CRP system extends from Texas Eastern’s Uniontown Compressor Station in western Pennsylvaniato 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 reverseopen seasons. See, e.g., PG&E Gas Transmission, 84 FERC ¶ 61,204, at 62,001 (1998) (finding that the
19
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-Canadaborder) 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, unwantedcapacity 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 notspecifically identify the other two shippers that participated in the Reverse Open Season.
20
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
21
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.
22
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
23
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., 141FERC ¶ 61,071 (2012), reh’g denied, 142 FERC ¶ 61,123 (2013).
24
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 in-
service 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 apoint off of the Marietta Extension, which is located on the CRP system. While Texas Eastern intended toexpand the Penn-Jersey system as part of the Project, Texas Eastern also could have expanded the CRPsystem up to the Marietta Extension without crossing the Delaware River and, therefore, deliveries at orupstream of the Marietta Extension could have been possible by the November 1, 2014 target in-servicedate for the Project. Ultimately, however, no receipt or delivery points on the CRP system were requestedas a result of the Open Season.
25
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 comparisonbetween Texas Eastern’s Project and ConocoPhillips’ hypotheticalproject.
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).
26
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 Penn-
Jersey 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 forcesand 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 itspipeline facilities to the unfettered judgment of the stockholders and directors of each natural gas companyinvolved.”); 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).
27
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 alsoMillennium 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 certaincircumstances, to require open-access transporters to construct interconnections, to direct natural gascompanies to extend facilities to serve a municipality or LDC, and to direct existing pipelines to expandoffshore 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 toserve a municipality or LDC.
30 See Panhandle v. FPC, 204 F.2d at 680 (“Congress meant to leave the question whether to employadditional capital in the enlargement of its pipeline facilities to the unfettered judgment of the stockholdersand directors of each natural gas company involved.”); see also Tennessee Gas Pipeline Co. v. ColumbiaGulf Transmission Co., 113 FERC ¶ 61,200, at PP 25-30 (2005); El Paso Natural Gas Co., et al., 104FERC ¶ 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 theinvestment capital for the purpose of enlarging pipeline facilities comes within that sphere. We can denythe proposed construction of facilities but except to the limited extent [NGA Section 7(a)] permits, wecannot require a company to risk its capital in a venture which in the exercise of its officers’ judgment, itconsiders unwise to undertake.”).
28
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 Penn-
Jersey 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 Penn-
Jersey 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
29
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.
30
E. The Commission Should Disregard Any Challenge by ConocoPhillips to theDesign 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.
31
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
32
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
33
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 Z-
2. 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, 129FERC ¶ 61,151 (2009); Texas Eastern Transmission, LP, 119 FERC ¶ 61,258 (2007); Texas EasternTransmission, LP, 99 FERC ¶ 61,383 (2002), order denying reh’g and granting clarification, 101 FERC ¶61,046 (2002).
32 Id.
34
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
35
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).
36
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. CP06-115-000and is incorporated herein by reference.
Exhibit B State Authorization
Omitted. Exhibit B has been filed in Docket No. CP06-115-000and 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 thisApplication.
Exhibit F Location of Facilities
Attached.
Exhibit F-I Environmental ReportAttached hereto in Volumes II through IV. Resource Report Nos.1 through 12 as specified in Sections 380.3 and 380.12 of theCommission’s regulations are included herewith. Appendicesfrom Resource Report 1 (landowner information) and ResourceReport 4 (cultural resource assessment) have been segregated andbound separately in Volume III and are labeled “ContainsPrivileged Information—Do Not Release.” Appendicescontaining Critical Energy Infrastructure Information have beensegregated and bound separately in Volume IV and are labeled
37
“Contains Critical Energy Infrastructure Information—Do NotRelease.”
Exhibits Gthrough G-II Flow Diagrams and Flow Diagram Data
Attached hereto as part of Volume IV and marked “ContainsCritical Energy Infrastructure Information—Do Not Release.”The confidential hydraulic models supporting Exhibits G throughG-II are available in electronic form only and are found inVolume III. Two sets of Exhibit G are included as part ofVolume IV. One set shows the forward-flow component of theProject, and the other set shows the reverse-flow component ofthe Project. With respect to the facilities accommodating thereverse-flow component of the Project, there have been nochanges with respect to the design of those facilities fortraditional forward flow. The facilities designed to accommodatethe forward-flow component are based on a winter peak daydesign, while the facilities designed for the reverse-flowcomponent are based on a reverse-flow design day. The twodesign day scenarios are mutually exclusive.
Exhibit H Total Gas Supply
Omitted. This information is contained in Section VI of thisApplication.
Exhibit I Market Data
Enclosed herewith under seal as part of Volume III and marked“Contains Privileged Information—Do Not Release.” Thisexhibit includes copies of the Precedent Agreements betweenTexas Eastern and the TEAM 2014 Project shippers.
Exhibit J Federal Authorizations
Attached. This exhibit identifies the following: each federalauthorization that the Project will require; the federal or stateagency or officer that will issue each required authorization; thedate each request for authorization was submitted; why anyrequest was not submitted and the date submission is expected;and the date by which final action on each federal authorizationhas been requested or is expected.
Exhibit K Cost of Facilities
Attached.
Exhibit L Financing
Omitted. Texas Eastern will finance the costs of the TEAM 2014Project through funds on hand and borrowings under short-termfinancing arrangements.
38
Exhibit M Construction, Operation and Maintenance
Omitted. Texas Eastern will construct or cause the proposedfacilities to be constructed, and will manage and operate theproposed 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 depreciationrate of 1.22% for the facilities proposed herein.
Exhibit P Tariff and Rates
Pro forma tariff records setting forth the proposed initialincremental recourse rates for the TEAM 2014 Project facilitiesare included herewith. In addition, Exhibit P includes the supportschedules for the derivation of such initial recourse rates.
Exhibit T Related Applications
Three of the six 1,100 HP reciprocating gas compressor unitsproposed for abandonment at the Delmont Compressor Stationwere certificated in Docket No. G-2341. The additional three1,100 HP reciprocating gas compressor units proposed forabandonment at the Delmont Compressor Station werecertificated in Docket No. G-9787. The 18,500 HP gas turbinecompressor unit proposed for abandonment at the DelmontCompressor Station was certificated in Docket No. CP81-4.
Exhibit U Contracts and Other Agreements
Omitted. No contracts or other agreements pertain to theabandonment of the facilities proposed herein.
Exhibit V Flow Diagram After Abandonment
Omitted. This exhibit is provided as part of Exhibits G throughG-II, which are attached hereto in Volume IV and marked“Contains Critical Energy Infrastructure Information—Do NotRelease.”
Exhibit W Impact on Customers
Omitted. No service to customers will be terminated by theabandonment of facilities proposed herein.
Exhibit X Effect on Existing Tariffs
Omitted. No effect upon any of Texas Eastern’s rate schedules ortariffs on file with the Commission will occur from granting the
39
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 SeasonNotice (Exhibit Z-1(b)), and related diagrams referenced inSection 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 SectionIV.C and IV.D.2 and in Resource Report 10, including theassociated costs for each alternative design, are attached hereto aspart of Volume IV and marked “Contains Critical EnergyInfrastructure Information—Do Not Release.”
Exhibit Z-4 Draft Environmental Assessment
Exhibit Z-5 Matrix of information in the Resource Reports reflectingCommission 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,
40
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 WFPformat. 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 regulationsbecause 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 andconfidential. Texas Eastern notes that the Commission’s eFiling system does not include the ability todesignate files as both CEII and privileged and confidential. Accordingly, Texas Eastern is marking thesehydraulic model files as privileged and confidential for eFiling purposes, but Texas Eastern requests bothCEII and privileged and confidential treatment for the files.
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, LLCAs General Partner to Texas Eastern Transmission, LP
Board of Managers:Theopolis HolemanJ. Patrick ReddyWilliam T. Yardley
Officers:William T. Yardley, PresidentBrian R. McKerlie, Vice President, Business Development, NortheastTransmissionJohn V. Adams, Vice President, Supply ChainGregory P. Bilinski, Vice President, Transmission ServicesGuy G. Buckley, Vice President and TreasurerFrederick S. (Steve) Bush, Vice President and ControllerAllen C. Capps, Vice PresidentStephen W. Craft, Vice PresidentJ. Andrew Drake, Vice President, Asset IntegrityTina V. Faraca, Vice President, Engineering and ConstructionRichard J. Kruse, Jr., Vice President, Regulatory and FERC Compliance OfficerJohn Thomas McCraw, Vice PresidentAllison McHenry, Assistant SecretaryJames M. Pruett, Vice PresidentPatricia M. Rice, Vice President and SecretaryDavid A. Shammo, Vice PresidentW. L. Whaley, Jr., Vice President, Gas ControlPaul K. Haralson, Assistant TreasurerThomas V. Wooden, Vice President, Field OperationsFulkra J. Mason, Vice President, Environmental, Health and SafetyJohn Bremner, Vice President, US Storage & Southeast Business DevelopmentGregg E. McBride, Vice President, Rates & CertificatesRichard 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 DSubsidiaries and Affiliates
Texas Eastern Transmission, LP is owned by:Spectra Energy Transmission Resources, LLC 99.00 %Spectra Energy Transmission Services, LLC 1.00 %, General Partner
Texas Eastern Transmission, LP owns:Texas Eastern Communications, Inc. 100.00 %Texas Eastern Terminal Company 100.00 %Spectra Energy Southeast Services, LLC 100.00 %
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit F
Location of Facilities
Texas Eastern Transmission, LPTEAM 2014 Project 7(b) and 7(c) Application ‐ Exhibit F ‐ Location of Facilities
Hunterdon County, NJ
Richmond County, NY
Multiple Receipts in:Greene/Fayette Counties PA &
Bi‐directional flow modificationsDelivery pointReceipt pointExisting TETLP system
Warren County, OH
Greene/Fayette Counties, PA &Marshall County, WV
Existing TETLP systemExisting station HP upgrades / additionsNew loop installationExisting station
Copiah County, MS
Acadia Parish, LA
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 K1 OF 42
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014
COST BASIS OF FACILITY ESTIMATES
The costs contained in this Exhibit K comprise a detailed estimate of the construction expenditures for the facilities proposedin 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 recentexperience and manufactures' catalogue information.
Each facility estimate includes contingency reflecting the possible extent that actual costs may exceed the direct estimatedvalues 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 K2 OF 42
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014
DESCRIPTION TOTAL
Compression $263,804,789
Pipeline $212,005,565
M & R $4,904,216
AFUDC $27,265,937
SUB TOTAL $507,980,507
Escalation $11,756,131
PROJECT TOTAL $519,736,638
EXHIBIT K3 OF 42
SUMMARY COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014
ITEM DESCRIPTIONCOMPRESSION 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
SUB TOTAL $278,700,829 $224,093,425 $5,186,253 $507,980,507
Escalation $5,584,166 $5,989,874 $182,091 $11,756,131
TOTAL PROJECT $284,284,995 $230,083,299 $5,368,344 $519,736,638
EXHIBIT K4 OF 42
NAME; TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014
DESCRIPTION TOTAL
Compression Facilities $284,284,995Pipeline Facilities $230,083,299Meter Station Facilities $5,368,344
PROJECT TOTAL $519,736,638
SUMMARY COST OF FACILITIES
EXHIBIT K5 OF 42
NAME; TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014
DESCRIPTION TOTAL
Holbrook Discharge Pipeline $42,650,756Bernville Discharge Pipeline $44,546,418Grantville Discharge Pipeline $44,788,969Perulack Discharge Pipeline $49,072,066Shermansdale Discharge Pipeline $43,547,619Launcher/Receiver Modifications - KY $1,076,030Launcher/Receiver Modifications - MS $1,740,434Launcher/Receiver Modifications - OH $973,914Launcher/Receiver Modifications - WV $181,632Launcher/Receiver Modifications - PA $436,916Launcher/Receiver Modifications - TN $894,548Launcher/Receiver Modifications - AL $173,997Armagh Compressor Sta. HP Addition $56,994,115Delmont Compressor Sta. HP Addition $100,942,093Delmont Compressor Sta. Retirement $1,052,897Entriken Compressor Sta. HP Addition $62,705,694Uniontown Compressor Sta. Upgrade $19,064,806Wheelersburg Compressor Sta. Upgrade $4,819,434Athens Compressor Sta. Upgrade $924,990Barton Compressor Sta. Upgrade $1,892,661Berne Compressor Sta. Upgrade $6,161,942Clinton Compressor Sta. Upgrade $944,156Danville Compressor Sta. Upgrade $3,267,711Egypt Compressor Sta. Upgrade $2,579,437Five Points Compressor Sta. Upgrade $889,750Gladeville Compressor Sta. Upgrade $846,681Holbrook Compressor Sta. Upgrade $1,021,964Kosciusko Compressor Sta. Upgrade $13,192,087Mt. Pleasant Compressor Sta. Upgrade $1,566,931Owingsville Compressor Sta. Upgrade $846,681Somerset Compressor Sta. Upgrade $842,236Summerfield Compressor Sta. Upgrade $2,882,048Tomkinsville Compressor Sta. Upgrade $846,681Chromatograph Installation - KY $1,493,139Chromatograph Installation - OH $959,273Chromatograph Installation - TN $2,169,364Chromatograph Installation - MS $746,568
PROJECT TOTAL $519,736,638
SUMMARY COST OF FACILITIES
EXHIBIT K6 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Holbrook Discharge Pipeline
ITEM DESCRIPTION PIPELINE
132 RIGHT OF WAY $1,962,236
133 RIGHT OF WAY DAMAGES $280,077
134 SURVEYS $1,253,458
135 MATERIALS $5,816,022
136 LABOR $18,716,125
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
SUBTOTAL $41,548,611
Escalation 3.05% $1,102,145
PROJECT TOTAL $42,650,756
EXHIBIT K7 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Bernville Discharge Pipeline
ITEM DESCRIPTION PIPELINE
132 RIGHT OF WAY $2,442,443
133 RIGHT OF WAY DAMAGES $727,255
134 SURVEYS $1,207,803
135 MATERIALS $5,799,872
136 LABOR $19,752,386
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
SUBTOTAL $43,395,287
Escalation 3.05% $1,151,131
PROJECT TOTAL $44,546,418
EXHIBIT K8 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Grantville Discharge Pipeline
ITEM DESCRIPTION PIPELINE
132 RIGHT OF WAY $2,027,376
133 RIGHT OF WAY DAMAGES $347,182
134 SURVEYS $1,304,306
135 MATERIALS $5,947,902
136 LABOR $20,596,350
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
SUBTOTAL $43,631,570
Escalation 3.05% $1,157,399
PROJECT TOTAL $44,788,969
EXHIBIT K9 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Perulack Discharge Pipeline
ITEM DESCRIPTION PIPELINE
132 RIGHT OF WAY $2,242,483
133 RIGHT OF WAY DAMAGES $272,218
134 SURVEYS $1,459,706
135 MATERIALS $6,465,914
136 LABOR $22,022,266
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
SUBTOTAL $47,803,986
Escalation 3.05% $1,268,080
PROJECT TOTAL $49,072,066
EXHIBIT K10 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Shermansdale Discharge Pipeline
ITEM DESCRIPTION PIPELINE
132 RIGHT OF WAY $1,966,191
133 RIGHT OF WAY DAMAGES $253,909
134 SURVEYS $1,255,890
135 MATERIALS $5,677,095
136 LABOR $19,709,928
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
SUBTOTAL $42,422,298
Escalation 3.05% $1,125,321
PROJECT TOTAL $43,547,619
EXHIBIT K11 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $56,532
146 CONTINGENCY $122,215
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $1,039,531
Escalation 4.04% $36,499
PROJECT TOTAL $1,076,030
EXHIBIT K12 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $91,438
146 CONTINGENCY $197,677
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $1,681,398
Escalation 4.04% $59,036
PROJECT TOTAL $1,740,434
EXHIBIT K13 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $51,170
146 CONTINGENCY $110,615
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $940,878
Escalation 4.04% $33,036
PROJECT TOTAL $973,914
EXHIBIT K14 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $9,542
146 CONTINGENCY $20,630
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $175,471
Escalation 4.04% $6,161
PROJECT TOTAL $181,632
EXHIBIT K15 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $192,162
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
SUBTOTAL $422,096
Escalation 4.04% $14,820
PROJECT TOTAL $436,916
EXHIBIT K16 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $46,998
146 CONTINGENCY $101,602
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $864,204
Escalation 4.04% $30,344
PROJECT TOTAL $894,548
EXHIBIT K17 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $9,141
146 CONTINGENCY $19,763
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $168,095
Escalation 4.04% $5,902
PROJECT TOTAL $173,997
EXHIBIT K18 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Armagh Compressor Sta. HP Addition
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $22,000
133 RIGHT OF WAY DAMAGES $25,000
134 SURVEYS $277,250
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 $75,000
148 OTHER SERVICES $282,055
SUBTOTAL $55,984,738
Escalation 2.07% $1,009,377
PROJECT TOTAL $56,994,115
EXHIBIT K19 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Delmont Compressor Sta. HP Addition
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $22,000
133 RIGHT OF WAY DAMAGES $25,000
134 SURVEYS $229,250
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 $75,000
148 OTHER SERVICES $1,334,555
SUBTOTAL $99,118,000
Escalation 2.09% $1,824,093
PROJECT TOTAL $100,942,093
EXHIBIT K20 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $452,961
137 ENGINEERING & INSPECTION $0
144 OVERHEAD $491,710
145 AFUDC $0
146 CONTINGENCY $85,658
147 LEGAL FEES $0
148 OTHER SERVICES $1,751
SUBTOTAL $1,032,080
Escalation 2.09% $20,817
PROJECT TOTAL $1,052,897
EXHIBIT K21 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Entriken Compressor Sta. HP Addition
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $22,000
133 RIGHT OF WAY DAMAGES $25,000
134 SURVEYS $292,250
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 $75,000
148 OTHER SERVICES $333,117
SUBTOTAL $61,595,164
Escalation 2.07% $1,110,530
PROJECT TOTAL $62,705,694
EXHIBIT K22 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Uniontown Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $22,000
133 RIGHT OF WAY DAMAGES $25,000
134 SURVEYS $199,250
135 MATERIALS $10,448,951
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 $0
148 OTHER SERVICES $20,000
SUBTOTAL $18,727,165
Escalation 2.07% $337,641
PROJECT TOTAL $19,064,806
EXHIBIT K23 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Wheelersburg Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $0
133 RIGHT OF WAY DAMAGES $0
134 SURVEYS $42,000
135 MATERIALS $762,751
136 LABOR $1,429,505
137 ENGINEERING & INSPECTION $948,513
144 OVERHEAD $473,471
145 AFUDC $253,198
146 CONTINGENCY $693,995
147 LEGAL FEES $0
148 OTHER SERVICES $52,527
SUBTOTAL $4,655,960
Escalation 4.04% $163,474
PROJECT TOTAL $4,819,434
EXHIBIT K24 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $48,596
146 CONTINGENCY $133,198
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $893,615
Escalation 4.04% $31,375
PROJECT TOTAL $924,990
EXHIBIT K25 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $99,435
146 CONTINGENCY $272,542
147 LEGAL FEES $0
148 OTHER SERVICES $204,069
SUBTOTAL $1,828,463
Escalation 4.04% $64,198
PROJECT TOTAL $1,892,661
EXHIBIT K26 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Berne Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $0
133 RIGHT OF WAY DAMAGES $0
134 SURVEYS $112,131
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 $0
148 OTHER SERVICES $291,084
SUBTOTAL $6,044,671
Escalation 4.04% $117,271
PROJECT TOTAL $6,161,942
EXHIBIT K27 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $49,603
146 CONTINGENCY $135,958
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $912,131
Escalation 4.04% $32,025
PROJECT TOTAL $944,156
EXHIBIT K28 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Danville Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $0
133 RIGHT OF WAY DAMAGES $0
134 SURVEYS $18,100
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
SUBTOTAL $3,156,871
Escalation 4.04% $110,840
PROJECT TOTAL $3,267,711
EXHIBIT K29 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Egypt Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $0
133 RIGHT OF WAY DAMAGES $0
134 SURVEYS $22,000
135 MATERIALS $429,518
136 LABOR $830,556
137 ENGINEERING & INSPECTION $424,174
144 OVERHEAD $233,040
145 AFUDC $96,113
146 CONTINGENCY $263,438
147 LEGAL FEES $0
148 OTHER SERVICES $218,544
SUBTOTAL $2,517,383
Escalation 4.04% $62,054
PROJECT TOTAL $2,579,437
EXHIBIT K30 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $130,614
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $874,511
Escalation 4.04% $15,239
PROJECT TOTAL $889,750
EXHIBIT K31 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Gladeville Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $0
133 RIGHT OF WAY DAMAGES $0
134 SURVEYS $5,000
135 MATERIALS $40,020
136 LABOR $249,040
137 ENGINEERING & INSPECTION $258,068
144 OVERHEAD $99,430
145 AFUDC $44,483
146 CONTINGENCY $121,921
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $817,962
Escalation 4.04% $28,719
PROJECT TOTAL $846,681
EXHIBIT K32 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $53,691
146 CONTINGENCY $147,162
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $987,299
Escalation 4.04% $34,665
PROJECT TOTAL $1,021,964
EXHIBIT K33 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $693,071
146 CONTINGENCY $1,899,654
147 LEGAL FEES $0
148 OTHER SERVICES $412,579
SUBTOTAL $12,744,616
Escalation 4.04% $447,471
PROJECT TOTAL $13,192,087
EXHIBIT K34 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $82,321
146 CONTINGENCY $225,638
147 LEGAL FEES $0
148 OTHER SERVICES $215,165
SUBTOTAL $1,513,781
Escalation 4.04% $53,150
PROJECT TOTAL $1,566,931
EXHIBIT K35 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Owingsville Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $0
133 RIGHT OF WAY DAMAGES $0
134 SURVEYS $5,000
135 MATERIALS $40,020
136 LABOR $249,040
137 ENGINEERING & INSPECTION $258,068
144 OVERHEAD $99,430
145 AFUDC $44,483
146 CONTINGENCY $121,921
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $817,962
Escalation 4.04% $28,719
PROJECT TOTAL $846,681
EXHIBIT K36 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $406,132
144 OVERHEAD $75,777
145 AFUDC $44,249
146 CONTINGENCY $123,638
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $827,810
Escalation 4.04% $14,426
PROJECT TOTAL $842,236
EXHIBIT K37 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Summerfield Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $0
133 RIGHT OF WAY DAMAGES $0
134 SURVEYS $81,531
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
SUBTOTAL $2,832,685
Escalation 4.04% $49,363
PROJECT TOTAL $2,882,048
EXHIBIT K38 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: Tomkinsville Compressor Sta. Upgrade
ITEM DESCRIPTION COMPRESSION
132 RIGHT OF WAY $0
133 RIGHT OF WAY DAMAGES $0
134 SURVEYS $5,000
135 MATERIALS $40,020
136 LABOR $249,040
137 ENGINEERING & INSPECTION $258,068
144 OVERHEAD $99,430
145 AFUDC $44,483
146 CONTINGENCY $121,921
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $817,962
Escalation 4.04% $28,719
PROJECT TOTAL $846,681
EXHIBIT K39 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $70,824
144 OVERHEAD $217,844
145 AFUDC $78,445
146 CONTINGENCY $169,591
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $1,442,493
Escalation 4.04% $50,646
PROJECT TOTAL $1,493,139
EXHIBIT K40 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $39,770
144 OVERHEAD $141,756
145 AFUDC $50,398
146 CONTINGENCY $108,953
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $926,735
Escalation 4.04% $32,538
PROJECT TOTAL $959,273
EXHIBIT K41 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $2,095,780
Escalation 4.04% $73,584
PROJECT TOTAL $2,169,364
EXHIBIT K42 OF 42
COST OF FACILITIES
NAME: TEXAS EASTERN TRANSMISSION LPDOCKET NO.:PROJECT: TEAM 2014PROJECT YEAR: 2014FACILITY: 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 $35,412
144 OVERHEAD $108,922
145 AFUDC $39,222
146 CONTINGENCY $84,795
147 LEGAL FEES $0
148 OTHER SERVICES $0
SUBTOTAL $721,245
Escalation 4.04% $25,323
PROJECT TOTAL $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 PSchedule 2
Texas Eastern Transmission, LPTEAM 2014 ProjectCost of Service and Rate Design
(1) (2) (3) (4)Line No. 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 Rate Derivation:9 Capacity (Dth/d) 600,000
10 Design Determinant 7,200,00011 Reservation Charge $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 PSchedule 3
Texas Eastern Transmission, LPTEAM 2014 ProjectOperation and Maintenance Expenses
(1) (2) (3) (4)Line No. Account Title 2014 2015 2016
1 Operation:2 850 Supervision & Engr. -Labor $37,794 $39,684 $41,6683 850 Supervision & Engr. -M&O $75,588 $79,367 $83,3364 851 Sys.Control & Load Dis. -Labor $2,537 $2,664 $2,7975 851 Sys.Control & Load Dis. -M&O $5,075 $5,328 $5,5956 852 Communication Systems -Labor $9,192 $9,651 $10,1347 852 Communication Systems -M&O $18,383 $19,303 $20,2688 853 Compressor Stations -Labor $58,419 $61,340 $64,4079 853 Compressor Stations -M&O $116,839 $122,681 $128,815
10 855 Electric Power $3,043,108 $3,195,263 $3,355,02711 856 Mains -Labor $8,838 $9,280 $9,74412 856 Mains -M&O $17,675 $18,559 $19,48713 857 M & R Station Expense -Labor $0 $0 $014 857 M & R Station Expense -M&O $0 $0 $015 858 Transportation by Others $0 $0 $016 860 Rents -M & O $1,977 $2,076 $2,18017 Total Operation $3,395,425 $3,565,196 $3,743,45618 Maintenance:19 861 Supervision & Engr. -Labor $9,852 $10,345 $10,86220 861 Supervision & Engr. -M&O $19,705 $20,690 $21,72521 862 Structures & Improvements -Labor $3,501 $3,676 $3,86022 862 Structures & Improvements -M&O $7,003 $7,353 $7,72123 863 Mains -Labor $4,193 $4,402 $4,62224 863 Mains -M&O $8,385 $8,805 $9,24525 864 Compressor Stations -Labor $50,125 $52,631 $55,26326 864 Compressor Stations -M&O $100,250 $105,262 $110,52527 865 M & R Stations -Labor $0 $0 $028 865 M & R Stations -M&O $0 $0 $029 866 Communication Systems -Labor $774 $813 $85330 866 Communication Systems -M&O $1,548 $1,625 $1,70731 867 Other Equipment -Labor $716 $751 $78932 867 Other Equipment -M&O $1,431 $1,503 $1,57833 Total Maintenance $207,483 $217,857 $228,75034 Total Direct O&M $3,602,908 $3,783,053 $3,972,206
35 Administrative and General:36 Property Insurance @ 0.20% $1,039,473 $1,091,447 $1,146,01937 Pensions & Benefits @ 23.05% $42,855 $44,998 $47,24838 Total Administrative and General $1,082,328 $1,136,444 $1,193,267
39 Total Operation & Maintenance Expenses $4,685,236 $4,919,497 $5,165,472
Docket No. CP13-___Exhibit PSchedule 4
Texas Eastern Transmission, LPTEAM 2014 ProjectDepreciation Expense and Other Taxes
(1) (2) (3) (4)Line No. Description 2014 2015 2016
1 Depreciation Expense:2 Depreciable Plant $519,736,638 $519,736,638 $519,736,6383 Depreciation Rate 1.22% 1.22% 1.22%4 Depreciation Exp. $6,340,787 $6,340,787 $6,340,787
5 Taxes Other than Income:
6 Gross Plant:7 Pennslyvania $467,005,945 $467,005,945 $467,005,9458 Ohio $18,453,587 $18,453,587 $18,453,5879 Kentucky $7,530,242 $7,530,242 $7,530,242
10 Tennessee $5,477,524 $5,477,524 $5,477,52411 Alabama $2,066,658 $2,066,658 $2,066,65812 Mississippi $19,202,682 $19,202,682 $19,202,68213 Total Gross Plant $519,736,638 $519,736,638 $519,736,638
14 Ad Valorem Taxes:15 Pennslyvania 0.0000% $0 $0 $016 Ohio 4.8919% $902,731 $911,758 $920,87617 Kentucky 0.8518% $64,145 $64,786 $65,43418 Tennessee 1.4955% $81,914 $82,733 $83,56019 Alabama 0.8234% $17,017 $17,187 $17,35920 Mississippi 3.0660% $588,762 $594,649 $600,59621 Total Ad Valorem Taxes $1,654,568 $976,545 $986,310
22 Franchise Taxes:23 Pennslyvania 0.0163% $75,975 $76,735 $77,50224 Ohio 0.0000% $0 $0 $025 Kentucky 0.0000% $0 $0 $026 Tennessee 0.0986% $5,403 $5,457 $5,51227 Alabama 0.0000% $0 $0 $028 Mississippi 0.0844% $16,207 $16,369 $16,53329 Total Franchise Taxes $97,585 $76,735 $77,502
30 Payroll Taxes:31 Labor Cost $185,941 $195,238 $205,00032 Payroll Taxes 8.3690% $15,561 $16,339 $17,156
33 Total Taxes Other than Income34 (Lines 21, 29 & 32) $1,767,715 $1,069,619 $1,080,969
Docket No. CP13-___Exhibit PSchedule 5
Texas Eastern Transmission, LPTEAM 2014 ProjectRate Base and Return
(1) (2) (3) (4)Line No. Description 2014 2015 2016
1 Rate Base:2 Gas Plant in Service $519,736,638 $519,736,638 $519,736,6383 Accumulated Depreciation ($3,170,394) ($9,511,181) ($15,851,968)4 Net Plant $516,566,244 $510,225,457 $503,884,670
5 Working Capital: Materials & Supplies @ 0.5640% $2,931,315 $3,077,880 $3,231,774
6 Accum. Deferred Income Taxes ($3,603,689) ($15,101,172) ($29,983,073)7 Total Rate Base $515,893,870 $498,202,165 $477,133,372
8 Return @ 12.130% $62,577,926 $60,431,923 $57,876,278
Docket No. CP13-___Exhibit PSchedule 6
Texas Eastern Transmission, LPTEAM 2014 ProjectFederal and State Income Taxes
(1) (2) (3) (4)Line No. Description 2014 2015 2016
1 Return $62,577,926 $60,431,923 $57,876,278
2 Adjustments:3 Interest and Debt Expense ($24,169,628) ($23,340,771) ($22,353,698)4 Amortization of Equity AFUDC $262,421 $262,421 $262,4215 Total Adjustments ($23,907,207) ($23,078,350) ($22,091,277)
6 Net Taxable Income $38,670,719 $37,353,573 $35,785,001
7 Federal Income Tax @ 35.00% $20,822,695 $20,113,462 $19,268,847
8 Pre-FIT (Lines 6 and 7) $59,493,414 $57,467,035 $55,053,848
9 State Income Tax @ 5.03% $3,150,223 $3,042,925 $2,915,145
Docket No. CP13-___Exhibit PSchedule 7
Texas Eastern Transmission, LPTEAM 2014 ProjectRate of Return
(1) (2) (3) (4)Line Capitalization Component Return No. Description Ratios Cost Component
1 Long-Term Debt 41.35% 11.33% 4.685%
2 Preferred 0.49% 5.60% 0.027%
3 Equity 58.16% 12.75% 7.415%
4 Total 100.00% 12.130%
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 1 of 20
Issued on: Effective on:
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: FT-1 RESERVATION FT-1 RESERVATION CHARGE* CHARGE ADJUSTMENT $/dth $/dth ______________________________ ______________________________ ACCESS AREA MAXIMUM MINIMUM MAXIMUM MINIMUM STX-AAB 6.5800 0.0000 0.2163 0.0000 WLA-AAB 2.6010 0.0000 0.0855 0.0000 ELA-AAB 2.1510 0.0000 0.0707 0.0000 ETX-AAB 1.9650 0.0000 0.0646 0.0000 STX-STX 5.5110 0.0000 0.1812 0.0000 STX-WLA 5.6700 0.0000 0.1864 0.0000 STX-ELA 6.5880 0.0000 0.2166 0.0000 STX-ETX 6.5870 0.0000 0.2166 0.0000 WLA-WLA 1.8340 0.0000 0.0602 0.0000 WLA-ELA 2.6070 0.0000 0.0857 0.0000 WLA-ETX 2.6080 0.0000 0.0857 0.0000 ELA-ELA 2.1550 0.0000 0.0709 0.0000 ETX-ETX 1.9690 0.0000 0.0647 0.0000 ETX-ELA 2.1560 0.0000 0.0709 0.0000 MARKET AREA MAXIMUM MINIMUM MAXIMUM MINIMUM M1-M1 4.1720 0.0000 0.1372 0.0000 M1-M2 7.7510 0.0000 0.2548 0.0000 M1-M3 10.1930 0.0000 0.3351 0.0000 M2-M2 6.0120 0.0000 0.1977 0.0000 M2-M3 8.5930 0.0000 0.2825 0.0000 M3-M3 4.8760 0.0000 0.1603 0.0000 * Reservation Charge reflects a storage surcharge of: 0.0970
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 2 of 20
Issued on: Effective on:
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1 FT-1 USAGE ZONE RATE CHARGES $/dth Pursuant to Sections 3.2 and 3.3 of Rate Schedule FT-1: STX WLA ELA ETX M1 M2 M3 USAGE-1 - MAXIMUM from STX 0.0103 0.0112 0.0170 0.0169 0.0341 0.0563 0.0717 from WLA 0.0112 0.0073 0.0123 0.0124 0.0295 0.0517 0.0671 from ELA 0.0170 0.0123 0.0111 0.0112 0.0283 0.0505 0.0659 from ETX 0.0169 0.0124 0.0112 0.0111 0.0283 0.0505 0.0659 from M1 0.0341 0.0295 0.0283 0.0283 0.0172 0.0394 0.0548 from M2 0.0563 0.0517 0.0505 0.0505 0.0394 0.0286 0.0440 from M3 0.0717 0.0671 0.0659 0.0659 0.0548 0.0440 0.0216 USAGE-1 - MINIMUM from STX 0.0061 0.0070 0.0127 0.0126 0.0256 0.0478 0.0632 from WLA 0.0070 0.0031 0.0080 0.0081 0.0210 0.0432 0.0586 from ELA 0.0127 0.0080 0.0068 0.0069 0.0198 0.0420 0.0574 from ETX 0.0126 0.0081 0.0069 0.0068 0.0198 0.0420 0.0574 from M1 0.0256 0.0210 0.0198 0.0198 0.0130 0.0352 0.0506 from M2 0.0478 0.0432 0.0420 0.0420 0.0352 0.0244 0.0398 from M3 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 0.0073 from ELA 0.0170 0.0123 0.0111 from ETX 0.0169 0.0124 0.0112 0.0111 from M1 0.0310 0.0264 0.0252 0.0252 0.0141 from M2 0.0513 0.0467 0.0455 0.0455 0.0344 0.0245 from M3 0.0653 0.0607 0.0595 0.0595 0.0484 0.0385 0.0181 USAGE-1 - BACKHAUL MINIMUM from STX 0.0061 from WLA 0.0070 0.0031 from ELA 0.0127 0.0080 0.0068 from ETX 0.0126 0.0081 0.0069 0.0068 from M1 0.0225 0.0179 0.0167 0.0167 0.0099 from M2 0.0428 0.0382 0.0370 0.0370 0.0302 0.0203 from M3 0.0568 0.0522 0.0510 0.0510 0.0442 0.0343 0.0139 USAGE-2 0.1148 0.1148 0.1148 0.1148 0.2692 0.4090 0.5047 ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 3 of 20
Issued on: Effective on:
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 ______________________________ ______________________________ NON- NON- ACCESS 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 1.7340 2.4380 4.1720 0.0570 0.0802 0.1372 M1-M2 5.3100 2.4410 7.7510 0.1746 0.0802 0.2548 M1-M3 7.7500 2.4430 10.1930 0.2548 0.0803 0.3351 M2-M2 3.5740 2.4380 6.0120 0.1175 0.0802 0.1977 M2-M3 6.1530 2.4400 8.5930 0.2023 0.0802 0.2825 M3-M3 2.4400 2.4360 4.8760 0.0802 0.0801 0.1603 *Rates are exclusive of surcharges which can also be recovered.
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 4 of 20
Issued on: Effective on:
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* STX WLA ELA ETX M1 M2 M3 MILEAGE from STX 0.0061 0.0070 0.0127 0.0126 0.0256 0.0478 0.0632 from WLA 0.0070 0.0036 0.0080 0.0081 0.0210 0.0432 0.0586 from ELA 0.0127 0.0080 0.0068 0.0069 0.0198 0.0420 0.0574 from ETX 0.0126 0.0081 0.0069 0.0068 0.0198 0.0420 0.0574 from M1 0.0256 0.0210 0.0198 0.0198 0.0130 0.0352 0.0506 from M2 0.0478 0.0432 0.0420 0.0420 0.0352 0.0244 0.0398 from M3 0.0632 0.0586 0.0574 0.0574 0.0506 0.0398 0.0174 NON-MILEAGE from STX 0.0042 0.0042 0.0043 0.0043 0.0085 0.0085 0.0085 from WLA 0.0042 0.0037 0.0043 0.0043 0.0085 0.0085 0.0085 from ELA 0.0043 0.0043 0.0043 0.0043 0.0085 0.0085 0.0085 from ETX 0.0043 0.0043 0.0043 0.0043 0.0085 0.0085 0.0085 from M1 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 0.0042 from M2 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 0.0042 from M3 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 0.0042 TOTAL from STX 0.0103 0.0112 0.0170 0.0169 0.0341 0.0563 0.0717 from WLA 0.0112 0.0073 0.0123 0.0124 0.0295 0.0517 0.0671 from ELA 0.0170 0.0123 0.0111 0.0112 0.0283 0.0505 0.0659 from ETX 0.0169 0.0124 0.0112 0.0111 0.0283 0.0505 0.0659 from M1 0.0341 0.0295 0.0283 0.0283 0.0172 0.0394 0.0548 from M2 0.0563 0.0517 0.0505 0.0505 0.0394 0.0286 0.0440 from M3 0.0717 0.0671 0.0659 0.0659 0.0548 0.0440 0.0216 USAGE-1 BACKHAUL RATE* STX WLA ELA ETX M1 M2 M3 MILEAGE from STX 0.0061 from WLA 0.0070 0.0031 from ELA 0.0127 0.0080 0.0068 from ETX 0.0126 0.0081 0.0069 0.0068 from M1 0.0225 0.0179 0.0167 0.0167 0.0099 from M2 0.0428 0.0382 0.0370 0.0370 0.0302 0.0203 from M3 0.0568 0.0522 0.0510 0.0510 0.0442 0.0343 0.0139 NON-MILEAGE from STX 0.0042 from WLA 0.0042 0.0042 from ELA 0.0043 0.0043 0.0043 from ETX 0.0043 0.0043 0.0043 0.0043 from M1 0.0085 0.0085 0.0085 0.0085 0.0042 from M2 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 from M3 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 0.0042 TOTAL from STX 0.0103 from WLA 0.0112 0.0073 from ELA 0.0170 0.0123 0.0111 from ETX 0.0169 0.0124 0.0112 0.0111 from M1 0.0310 0.0264 0.0252 0.0252 0.0141 from M2 0.0513 0.0467 0.0455 0.0455 0.0344 0.0245 from M3 0.0653 0.0607 0.0595 0.0595 0.0484 0.0385 0.0181 *Rates are exclusive of surcharges which can also be recovered.
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 5 of 20
Issued on: Effective on:
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 INCREMENTAL FACILITY CHARGE $/dth PURSUANT TO SECTION 3.4 OF RATE SCHEDULE FT-1: Maximum Minimum To applicable customers converting from Rate Schedule FTS in Docket No. CP82-446: RESERVATION CHARGE 0.6600 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0217 0.0000 Customer dth Bay State Gas Company 4,235 Boston Gas Company d/b/a National Grid 21,394 Colonial Gas Company d/b/a National Grid 1,951 Connecticut Natural Gas Corporation 6,340 Town of Middleborough, Massachusetts 116 New Jersey Natural Gas Company 1,060 Northern Utilities, Inc. 965 Southern Connecticut Gas Company 4,922 Yankee Gas Services Company 6,066 To applicable customers converting from Rate Schedule FTS-4 in Docket No. CP87-4: RESERVATION CHARGE 3.0110 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0990 0.0000 Customer dth Brooklyn Union Gas Company d/b/a National Grid 27,500 KeySpan Gas East Corporation d/b/a National Grid 22,500 New Jersey Natural Gas Company 40,000 Pivotal Utility Holdings, Inc. 10,000 Public Service Electric & Gas Company 40,000 To applicable customers converting from Rate Schedule FTS-5 in Docket No. CP87-312:RESERVATION CHARGE 0.0000 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0000 0.0000 Customer dth Colonial Gas Company d/b/a National Grid 2,326 UGI Central Penn Gas, Inc. 4,000 Yankee Gas Services Company 125 To applicable customers converting from Rate Schedule FTS-7 in Docket No. CP80-170:RESERVATION CHARGE 0.0000 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0000 0.0000 Customer dth Connecticut Natural Gas Corporation 4,231 Yankee Gas Services Company 3,015 To applicable customers converting from Rate Schedule FTS-8 in Docket No. CP85-803:RESERVATION CHARGE 0.0000 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0000 0.0000 Customer dth Yankee Gas Services Company 39
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 6 of 20
Issued on: Effective on:
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 dth ______________________________________ _______ Liberty Electric Power, LLC 84,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 4.4610 0.1180 USAGE-2 CHARGE 0.1467 RESERVATION CHARGE ADJUSTMENT 0.1467 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.1467 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. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 7 of 20
Issued on: Effective on:
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 Maximum Minimum Rates Pursuant to Section 3.2 of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE 10.5510 0.0000 USAGE-2 CHARGE 0.3469 RESERVATION CHARGE ADJUSTMENT 0.3469 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.3469 0.0000 BASE UNIT ELECTRIC POWER COST 0.2917 ELECTRIC POWER COST ADJUSTMENT -0.5250 ADJUSTED ELECTRIC POWER COST -0.2333 ASA SURCHARGE -1.7781 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: In-Path 3.27% Out-of-Path 5.21% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 8 of 20
Issued on: Effective on:
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 100,000 PSEG Power, LLC 50,000 Maximum Minimum Rates Pursuant to Section 3.2 of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE 19.9110 0.1110 USAGE-2 CHARGE 0.6545 RESERVATION CHARGE ADJUSTMENT 0.6545 0.0036 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.6545 0.0036 BASE UNIT ELECTRIC POWER COST 1.9722 ELECTRIC POWER COST ADJUSTMENT -2.6030 ADJUSTED ELECTRIC POWER COST -0.6308 ASA SURCHARGE -1.3586 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: In-Path 2.44% Out-of-Path 3.64% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 9 of 20
Issued on: Effective on:
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. CP92-165 (North Carolina Project): ________________________________________________________ Customer dth ______________________________________ ______ Dominion Transmission, Inc. 30,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 6.5600 0.080 USAGE-2 CHARGE 0.2156 RESERVATION CHARGE ADJUSTMENT 0.2156 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. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 10 of 20
Issued on: Effective on:
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 dth ______________________________________ ______ PECO Energy Company 29,210 UGI Utilities, Inc. 4,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 10.4390 0.000 USAGE-2 CHARGE 0.3432 RESERVATION CHARGE ADJUSTMENT 0.3432 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.3432 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. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 11 of 20
Issued on: Effective on:
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. CP95-76 and CP95-2 (Philadelphia Lateral Expansion): ____________________________________________________ Customer dth ______________________________________ ______ Grays Ferry Cogeneration Partnership 15,000 Sun Company, Inc. 15,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 1.9410 0.0000 USAGE-2 CHARGE 0.0638 RESERVATION CHARGE ADJUSTMENT 0.0638 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.0638 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. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 12 of 20
Issued on: Effective on:
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 dth ______________________________________ ______ PECO Energy Company 93,000 Paulsboro Refining Company LLC 8,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 1.5830 0.0000 USAGE-2 CHARGE 0.0520 RESERVATION CHARGE ADJUSTMENT 0.0520 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.0520 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. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 13 of 20
Issued on: Effective on:
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 dth ____________________________________ _______ PPL Energy Plus, LLC 120,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: Effective October 1 through April 30 RESERVATION CHARGE 0.6040 0.0000 USAGE-2 CHARGE 0.0199 RESERVATION CHARGE ADJUSTMENT 0.0199 0.0000 Effective May 1 through September 30 RESERVATION CHARGE 1.2690 0.0000 USAGE-2 CHARGE 0.0417 RESERVATION CHARGE ADJUSTMENT 0.0417 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: 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 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. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 14 of 20
Issued on: Effective on:
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. CP02-381 (M1 Expansion Project): Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 5.5500 0.0000 USAGE-2 CHARGE 0.1824 RESERVATION CHARGE ADJUSTMENT 0.1824 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.1824 0.0000 BASE UNIT ELECTRIC POWER COST 0.7921 ELECTRIC POWER COST ADJUSTMENT -1.6630 ADJUSTED ELECTRIC POWER COST -0.8709 APPLICABLE SHRINKAGE PERCENTAGE (LAUF) Effective Year Around: December 1 through November 30 0.40% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 15 of 20
Issued on: Effective on:
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. 25,000 PPL Energy Plus, LLC 30,000 Maximum Minimum Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $21.7860 $0.0480 USAGE-1 CHARGE $-0.0099 USAGE-2 CHARGE $0.7064 RESERVATION CHARGE ADJUSTMENT $0.7163 $0.0016 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.7163 $0.0016 BASE UNIT ELECTRIC POWER COST 1.0597 ELECTRIC POWER COST ADJUSTMENT -1.4960 ADJUSTED ELECTRIC POWER COST -0.4363 ASA USAGE SURCHARGE -0.0099 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: 1.59% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 16 of 20
Issued on: Effective on:
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 Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $18.9590 $0.0710 USAGE-1 CHARGE $-0.0001 USAGE-2 CHARGE $0.6232 RESERVATION CHARGE ADJUSTMENT $0.6233 $0.0023 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.6233 $0.0023 BASE UNIT ELECTRIC POWER COST 1.6032 ELECTRIC POWER COST ADJUSTMENT -1.0810 ADJUSTED ELECTRIC POWER COST 0.5222 ASA USAGE SURCHARGE -0.0001 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: 3.91% April 1 through November 30: 3.48% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 17 of 20
Issued on: Effective on:
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 Maximum Minimum Rates Pursuant to Section 3.2(E&F) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $3.1240 $0.0000 USAGE-2 CHARGE $0.1027 RESERVATION CHARGE ADJUSTMENT $0.1027 $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. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 18 of 20
Issued on: Effective on:
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 dth ______________________________ ______ Range Resources-Appalachia, LLC 150,000 Chesapeake Utilities Corporation 50,000 Maximum Minimum Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $17.4990 $0.0270 USAGE-1 CHARGE $0.0000 USAGE-2 CHARGE $0.5753 RESERVATION CHARGE ADJUSTMENT $0.5753 $0.0010 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.5753 $0.0010 BASE UNIT ELECTRIC POWER COST 1.3677 ELECTRIC POWER COST ADJUSTMENT 0.0000 ADJUSTED ELECTRIC POWER COST 1.3677 ASA USAGE SURCHARGE 0.0000 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: 1.93% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 19 of 20
Issued on: Effective on:
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 dth ______________________________ ______ Grays Ferry Cogeneration Partnership 20,000 Paulsboro Refining Company LLC 7,000 Maximum Minimum Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $8.3910 $0.0000 USAGE-1 CHARGE $0.0000 USAGE-2 CHARGE $0.2759 RESERVATION CHARGE ADJUSTMENT $0.2759 $0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.2759 $0.0000 BASE UNIT ELECTRIC POWER COST 0.0467 ELECTRIC POWER COST ADJUSTMENT 0.0000 ADJUSTED ELECTRIC POWER COST 0.0467 APPLICABLE SHRINKAGE PERCENTAGE (LAUF) December 1 through November 30: 0.02% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
Texas Eastern Transmission, LP Part 4 - Statements of Rates FERC Gas Tariff 2. Rate Schedule FT-1 Eighth Revised Volume No. 1 Version 20.0.0 Page 20 of 20
Issued on: Effective on:
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. 300,000 EQT Energy, LLC 300,000
Maximum Minimum Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $13.7980 $0.0300 USAGE-1 CHARGE $0.0000 USAGE-2 CHARGE $0.4536 RESERVATION CHARGE ADJUSTMENT $0.4536 $0.0010 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.4536 $0.0010 BASE UNIT ELECTRIC POWER COST 0.4227 ELECTRIC POWER COST ADJUSTMENT 0.0000 ADJUSTED ELECTRIC POWER COST 0.4227 ASA USAGE SURCHARGE 0.0000 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: 1.67% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 1 of19 20
Issued on: Effective on:
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: FT-1 RESERVATION FT-1 RESERVATION CHARGE* CHARGE ADJUSTMENT $/dth $/dth ______________________________ ______________________________ ACCESS AREA MAXIMUM MINIMUM MAXIMUM MINIMUM STX-AAB 6.5800 0.0000 0.2163 0.0000 WLA-AAB 2.6010 0.0000 0.0855 0.0000 ELA-AAB 2.1510 0.0000 0.0707 0.0000 ETX-AAB 1.9650 0.0000 0.0646 0.0000 STX-STX 5.5110 0.0000 0.1812 0.0000 STX-WLA 5.6700 0.0000 0.1864 0.0000 STX-ELA 6.5880 0.0000 0.2166 0.0000 STX-ETX 6.5870 0.0000 0.2166 0.0000 WLA-WLA 1.8340 0.0000 0.0602 0.0000 WLA-ELA 2.6070 0.0000 0.0857 0.0000 WLA-ETX 2.6080 0.0000 0.0857 0.0000 ELA-ELA 2.1550 0.0000 0.0709 0.0000 ETX-ETX 1.9690 0.0000 0.0647 0.0000 ETX-ELA 2.1560 0.0000 0.0709 0.0000 MARKET AREA MAXIMUM MINIMUM MAXIMUM MINIMUM M1-M1 4.1720 0.0000 0.1372 0.0000 M1-M2 7.7510 0.0000 0.2548 0.0000 M1-M3 10.1930 0.0000 0.3351 0.0000 M2-M2 6.0120 0.0000 0.1977 0.0000 M2-M3 8.5930 0.0000 0.2825 0.0000 M3-M3 4.8760 0.0000 0.1603 0.0000 * Reservation Charge reflects a storage surcharge of: 0.0970
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 2 of19 20
Issued on: Effective on:
CURRENTLY EFFECTIVE SERVICE RATES APPLICABLE TO OPEN ACCESS, PART 284, RATE SCHEDULES IN FERC GAS TARIFF, EIGHTH REVISED VOLUME NO. 1 FT-1 USAGE ZONE RATE CHARGES $/dth Pursuant to Sections 3.2 and 3.3 of Rate Schedule FT-1: STX WLA ELA ETX M1 M2 M3 USAGE-1 - MAXIMUM from STX 0.0103 0.0112 0.0170 0.0169 0.0341 0.0563 0.0717 from WLA 0.0112 0.0073 0.0123 0.0124 0.0295 0.0517 0.0671 from ELA 0.0170 0.0123 0.0111 0.0112 0.0283 0.0505 0.0659 from ETX 0.0169 0.0124 0.0112 0.0111 0.0283 0.0505 0.0659 from M1 0.0341 0.0295 0.0283 0.0283 0.0172 0.0394 0.0548 from M2 0.0563 0.0517 0.0505 0.0505 0.0394 0.0286 0.0440 from M3 0.0717 0.0671 0.0659 0.0659 0.0548 0.0440 0.0216 USAGE-1 - MINIMUM from STX 0.0061 0.0070 0.0127 0.0126 0.0256 0.0478 0.0632 from WLA 0.0070 0.0031 0.0080 0.0081 0.0210 0.0432 0.0586 from ELA 0.0127 0.0080 0.0068 0.0069 0.0198 0.0420 0.0574 from ETX 0.0126 0.0081 0.0069 0.0068 0.0198 0.0420 0.0574 from M1 0.0256 0.0210 0.0198 0.0198 0.0130 0.0352 0.0506 from M2 0.0478 0.0432 0.0420 0.0420 0.0352 0.0244 0.0398 from M3 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 0.0073 from ELA 0.0170 0.0123 0.0111 from ETX 0.0169 0.0124 0.0112 0.0111 from M1 0.0310 0.0264 0.0252 0.0252 0.0141 from M2 0.0513 0.0467 0.0455 0.0455 0.0344 0.0245 from M3 0.0653 0.0607 0.0595 0.0595 0.0484 0.0385 0.0181 USAGE-1 - BACKHAUL MINIMUM from STX 0.0061 from WLA 0.0070 0.0031 from ELA 0.0127 0.0080 0.0068 from ETX 0.0126 0.0081 0.0069 0.0068 from M1 0.0225 0.0179 0.0167 0.0167 0.0099 from M2 0.0428 0.0382 0.0370 0.0370 0.0302 0.0203 from M3 0.0568 0.0522 0.0510 0.0510 0.0442 0.0343 0.0139 USAGE-2 0.1148 0.1148 0.1148 0.1148 0.2692 0.4090 0.5047 ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 3 of19 20
Issued on: Effective on:
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 ______________________________ ______________________________ NON- NON- ACCESS 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 1.7340 2.4380 4.1720 0.0570 0.0802 0.1372 M1-M2 5.3100 2.4410 7.7510 0.1746 0.0802 0.2548 M1-M3 7.7500 2.4430 10.1930 0.2548 0.0803 0.3351 M2-M2 3.5740 2.4380 6.0120 0.1175 0.0802 0.1977 M2-M3 6.1530 2.4400 8.5930 0.2023 0.0802 0.2825 M3-M3 2.4400 2.4360 4.8760 0.0802 0.0801 0.1603 *Rates are exclusive of surcharges which can also be recovered.
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 4 of19 20
Issued on: Effective on:
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* STX WLA ELA ETX M1 M2 M3 MILEAGE from STX 0.0061 0.0070 0.0127 0.0126 0.0256 0.0478 0.0632 from WLA 0.0070 0.0036 0.0080 0.0081 0.0210 0.0432 0.0586 from ELA 0.0127 0.0080 0.0068 0.0069 0.0198 0.0420 0.0574 from ETX 0.0126 0.0081 0.0069 0.0068 0.0198 0.0420 0.0574 from M1 0.0256 0.0210 0.0198 0.0198 0.0130 0.0352 0.0506 from M2 0.0478 0.0432 0.0420 0.0420 0.0352 0.0244 0.0398 from M3 0.0632 0.0586 0.0574 0.0574 0.0506 0.0398 0.0174 NON-MILEAGE from STX 0.0042 0.0042 0.0043 0.0043 0.0085 0.0085 0.0085 from WLA 0.0042 0.0037 0.0043 0.0043 0.0085 0.0085 0.0085 from ELA 0.0043 0.0043 0.0043 0.0043 0.0085 0.0085 0.0085 from ETX 0.0043 0.0043 0.0043 0.0043 0.0085 0.0085 0.0085 from M1 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 0.0042 from M2 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 0.0042 from M3 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 0.0042 TOTAL from STX 0.0103 0.0112 0.0170 0.0169 0.0341 0.0563 0.0717 from WLA 0.0112 0.0073 0.0123 0.0124 0.0295 0.0517 0.0671 from ELA 0.0170 0.0123 0.0111 0.0112 0.0283 0.0505 0.0659 from ETX 0.0169 0.0124 0.0112 0.0111 0.0283 0.0505 0.0659 from M1 0.0341 0.0295 0.0283 0.0283 0.0172 0.0394 0.0548 from M2 0.0563 0.0517 0.0505 0.0505 0.0394 0.0286 0.0440 from M3 0.0717 0.0671 0.0659 0.0659 0.0548 0.0440 0.0216 USAGE-1 BACKHAUL RATE* STX WLA ELA ETX M1 M2 M3 MILEAGE from STX 0.0061 from WLA 0.0070 0.0031 from ELA 0.0127 0.0080 0.0068 from ETX 0.0126 0.0081 0.0069 0.0068 from M1 0.0225 0.0179 0.0167 0.0167 0.0099 from M2 0.0428 0.0382 0.0370 0.0370 0.0302 0.0203 from M3 0.0568 0.0522 0.0510 0.0510 0.0442 0.0343 0.0139 NON-MILEAGE from STX 0.0042 from WLA 0.0042 0.0042 from ELA 0.0043 0.0043 0.0043 from ETX 0.0043 0.0043 0.0043 0.0043 from M1 0.0085 0.0085 0.0085 0.0085 0.0042 from M2 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 from M3 0.0085 0.0085 0.0085 0.0085 0.0042 0.0042 0.0042 TOTAL from STX 0.0103 from WLA 0.0112 0.0073 from ELA 0.0170 0.0123 0.0111 from ETX 0.0169 0.0124 0.0112 0.0111 from M1 0.0310 0.0264 0.0252 0.0252 0.0141 from M2 0.0513 0.0467 0.0455 0.0455 0.0344 0.0245 from M3 0.0653 0.0607 0.0595 0.0595 0.0484 0.0385 0.0181 *Rates are exclusive of surcharges which can also be recovered.
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 5 of19 20
Issued on: Effective on:
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 INCREMENTAL FACILITY CHARGE $/dth PURSUANT TO SECTION 3.4 OF RATE SCHEDULE FT-1: Maximum Minimum To applicable customers converting from Rate Schedule FTS in Docket No. CP82-446: RESERVATION CHARGE 0.6600 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0217 0.0000 Customer dth Bay State Gas Company 4,235 Boston Gas Company d/b/a National Grid 21,394 Colonial Gas Company d/b/a National Grid 1,951 Connecticut Natural Gas Corporation 6,340 Town of Middleborough, Massachusetts 116 New Jersey Natural Gas Company 1,060 Northern Utilities, Inc. 965 Southern Connecticut Gas Company 4,922 Yankee Gas Services Company 6,066 To applicable customers converting from Rate Schedule FTS-4 in Docket No. CP87-4: RESERVATION CHARGE 3.0110 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0990 0.0000 Customer dth Brooklyn Union Gas Company d/b/a National Grid 27,500 KeySpan Gas East Corporation d/b/a National Grid 22,500 New Jersey Natural Gas Company 40,000 Pivotal Utility Holdings, Inc. 10,000 Public Service Electric & Gas Company 40,000 To applicable customers converting from Rate Schedule FTS-5 in Docket No. CP87-312:RESERVATION CHARGE 0.0000 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0000 0.0000 Customer dth Colonial Gas Company d/b/a National Grid 2,326 UGI Central Penn Gas, Inc. 4,000 Yankee Gas Services Company 125 To applicable customers converting from Rate Schedule FTS-7 in Docket No. CP80-170:RESERVATION CHARGE 0.0000 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0000 0.0000 Customer dth Connecticut Natural Gas Corporation 4,231 Yankee Gas Services Company 3,015 To applicable customers converting from Rate Schedule FTS-8 in Docket No. CP85-803:RESERVATION CHARGE 0.0000 0.0000 RESERVATION CHARGE ADJUSTMENT 0.0000 0.0000 Customer dth Yankee Gas Services Company 39
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 6 of19 20
Issued on: Effective on:
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 dth ______________________________________ _______ Liberty Electric Power, LLC 84,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 4.4610 0.1180 USAGE-2 CHARGE 0.1467 RESERVATION CHARGE ADJUSTMENT 0.1467 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.1467 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. 0.0018
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 7 of19 20
Issued on: Effective on:
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 Maximum Minimum Rates Pursuant to Section 3.2 of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE 10.5510 0.0000 USAGE-2 CHARGE 0.3469 RESERVATION CHARGE ADJUSTMENT 0.3469 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.3469 0.0000 BASE UNIT ELECTRIC POWER COST 0.2917 ELECTRIC POWER COST ADJUSTMENT -0.5250 ADJUSTED ELECTRIC POWER COST -0.2333 ASA SURCHARGE -1.7781 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: In-Path 3.27% Out-of-Path 5.21% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 8 of19 20
Issued on: Effective on:
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 100,000 PSEG Power, LLC 50,000 Maximum Minimum Rates Pursuant to Section 3.2 of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE 19.9110 0.1110 USAGE-2 CHARGE 0.6545 RESERVATION CHARGE ADJUSTMENT 0.6545 0.0036 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.6545 0.0036 BASE UNIT ELECTRIC POWER COST 1.9722 ELECTRIC POWER COST ADJUSTMENT -2.6030 ADJUSTED ELECTRIC POWER COST -0.6308 ASA SURCHARGE -1.3586 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: In-Path 2.44% Out-of-Path 3.64% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
2. Rate Schedule FT-1 Version 19.0.0 20.0.0 Page 9 of19 20
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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. CP92-165 (North Carolina Project): ________________________________________________________ Customer dth ______________________________________ ______ Dominion Transmission, Inc. 30,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 6.5600 0.080 USAGE-2 CHARGE 0.2156 RESERVATION CHARGE ADJUSTMENT 0.2156 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. 0.0018
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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 dth ______________________________________ ______ PECO Energy Company 29,210 UGI Utilities, Inc. 4,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 10.4390 0.000 USAGE-2 CHARGE 0.3432 RESERVATION CHARGE ADJUSTMENT 0.3432 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.3432 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. 0.0018
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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. CP95-76 and CP95-2 (Philadelphia Lateral Expansion): ____________________________________________________ Customer dth ______________________________________ ______ Grays Ferry Cogeneration Partnership 15,000 Sun Company, Inc. 15,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 1.9410 0.0000 USAGE-2 CHARGE 0.0638 RESERVATION CHARGE ADJUSTMENT 0.0638 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.0638 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. 0.0018
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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 dth ______________________________________ ______ PECO Energy Company 93,000 Paulsboro Refining Company LLC 8,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 1.5830 0.0000 USAGE-2 CHARGE 0.0520 RESERVATION CHARGE ADJUSTMENT 0.0520 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.0520 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. 0.0018
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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 dth ____________________________________ _______ PPL Energy Plus, LLC 120,000 Rates Pursuant to Section 3.2 of Rate Schedule FT-1: Effective October 1 through April 30 RESERVATION CHARGE 0.6040 0.0000 USAGE-2 CHARGE 0.0199 RESERVATION CHARGE ADJUSTMENT 0.0199 0.0000 Effective May 1 through September 30 RESERVATION CHARGE 1.2690 0.0000 USAGE-2 CHARGE 0.0417 RESERVATION CHARGE ADJUSTMENT 0.0417 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: 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 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. 0.0018
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Issued on: Effective on:
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. CP02-381 (M1 Expansion Project): Rates Pursuant to Section 3.2 of Rate Schedule FT-1: RESERVATION CHARGE 5.5500 0.0000 USAGE-2 CHARGE 0.1824 RESERVATION CHARGE ADJUSTMENT 0.1824 0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE 0.1824 0.0000 BASE UNIT ELECTRIC POWER COST 0.7921 ELECTRIC POWER COST ADJUSTMENT -1.6630 ADJUSTED ELECTRIC POWER COST -0.8709 APPLICABLE SHRINKAGE PERCENTAGE (LAUF) Effective Year Around: December 1 through November 30 0.40% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
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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. 25,000 PPL Energy Plus, LLC 30,000 Maximum Minimum Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $21.7860 $0.0480 USAGE-1 CHARGE $-0.0099 USAGE-2 CHARGE $0.7064 RESERVATION CHARGE ADJUSTMENT $0.7163 $0.0016 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.7163 $0.0016 BASE UNIT ELECTRIC POWER COST 1.0597 ELECTRIC POWER COST ADJUSTMENT -1.4960 ADJUSTED ELECTRIC POWER COST -0.4363 ASA USAGE SURCHARGE -0.0099 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: 1.59% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
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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 Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $18.9590 $0.0710 USAGE-1 CHARGE $-0.0001 USAGE-2 CHARGE $0.6232 RESERVATION CHARGE ADJUSTMENT $0.6233 $0.0023 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.6233 $0.0023 BASE UNIT ELECTRIC POWER COST 1.6032 ELECTRIC POWER COST ADJUSTMENT -1.0810 ADJUSTED ELECTRIC POWER COST 0.5222 ASA USAGE SURCHARGE -0.0001 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: 3.91% April 1 through November 30: 3.48% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
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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 Maximum Minimum Rates Pursuant to Section 3.2(E&F) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $3.1240 $0.0000 USAGE-2 CHARGE $0.1027 RESERVATION CHARGE ADJUSTMENT $0.1027 $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. 0.0018
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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 dth ______________________________ ______ Range Resources-Appalachia, LLC 150,000 Chesapeake Utilities Corporation 50,000 Maximum Minimum Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $17.4990 $0.0270 USAGE-1 CHARGE $0.0000 USAGE-2 CHARGE $0.5753 RESERVATION CHARGE ADJUSTMENT $0.5753 $0.0010 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.5753 $0.0010 BASE UNIT ELECTRIC POWER COST 1.3677 ELECTRIC POWER COST ADJUSTMENT 0.0000 ADJUSTED ELECTRIC POWER COST 1.3677 ASA USAGE SURCHARGE 0.0000 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: 1.93% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
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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 dth ______________________________ ______ Grays Ferry Cogeneration Partnership 20,000 Paulsboro Refining Company LLC 7,000 Maximum Minimum Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $8.3910 $0.0000 USAGE-1 CHARGE $0.0000 USAGE-2 CHARGE $0.2759 RESERVATION CHARGE ADJUSTMENT $0.2759 $0.0000 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.2759 $0.0000 BASE UNIT ELECTRIC POWER COST 0.0467 ELECTRIC POWER COST ADJUSTMENT 0.0000 ADJUSTED ELECTRIC POWER COST 0.0467 APPLICABLE SHRINKAGE PERCENTAGE (LAUF) December 1 through November 30: 0.02% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
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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. 300,000 EQT Energy, LLC 300,000 Maximum Minimum Rates Pursuant to Section 3.2(C&D) of Rate Schedule FT-1: _______ _______ RESERVATION CHARGE $13.7980 $0.0300 USAGE-1 CHARGE $0.0000 USAGE-2 CHARGE $0.4536 RESERVATION CHARGE ADJUSTMENT $0.4536 $0.0010 Rates Pursuant to Section 3.14 of the General Terms and Conditions: VOLUMETRIC RESERVATION CHARGE $0.4536 $0.0010 BASE UNIT ELECTRIC POWER COST 0.4227 ELECTRIC POWER COST ADJUSTMENT 0.0000 ADJUSTED ELECTRIC POWER COST 0.4227 ASA USAGE SURCHARGE 0.0000 APPLICABLE SHRINKAGE PERCENTAGE December 1 through November 30: 1.67% ALL ZONES $/dth ACA COMMODITY SURCHARGE TO APPLICABLE CUSTOMERS, PURSUANT TO SECTION 15.5 OF THE GENERAL TERMS AND CONDITIONS. 0.0018
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Y
Accounting Treatment of Abandonment
TEXAS EASTERN TRANSMISSION, LPEXHIBIT Y Retire One 18,500 HP Turbine and Six 1,100 HP RecipsAt Delmont Compressor Station For TEAM 2014
ENTRY DEBIT CREDIT ACCOUNT DESCRIPTION DEBIT CREDIT
1 1088 Retirement Work in Progress 5,851,7201010 Gas Plant in Service 5,851,720
To record the retirement from Gas Plant in Service.
2 1088 Retirement Work in Progress 1,052,897 1310 Cash 1,052,897
To record Cost of Removal
3 1080 Provision for Accumulated Depreciation 6,904,6171088 Retirement Work in Progress 6,904,617
To record clearance of Retirement Work in Progress.
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.
Texas Eastern Appalachia to Market (TEAM 2014)
Moving emerging natural gas supplies from the Appalachian region to diverse market destinations along Eastern footprint from the Northeast to the Midwest, and Gulf Coast.
Binding Open Season NoticeJanuary 17, 2012 –
Moving emerging natural gas supplies from the Appalachian region to diverse market destinations along Eastern footprint from the Northeast to the Midwest, and Gulf Coast.
Binding Open Season Notice – February 17, 2012
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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. 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.
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.
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
export, Gas-to-Liquids, and other market opportunities in the Southeast and Gulf Coast.
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.
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
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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.
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.
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.
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.
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.
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
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
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in order to finalize the terms on which service will be provided.
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.
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.
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.
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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
Maximum Daily Quantity ____________________________
Eastward Firm Path (50% of MDQ)
Receipt Point(s) Quantity (Dth/d) Delivery Point(s) [1] Quantity (Dth/d)
Westward Firm Path (50% of MDQ)
Receipt Point(s) Quantity (Dth/d) Delivery Point(s) [1] 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 713-627-4727 fax Attention: Bobby Huffman RLHuffman@spectraenergy.com 5400 Westheimer Court Houston, TX 77056 [1] The sum of multiple nominated delivery point quantities may not exceed the Maximum Daily Quantity.
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 non-recallable 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 non-recallable 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 e-mailing 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
TEAM 2014 Path vs. Contract Paths Proposed for Turn Back
Texas Eastern Transmission, LP Docket No. CP13-___-000
Exhibit Z-1(c) Sheet 1 of 1
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Exhibit Z-1(d)
Diagram of Project Scope Based on Turnback Offers
TEAM 2014 Path after Including Capacity Turn Back
Texas Eastern Transmission, LP Docket No. CP13-___-000
Exhibit Z-1(d) Sheet 1 of 1
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 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 MDthVolume Determinant = 300 MDth/DFuel 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 MDthVolume Determinant = 300 MDth/DFuel 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.
INCREMENTAL FUEL AND ELECTRIC POWER COST DERIVATIONTEAM 2014 PROJECT (600 MDth/D)
Texas Eastern Transmission, LPDocket No. CP13-___-000Exhibit Z-2Sheet 2 of 4
Fuel AnnualStation Unit(s) Installed "Base" "Expansion" Difference Fuel rate Difference Electric CostUniontown Cent - Mars 100 - Unit 1T 12,250 12,250 13,300 1,050 0.000274 0.288
Cent - Mars 100 - Unit 2T 12,250 12,250 13,300 1,050 0.000274 0.288Electric - Unit 1E 14,300 13,591 13,591 0 Electric - Unit 2E 16,000 19,484 17,728 -1,756 N/A -$210,747Electric - Unit 3E 20,000 20,000 20,000 0
Delmont Recip - KVG (6 x 1100 HP each) 6,600 6,600 0 -6,600 0.000249 -1.643Recip - KVS (4 x 2000 HP each) 8,000 8,000 0 -8,000 0.000249 -1.992Cent - Mars 100 13,300 13,300 13,300 0 Cent - Frame 5 18,500 19,975 0 -19,975 0.000274 -5.473Cent - Titan 250 - TEAM 2014 26,000 0 26,000 26,000 0.000229 5.954Electric - TEAM 2014 26,000 0 26,000 26,000 N/A $3,120,000
Armagh Cent - Frame 5 22,000 23,250 22,000 -1,250 0.000274 -0.343Cent - Titan 130 - TEAM 2014 18,100 0 18,008 18,008 0.000229 4.124
Lilly Cent - W52 5,000 5,300 5,000 -300 0.000274 -0.082Cent - W52 5,000 5,300 5,000 -300 0.000274 -0.082Cent - DC990 5,000 5,300 5,000 -300 0.000274 -0.082Cent - Frame 5 19,800 21,000 19,800 -1,200 0.000274 -0.329
Entriken Cent - Frame 5 22,000 23,250 22,000 -1,250 0.000274 -0.343Cent - Titan 250 - TEAM 2014 26,000 0 22,489 22,489 0.000229 5.150
Perulack Cent - DC990 5,000 5,400 5,400 0Cent - DC990 5,000 5,400 5,400 0Cent - DC990 5,000 5,400 5,400 0Cent - Frame 5 19,800 19,800 19,480 -320 0.000274 -0.088
Shermans Dale Cent - Frame 5 19,800 19,800 18,960 -840 0.000274 -0.230Cent - Frame 5 22,000 22,000 22,000 0
Grantville Cent - W52 5,000 5,000 5,000 0Cent - W52 5,000 5,000 5,000 0Cent - DC990 5,000 5,000 5,000 0Cent - Frame 5 18,500 18,500 19,123 623 0.000274 0.171
Bernville Cent - Frame 5 19,800 19,800 19,800 0Cent - Frame 5 22,000 22,000 22,000 0
Bechtelsville Cent - W52 5,000 5,000 5,000 0Cent - W52 5,000 5,000 5,000 0Cent - DC990 5,000 5,000 5,000 0Cent - Frame 5 18,500 18,500 18,500 0
Lambertville Recip (2 x 2200 HP) 4,400 3,419 3,633 214 0.000249 0.053Cent - DC 990 5,100 5,175 5,100 -75 0.000274 -0.021Cent - DC 990 5,100 5,175 5,100 -75 0.000274 -0.021Electric Unit 10,000 10,000 9,124 -876 N/A -$105,120
Total Incremental Fuel (MDth/D) 5.299Total Annual Electric Cost $2,804,133
Incremental Fuel (MDth/D) 5.299
TEAM Forward Flow Fuel % (5.299/(5.299+300)) 1.74%TEAM Forward Flow LAUF (M2-M3) 0.66%Total TEAM Forward Flow Shrinkage 2.40%
INCREMENTAL FUEL AND ELECTRIC POWER COST DERIVATIONTEAM 2014 PROJECT FORWARD HAUL (300 MDth/D)
Horsepower Utilized
Texas Eastern Transmission, LPDocket No. CP13-___-000Exhibit Z-2Sheet 3 of 4
Fuel AnnualStation Unit(s) Installed "Base" "Expansion" Difference Fuel rate Difference Electric CostHolbrook Recip - GMV-10-S (4 x 1350 hp each) 5,400 0 0 0 0.000249 0.000
Recip - GMVA-10 (4 x 1350 hp each) 5,400 0 0 0 0.000249 0.000Recip - KVS412 (4 x 2000 hp each) 8,000 0 0 0 0.000249 0.000Gas Turbine 1T 13,333 0 0 0 0.000274 0.000Gas Turbine 2T 13,333 0 0 0 0.000274 0.000Gas Turbine 3T 13,333 0 0 0 0.000265 0.000
Berne Electric Motors (6 x 2500 hp each) 15,000 0 0 0 N/A 0.000Electric Motor (1 x 15,000 hp) 15,000 0 0 0 N/A 0.000DC 990 5,100 0 0 0 0.000274 0.000
Summerfield Electric Motors (4 x 2000 hp each) 8,000 0 0 0 N/A 0.000Electric Motors (1 x 11000 hp each) 11,000 0 0 0 N/A 0.000
Somerset Recip - GMV-10 (7 x 1100 hp each) 7,700 0 0 0 0.000249 0.000Solar Mars Gas Turbine 10,600 0 0 0 0.000274 0.000
Five Points Electric Motors (3 x 2000 hp each) 6,000 0 0 0 N/A 0.000Solar Mars Gas Turbine 10,600 0 0 0 0.000274 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) 15,000 0 4,142 4,142 N/A 0.000 103,550Electric Motor (1 x 15,000 hp) 15,000 0 0 0 N/A 0.000
Owingsville GE Frame 3 Gas Turbines (4 x 8000 hp each) 32,000 0 0 0 0.000274 0.000GE Frame 5 Gas Turbine 18,500 0 0 0 0.000274 0.000
Danville Recip - HBA-8 (7 x 1760 hp each) 12,320 0 0 0 0.000249 0.000Recip - HBA-8 T(3 x 2050 hp each) 6,150 0 0 0 0.000249 0.000GE Frame 3 Gas Turbines (2 x 8000 hp each) 16,000 0 0 0 0.000274 0.000GE Frame 5 Gas Turbine 18,500 0 0 0 0.000274 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) 15,000 0 0 0 N/A 0.000Electric Motor (1 x 15,000 hp) 15,000 0 0 0 N/A 0.000GE Frame 5 Gas Turbine 18,500 0 0 0 0.000274 0.000
Mt. Pleasant Electric Motors (2 x 15,000 hp) 30,000 0 0 0 N/A 0.000Electric Motor (1 x 20,000 hp) 20,000 0 0 0 N/A 0.000
Barton Electric Motors (6 x 3000 hp each) 18,000 0 0 0 N/A 0.000Electric Motor (1 x 20,000 hp) 20,000 0 0 0 N/A 0.000GE Frame 5 Gas Turbine 19,800 0 0 0 0.000274 0.000
Egypt Electric Motors (2 x 20,000 hp) 40,000 0 0 0 N/A 0.000Electric Motor (1 x 15,000 hp) 15,000 0 0 0 N/A 0.000
Kosciusko Recip - GMV-10-S (14 x 2500 hp each) 35,000 0 0 0 0.000249 0.000Electric Motor 16,875 0 5,417 5,417 N/A 0.000 135,425
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) 18,450 0 0 0 0.000249 0.000Recip - TLA (4 x 3400 hp each) 13,600 0 2,357 2,357 0.000249 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 7,600 0 0 0 0.000274 0.000GE Frame 3 Gas Turbine 8,000 0 0 0 0.000274 0.000
Total Incremental Fuel (MDth/D) 0.555Total Annual Electric Cost $238,975
Incremental Fuel (MDth/D) 0.555TEAM Reverse Flow Fuel % (0.555/(0.555+300)) 0.18%TEAM Reverse Flow LAUF 0.75%Total Reverse Flow Shrinkage 0.93%
Horsepower Utilized
INCREMENTAL FUEL AND ELECTRIC POWER COST DERIVATIONTEAM 2014 PROJECT REVERSE FLOW (300 MDth/D)
Texas Eastern Transmission, LPDocket No. CP13-___-000Exhibit Z-2Sheet 4 of 4
Percentage Dollars ($)Forward Flow (300 MDth/D) Fuel 1.74% EPC $2,804,133Reverse Flow (300 MDth/D) Fuel 0.18% EPC $238,975LAUF (Lost and Unaccounted For) Forward Flow (M2 - M3) 0.66% Reverse Flow (M2 - M2/WLA/ELA) 0.75%
Total Daily Fuel including LAUF 3.33%TEAM 2014 Fuel Shrinkage (600 MDth/D) 1.67%
Total Annual Estimated EPC $3,043,108
EPC : Electric Power Cost
INCREMENTAL FUEL AND ELECTRIC POWER COST DERIVATIONTEAM 2014 PROJECT (600 MDth/D)
SUMMARY
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
Page 1 of 13
TEAM 2014 ProjectFERC Resource Report Data Requests
Response Location/Comment
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.
Resource Report 1 Table 1.3-2 and Resource Report 8 Table 8.1-5 have been updated to include the requested information.
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.
updated Section 1.5.2 - geotech info to be provided supplemental
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.
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 be looped, and confirm that landowner permission would be obtained for all permanent access roads.
Access Road Table 1.3-2 in Section 1.3.1 includes identification of permanent 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. Pipeyared and wareyard locations and descriptions can be found in Table 1.3-3, which has been added to Section 1.3.1
6. Confirm that all bi-directional facility modifications would take place entirely on Texas Eastern owned or leased property.
Section 1.3.3 - text has been updated to include information about work that will occur outside of the Texas Eastern ROW.
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 )
Section 1.4 has been revised and now also includes Table 1.4-1 Cumulative Projects.
Resource Report 1
Page 2 of 13
TEAM 2014 ProjectFERC Resource Report Data Requests
Response Location/Comment8. 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.
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.
9. Describe the process Texas Eastern would implement to resolve landowner complaints. Section 1.8 has been updated to include a summary of Texas Eastern's process for resolving landowner concerns.
10. Identify how many environmental inspectors Texas Eastern would employ to ensure environmental compliance during construction of the facilities.
Section 1.5.5 has been updated to state that There will be a minimum of one environmental inspector per construction spread.
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.
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.
1. Provide the following tables:a. Waterbody Crossing Summary Table – number and types of waterbodies crossed by loop (including project totals);
Table Added 2.2-3
b. Wetlands Crossing Summary Table – number and types of wetlands crossed by loop (including project totals);
Table Added 2.3-3
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
Edited Table 2.2-1 and 2.2-2
d. Revised table 2.3-1 – remove “county/state”, “hgm code”, “water type”, “latitude/longitude”, “USGS quad name”, “watershed”, and “class of aquatic resources”.
Edited Table 2.3-1 and 2.3-2
1. Identify in table format the fish species commonly associated with each fisheries and waterbody type.
Edited Table 3.1-1
2. Identify in table format the wildlife species commonly associated with each habitat type. 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
Resource Report 3 - Fisheries, Vegetation, and Wildlife
Resource Report 2 - Water Use and Quality
Page 3 of 13
TEAM 2014 ProjectFERC Resource Report Data Requests
Response Location/Commenta. 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;
additional text added to Section 3.3.3
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
additional text added to Section 3.3.3
c. documentation of consultation with the FWS regarding project-related impacts on migratory bird species of special concern.
additional text added to Section 3.3.3
5. Confirm that birds of conservation concern were accounted for in table 3.3-2. Table 3.3-3 was added6. Describe the feasibility of clearing natural or semi-natural habitats and performing maintenance activities between September 1 and March 31.
Section 3.3.3 provides Texas Eastern's standard schedule that maintenance activites will not occur April 15-August 1.
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.
Section 3.3.2 Migatory Birds was added
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.
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); Section 6.4.5 has been updated.b. discussion of how landslides in adjacent slope could affect the pipeline or facility; Information added to intro of Section 6.4.5c. 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;
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. Discussion added to intro of 6.4.53. In Section 6.1.2 describe or clarify the following:a. each compressor station site’s vertical relief and slope configuration; Information has been added to Section 6.1.2
Resource Report 6 – Geological Resources
Page 4 of 13
TEAM 2014 ProjectFERC Resource Report Data Requests
Response Location/Commentb. describe slope stability of immediately adjacent ascending and descending slopes from the facility;
Information has been added to Section 6.1.2
c. state if grading will be required to build the compressor modifications and how much cut and/or fill is planned for each; and
Information has been added to Section 6.1.2
d. describe if modifications to the slopes are anticipated. Information has been added to Section 6.1.24. Section 6.2 states that blasting will be required. Provide a blasting plan for the Project. 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 of the Bernville Loop. Perform detailed field mapping to investigate the presence of possible karst 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.
Karst location map added as figure 6.4-2 and discussion was added to the individual segments in 6.4.4 including past experience.
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 Yard.
Added to Section 6.4.5 under "Pipeyards and Wareyards"
8. In Section 6.4.6, identify Project sites or proposed loops that are located within a 100 year flood zone and depict boundaries of the flood zone on alignment sheets.
Added to Section 6.4.6 and the alignments
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 importance.
Information included under Section 7.3
3. Given the history of oil and gas exploration and production in the region, discuss the potential for 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.
This comment is addressed in section 7.2.6.
Resource Report 7 – Soils
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Response Location/Comment4. 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.
NRCS consultation discussed in Section 7.4
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.
Site-specific residential plans have been added to RR8.
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.
Section 8.1.5 has been updated to provide the requested information.
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).
Table 8.2-1 has been updated to include a column for workspace location.
1. Include a table identifying all existing emission sources at each compressor station. 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 type (reciprocating, turbine), horsepower, and fuel type for each unit.
Tables have been added that identify each existing compressor unit at each 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 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.
Information to be provided in a Supplemental submission.
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
Resource Report 8 – Land Use
Resource Report 9 – Air and Noise Quality
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Response Location/Comment5. Include a discussion on the applicability of New Source Performance Standard Subpart Kb for the Delmont Compressor Station related to the pressure vessels and storage tanks proposed to be installed. Also provide a discussion on the applicability of National Emission Standard for Hazardous Air Pollutants Subpart EEEE related to truck loading activities.
Discussion of NSPS and NESHAP applicability to storage tanks and truck loading at Delmont is addressed in Section 9.1.3.2.
6. Include a discussion for each compressor station of the potentially applicable NESHAPs (including subparts YYYY and ZZZZ).
Discussion of NESHAP applicability is addressed in Sections 9.1.3.1 thru 9.1.3.4.
7. Revise table 9.1-3 to include a per pollutant breakdown, for each compressor station, of the 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.
Information to be provided in a Supplemental submission.
8. Revise tables 9.1-4A and 9.1-4B to provide construction emissions for all facilities associated with the project, including those listed in Tables 1.2-3 and 1.2-4. Provide the supporting detailed emission calculations.
Information to be provided in a Supplemental submission.
9. Provide an air modeling screening analysis (AERSCREEN) for operating emissions for existing and 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.
Information to be provided in a Supplemental submission.
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Response Location/Comment10. General Conformity applies to all portions of the project located within designated non-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 9.1-5 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.
Information to be provided in a Supplemental submission.
11. Update Section 9.1.5.2 (Cumulative Impacts) to address other projects or facilities besides the 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.
Information to be provided in a Supplemental submission.
12. For each compressor station, Resource Report 9 identifies potential noise control mitigation which match those identified in the Hoover and Keith, Inc reports. Clarify whether Texas Eastern commits to implementing these noise control mitigation measures. Also identify whether the projected noise levels for the compressor station assumes these measures are implemented.
A statement has been added to each noise control mitigation section in report confirming mitigation measures will be 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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Response Location/Comment14. 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.
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.
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).
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.
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.
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 a table of each existing compressor unit, the manufacturer, unit type and model, fuel source, horsepower (using the same rating methodology for all units), and in-service dates.
Information is included in Appendix L. Section 3.0 of H&K Report No. 2710 for Entriken (dated Jan. 7, 2013) & Section 3.0 of H&K Report No. 2713 for 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 that there would also be an added “maintenance” type of gas blowdown vent associated with the compressor units. Provide a noise analysis associated with this maintenance blowdown identifying the projected noise level at the nearest NSAs for each compressor station and identify whether the blowdowns would be piped to a silencer.
Information is included in Appendix L. Respective H&K reports for Delmont, Armagh and Entriken includes noise analysis of the maintenance gas blowdown event and whether blowdown venting will include a silencer.
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Response Location/Comment19. Provide a noise analysis, including all supporting detailed calculations, for all NSAs within one-half mile of each HDD entry and exit site. This analysis should include:
Appendix L and new section 9.2.4.6 added to RR9. Currently, there will be 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 occur;
Distance/direction of identified closest NSAs included in Section 2.0 of the 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
c. background noise levels and estimated drilling noise contributions at the NSAs; Information is included in Appendix L (Section 5.0 the respective H&K report)
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
Statement added to each noise control mitigation section in report confirming mitigation measures will be implemented.
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.
Information to be provided in a Supplemental submission.
4. Provide detailed flow diagrams and hydraulic flow models to support Texas Eastern’s TEAM 2014 Project as currently contemplated.
Attachment B of Texas Eastern's February 6, 2013 Response Resource Report 10 – Alternatives
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Response Location/Comment5. Discuss the system operational reasons for Texas Eastern rejecting the following alternatives:
a. expanding the Capacity Restoration Project (CRP) system. Also, compare and contrast the future expandability of the Penn-Jersey system versus the CRP system; andb. 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.
Attachments C and D of Texas Eastern's February 6, 2013 Response
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.”
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.
Attachments C and D of Texas Eastern's February 6, 2013 Response
7. Identify and describe system alternatives that incorporate GSC’s inclusion of various levels of turnback capacity from ConocoPhillips. These alternatives should address:
a. expanding the CRP system; andb. 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.
Attachments C and D of Texas Eastern's February 6, 2013 Response
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Response Location/Comment8. Provide the information below for each system alternative identified in Question 5: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; andi. 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.
Attachments C and D of Texas Eastern's February 6, 2013 Response
9. Specifically describe the potential scheduling, permitting and costs impacts associated with the 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.
Attachments C and D of Texas Eastern's February 6, 2013 Response
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”;
Section 10.2.1 of Resource Report 10
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 10.2.9 of Resource Report 10
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Response Location/Comment10. 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.”
Section 10.2.10 of Resource Report 10
11. Provide tables that compare the following:
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; andThe table should address items a – i identified in Question 8 of this request.
Table 10.2-1 of Resource Report 10
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.
Table 10.2-2 of Resource Report 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:
a. the Perulack East Discharge Pipeline;
Section 10.2.3 of Resource Report 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:
b. the Shermans Dale Discharge Pipeline;
Section 10.2.4 of Resource Report 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:
c. the Grantville East Discharge Pipeline; and
Section 10.2.4 of Resource Report 10
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Response Location/Comment12. 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:
d. the Bernville Discharge Pipeline.
Section 10.2.7 of Resource Report 10
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.
Section 10.3.2 of Resource Report 10
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.
Section 10.2.1 of Resource Report 10
Resource Report 11 – Reliability and Safety1. Identify the US Department of Transportation Class locations and High Consequence Areas by milepost along the pipeline loops.
shown on alignments / referenced in RR11
TEXAS EASTERN TRANSMISSION, LP
TEAM 2014 PROJECT
DOCKET NO. CP13-___-000
Notice
UNITED STATES OF AMERICAFEDERAL ENERGY REGULATORY COMMISSION
Texas Eastern Transmission, LP ) Docket No. CP13-___-000
ABBREVIATED APPLICATION OFTEXAS EASTERN TRANSMISSION, LP
FOR A CERTIFICATE OF PUBLIC CONVENIENCE AND NECESSITYAND FOR RELATED AUTHORIZATIONS AND
ORDER APPROVING ABANDONMENT
( )
Take notice that on February 27, 2013, Texas Eastern Transmission, LP (“TexasEastern”), 5400 Westheimer Court, Houston, Texas 77056, filed with the Federal EnergyRegulatory Commission an application under Sections 7(b) and 7(c) of the Natural GasAct (“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, andmaintain certain pipeline and compression facilities and related appurtenances and toabandon in place certain compression facilities necessary to increase capacity on theTexas Eastern system by 600,000 dekatherms per day from supply points in theMarcellus Shale region to delivery points in New York, New Jersey, Ohio, Mississippiand Louisiana; (ii) authority to charge initial incremental recourse rates for firm serviceon the TEAM 2014 Project facilities and existing system rates for interruptible service onsuch facilities; and (iii) any waivers, authority, and further relief as may be necessary toimplement the proposal contained in its application.
Texas Eastern requests that the Commission grant the requested authorizationsand related approvals on or before November 21, 2013. Texas Eastern states that issuingan order by this date will help to ensure that the TEAM 2014 Project is in service byNovember 1, 2014, in time to meet the transportation needs of the TEAM 2014 Projectshippers and to ensure that the additional capacity is available as the TEAM 2014 Projectshippers’ production comes on line.
The name, address, and telephone number of the person to whom correspondenceand communications concerning this Application should be addressed is:
2
Berk DonaldsonDirector, Rates and CertificatesTexas Eastern Transmission, LPP.O. Box 1642Houston, Texas 77251-1642Phone: (713) 627-4488Fax: (713) 627-5947
Any person desiring to intervene or to protest this filing must file in accordancewith 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 determiningthe appropriate action to be taken, but will not serve to make protestants parties to theproceeding. Any person wishing to become a party must file a notice of intervention ormotion to intervene, as appropriate. Such notices, motions, or protests must be filed onor before the comment date. Anyone filing a motion to intervene or protest must serve acopy of that document on the Applicant. On or before the comment date, it is notnecessary to serve motions to intervene or protests on persons other than the Applicant.
The Commission encourages electronic submission of protests and interventionsin lieu of paper using the “eFiling” link at http://www.ferc.gov. Persons unable to fileelectronically should submit an original and 14 copies of the protest or intervention to theFederal 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” linkand 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 receiveemail notification when a document is added to a subscribed docket(s). For assistancewith 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. BoseSecretary
US 1735967v.23
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